20-F 1 a13-10914_120f.htm 20-F

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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

FORM 20-F

o | REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR (g) |
| OF THE SECURITIES EXCHANGE ACT OF 1934 |
| or |
x | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) |
| OF THE SECURITIES EXCHANGE ACT OF 1934 |
| For the fiscal year ended December 31, 2012 |
| or |
o | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) |
| OF THE SECURITIES EXCHANGE ACT OF 1934 |
| or |
o | SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) |
| OF THE SECURITIES EXCHANGE ACT OF 1934 |
| Date of event requiring this shell company report: N/A |
| Commission file number 1-15224 |

COMPANHIA ENERGÉTICA DE MINAS GERAIS – CEMIG

(Exact name of Registrant as specified in its charter)

ENERGY CO OF MINAS GERAIS

(Translation of Registrant’s name into English)

BRAZIL

(Jurisdiction of incorporation or organization)

Avenida Barbacena, 1200, Belo Horizonte, M.G., 30190-131

(Address of principal executive offices)

Securities registered or to be registered pursuant to Section 12(b) of the Act:

Title of each class: | Name of exchange on which registered:
Preferred Shares, R$5.00 par value | New York Stock Exchange*
American Depositary Shares, each | New York Stock Exchange
representing 1 Preferred Share, without par value |
Common Shares, R$5.00 par value | New York Stock Exchange*
American Depositary Shares, each | New York Stock Exchange
representing 1 Common Share, |
without par value |

Securities registered or to be registered pursuant to Section 12(g) of the Act:

None

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act:

None

Indicate the number of outstanding shares of each of the issuer’s classes of capital or common stock as of the close of the period covered by the annual report:

372,837,085 Common Shares

480,181,143 Preferred Shares

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes x No o

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934. Yes o No x

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days. Yes x No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes o No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one): Large accelerated filer x Accelerated Filer o Non accelerated filer o

Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing: U.S. GAAP o IFRS x Other o

If “Other” has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow: Item 17 o Item 18 o

If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act) Yes o No x

* Not for trading but only in connection with the registration of American Depositary Shares, pursuant to the requirements of the Securities and Exchange Commission.

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PART I |  | 4
Item 1. | Identity of Directors, Senior Management and Advisers | 4
Item 2. | Offer Statistics and Expected Timetable | 4
Item 3. | Key Information | 4
Item 4. | Information on the Company | 19
Item 4A. | Unresolved Staff Comments | 70
Item 5. | Operating and Financial Review and Prospects | 70
Item 6. | Directors, Senior Managers and Employees | 95
Item 7. | Major Shareholders and Related Party Transactions | 106
Item 8. | Financial Information | 107
Item 9. | The Offer and Listing | 115
Item 10. | Additional Information | 119
Item 11. | Quantitative and Qualitative Disclosures about Market Risk | 133
Item 12. | Description of Securities Other than Equity Securities | 135
PART II |  | 136
Item 13. | Defaults, Dividend Arrearages and Delinquencies | 136
Item 14. | Material Modifications to the Rights of Security Holders and Use of Proceeds | 136
Item 15. | Controls and Procedures | 137
Item 16A. | Audit Committee Financial Expert | 138
Item 16B. | Code of Ethics | 138
Item 16C. | Principal Accountant Fees and Services | 138
Item 16D. | Exemptions from the Listing Standards for Audit Committees | 139
Item 16E. | Purchases of Equity Securities by the Issuer and Affiliated Purchasers | 139
Item 16F. | Change in Registrant’s Certifying Accountant | 139
Item 16G. | Corporate Governance | 139
PART III |  | 141
Item 17. | Financial Statements | 141
Item 18. | Financial Statements | 141
Item 19. | Exhibits | 142

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PRESENTATION OF FINANCIAL INFORMATION

Companhia Energética de Minas Gerais–CEMIG is a sociedade por ações, de economia mista (a state-controlled mixed capital company) organized under the laws of the Federative Republic of Brazil, or Brazil. References in this annual report to “CEMIG,” “we,” “us,” “our” and the “Company” are to Companhia Energética de Minas Gerais–CEMIG and its consolidated subsidiaries, except when the reference is specifically to Companhia Energética de Minas Gerais–CEMIG (parent company only) or the context otherwise requires. References to the “real,” “reais” or “R$” are to Brazilian reais (plural) and the Brazilian real (singular), the official currency of Brazil, and references to “U.S. dollars,” “dollars” or “US$” are to United States dollars.

We maintain our books and records in reais. We prepare our financial statements in accordance with accounting practices adopted in Brazil, and with International Financial Reporting Standards or “IFRS”, as issued by the International Accounting Standards Board (IASB). For purposes of this annual report we prepared the consolidated statements of financial position as of December 31, 2012 and 2011 and the related consolidated statements of income and comprehensive income, cash flows and changes in shareholders’ equity for the years ended December 31, 2012, 2011 and 2010, in reais in accordance with International Financial Reporting Standards or IFRS, as issued by the IASB. Deloitte Touche Tohmatsu Auditores Independentes has audited our consolidated financial statements as of and for the year ended December 31, 2012 and KPMG Auditores Independentes has audited our consolidated financial statements as of and for the years ended December 31, 2011 and 2010, as stated in their respective reports appearing elsewhere herein.

This annual report contains translations of certain real amounts into U.S. dollars at specified rates solely for the convenience of the reader. Unless otherwise indicated, such U.S. dollar amounts have been translated from reais at an exchange rate of R$2.0476 to US$1.00, as certified for customs purposes by the U.S. Federal Reserve Board as of December 31, 2012. See “Item 3. Key Information–Exchange Rates” for additional information regarding exchange rates. We cannot guarantee that U.S. dollars can be converted into reais, or that reais can be converted into U.S. dollars, at the above rate or at any other rate.

MARKET POSITION AND OTHER INFORMATION

The information contained in this annual report regarding our market position is, unless otherwise indicated, presented for the year ended December 31, 2012 and is based on, or derived from, reports issued by the Agência Nacional de Energia Elétrica (the Brazilian National Electric Energy Agency), or Aneel, and by the Câmara de Comercialização de Energia Elétrica (the Brazilian Electric Power Trading Chamber), or CCEE.

Certain terms are defined the first time they are used in this annual report. As used herein, all references to “GW” and “GWh” are to gigawatts and gigawatt hours, respectively, references to “MW” and “MWh” are to megawatts and megawatt-hours, respectively, and references to “kW” and “kWh” are to kilowatts and kilowatt-hours, respectively.

References in this annual report to the “common shares” and “preferred shares” are to our common shares and preferred shares, respectively. References to “Preferred American Depositary Shares” or “Preferred ADSs” are to American Depositary Shares, each representing one preferred share. References to “Common American Depositary Shares” or “Common ADSs” are to American Depositary Shares, each representing one common share. Our Preferred ADSs and Common ADSs are referred to collectively as “ADSs,” and Preferred American Depositary Receipts, or Preferred ADRs and Common American Depositary Receipts, or Common ADRs, are referred to collectively as “ADRs.”

On April 29, 2009, a 25.00% stock dividend was paid on the preferred and common shares. On May 13, 2009, a corresponding adjustment was made to the ADSs through the issuance of additional ADSs. On April 29, 2010, a 10.00% stock dividend was paid on the preferred and common shares. On May 10, 2010, a corresponding adjustment was made to the ADSs through the issuance of additional ADSs. On April 30, 2012, a 25.00% stock dividend was paid on the preferred shares and common shares. On May 11, 2012, a corresponding adjustment was made to the ADSs through the issuance of additional ADSs. On May 7, 2013, subject to the approval of the shareholders at the General Meeting to be held on April 30, 2013, a 12.85% stock dividend will be paid on the preferred and common shares. On May 14, 2013, subject to the approval of the shareholders at the General Meeting to be held on April 30, 2013, a corresponding adjustment will be made to the ADSs through the issuance of additional ADSs. The Preferred ADSs are evidenced by Preferred ADRs, issued pursuant to a Second Amended and Restated Deposit Agreement, dated as of August 10, 2001, as amended on June 11, 2007, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of Preferred ADSs evidenced by Preferred ADRs issued thereunder (the “Second Amended and Restated Deposit Agreement”). The Common ADSs are evidenced by Common ADRs, issued pursuant to a Deposit Agreement, dated as of June 12, 2007, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of Common ADSs evidenced by Common ADRs issued thereunder (the “Common ADS Deposit Agreement” and, together with the Second Amended and Restated Deposit Agreement, and on the “Deposit Agreements”).

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FORWARD-LOOKING INFORMATION

This annual report includes forward-looking statements, principally in “Item 3. Key Information,” “Item 5, Operating and Financial Review and Prospects” and “Item 11. Quantitative and Qualitative Disclosures about Market Risk.” We have based these forward-looking statements largely on our current expectations and projections about future events and financial trends affecting our business. These forward-looking statements are subject to risks, uncertainties and assumptions relating to, among other things:

· general economic, political and business conditions, principally in Latin America, Brazil, the State of Minas Gerais, in Brazil, or Minas Gerais, the State of Rio de Janeiro, in Brazil, or Rio de Janeiro, as well as other states in Brazil;

· inflation and changes in currency exchange rates;

· enforcement of legal regulation in Brazil’s electricity sector;

· changes in volumes and patterns of consumer electricity usage;

· competitive conditions in Brazil’s electricity generation, transmission and distribution markets;

· our expectations and estimates concerning future financial performance, financing plans and the effects of competition;

· our level of debt and the maturity profile of our debt;

· the likelihood that we will receive payment in connection with accounts receivable;

· trends in the electricity generation, transmission and distribution industry in Brazil, and in particular in Minas Gerais and Rio de Janeiro;

· changes in rainfall and the water levels in the reservoirs used to run our hydroelectric power generation facilities;

· our capital expenditure plans;

· our ability to serve our consumers on a satisfactory basis;

· our ability to renew our concessions, approvals and licenses on terms as favorable as those currently in effect or at all;

· existing and future governmental regulation as to electricity rates, electricity usage, competition in our concession area and other matters;

· our ability to integrate the operations of companies we have acquired and that we may acquire;

· existing and future policies of the Federal Government of Brazil, which we refer to as the Federal Government;

· existing and future policies of the government of Minas Gerais, which we refer to as the State Government, including policies affecting its investment in us and the plans of the State Government for future expansion of electricity generation, transmission and distribution in Minas Gerais; and

· other risk factors as set forth under “Item 3. Key Information—Risk Factors.”

The forward-looking statements referred to above also include information with respect to our capacity expansion projects that are under way and those that we are currently evaluating. In addition to the above risks and uncertainties, our potential expansion projects involve engineering, construction, regulatory and other significant risks, which may:

· delay or prevent successful completion of one or more projects;

· increase the costs of projects; and

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· result in the failure of facilities to operate or generate income in accordance with our expectations.

The words “believe,” “may,” “will,” “estimate,” “continue,” “anticipate,” “intend,” “expect” and similar words are intended to identify forward-looking statements. We undertake no obligation to update publicly or revise any forward-looking statements because of new information, future events or otherwise. In light of these risks and uncertainties, the forward-looking information, events and circumstances discussed in this annual report might not occur. Our actual results and performance could differ substantially from those anticipated in our forward-looking statements.

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PART I

Item 1. Identity of Directors, Senior Management and Advisers

Not applicable.

Item 2. Offer Statistics and Expected Timetable

Not applicable.

Item 3. Key Information

Selected Consolidated Financial Data

The following tables present our selected consolidated financial and operating information in IFRS as of the dates and for each of the periods indicated. You should read the following information together with our consolidated financial statements, including the notes thereto, included in this annual report and the information set forth in “Item 5. Operating and Financial Review and Prospects” and “Presentation of Financial Information.”

The selected consolidated financial data as of December 31, 2012, 2011 and 2010 and for each of the years ended December 31, 2012, 2011 and 2010, in IFRS, has been derived from our audited consolidated financial statements and the notes thereto included elsewhere in this annual report. U.S. dollar amounts in the table below are presented for your convenience. Unless otherwise indicated, these U.S. dollar amounts have been translated from reais at R$2.0476 per US$1.00, the exchange rate as of December 31, 2012. The real has historically experienced high volatility. We cannot guarantee that U.S. dollars can be converted into reais, or that reais can be converted into U.S. dollars, at the above rate or at any other rate. On April 19, 2013, the exchange rate for reais was R$2,0075 per US$1.00. See “—Exchange Rates.”

Certain balances in the prior year financial statements, although not material in scale, were reclassified for the purposes of comparison with the financial statements for the year ended December 31, 2012. The prior period errors were neither material nor intentional. Although the adjustments were not material in scale, individually or in aggregate, the Company decided to adjust the comparative balances of 2011 and 2010 for the presentation of the financial statements for 2012, with the objective of maintaining the optimum comparison of the balances. Neither net profits nor net assets were adjusted as a result of the reclassifications. Refer to note 2.5 of our consolidated financial statements for further details.

Selected Consolidated Financial Data in IFRS

Selected Consolidated Financial Data in IFRS |  | As and for the year ended December 31, |  |  |
|  | 2012 |  | 2012 |  | 2011 |  | 2010 |  | 2009 |
|  | (in millions of US$)(1) |  | (in millions of R$ except per share/ADS data or otherwise indicated) |
Income Statement Data: |  |  |  |  |  |  |  |  |  |  |
Net operating revenues: |  |  |  |  |  |  |  |  |  |  |
Electricity sales to final consumers |  | 8,142 |  | 16,671 |  | 14,955 |  | 13,219 |  | 13,233 |
Revenue from wholesale supply to other concession holders and PROINFA |  | 948 |  | 1,942 |  | 1,613 |  | 1,469 |  | 1,638 |
Revenue from use of the electricity distribution grid (TUSD) |  | 1,082 |  | 2,216 |  | 1,978 |  | 1,658 |  | 1,332 |
Revenue from use of the concession transmission system |  | 818 |  | 1,675 |  | 1,407 |  | 1,141 |  | 879 |
Transmission indemnity revenue |  | 94 |  | 192 |  | - |  | - |  | - |
Construction revenues |  | 797 |  | 1,631 |  | 1,541 |  | 1,341 |  | 1,291 |
Transactions in electricity on the CCEE |  | 209 |  | 427 |  | 269 |  | 133 |  | 137 |
Other operating revenues |  | 647 |  | 1,324 |  | 983 |  | 924 |  | 652 |
Taxes on revenue and regulatory charges |  | (3,720) |  | (7,618) |  | (6,997) |  | (6,095) |  | (5,737) |
Total net operating revenues |  | 9,017 |  | 18,460 |  | 15,749 |  | 13,790 |  | 13,425 |

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Selected Consolidated Financial Data in IFRS |  | As and for the year ended December 31, |  |  |
|  | 2012 |  | 2012 |  | 2011 |  | 2010 |  | 2009 |
|  | (in millions of US$)(1) |  | (in millions of R$ except per share/ADS data or otherwise indicated) |
Operating costs and expenses: |  |  |  |  |  |  |  |  |  |  |
Electricity purchased for resale |  | (2,906) |  | (5,951) |  | (4,278) |  | (3,722) |  | (3,199) |
Charges for the use of transmission facilities of the basic grid |  | (494) |  | (1,011) |  | (830) |  | (729) |  | (853) |
Depreciation and amortization |  | (489) |  | (1,001) |  | (983) |  | (927) |  | (904) |
Personnel |  | (665) |  | (1,361) |  | (1,249) |  | (1,212) |  | (1,318) |
Gas purchased for resale |  | (242) |  | (495) |  | (329) |  | (225) |  | (167) |
Royalties for usage of water resources |  | (91) |  | (186) |  | (154) |  | (140) |  | (154) |
Outsourced services |  | (550) |  | (1,127) |  | (1,031) |  | (923) |  | (819) |
Post-employment obligations |  | (65) |  | (134) |  | (124) |  | (107) |  | (150) |
Materials |  | (40) |  | (82) |  | (98) |  | (134) |  | (114) |
Provisions for operating losses |  | (382) |  | (782) |  | (257) |  | (138) |  | (124) |
Employee’ and managers’ profit sharing |  | (119) |  | (244) |  | (221) |  | (325) |  | (239) |
Construction costs |  | (796) |  | (1,630) |  | (1,529) |  | (1,328) |  | (1,410) |
Other operating expenses, net |  | (310) |  | (634) |  | (362) |  | (321) |  | (316) |
Total operating costs and expenses |  | (7,149) |  | (14.638) |  | (11,445) |  | (10,231) |  | (9,767) |
Equity in Subsidiaries |  | (1) |  | (3) |  | (1) |  | - |  | - |
Gain on dilution of interest in jointly controlled subsidiaries |  | 129 |  | 264 |  | - |  | - |  | - |
Operational profit before Financial revenue (expenses) and Taxes |  | 1,996 |  | 4,083 |  | 4,303 |  | 3,559 |  | 3.658 |
Financial revenues (expenses), net |  | 611 |  | 1,252 |  | (970) |  | (753) |  | (326) |
Profit before taxes |  | 2,607 |  | 5,335 |  | 3,333 |  | 2,806 |  | 3,332 |
Income taxes expense |  | (519) |  | (1,063) |  | (918) |  | (548) |  | (1,126) |
Profit for the year |  | 2,088 |  | 4,272 |  | 2,415 |  | 2,258 |  | 2,206 |
Non-controlling interests |  |  |  |  |  |  |  |  |  | (73) |
Other comprehensive income (loss) |  | 1 |  | 3 |  | 6 |  |  |  |  |
Comprehensive income |  | 2,089 |  | 4,275 |  | 2,421 |  | 2,258 |  | 2,133 |
Basic earnings (loss): (2) |  |  |  |  |  |  |  |  |  |  |
Per common share |  | 2.45 |  | 5.01 |  | 2.83 |  | 2.65 |  | 2.59 |
Per preferred share |  | 2.45 |  | 5.01 |  | 2.83 |  | 2.65 |  | 2.59 |
Per ADS |  | 2.45 |  | 5.01 |  | 2.83 |  | 2.65 |  | 2.59 |
Diluted earnings (loss): (2) |  |  |  |  |  |  |  |  |  |  |
Per common share |  | 2.45 |  | 5.01 |  | 2.83 |  | 2.65 |  | 2.59 |
Per preferred share |  | 2.45 |  | 5.01 |  | 2.83 |  | 2.65 |  | 2.59 |
Per ADS |  | 2.45 |  | 5.01 |  | 2.83 |  | 2.65 |  | 2.59 |

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|  | As and for the year ended December 31, |  |  |
|  | 2012 |  | 2012 |  | 2011 |  | 2010 |  | 2009 |
|  | (in millions of US$)(1) |  | (in millions of R$ except per share/ADS data or otherwise indicated) |
Balance Sheet Data: |  |  |  |  |  |  |  |  |  |  |
Assets: |  |  |  |  |  |  |  |  |  |  |
Current assets |  | 5,856 |  | 11,990 |  | 8,532 |  | 8,086 |  | 8,617 |
Property, plant and equipment, net |  | 4,303 |  | 8,811 |  | 8,662 |  | 8,229 |  | 8,303 |
Intangible assets |  | 2,185 |  | 4,473 |  | 5,404 |  | 4,948 |  | 3,705 |
Financial assets of concessions |  | 5,453 |  | 11,166 |  | 9,086 |  | 7,672 |  | 5,508 |
Account receivable from the Minas Gerais State Government |  | - |  | - |  | 1,830 |  | 1,837 |  | 1,824 |
Other assets |  | 2,116 |  | 4,333 |  | 3,495 |  | 2,702 |  | 2,337 |
Total assets |  | 19,913 |  | 40,773 |  | 37,009 |  | 33,474 |  | 30,294 |
Liabilities: |  |  |  |  |  |  |  |  |  |  |
Current portion of long-term financing |  | 3,470 |  | 7,106 |  | 7,821 |  | 2,203 |  | 6,659 |
Other current liabilities |  | 3,517 |  | 7,201 |  | 4,348 |  | 4,200 |  | 3,620 |
Total current liabilities |  | 6,987 |  | 14,307 |  | 12,169 |  | 6,403 |  | 10,279 |
Non-current financing |  | 4,427 |  | 9,064 |  | 7,958 |  | 11,024 |  | 4,634 |
Employee post-retirement benefits non-current. |  | 1,089 |  | 2,229 |  | 2,187 |  | 2,062 |  | 1,915 |
Other non-current liabilities |  | 1,528 |  | 3,129 |  | 2,950 |  | 2,509 |  | 2,301 |
Total non-current liabilities |  | 7,010 |  | 14,422 |  | 13,095 |  | 15,595 |  | 8,850 |
Share capital |  | 2,083 |  | 4,265 |  | 3,412 |  | 3,412 |  | 3,102 |
Capital reserves |  | 1,931 |  | 3,954 |  | 3,954 |  | 3,954 |  | 3,969 |
Profit reserves |  | 1,395 |  | 2,856 |  | 3,293 |  | 2,874 |  | 3,177 |
Accumulated other comprehensive income |  | 471 |  | 965 |  | 1,081 |  | 1,211 |  | 1,343 |
Other shareholders´equity |  | 2 |  | 4 |  | 5 |  | 25 |  | (426) |
Total shareholders´equity |  | 5,882 |  | 12,044 |  | 11,745 |  | 11,476 |  | 11,165 |
Total liabilities and shareholders´equity |  | 19,913 |  | 40,773 |  | 37,009 |  | 33,474 |  | 30,294 |

Other Data:

Outstanding shares basic:(2) | 2012 |  | 2011 |  | 2010 |  | 2009 |  |  |
Common |  | 372,837,085 |  | 372,837,085 |  | 372,837,085 |  | 372,837,085 |  |  |
Preferred |  | 480,181,143 |  | 480,181,143 |  | 480,181,143 |  | 480,181,143 |  |  |
Dividends per share (2) |  |  |  |  |  |  |  |  |  |  |
Common |  | R$2.50 |  | R$1.52 |  | R$1.40 |  | R$1.09 |  |  |
Preferred |  | R$2.50 |  | R$1.52 |  | R$1.40 |  | R$1.09 |  |  |
Dividends per ADS (2) |  | R$2.50 |  | R$1.52 |  | R$1.40 |  | R$1.09 |  |  |
Dividends per share (3)(2) |  |  |  |  |  |  |  |  |  |  |
Common |  | US$1.22 |  | US$0.74 |  | US$0.69 |  | US$0.53 |  |  |
Preferred |  | US$1.22 |  | US$0.74 |  | US$0.69 |  | US$0.53 |  |  |
Dividends per ADS (3)(2) |  | US$1.22 |  | US$0.74 |  | US$0.69 |  | US$0.53 |  |  |
Outstanding shares—diluted: (2) |  |  |  |  |  |  |  |  |  |  |
Common |  | 372,837,085 |  | 372,837,085 |  | 372,837,085 |  | 372,837,085 |  |  |
Preferred |  | 480,181,143 |  | 480,181,143 |  | 480,181,143 |  | 480,181,143 |  |  |
Dividends per share diluted (2) |  |  |  |  |  |  |  |  |  |  |
Common |  | R$2.50 |  | R$1.52 |  | R$1.40 |  | R$1.09 |  |  |
Preferred |  | R$2.50 |  | R$1.52 |  | R$1.40 |  | R$1.09 |  |  |
Dividends per ADS diluted (2) |  | R$2.50 |  | R$1.52 |  | R$1.40 |  | R$1.09 |  |  |
Dividends per share diluted (3)(2) |  |  |  |  |  |  |  |  |  |  |
Common |  | US$1.22 |  | US$0.74 |  | US$0.69 |  | US$0.53 |  |  |
Preferred |  | US$1.22 |  | US$0.74 |  | US$0.69 |  | US$0.53 |  |  |
Dividends per ADS diluted (3)(2) |  | US$1.22 |  | US$0.74 |  | US$0.69 |  | US$0.53 |  |  |

(1) Converted at the exchange rate of US$1.00 to R$2.0476, the exchange rate as of December 31, 2012. See “—Exchange Rates.”

(2) Per share numbers have been adjusted to reflect the stock dividends on our shares in April 2012, and per ADS numbers have been adjusted to reflect the corresponding adjustments to our ADS.

(3) This information is presented in U.S. dollars at the exchange rate in effect as of the end of each year.

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Exchange Rates

On March 4, 2005, the National Monetary Council (Conselho Monetário Nacional), or CMN, consolidated the commercial rate exchange market and the floating rate market into a single exchange market. Such regulation allows, subject to certain procedures and specific regulatory provisions, the purchase and sale of foreign currency and the international transfer of reais by a foreign person or company, without limitation as to amount. Additionally, all foreign exchange transactions must be carried out by financial institutions authorized by the Brazilian Central Bank (Banco Central do Brasil), or the Central Bank, to operate in this market.

Brazilian law provides that whenever there (i) is a significant imbalance in Brazil’s balance of payments or (ii) are major reasons to foresee a significant imbalance in Brazil’s balance of payments, temporary restrictions may be imposed on remittances of foreign capital abroad. In the past, the Central Bank has intervened occasionally to control unstable movements in foreign exchange rates. We cannot predict whether the Central Bank or the Federal Government will continue to let the real float freely or will intervene in the exchange rate market. The real may depreciate or appreciate against the U.S. dollar and other currencies substantially in the future. Exchange rate fluctuations may affect the U.S. dollar amounts received by the holders of Preferred ADSs or Common ADSs. We will make any distributions with respect to our preferred shares or common shares in reais and the depositary will convert these distributions into U.S. dollars for payment to the holders of Preferred ADSs and Common ADSs. We cannot asure you that such measures will not be taken by the Brazilian Government in the future, which could prevent us from making payments to the holders of our ADSs. Exchange rate fluctuations may also affect the U.S. dollar equivalent of the real price of the preferred shares or common shares on the Brazilian stock exchange where they are traded. Exchange rate fluctuations may also affect our results of operations. For more information see “Risk Factors — Risks Relating to Brazil — Exchange rate instability may adversely affect our business, results of operations and financial condition and the market price of our shares, the Preferred ADSs and the Common ADSs.”

The table below sets forth, for the periods indicated, the low, high, average and period-end exchange rates for reais, expressed in reais per US$1.00.

|  | Reais per US$1.00 |
Month |  | Low |  | High |  | Average |  | Period-end |
October 2012 |  | 2.0210 |  | 2.0436 |  | 2.0297 |  | 2.0298 |
November 2012 |  | 2.0304 |  | 2.1118 |  | 2.0662 |  | 2.1118 |
December 2012 |  | 2.0445 |  | 2.1141 |  | 2.0775 |  | 2.0476 |
January 2013 |  | 1.9860 |  | 2.0478 |  | 2.0281 |  | 1.9875 |
February 2013 |  | 1.9564 |  | 1.9913 |  | 1.9729 |  | 1.9767 |
March 2013 |  | 1,9480 |  | 2,0210 |  | 1,9842 |  | 2,0210 |
April 2013 (1) |  | 1,9690 |  | 2,0235 |  | 1,9973 |  | 2,0075 |

(1) As of April 19, 2013.

|  | Reais per US$1.00 |
Year Ended December 31, |  | Low |  | High |  | Average |  | Period-end |
2008 |  | 1.5580 |  | 2.6190 |  | 1.8322 |  | 2.3130 |
2009 |  | 1.6995 |  | 2.4420 |  | 1.9976 |  | 1.7425 |
2010 |  | 1.6574 |  | 1.8885 |  | 1.7600 |  | 1.6631 |
2011 |  | 1.5375 |  | 1.8865 |  | 1.6723 |  | 1.8627 |
2012 |  | 1.6997 |  | 2.1141 |  | 1.9535 |  | 2.0476 |

Source: U.S. Federal Reserve Board

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Risk Factors

You should consider the following risks as well as the other information in this annual report in evaluating an investment in our company.

Risks Relating to CEMIG

Public authorities may intervene in our concessions to ensure the appropriate provision of services, which could adversely affect our business, results of operations and financial condition.

Public authorities may intervene in concessions to ensure the appropriate provision of services, and/or faithful compliance with provisions of contracts, regulations and/or laws, and may also interfere in transactions or regulate revenues arising from operations of our facilities. Intervention from public authorities in our concessions, interference in transactions or regulation of revenue could adversely affect our business, results of operations and financial condition.

We cannot be certain of the renewal of our concessions.

We carry out a majority of our power generation, transmission and distribution activities pursuant to concession agreements entered into with the Federal Government. The Brazilian Constitution requires that all concessions relating to public services be awarded through a bidding process. In 1995, in an effort to implement these constitutional provisions, the Federal Government adopted certain laws and regulations, known collectively as the Concessions Law, governing bidding procedures in the power industry. In accordance with the Law No. 8,987 of February 13, 1995, or the Concessions Law, as modified by Federal Law No. 10,848 of March 15, 2004, or the New Industry Model Law, upon application by the concessionaire, existing concessions may be renewed by the Federal Government for additional periods of up to 20 years without being subject to the bidding process, provided that the concessionaire has met minimum performance standards and that the proposal is acceptable to the Federal Government.

On September 11, 2012 the Brazilian government issued Provisional Measure 579, or PM 579, later converted into Law No. 12,783, which governs the extension of the concessions granted before Law No. 9074 of July 9, 1995. Under PM 579, these concessions can be extended only once, for up to 30 years, at the option of the concession-granting power. On December 4, 2012, the Company signed the third amendment to Transmission Concession Contract 006/1997, which extended concession for 30 years under the terms of PM 579 from January 1, 2013. However, the Company opted not to request extension of the generation concessions that expire within the period 2013 to 2017. For the plants that would have had a first extension before PM 579, which include the Jaguara, São Simão and Miranda plants, we believe the Generation Concession Contract 007/1997 allows for the extension of the concession of those plants for an additional 20 years, subject to no additional conditions. For the other generation companies the have concessions that expire over the period from 2015 to 2017, which includes Três Marias, Salto Grande, Itutinga, Camargos, Piau, Gafanhoto, Peti, Tronqueiras, Joasal, Martins, Cajuru, Paciência, Marmelos, Sumidouro, Anil, Poquim, Dona Rita and Volta Grande, we have opted, under the terms of PM 579, not to apply for an extension of their concessions.

In light of the degree of discretion granted to the Federal Government, in relation to new concession contracts, renewal of existing concessions, and in accordance with the provisions established by PM 579 for renewal of distribution, generation and transmission concession contracts, we cannot guarantee that new concessions will be obtained or that our present concessions will be renewed on terms as favorable as those currently in effect. See “Item 4. Information on the Company—Competition—Concessions” and “Item 4. The Brazilian Power Industry—Concessions.” Non-renewal of any of our concessions could adversely affect our business, results of operations and financial condition.

We might be unable to complete our proposed capital expenditure program.

Our by-laws state that we may use up to 40.0% of our annual EBITDA (earnings before interest, income taxes, depreciation and amortization), each fiscal year, on capital investments and acquisitions. Our ability to carry out our capital expenditure program is dependent upon a number of factors, including our ability to charge adequate rates for our services, our access to domestic and international capital markets and a variety of operating and other factors. In addition, our plans to expand our distribution capacity are subject to the competitive bidding process governed by the Concessions Law. We cannot give any assurance that we will have the financial resources to complete this program, which could affect our business, results of operations and financial condition.

Aneel has discretion to establish the rates Cemig Distribution charges consumers. These rates are determined by Aneel and designed to preserve the economic and financial equilibrium of concession contracts entered into with Aneel (acting on behalf of the Federal Government).

Concession agreements and Brazilian law establish a price cap mechanism that permits three types of rate adjustments: (1) the annual readjustment; (2) the periodic revision; and (3) the extraordinary revision. The annual readjustment is designed to

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compensate us for changes in our costs that are beyond our control, such as the cost of electricity to supply consumers, which are established by the government, and charges for transmitting and distributing electricity through transmission and distribution facilities of other companies. Every five years there is a periodic tariff revision aimed at compensating us for the same variations in our costs considered for the annual readjustment, remunerating us for the assets we have built during the five year period, and setting a factor based on our scale gains, which will be considered in our annual rate adjustments. If there is an unforeseen event that significantly alters the economicand financial equilibrium of our concession, there may be an extraordinary revision of our rates by Aneel.

Under all three forms of readjustments, in spite of there being pre-established rules and procedures that must be followed by both Aneel and us, Aneel may act as it deems appropriate and opportune in any given situation for the benefit of consumers’ rights. Thus, although our concession agreements provide that we must remain in economic and financial balance, we cannot assure you that Aneel will establish rates that will adequately compensate us in relation to the investments made or that will fully cover the operational costs of the concession holders.

Disruptions in the operation or deterioration in the quality of our services may have an adverse effect on our business, financial condition and results of operations.

The operation of complex electricity transmission networks and systems involves various risks, such as operational difficulties and unexpected interruptions, caused by events outside of our control. These events include accidents, breakdown or failure of equipment or processes, performance below expected levels of availability and efficiency of the transmission assets and disasters such as explosions, fires, natural phenomena, landslides, sabotage or other similar events. Furthermore, actions by government agencies responsible for the electricity network, the environment, operations and other issues that affect electricity transmission could adversely affect the functioning and profitability of the operations of our transmission lines.

Our insurance coverage may not be sufficient to fully cover costs and/or losses we may incur as a result of damage to our assets and/or service interruptions, which could result in an adverse effect on our business, financial condition and results of operations. For more information on our insurance coverage risk, see “—The insurance contracted by us may be insufficient to compensate for damages.”

The revenues we generate from establishing, operating and maintaining our facilities depend on the availability of our services. If our services become unavailable, we may be subject to reductions in the Permitted Annual Revenue (Receita Anual Permitida, or “RAP”) associated with our concession agreements, and we may face certain penalties, depending on the level of duration of the service unavailability. Therefore, interruptions in our transmission lines and substations may cause a material adverse effect on our business, financial condition and results of operations.

We may incur losses in connection with pending litigation.

We are currently defending several legal and administrative proceedings relating to civil, administrative, environmental, tax, labor and other claims. These claims involve a wide range of issues and seek indemnities and reparation in money and by specific performance. Several individual disputes account for a significant part of the total amount of claims against us. Our consolidated financial statements include contingency provisions in the total amount of R$468 million as of December 31, 2012 for actions in which the existence of a present obligation on the date of the financial statements was considered to be more likely than not. Unfavourable decisions in our legal proceedings may reduce our liquidity and adversely affect our business, financial condition or results of operations. In the event our contingency provisions are insufficient, payments for actions in excess of the amounts provisioned could adversely affect our results of operations and financial condition.

The rules for the sale of electric energy and market conditions could affect our energy selling prices.

Under applicable law, our generation companies are not allowed to sell energy directly to our distribution companies. As a result, our generation companies have to sell electricity in a regulated market through public auctions conducted by Aneel (the “Regulated Market,” the “Regulated Contracting Environment - ACR,” or the “Pool”) or in the Free Market (the “ACL”). Legislation allows distributors that contract with our generation companies under the Regulated Market to reduce the quantity of energy contracted for under existing energy contracts by up to 4% per year of the original contract amount for the entire contract period, exposing our generation companies to the risk of failing to sell their remaining energy at adequate prices.

We perform trading activities through power purchase and sale agreements, mainly in the ACL, through our generation and trading subsidiaries. Contracts in the ACL may be entered into with other generating agents, energy traders, or mainly, with “Free Consumers”. Free Consumers are consumers with demand equal to or greater than 3 MW, who are allowed to choose their electricity supplier. Some contracts with this type of consumer give them the flexibility to purchase more or less energy (by 5% on average) from us than was originally contracted for by such consumers, which may adversely impact our business, results of operations and financial

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condition. Other contracts do not allow for this kind of flexibility in the purchase of energy, however, the increase in market competition in the Free Market can influence the occurrence of this type of arrangement in purchase contracts in this market.

In addition to Free Consumers, there is a category of customers referred as “Special Consumers”, which are consumers with contracted demand between 500kW and 3MW. Special Consumers are eligible to buy energy in the Free Market so long as they buy electricity from alternative sources, such as Small Hydroelectric Plants, biomass plants or wind farms. We have conducted these types of transactions with Special Consumers through some of our own energy resources located within certain of our subsidiaries, but from 2009 on, we have increased these alternative-energy transactions, and have developed a portfolio of purchase contracts for this type of energy. The terms of these agreements for the sale of energy to Special Consumers have certain flexibilities with regards to consumption level requirements designed to meet the demands of Special Customers, which are linked to the customer’s energy consumption level history. Large variations in the market price of energy may generate short-term positions that could adversely affect our results of operations and financial condition.

The lack of liquidity in the trading market or volatility in future prices due to market conditions and/or market perceptions may negatively affect our results of operations. Also, if we are unable to sell all the power capacity under our purchase contracts in the regulated auctions or in the free market, the unsold capacity will be settled in the CCEE at settlement prices (Preços de Liquidação de Diferenças), or PLD, which tend to be very volatile. If this occurs in periods of low settlement prices, our revenues and results of operations could be adversely affected.

The introduction of Law No. 12,783 brought certain changes to the organization of the Brazilian Energy Market and the impacts of this new regulation cannot yet be assessed, however its implementation may have an adverse effect on our business and results of operations.

Requirements and restrictions by the environmental agencies could cause additional costs for us.

Our operations related to generation, distribution and transmission of electricity, and distribution of natural gas, are subject to various federal, state and municipal laws and regulations, and also to numerous requirements relating to the protection of health and the environment. Delays by the environmental authorities, or refusal of license requests by them, and/or any inability on our part to meet the requirements established by the environmental authorities during the environmental licensing process may result in additional costs, or even prohibit or restrict, depending on each individual case, the construction or maintenance of these projects.

Non-compliance with environmental laws and regulations, such as building and operation of a potentially polluting facility without a valid environmental license or authorization, could, in addition to the obligation to redress any damages that may be caused, result in criminal, civil and/or administrative sanctions being applied to us. Under Brazilian legislation, criminal penalties such as restriction of rights, and even imprisonment, may be applied to individuals (including managers of legal entities), and penalties such as fines, restriction of rights or community service may be applied to legal entities. With respect to administrative sanctions, depending on the circumstances, the environmental authorities may: impose warnings or fines, ranging from R$50 thousand to R$50 million; require partial or total suspension of activities; suspend or restrict tax benefits; cancel or suspend lines of credit from governmental financial institutions; or prohibit us from contracting with governmental agencies, companies or authorities. Any of these events could adversely affect our business, results of operation and financial condition.

We are also subject to Brazilian legislation, which requires payment of compensation in the event that our activities have polluting effects. Under the federal legislation, up to 0.5% of the total amount invested in the implementation of a project that causes significant environmental impact must be applied toward compensation measures, in an amount to be determined on a case by case basis by environmental authorities according to the extent of the environmental impact of the project. Certain provisions of the state legislation provide that compensation measures should be adopted retroactively for projects concluded before the relevant legislation was enacted. The retroactive nature of these provisions is being contested by some companies, and the matter is also being discussed between The Minas Gerais State Environment and Sustainable Development Office (Secretaria de Estado de Meio-Ambiente e Desenvolvimento Sustentável, or Semad), the Office of the Attorney General of the State (Procuradoria Geral do Estado, or PGE), and the Minas Gerais Industries Association (Federação das Indústrias de Minas Gerais, or Fiemg), and it is not yet clear whether such provisions will be applied in practice. At this moment, it is not possible to evaluated the effects of this legislation on us, but such legislation may result in additional costs for us, which could adversely affect our business, results of operations and financial condition. See “Item 4. Information on the Company — Environmental Issues — Compensatory Measures”.

In addition, the laws of the State of Minas Gerais require the constitution of a Legal Forest Reserve, corresponding to 20% of the total area of the rural property, used in our operations. Due to the Opinion of the Minas Gerais State Economic Development Office (Secretaria Estadual de Desenvolvimento Econômico, or SEDE), that the Legal Forest Reserve does not apply to hydroelectric operations and the impact of the New Brazilian Forest Code on legislation in the State of Minas Gerais, this issue has not yet been decided. There also has not been any final decision on the application of the Legal Forest Reserve requirement to projects already in operation and to future projects. At this moment, it is not possible to evaluated the effects of such legislation on us, but it could

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adversely affect our business, results of operations and financial condition. See “Item 4. Information on the Company — Environmental Issues — Legal Forest Reserves”.

Finally, the adoption or implementation of new safety, health and environmental laws, new interpretations of existing laws, increased rigidity in the application of the environmental laws, or other developments in the future might require us to make additional capital expenditure or incur operating expenses in order to maintain our current operations; or to curtail our production activities or take other actions that could have an adverse effect on our business, results of operation or financial condition.

We are controlled by the State Government which may have specific interests in our business that are different from yours.

As our controlling shareholder, the government of the State of Minas Gerais exercises substantial influence on the strategic orientation of our business. The government of the State of Minas Gerais currently holds approximately 51% of our common shares and, consequently, has the right to the majority of votes in decisions of the General Meetings of our Shareholders, and can (i) elect the majority of the members of our Board of Directors, and (ii) decide matters requiring approval by a specific majority of our shareholders, including transactions with related parties, shareholding reorganizations and the date and payment of any dividends.

In the past, the State Government has used, and may in the future use, its status as our controlling shareholder to decide whether we should engage in certain activities and make certain investments aimed, principally, to promote its political, economic or social objectives and not necessarily to meet the objective of improving our business and/or operational results. Such actions could materially adversely affect our business, results of operation and financial condition.

Delays in the expansion of our facilities may significantly increase our costs.

We are currently engaged in the construction of additional hydroelectric and wind farm power plants, transmission lines and substations, and the evaluation of other potential expansion projects. Our ability to complete an expansion project on time, within a given budget and without adverse economic effects, is subject to a number of risks. For instance:

· we may experience problems in the construction phase of an expansion project; (e.g.: work stoppages, unforeseen geological conditions, environmental and political uncertainties, liquidity of partners and contractors.

· we may face regulatory or legal challenges that delay the initial operation date of an expansion project;

· our new facilities may not operate at the designated capacity the cost of the operation may be greater than forecast;

· we may face a delay in relation to planned deadline s on a project;

· we may not be able to obtain adequate working capital to finance our expansion projects; and

· we may encounter environmental issues and claims by the local population during power plant construction or related to the transmission lines and substation construction.

If we experience these or other problems relating to the expansion of our electricity generation or transmission capacity we may be exposed to increased costs or we may fail to achieve the revenues we expected in connection with such expansion projects.

Aneel has discretion in setting the Permitted Annual Revenue of our transmission companies, and any adjustments that result in a decrease to such Permitted Annual Revenue could have a material adverse effect on our results of operations and financial condition.

The RAP that we receive through our transmission companies is determined by Aneel taking into account the terms of the concession contracts entered into with Aneel, on behalf of the Federal Government. The concession contracts and the law provide that the revenues of transmission companies are decided by Aneel, and are calculated based on the availability of assets (lines and substations) to the Brazilian National Electric Grid (Sistema Interligado Nacional, or SIN). The concession contracts provide for two mechanisms for adjustment of revenues: (i) annual tariff adjustments; and (ii) the periodic tariff review (revisão tarifária periódica, or RTP). The annual tariff adjustment of our transmission revenues takes place annually in June and is effective in July of the same year. The annual tariff adjustments consider the permitted revenues of the projects that have come into operation and the revenue from the previous period is adjusted by the Amplified National Consumer Price Index (Índice Nacional de Preços ao Consumidor Amplo, or IPCA). The periodic tariff review used to take place every four years, but Law No. 12,783 changed the tariff review period to five years. Our first periodic tariff review took place in July 2005 and the second in July 2009. During the periodic tariff review, the investments made by the concession holder in the period and the operational costs of the concession are analyzed by Aneel, taking into account only investment that it deems to be prudent, and operational costs that it assesses as having been efficient through a benchmarking methodology developed by utilizing an efficiency model based on data comparison among several Brazilian

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transmission companies. Therefore, the tariff review mechanism is subject to some extent to the discretionary power of Aneel, since it may omit to include investments that have been made, and can recognize operational costs as being lower than those actually incurred, which may result in a material adverse effect on our business, results of operations and financial condition.

As mentioned above, we extended the concessions of certain of our transmission utilities by the terms of Law No. 12,783, which resulted in an adjustment to the RAP of those concessions, lowering the revenue we will received from such concessions. The Brazilian Government compensated us for a reduction in the RAP of a portion of these concessions, but the assets in operation before 2000 have not yet been compensated. According to Law No. 12,783, we will be compensated for the reduction in the RAP of the assets in operation before 2000 in 30 years, adjusted by the IPCA.

Labor-related legal claims, strikes and/or work stoppages could have an adverse impact on our business.

Substantially all of our employees are covered by Brazilian labor legislation applicable to private sector employees. We have entered into collective bargaining agreements with the labor unions representing most of these employees.

We are currently defending a number of labor-related claims brought by our employees that mostly relate to overtime and compensation for occupational hazards. We are also subject to claims related to outsourcing of services, in which employees of our contractors and subcontractors have brought actions against us for the payment of outstanding labor liabilities. See “Item 8. Financial Information—Legal Proceedings—Labor and Pension Fund Obligations.”

In the negotiations for reaching the 2010 collective agreement, part of our employees went on strike for 20 days. During the 2011 negotiations for renewal of the Collective Employment Agreement (Acordo Coletivo de Trabalho, or ACT), there were five intermittent days of stoppages by our employees. During the 2012 negotiations for the renewal of the ACT, there was one day of stoppage by 12% of our employees. In all of these events, our Operational Emergency Committee was activated and the strikes and stoppages did not affect the supply of electricity to our consumers.

We do not have insurance against losses incurred as a result of business interruptions caused by employment-related actions. In the event of a strike, we may face an immediate loss of revenue. Contractual disputes, strikes, complaints or other types of conflicts relating to our employees or to unions that represent them may cause an adverse effect on our business, results of operations or financial condition, or on our ability to maintain normal levels of service.

We are subject to rules and limits applied to levels of public sector borrowing and to restrictions on the use of certain funds we raise, which could prevent us from obtaining financing.

As a state-controlled company, we are subject to rules and limits on the level of credit applicable to the public sector issued by the CMN and by the Central Bank. These rules set certain parameters and conditions for financial institutions to be able to offer credit to public sector entities. Thus, if our operations do not fall within these parameters and conditions, we may have difficulty in obtaining financing from Brazilian financial institutions, which could create difficulties in the implementation of our investment plan. Brazilian legislation also establishes that a state-controlled company, in general, may use proceeds from external transactions with commercial banks (debt, including bonds) only to refinance financial obligations. As a result of these regulations, our capacity to incur debt is limited, and this could negatively affect the implementation of our investment plan.

We are subject to extensive and uncertain governmental legislation and regulation and any changes to such legislation and regulation could materially adversely affect our business, results of operations and financial condition.

The Brazilian Federal Government has been implementing policies that have a far-reaching impact on the Brazilian energy sector and, in particular, the electricity industry. As part of the restructuring of the industry, the New Industry Model Law, introduced a new regulatory framework for the Brazilian electricity industry.

This regulatory structure has undergone several changes over recent years, the most recent being PM 579, which governs the extension of the concessions granted by Law No. 9,074 of July 7, 1995. Under this law, these concessions can be extended only once for up to 30 years, at the option of the concession-granting power.

The constitutionality of the New Industry Model Law is currently being challenged before the Brazilian Supreme Court (Supremo Tribunal Federal, or STF). As of the date of this report, the STF had not reached a final decision, and therefore, the New Industry Model Law is in full force and effect. If the New Industry Model Law is considered to be unconstitutional by the STF, the regulatory framework introduced by that law might cease to be in effect, which would generate uncertainty as to how and when the

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Federal Government will be able to introduce changes to the electricity industry. Therefore, any decision on the constitutionality of the New Industry Model Law could have a material adverse effect on our activities, results of operations and financial condition.

Also, we cannot guarantee that new concessions will be obtained or that our present concessions will be renewed on terms that are as favorable as those currently in effect.

There are contractual restrictions on our capacity to incur debt.

We are subject to certain restrictions on our ability to incur debt due to covenants set forth in our loan agreements. In the event of our non-compliance with any such covenants in our loan agreements, the total principal, future interest and any penalties due under these agreements may become immediately due and payable. In 2010, 2011 and 2012, we were at times in non-compliance with our covenants under our loan agreements, but we were able to obtain waivers from our creditors with regard to such non-compliances. As to 2012, in particular, the figures that gave rise to the waiver from ItaúBBA were preliminary and the actual figures ended up being not compatible with the obtained waiver. As another waiver was not obtained prior to December 31, 2012, not only the loan but others with cross-default conditions had to be recognized as a current liability. The amount transferred to current liabilities as a result of non-compliance with the covenant was R$ 1,206 million. We expect to obtain the waiver from ItaúBBA in May 2013. Although we have succeeded in obtaining the waivers, no assurance can be given that we would be successful in obtaining any waivers in the future. Early maturity of our obligations could adversely affect our financial condition especially in light of cross default provisions in several of our loan and financing contracts. The existence of limitations on our indebtedness could prevent us from executing new agreements to finance our operations or to refinance our existing obligations which could adversely affect our business, results of operations and financial condition.

We operate without insurance policies against catastrophes and general third party liability.

We do not have general third party liability insurance covering accidents, other than in connection with Aeronautical events, and have not asked for bids related to this type of insurance. In addition, we have not asked for bids for, nor do we carry, insurance coverage for major catastrophes affecting our facilities, such as earthquakes and floods, nor for business interruption risk; nor for operating system failures. Accidents or catastrophic events may materially adversely affect our business, results of operations or financial condition. See “Item 10. Additional Information—Insurance.”

The insurance contracted by us may be insufficient to compensate for damages.

The Company maintains insurance only for fire , risks involving our aircrafts and helicopters, and operational risks, such as damage to equipment, as well as those types of insurance coverage that are required by law, including transport insurance for goods belonging to us.

We cannot guarantee that our insurance policies are sufficient to cover in full any liabilities that may arise in the course of our business nor that these insurance policies will continue to be available in the future. The occurrence of claims in excess of the amount insured or which are not covered by our insurance policies might generate significant and unexpected additional costs for us, which could have a material adverse effect on our business, results of operation and financial condition.

Our level of consumer default could adversely affect our business, results of operations and financial condition.

As of December 31, 2012, our total past due receivables from final consumers were approximately R$1,324 million, corresponding to 7.17% of our net revenues for 2012, and our allowance for doubtful accounts was R$723 million. Approximately 12,54% our total receivables were owed by entities in the public sector. We may be unable to recover debts from several municipalities and other defaulting consumers. If these debts are not totally or partially recovered, we will experience an adverse impact on our business, results of operations and financial condition. In addition, any consumer defaults in excess of our allowance for doubtful accounts could have an adverse effect on our business, results of operations and financial condition.

We are strictly liable for any damages resulting from inadequate rendering of electricity services.

Under Brazilian law, we are strictly liable for direct and indirect damages resulting from the inadequate rendering of electricity distribution services. In addition, when damages are caused to end consumers as a result of outages or disturbances in the generation, transmission and distribution system, whenever these outages or disturbances are not attributed to an identifiable member of the National System Operator (Operador Nacional do Sistema, or ONS) or to the ONS itself, the liability for such damages is shared among generation, distribution and transmission companies. Until a final allocation is defined, the liability for such damages will be shared in the proportion of 35.7% to distribution agents, 28.6% to transmission agents and 35.7% to generation agents. These proportions are established by the number of votes that each class of energy concessionaires receives in the general meeting of the

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ONS, and as such, they are subject to change in the future. Our business, results of operations and financial condition might be adversely affected as a result of any such damages.

Aneel may impose fines on us for failing to comply with the terms and conditions of our concession agreements, and/or the authorizations granted to us, which could result in fines, other penalties and, depending on the severity of non-compliance, expropriation of the concession agreements or revocation of the authorizations.

We conduct our generation, transmission and distribution activities pursuant to concession agreements entered into with the Federal Government through Aneel and/or pursuant to authorizations granted to the companies of our portfolio, as the case may be. Aneel may impose penalties on us if we fail to comply with any provision of the concession agreements, including compliance with the established quality standards. Depending on the severity of the non-compliance, these penalties could include:

· fines per breach of contract of up to 2.0% of the concessionaire’s revenues in the year ended immediately prior to the date of the relevant breach;

· injunctions related to the construction of new facilities and equipment;

· restrictions on the operation of existing facilities and equipment;

· temporary suspension from participating in bidding processes for new concessions for a period of up to two years;

· intervention by Aneel in the management of the concessionaire that it is in breach; and

· termination of the concession.

In addition, the Federal Government has the power to terminate any of our concessions or authorizations, prior to the end of the concession term in the case of bankruptcy or dissolution, or by means of expropriation for reasons related to the public interest.

Also, delays regarding the implementation and construction of new energy undertakings can also trigger the imposition of regulatory penalties by Aneel, which, under Aneel’s Resolution No. 63 of May 12, 2004, can vary from warnings to the early termination of these concessions or authorizations.

We cannot guarantee that Aneel will not impose penalties or terminate our concessions or authorizations in the event of a breach. Any compensation we may receive upon the termination of the concession contract and/or the authorizations may not be sufficient to compensate us for the full value of certain investments. If any of our concession agreements are terminated and we are at fault, the effective amount of compensation could be reduced through fines or other penalties. Termination of our concession contracts, or imposition of penalties might adversely affect our business, results of operations and financial condition.

Our ability to distribute dividends is subject to limitations.

Whether or not you receive dividends depends on whether our financial condition permits us to distribute dividends under Brazilian law, and whether our shareholders, on the recommendation of our Board of Directors acting in its discretion, determine that our financial condition warrants a suspension of the distribution of dividends in excess of the amount of mandatory distribution required under our by-laws, in the case of the preferred shares.

Because we are a holding company with no revenue-producing operations other than those of our operating subsidiaries, we will be able to distribute dividends to shareholders only if we receive dividends or other cash distributions from our operating subsidiaries. The dividends that our subsidiaries may distribute to us depend on our subsidiaries generating sufficient profit in any given fiscal year. Dividends can be paid out from the profit accrued in each fiscal year, or from accumulated profits from previous years, or from capital reserves. Such dividends are calculated and paid in accordance with Law No. 11,638 (which amended numerous provisions of Law No. 6,404/76), or Brazilian Corporate Law, and the provisions of the by-laws of each of our regulated subsidiaries.

We will need funds in the short term to fund our current and expected acquisitions.

We will need funds in the short term to fund our current and future acquisitions and investments. However, no assurance can be given that we will be able to raise such funds in a timely manner and in the amounts necessary or at competitive rates, or that we will otherwise have supplemental cash-on-hand available to finance our investments and our acquisitions. If we are unable to raise funds as planned, we may be unable to meet our acquisition commitments, and our investment program could suffer delays or significant changes, which could adversely affect our business, financial condition or prospects.

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Foreign shareholders may be unable to enforce judgments against our directors or officers.

All of our directors and officers named in this annual report reside in Brazil. Substantially all of our assets, as well as the assets of these persons, are located in Brazil. As a result, it may not be possible for foreign shareholders to effect service of process within the United States or other jurisdictions outside Brazil upon these persons, attach their assets, or enforce against them or us in United States courts, or the courts of other jurisdictions outside Brazil, judgments predicated upon the civil liability provisions of the securities laws of the United States or the laws of such other jurisdictions. See “Item 10. Additional Information—Difficulties of Enforcing Civil Liabilities Against Non-U.S. Persons.”

Risks Relating to Brazil

The Federal Government exercises significant influence on the Brazilian economy. Political and economic conditions can have a direct impact on our business.

The Federal Government intervenes frequently in the country’s economy and occasionally makes significant changes in monetary, fiscal and regulatory policy. Our business, results of operations or financial condition may be adversely affected by changes in government policies, and also by:

· fluctuations in the exchange rate;

· inflation;

· instability of prices;

· changes in interest rates;

· fiscal policy;

· other political, diplomatic, social and economic developments which may affect Brazil or the international markets;

· control on capital flows; and/or

· limits on foreign trade.

Measures by the Brazilian government to maintain economic stability, and also speculation on any future acts of the Brazilian government, can generate uncertainties in the Brazilian economy and uncertainties about the possible political crisis can contribute to economic stability and increased volatility in the domestic capital markets, adversely affecting our business, results of operations or financial condition. If the political and economic situations deteriorate, we may face increased costs.

The new President of Brazil took office at the beginning of 2011. The President has considerable power to determine governmental policies and actions that relate to the Brazilian economy. Uncertainties in relation to any political crises might contribute to economic instability. This could increase the volatility of the market for Brazilian securities and could have an adverse effect on the Brazilian economy and our business, results of operations and financial condition. It is not possible to predict whether the present government or any subsequent governments will have an adverse effect on the Brazilian economy, and consequently on our business.

Inflation and certain governmental measures to curb inflation may contribute significantly to economic uncertainty in Brazil and could harm our business and the market value of our shares, the Preferred ADSs and the Common ADSs.

Brazil has in the past experienced extremely high rates of inflation. Inflation, and some of the Federal Government’s measures taken in an attempt to curb inflation, have had significant negative effects on the Brazilian economy. Since the introduction of the real in 1994, Brazil’s inflation rate has been substantially lower than in previous periods. According to the IPCA, Brazilian annual inflation rates in 2010, 2011 and 2012 were 5.9%, 6.5% and 5.5%, respectively. No assurance can be given that inflation will remain at these levels.

Future measures taken by the Federal Government, including interest rate changes, intervention in the foreign exchange market or actions to adjust the value of the real might trigger increases in inflation, and consequently, have adverse economic impacts on our business, results of operations and financial condition. If Brazil experiences high inflation in the future, we might be unable to adjust the rates we charge our consumers to offset the effects of inflation on our cost structure.

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Substantially all of our cash operating expenses are denominated in reais and tend to increase with Brazilian inflation. Inflationary pressures might also hinder our ability to access foreign financial markets or might lead to further government intervention in the economy, including the introduction of government policies that could harm our business, results of operations and financial condition or adversely affect the market value of our shares and as a result, our Preferred ADSs and Common ADSs.

Exchange rate instability may adversely affect our business, results of operations and financial condition and the market price of our shares, the Preferred ADSs and the Common ADSs.

The Brazilian currency has been devalued periodically during the last four decades. Throughout this period, the Federal Government has implemented various economic plans and utilized a number of exchange rate policies, including sudden devaluations, periodic mini-devaluations during which the frequency of adjustments has ranged from daily to monthly, floating exchange rate systems, exchange controls and dual exchange rate markets. Although over long periods depreciation of the Brazilian currency generally has correlated with the rate of inflation in Brazil, devaluation over shorter periods has resulted in significant fluctuations in the exchange rate between the Brazilian currency and the U.S. dollar and currencies of other countries.

In 2012, the real depreciated 9.93% against the U.S. dollar. Considering the volatility the world economy is facing, no assurance can be given that the real will not continue to depreciate against the dollar. On December 31, 2012, the buy exchange rate for the U.S. dollar against the real was R$2.0476 to US$1.00. See “Item 3 Key Information — Exchange Rates.”

As of December 31, 2012, approximately 3.27% of our total indebtedness under loans, financings and debentures was denominated in currencies other than the real (92.61% of that being denominated in U.S. dollars). If the real depreciates against the U.S. dollar, our related financial expenses will increase and our results of operations and financial condition could be adversely affected. We recorded foreign exchange-related gain of R$13 million in 2010, foreign exchange-related losses of R$19 million in 2011 and foreign exchange-related losses of R$38 million in 2012. We also have entered into certain power purchase agreements that are dollar denominated. We cannot guarantee that derivatives instruments and the proceeds from our dollar-denominated purchase agreements will be sufficient to avoid an adverse effect on our business, results of operations and financial condition in the event of adverse exchange rate fluctuations. See “Item 11. Quantitative and Qualitative Disclosures about Market Risk—Exchange Rate Risk” for information about our foreign exchange risk hedging policy.

Changes in economic and market conditions in other countries, especially Latin American and emerging market countries, may adversely affect our business, results of operations and financial condition, as well as the market price of our shares, the Preferred ADS and the Common ADSs.

The market value of securities of Brazilian companies is affected to varying degrees by economic and market conditions in other countries, including other Latin American countries and emerging market countries. Although the economic conditions of such countries may differ significantly from the economic conditions of Brazil, the reactions of investors to events in those countries may have an adverse effect on the market value of securities of Brazilian issuers. Crises in other emerging market countries might reduce investor’s interest in securities of Brazilian issuers, including us. This could make it more difficult for us to access the capital markets and finance our operations in the future on acceptable terms or at all. Due to the characteristics of the Brazilian power industry (which requires significant investments in operating assets) and due to our financing needs, if access to the capital and credit markets is limited, we could face difficulties in completing our investment plan and refinancing our obligations which could adversely affect our business, results of operations and financial condition.

Political and economic instability in Brazil may affect us.

Periodically, allegations of unethical or illegal conduct have been made with respect to figures in the Brazilian government, including legislators and/or party officials. Further allegations on unethical or illegal conduct might be made at any time in relation to persons of the Brazilian government, including legislators and/or party representatives. If these events lead to a materially adverse perception of Brazil among investors, the trading value of our shares, the Preferred ADSs and the Common ADSs could decline, and our ability to access international markets could suffer. In addition, any political instability resulting from such events could cause us to re-assess our strategies if the Brazilian economy suffers as a result.

Risks Relating to the Preferred Shares, Common Shares, Preferred ADSs and Common ADSs

The preferred shares and Preferred ADSs generally do not have voting rights and the Common ADSs can only be voted by proxy by providing voting instructions to the depositary.

In accordance with the Brazilian Corporate Law and our by-laws, holders of our preferred shares, and, by extension, holders of our Preferred ADSs representing preferred shares, are not entitled to vote at our shareholders’ meetings, except in very limited circumstances. Holders of our Common ADSs representing common shares are not able to vote at our shareholders’ meetings, but

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rather vote by proxy by providing voting instructions to the depositary. Holders of our Preferred ADSs may also encounter difficulties in the exercise of certain rights, including limited voting rights. Under some circumstances, such as failure to provide the depositary with voting materials on a timely basis, holders of our Preferred ADSs and Common ADSs may not be able to vote by instructing the depositary.

Exchange controls and restrictions on remittances abroad may adversely affect holders of Preferred ADSs and Common ADSs.

You may be adversely affected by the imposition of restrictions on the remittance to foreign investors of the proceeds of their investments in Brazil and the conversion of reais into foreign currencies. Restrictions of this type would hinder or prevent the conversion of dividends, distributions or the proceeds from any sale of preferred shares or common shares from reais into U.S. dollars. We cannot guarantee that the Federal Government will not take similar measures in the future. See “Item 3. Key Information—Exchange Rates.”

Changes in Brazilian tax laws may have an adverse impact on the taxes applicable to a disposition of our shares, Preferred ADSs or Common ADSs.

Law No. 10,833 of December 29, 2003 provides that the sale of assets located in Brazil by a non-resident to either a Brazilian resident or a non-resident is subject to taxation in Brazil, regardless of whether the sale occurs outside or within Brazil. This provision results in the imposition of income tax on the gains arising from a disposition of our preferred shares or common shares by a non-resident of Brazil to another non-resident of Brazil. There is no judicial guidance as to the application of Law No. 10,833 and, accordingly, we are unable to predict whether Brazilian courts may decide that it applies to disposals of our Preferred ADSs and Common ADSs between non-residents of Brazil. However, in the event that the disposal of assets is interpreted to include a disposal of our Preferred ADSs and Common ADSs, this tax law would accordingly result in the imposition of withholding taxes on the disposal of our Preferred ADSs and Common ADSs by a non-resident of Brazil to another non-resident of Brazil.

Exchanging Preferred ADSs or Common ADSs for underlying shares may have unfavorable consequences.

The Brazilian custodian for the preferred shares and common shares must obtain an electronic certificate of foreign capital registration from the Central Bank to remit U.S. dollars from Brazil to other countries for payments of dividends, any other cash distributions, or to remit the proceeds of a sale of shares. If you decide to exchange your Preferred ADSs or Common ADSs for the underlying shares, you will be entitled to continue to rely, for five business days from the date of the exchange, on the depositary bank’s electronic certificate of registration in order to receive any proceeds distributed in connection with the shares. Thereafter, you may not be able to obtain and remit U.S. dollars abroad upon the disposition of the shares, or distributions relating to the shares, unless you obtain your own certificate of registration under CMN Resolution No. 2,689 of January 26, 2000, which entitles foreign investors to buy and sell on the Brazilian stock exchanges. If you do not obtain this certificate, you will be subject to less favorable tax treatment on gains with respect to the preferred or common shares. If you attempt to obtain your own certificate of registration, you may incur expenses or suffer significant delays in the application process. Obtaining a certificate of registration involves generating significant documentation, including completing and filing various electronic forms with the Central Bank and the Brazilian Securities Commission (Comissão de Valores Mobiliários), or the CVM. In order to complete this process, the investor will usually need to engage a consultant or attorney who has expertise in Central Bank and CVM regulations. Any delay in obtaining this certificate could adversely impact your ability to receive dividends or distributions relating to the preferred shares or common shares abroad or the return of your capital in a timely manner. If you decide to exchange your preferred shares or common shares back into Preferred ADSs or Common ADSs, respectively, once you have registered your investment in the preferred shares or common shares, you may deposit your preferred shares or common shares with the custodian and rely on the depositary bank’s certificate of registration, subject to certain conditions. See “Item 10. Additional Information—Taxation—Brazilian Tax Considerations.”

We cannot assure you that the depositary bank’s certificate of registration or any certificate of foreign capital registration obtained by you may not be affected by future legislative or other regulatory changes, or that additional Brazilian restrictions applicable to you, the disposition of the underlying preferred shares or common shares or the repatriation of the proceeds from disposition could not be imposed in the future.

The relative volatility and illiquidity of the Brazilian securities market may adversely affect our shareholders.

Investing in Brazilian securities, such as the preferred shares, common shares, Preferred ADSs or Common ADSs, generally involves a higher degree of risk than investing in securities of issuers from countries with more stable political and economic environments and such investments are generally considered speculative in nature. These investments are subject to certain economic and political risks, such as, among others:

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· changes to the regulatory, tax, economic and political environment that may affect the ability of investors to receive payment, in whole or in part, with respect to their investments; and

· restrictions on foreign investment and on repatriation of capital invested.

The Brazilian securities market is substantially smaller, less liquid, more concentrated and more volatile than major securities markets in the United States. This may substantially limit your ability to sell the shares underlying your Preferred ADSs or Common ADSs for the desired price and within the desired period. In 2012, the São Paulo Stock Exchange (BM&FBovespa S.A. — Bolsa de Valores, Mercadorias e Futuros), or BM&FBovespa, the only stock exchange in Brazil on which shares are traded, had an average market capitalization of approximately R$2.52 trillion, as of December 31, 2012, and average daily trading volume of approximately R$7.2 billion. In comparison, the operating companies listed on the New York Stock Exchange, Inc., or the NYSE, had a market capitalization of approximately US$19.9 trillion as of December 31, 2012 and an average daily trading volume of approximately US$98.1 billion in 2012.

Shareholders may receive reduced dividend payments if our net income does not reach certain levels.

Under our by-laws, we must pay our shareholders a mandatory annual dividend equal to at least 50% of our net income for the preceding fiscal year, based on our financial statements prepared in accordance with IFRS, and also in accordance with the accounting practices adopted in Brazil, and holders of preferred shares have priority of payment. Our by-laws also require that the mandatory annual dividend we pay to holders of our preferred shares equal at least the greater of 10% of the par value of our shares or 3% of the stockholders equity of our shares, in the event that such amount is greater than the payment based on 50% of our net income. If we do not have net income or our net income is insufficient in a fiscal year, our management may recommend at the annual shareholders’ meeting in respect of that year that the payment of the mandatory dividend should not be made. However, under the guarantee of the State Government, our controlling shareholder, a minimum annual dividend of 6% of par value would in any event be payable to all holders of common shares and preferred shares issued up to August 5, 2004 (other than public and governmental holders) in the event that mandatory distributions have not been made in a given fiscal year. See “Item 8. Financial Information—Dividend Policy and Payments” for a more detailed discussion.

Holders of the Preferred ADSs and Common ADS and holders of our shares may have different shareholders’ rights than holders of shares in U.S. companies.

Our corporate governance, disclosure requirements and accounting standards are governed by our by-laws, by the Level 1 Differentiated Corporate Governance Practices of the BM&FBovespa, by the Brazilian Corporate Law and by the CVM. These regulations may differ from the legal principles that would apply if we were incorporated in a jurisdiction in the United States, such as Delaware or New York, or in other jurisdictions outside Brazil. In addition, the rights of an ADS holder, which are derivative of the rights of holders of our common or preferred shares, as the case may be, to protect their interests against actions by our board of directors and controlling shareholders, are different under Brazilian Corporate Law than under the laws of other jurisdictions. Rules against insider trading and self- dealing and other rules for the preservation of shareholder interests may also be different in Brazil than in the United States, potentially disadvantaging holders of the preferred shares, common shares, Preferred ADSs and Common ADSs.

The sale of a significant number of our shares or the issuance of new shares may materially and adversely affect the market price of our shares, Preferred ADSs and Common ADSs.

Sales of a substantial number of shares or the perception that such sales could take place could adversely affect the prevailing market price of our shares, the Preferred ADSs and the Common ADSs. As a consequence of the issuance of new shares or sales of shares by existing shareholders, the market price of our shares and, by extension, the Preferred ADSs and Common ADSs, may decrease significantly.

You may not be able to exercise preemptive rights with respect to our securities.

You may not be able to exercise the preemptive rights relating to the shares underlying your Preferred ADSs or Common ADSs unless a registration statement under the United States Securities Act of 1933, as amended, or the Securities Act, is effective with respect to those rights or an exemption from the registration requirements of the Securities Act is available. We are not obligated to file a registration statement with respect to the shares relating to these preemptive rights, and we cannot assure you that we will file any such registration statement. Unless we file a registration statement or an exemption from registration applies, you may receive only the net proceeds from the sale of your preemptive rights by the depositary or, if the preemptive rights cannot be sold, they will be allowed to lapse.

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Item 4. Information on the Company

Organization and Historical Background

We were organized in Minas Gerais, Brazil on May 22, 1952 as a sociedade por ações de economia mista (a state-controlled mixed capital company) with indefinite duration, pursuant to Minas Gerais State Law No. 828 of December 14, 1951 and its implementing regulation, Minas Gerais State Decree 3,710 of February 20, 1952. Our full legal name is Companhia Energética de Minas Gerais–CEMIG, but we are also known as CEMIG. Our headquarters are located at Avenida Barbacena, 1200, Belo Horizonte, Minas Gerais, Brazil. Our main telephone number is (55-31) 3506-3711.

In order to comply with legal and regulatory provisions pursuant to which we were required to unbundle our vertically integrated businesses, in 2004 we incorporated two wholly-owned subsidiaries of CEMIG: Cemig Geração e Transmissão S.A., referred to as Cemig Generation and Transmission, and Cemig Distribuição S.A., referred to as Cemig Distribution. Cemig Generation and Transmission and Cemig Distribution were created to carry out the activities of electricity generation and transmission, and distribution, respectively.

The following are our principal subsidiaries, which are consolidated in our financial statements as of and for the year ended December 31, 2012, all of which are incorporated in Brazil:

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Our main subsidiaries and jointly controlled entities include:

· Cemig Geração e Transmissão S.A., or Cemig Generation and Transmission (100% interest) which engages in electricity generation and transmission.

· Cemig Distribuição S.A., or Cemig Distribution (100% interest) which engages in electricity distribution.

· Light S.A. (“Light”) (jointly controlled, 26.06% direct and a 6.42% indirect interest in its total capital). The main holdings of Light are Light Energia S.A. (“Light Energia”), a generator of electricity, Light Serviços de Eletricidade S.A., an electricity distributor, and Light Esco Ltda., which operates in energy trading and energy efficiency. For further details, please see “—Acquisition of Interest in Light.”

· Companhia de Gás de Minas Gerais (“Gasmig”) (jointly controlled, 59.57% interest) which acquires, transports, distributes and sells natural gas.

· Trasmissora Aliança de Energia Elétrica S.A. (“TAESA”), formerly Terna Participações S.A., (jointly controlled, 43.36% indirect interest in its total capital), a holding company which operates in electricity transmission in 16 states of Brazil through the following companies, which it controls or in which it has stockholding interests:

n Empresa de Transmissão do Alto Uruguai S.A. (“ETAU”) (holding 52.58% of the registered capital),

n Brasnorte Transmissora de Energia S.A. (holding 38.67% of the registered capital),

n ATE II Transmissora de Energia S.A. (holding 100% of the registered capital),

n ATE III Transmissora de Energia S.A. (holding 100% of the registered capital) and

n São Gotardo Transmissora de Energia S.A (holding 100% of the registered capital)

Strategy

Our vision and goal is to “consolidate our position as the largest group in the Brazilian electricity sector in this decade, with a presence in the natural gas industry, and becoming a world leader in sustainability, admired by clients and recognized for our strength and performance.

In order to achieve our vision of the future and to follow our Long Term Strategic Plan, we have the following goals:

· Strive to be a national leader in the markets we operate, with a focus on market share;

· Strive for operational efficiency in asset management;

· Be one of the most attractive companies for investors;

· Be a benchmark in corporate management and governance;

· Be innovative in the search for technological solutions for our business;

· Be a benchmark in social, economic and environmental sustainability.

We have taken part in several transactions in the last year, which includes among others, the following:

Acquisition of Interest in Light

On May 12, 2011, our subsidiary Parati S.A. — Participações em Ativos de Energia Elétrica (“Parati”), an unlisted special purpose company, incorporated in October, 2008, which has as its corporate purpose the participation in the capital stock of other companies, domestic or foreign, as a partner or shareholder, acquired from Fundo de Investimento em Participações — PCP (“FIP PCP”) 54.08% of the total share capital of Redentor Energia S.A., which holds indirectly 13.03% of the share capital of Light, through its subsidiary RME — Rio Minas Energia Participações S.A.

On July 7, 2011, Parati acquired from Enlighted Partners Venture Capital LLC 100% of its holdings in Luce LLC (“Luce”), owner of 75% of the unit shares of Luce Brasil Fundo de Investimento em Participações (“FIP Luce”), which holds indirectly 13.03% of the total shares of Light, through Luce Empreendimentos e Participações S.A. (“LEPSA”). With this acquisition Parati, which already indirectly held 7.05% of the total and voting capital of Light S.A., became indirect holder of 16.82% of the total and voting stock of Light.

On July 28, 2011, Parati acquired, from Fundação de Seguridade Social Braslight (“Braslight”) the totality of Braslight’s unit shares in FIP Luce. The amount received by Braslight for the sale of FIP Luce’s total shares was R$ 171,981,877.12. Thus Parati

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became the holder of 100% of the unit shares of FIP Luce, and, indirectly, the holder of the equivalent of 20.08% of the total and voting stock of Light.

As a result of the acquisition of the stockholding of FIP PCP, and in accordance with the rules of the Novo Mercado, the highest standard of corporate governance for companies listed in BM&FBovespa, Parati made a firm offer to acquire the shares held by the non-controlling stockholders of Redentor Energia S.A., granting them rights similar to tag-along rights.

On September 30, 2011, Parati acquired 46,341,664 shares held by minority stockholders, increasing its stockholding interest in Redentor Energia S.A. to 96.80% of its total capital. The remaining 3.20%, or 3,467,599 common shares, continued to be held by minority stockholders. After this transaction, Parati indirectly holds the equivalent of 25.64% of the total and voting stock of Light.

On March 14, 2013, Parati carried out a public offer for acquisition of shares aiming at the cancellation of Redentor Energia S.A.’s Listing Registration and its exit from the Novo Mercado segment. As a result of this public offer, Redentor Energia exits form the Novo Mercado segment, but it had to remain listed in BM&FBovespa.

On December 31. 2011, Parati held, directly, 25.64% of the registered capital of Light S.A. (“Light”). We held 25% of Parati’s share capital; and Redentor Fundo de Investimento em Participações held 75%. On December 31, 2011, we held a 32.47% total interest in Light, which included a direct 26.06% interest and an indirect 6.41% interest through Parati.

On February 10, 2012, Light approved the acquisition of 26,520,000 common shares (equivalent to a 51% equity interest) of Guanhães Energia S.A. (“Guanhães Energia”) by Light Energia for R$ 25.0 million (in May 2011 equivalent currency, adjusted by the IPCA index until the date of closing of the transaction).The acquisition is conditional on prior approval by Aneel and will be submitted to the Brazilian antitrust authority (Conselho Administrativo de Defesa Econômica, or CADE).

On August 28, 2012, Light Energia signed the final closing agreement with Investminas Participações S.A. for the acquisition of 26,520,000 Class A common shares in Guanhães Energia S.A., equivalent to 51% of its share capital, for R$ 26,586,219.15.

On September 10, 2012 Light Energia issued 30 non-convertible debentures, with nominal unit value of R$1.0 million , maturing on June 4, 2026, for a total of R$30.0 million.

Acquisition of Interest in Transmission Companies from Abengoa

On November 30, 2011, TAESA, one of our jointly controlled companies, completed acquisition of interests of the ABENGOA Group (comprised of the companies disclosed below), as follows:

(i) 50% of the shares held by Abengoa Concessões Brasil Holding S.A. (“Abengoa”) in the share capital of União de Transmissoras de Energia Elétrica Holding S.A. (“UNISA”), the current name of Abengoa Participações Holding S.A., which holds 100% of the total share capital of the transmission companies:

STE – Sul Transmissora de Energia S.A. (“STE”),

ATE Transmissora de Energia S.A. (“ATE”),

ATE II Transmissora de Energia S.A. (“ATE II”), and

ATE III Transmissora de Energia S.A. (“ATE III”, together with STE, ATE and ATE II, the “UNISA Transmission Companies”), and

(ii) 100% of the shares held by Abengoa and by Abengoa Construção Brasil Ltda. in the share capital of NTE — Nordeste Transmissora de Energia S.A.

Under the pricing provisions in the share purchase agreement with the Abengoa Group, the total amount paid by TAESA for the acquisition was R$1,163 million, with the proceeds of its fourth issue of promissory notes, financial settlement of which took place on November 29, 2011. The operating assets acquired include 1,579 miles of transmission lines, with a Permitted Annual Revenue (Receita Anual Permitida, or “RAP”) of R$509 million, representing an increase of R$309 million in TAESA’s RAP 2011/2012.

On March 16, 2012, TAESA, signed a share purchase agreement with Abengoa for acquisition of the remaining 50% of the shares held by Abengoa in UNISA, which in turn owns 100% of the share capital of the UNISA Transmission Companies. TAESA will pay a total amount of R$ 863.5 million in December 31, 2011 equivalent currency, for this acquisition. This amount will be updated by the accumulated variation of the Brazilian benchmark rate (“SELIC”)between the base date and the business day immediately preceding the date of completion of the transaction, when the actual acquisition of the shares by TAESA will take place. The acquisition price will be adjusted for remuneration and increases or reductions of capital that take place between the base date and the date of completion of the transaction. Completion of the transaction and actual acquisition of the shares by TAESA will be subject to the fulfillment of certain suspensive conditions, which include: (i) approval by the General Meeting of Stockholders of TAESA; (ii)

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consent of the financing banks of the UNISATransmission Companies; and (iii) approval of the transaction by Aneel. Also, the transaction will be submitted to CADE, in accordance with Law 8884/94. On July 3, 2012, TAESA concluded the acquisition of the remaining 50% interest of Abengoa in UNISA (STE, ATE, ATE II and ATE III) for the amount of R$ 904 million. TAESA financed this acquisition by the issue of R$ 905 million in promissory notes.

Transfer of equity interests of the TBE transmission assets, held by Cemig and Cemig Generation and Transmission, to TAESA

On May 17, 2012, Cemig and TAESA signed a Private Contract for Investment in Transmission Assets, agreeing to transfer to TAESA the minority equity interests held by Cemig and Cemig Generation and Transmission in the share capital of the following holders of public electricity service concessions:

(i) Empresa Catarinense de Transmissão de Energia S.A.– ECTE;

(ii) Empresa Regional de Transmissão de Energia S.A. – ERTE;

(iii) Empresa Norte de Transmissão de Energia S.A. – ENTE;

(iv) Empresa Paranaense de Transmissão de Energia S.A. – ETEP;

(v) Empresa Amazonense de Transmissão de Energia S.A. – EATE; and

(vi) Empresa Brasileira de Transmissão de Energia S.A. – EBTE.

Within the scope of this stockholding restructuring, TAESA will disburse the amount of R$ 1,732 million, of which R$ 1,668 million will be paid to Cemig and R$ 64 million will be paid to Cemig Generation and Transmission. These amounts will be updated by the CDI rate from December 31, 2011, less any dividends and/or interest on equity that is declared, whether paid or not. The amount involved was agreed by the companies based on technical valuations conducted by independent external evaluators.

This shareholding restructuring is in accordance with our strategic planning, which aims to consolidate our holdings in electricity transmission companies in a single corporate vehicle, and to optimize our ability to assess opportunities in future auctions of transmission lines and acquisition of transmission assets in operation.

Acquisition of the São Gotardo substation by TAESA in Aneel Auction 005/2012

On June 6, 2012, TAESA won Lot E of Aneel Auction 005/2012. TAESA created a special-purpose company (“SPC”) named São Gostardo Transmissora de Energia S.A. to which Aneel granted the right to commercial operation of the concession comprising two transmission functions within the São Gotardo 2 substation in the state of Minas Gerais. TAESA did not offer a discount in relation to the initial base RAP of R$ 3,74 million and expects to complete construction within the period stipulated by Aneel, February 2014.

TAESA follow-on equity offering

On July 19, 2012, in a follow-on equity offering, TAESA issued 24 million units (each presenting one common share and two preferred shares), at R$ 65 per unit..On August 20, 2012, the bookrunners exercised the overallotment option and TAESA issued an additionl 3 million units, totaling 27 million units issued in the follow-on equity offering. The share capital of TAESA was increased, within the limit of its authorized capital, in the amount of R$1.755 billion, by issuance of 81 million new shares: 27 million common and 54 million preferred shares. Under Brazilian Corporate Law, and our by-laws, existing stockholders did not have a right of first refusal in this subscription. As a result of the follow-on equity offering, Cemig Generation and Transmission’s holding in TAESA was diluted, from 56.69% to 43.36%. The mentioned operation gave rise to a gain in the amount of R$ 259, reported in our profit and loss account for the third quarter of 2012.

On December 4, 2012, TAESA underwent a three-for-one split of all its shares: each share (whether or not represented by or included in a deposit certificate (or “unit”)) became three shares of the same type. The split had no effect on TAESA’s equity, on the ratio of common to preferred shares, or on any feature or attribute of any share.. After the split, TAESA has 1,033,496,721 shares: 691,553,133 common shares and 341,943,588 preferred shares; and there is no change in the total value of TAESA’s share capital.

Acquisition of Interest in Renova

Renova Energia S.A. (“Renova”) is a company generating electricity from renewable sources focused on wind farms and small hydroelectric plants (PCHs). Renova prospects for, develops and implements renewable energy enterprises and is currently the only company listed on the BM&FBovespa dedicated to working with alternative energy sources in Brazil. It has created the largest wind farm complex in Brazil, located in the semi-arid region of the Brazilian state of Bahia, and sold a total of 690MW of installed electricity generation capacity in the reserve energy auctions of 2009 and 2010, the A–3 auction of 2011 and the A-5 auction of 2012.

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On August 19, 2011 Light, through its subsidiary Light Energia, subscribed 50,561,797 of Renova’s common shares. As a result, Light Energia holds 34.85% of Renova’s common shares and 25.9% of its total capital. The transaction included a private placement of Renova’s shares in the approximate amount of R$ 360.0 million. Renova1s minority shareholders participated in the private placement, resulting in a total capital injection of R$ 376.0 million.

The common shares subscribed by Light Energia are part of the controlling stockholding block of Renova, and represent half of the shares comprising the control block, with the same rights and preferences attributed to the other common shares issued by Renova. To make the transaction possible, RR Participações S.A. (“RR Participações”) and certain stockholders of Renova waived their right of first refusal in favor of Light Energia. Light Energia and RR Participações entered into a stockholders’ agreement which regulated the exercise of the right to vote, purchase and sale of shares issued by the Renova held by the parties, and their rights and obligations as stockholders of the Renova. Light has experience in building and operating generation projects, and sale and placement of electricity. We understand that this combination will enable Renova to position itself as one of the largest players in wind generation in Latin America, with unique and extremely attractive characteristics. The agreement also contains a commitment by Light to purchase 400MW of installed power capacity provided by Renova’s wind projects. The companies further have the right of first refusal in the purchase or sale, as applicable, of wind energy in long-term The principal purpose of this acquisition is to accelerate the growth of Renova through a combination of its own technical capacity and pioneering experience in development of new projects and business with our own experience and contracts entered into in the Free Market.

On June 22, 2012, the Contract for Subscription of Units issued by Renova, was entered into between BNDES Participações S.A. (“BNDESPar”), Renova, Light, Light Energia and RR Participações, governing the investment by BNDESPar in Renova. The contract is for a capital increase in Renova, to be decided at a later date, in the total amount of up to R$ 314,700,407.85, at the price of R$ 9.3334 per share. The entry of BNDESPar into Renova provides increased negotiating and financial capacity for it to make the investments planned up to that time. Due to this operation, as of 31 December, 2012, Light’s interest in Renova was 21.99%.

The table below shows the Renova portfolio of projects.

Contracted Capacity (MW) | 1090
LER 2009 | 294
LER 2010 | 162
A-3 2011 | 212
PPA Free Market | 400
A-5 2012 | 22,4
Certified Projects (MW) | 2200
Developing Projects (MW) | 2400

In July, 2012, Renova Energia set up Alto Sertão I, a wind farm complex, located among the cities of Caetité, Igaporã and Guanambi, in the Southwest region of the state of Bahia. Alto Sertão I is considered the largest wind farm complex in Latin America, with an installed capacity of 294 MW, enough to supply 540,000 homes, the complex had an investment of R$1.2 billion and consists of 14 wind farms and 184 turbines.

Acquisition of Interest in Guanhães Energia

On February 10, 2012, Light approved the acquisition of 26,520,000 common shares (equivalent to a 51% equity interest) of Guanhães Energia S.A. (“Guanhães Energia”) by Light Energia for R$ 25.0 million (in May 2011 equivalent currency, adjusted by the IPCA index until the date of closing of the transaction).The acquisition is conditional on prior approval by Aneel and will be submitted to the Brazilian antitrust authority (Conselho Administrativo de Defesa Econômica, or CADE).

On August 28, 2012, Light Energia signed the final closing agreement with Investminas Participações S.A. for the acquisition of 26,520,000 Class A common shares in Guanhães Energia S.A., equivalent to 51% of its share capital, for R$ 26.5 million. For more information regarding Guanhães Energia, see “Expansion of Generation Capacity” section.

Acquisition of 9.77% interest in Norte Energia S.A.: the Belo Monte Hydroelectric Plant

The Belo Monte Hydroelectric Plant (“Belo Monte”) is the largest plant currently under construction in the world, and when completed will have installed capacity of 11,233 MW, with Assured Energy of 4,571 MW average. The commercial operation is planned to start in February 2015, and the concession period is 35 years. The concession for the construction and operation of the Belo Monte Hydroelectric Plant, on the Xingu River, in the Brazilian state of Pará, belongs to Norte Energia S.A. (“Norte Energia”), which won the auction held in April 2010.

The Northern region of Brazil is the principal expansion frontier for generation of hydroelectric energy in Brazil, and more than 60% of the potential for hydroelectric expansion is still available. Therefore, we understand that the participation in this project has strategic value. The Belo Monte Hydroelectric Plant is the second project in the region in which Cemig Generation and Transmission is participating, the first being its 10% interest in the consortium building the Santo Antônio Hydroelectric Plant in the Brazilian State of Rondônia.

Amazônia Energia Participações S.A. (“Amazônia Energia”) is a special-purpose company in which the stockholders are: Light S.A., with 51% of the voting stock and 25.5% of the total stock; and Cemig Generation and Transmission, with 49% of the

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voting stock and 74.5% of the total stock. On October 25, 2011, Amazônia Energia signed share purchase agreements with six companies that held, in aggregate, an interest of 9.77% in Norte Energia, as follows: (i) Construtora Queiroz Galvão S.A.: 2.51%; (ii) Construtora OAS Ltda.: 2.51%; (iii) Contern Construções e Comércio Ltda.: 1.25%; (iv) Cetenco Engenharia S.A.: 1.25%; (v) Galvão Engenharia S.A.: 1.25%; and (vi) J. Malucelli Construtora de Obras S.A.: 1%.

The acquisition price corresponds to the amount of the injections of capital made by the vendors, adjusted by the IPCA index up to October 26, 2011, in the amount of R$ 118.69 million.

The transaction involving the participation of Amazônia Energia as a stockholder of Norte Energia was approved by the Extraordinary General Meeting of Norte Energia and by our and Light’s Boards of Directors. The Brazilian electricity regulator, Aneel, has been informed about the transaction, and it has been submitted to CADE, in accordance with Law 8884/94.

The transaction adds 818 MW of generation capacity to our total holdings, increasing our market share in Brazilian electricity generation from 7% to 8%; and adds 280 MW to the total generation capacity of Light.

Advantages of this transaction include the following: (i) the principal contracts for building works and equipment have been signed; (iii) the principal risks associated with the project have been considerably mitigated; (ii) future injections of capital will be diluted over nine years, and will use the cash flow generated by the project itself during the last three of those years; (iv) the environmental costs have been defined; and (v) all of the sales transactions for the electricity have already been established.

This acquisition will not have any effect on the policy for payment of dividends to our stockholders.

Increase of stockholding in Gasmig

On December 27, 2011, our Board of Directors authorized the acquisition of 10,781,736 nominal common shares and 7,132,773 nominal preferred shares, representing 4.38% of the total capital of Companhia de Gás de Minas Gerais — Gasmig, which belonged to the State of Minas Gerais, for R$ 67.2 million, corresponding to a price per share of approximately R$3.75, lately adjusted to the value given by an independent valuation opinion prepared by a specialized institution, which resulted in a valuation of the holding acquired at R$65. For more information, see the section “14. Investment”, in the Financial Statements.

Acquisition by Cemig of an equity interest in Gás Brasiliano (GBD)

On February 8, 2012, CEMIG signed an investment agreement with Petrobrás Gás S.A — Gaspetro and Gás Brasiliano Distribuidora S.A (“GBD”), to subscribe common shares representing 40% of the share capital of GBD, subject to certain prior conditions. GBD is a natural gas distribution company that distributes to consumers in the residential, industrial, and commercial sectors, the automobile industry, co-generation plants, and thermal generation plants.

Increase in the interest held by Cemig Capim Branco Energia S.A. in the Capim Branco Energia Consortium

At a board meeting on December 28, 2012, Cemig authorized its wholly-owned subsidiary, Cemig Capim Branco Energia S.A. (“Cemig Capim Branco”), to accept an offer made by Suzano Papel e Celulose S.A. and its subsidiaries (“Suzano”), on December 27, 2012, for acquisition by Cemig Capim Branco of its proportional interest in the 17.89% interest held by Suzano in the Capim Branco Energia Consortium (“the Consortium”), and also stated the intention to acquire any shares remaining in the event that the other consortium members did not exercise their rights of first refusal, as specified in the Consortium Constitution Agreement. Suzano’s interest in the Consortium proportionately represents about 81MW of installed capacity, at the Amador Aguiar I and II hydroelectric plants, and assured average power of 51MW. The members of the Consortium other than Suzano are Cemig Capim Branco, with 21.05% Vale S.A., with 48.42%; and Votorantim Metais Zinco S.A., with 12.63%. On March 12, 2013 Cemig Capim Branco signed the final contract for the acquisition of 30.30% of Suzanos’s 17.89% interest in the Consortium. The total price agreed, subject to any adjustments, for Suzano’s 17.89% interest in the Consortium was R$ 320 million. Of this total, the proportional interest to be acquired by Cemig Capim Branco represents a total of approximately R$97 million. The transaction is subject to completion, and approvals by Aneel and CADE.

Capital Expenditures

Capital expenditures for the years ended December 31, 2012, 2011 and 2010 in millions of reais, were as follows:

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|  | Year ended December 31, |
|  | 2012 |  | 2011 |  | 2010 |
Distribution network |  | 1,446 |  | 1,857 |  | 2,050 |
Power Generation |  | 804 |  | 972 |  | 359 |
Transmission network |  | 446 |  | 1,030 |  | 1,581 |
Others |  | 834 |  | 121 |  | 132 |
Total capital expenditures |  | 3,530 |  | 3,980 |  | 4,122 |

Recent changes in the regulation of the energy sector, especially those introduced to the generation and transmission business by Law No. 12,783, and Cemig Distribution’s tariff review (held in April 2013) have required more precise budget planning. As of the date of this report, our Capital Expenditure and Investment Plan for 2013 had not yet been approved by us.

We expect to fund our capital expenditures in 2013 mainly from our cash flow from operations and, to a lesser extent, through financing. We expect to finance our expansion and projects by commercial bank loans and by issuing debentures in the local market.

Business Overview

General

We run a business related to generation, transmission, distribution and sale of electricity, gas distribution, telecommunications and the provision of energy solutions.

Cemig

Cemig engages in transactions for the purchase and sale of electricity through its subsidiaries. Total resources used in the year 2012 amounted to 83,912 GWh, an amount that is 2.9% higher than the resources used in the previous year. The amount of energy produced in 2012 was 38,433 GWh, which represented an increase of 12.7% over 2011 and the amount of energy purchased totaled 45,479 GWh, which represented an decrease of 4.1% over 2011. This refers to the energy purchased form Itaipu 8,422 GWh and energy purchased by CCEE and other companies (37,057 GWh).

The energy traded in 2012 was 48,487 GWh, an amount 1.34% higher than traded in 2011, and 94.9% of that value (46,015 GWh) was traded to final consumers, both captive and free.

The total losses of energy in the core network and distribution networks totaled 6,317 GWh, which corresponds to 7.5% of total resources and 10.6% higher than the losses in 2011 (5,712 GWh).

The table below shows the breakdown of resources and power requirements by Cemig traded in the last three years.

CEMIG’S ELECTRIC ENERGY BALANCE (6)

(GWh) |  | Year ended December 31, |
|  | 2012 |  | 2011 |  | 2010 |
RESOURCES |  | 83,912 |  | 81,523 |  | 77,752 |
Electricity generated by CEMIG (1) |  | 35,382 |  | 31,276 |  | 30,361 |
Electricity generated by auto-producers |  | 1,100 |  | 997 |  | 980 |
Electricity generated by Ipatinga |  | 309 |  | 308 |  | 300 |
Electricity generated by Barreiro |  | 82 |  | 60 |  | 65 |
Electricity generated by Sá Carvalho |  | 405 |  | 356 |  | 380 |
Electricity generated by Horizontes |  | 54 |  | 53 |  | 80 |
Electricity generated by Cemig PCH |  | 70 |  | 51 |  | 58 |
Electricity generated by Rosal Energia |  | 249 |  | 251 |  | 310 |
Electricity generated by Amador Aguiar |  | 656 |  | 580 |  | 614 |
Electricity generated by Cachoeirão (5) |  | 126 |  | 163 |  | 134 |
Electricity bought from Itaipu |  | 8,422 |  | 8,475 |  | 8,590 |
Electricity bought from CCEE and other companies (2)(3) |  | 37,057 |  | 38,953 |  | 35,880 |

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REQUIREMENTS |  | 83,912 |  | 81,523 |  | 77,752 |
Electricity delivered to final consumers (4) |  | 46,015 |  | 45,346 |  | 43,272 |
Electricity delivered to auto-producers |  | 994 |  | 991 |  | 993 |
Electricity delivered by Ipatinga |  | 309 |  | 308 |  | 300 |
Electricity delivered by Barreiro |  | 97 |  | 100 |  | 99 |
Electricity delivered by Sá Carvalho |  | 476 |  | 498 |  | 496 |
Electricity delivered by Horizontes |  | 81 |  | 83 |  | 85 |
Electricity delivered by Cemig PCH |  | 109 |  | 115 |  | 121 |
Electricity delivered by Rosal Energia |  | 263 |  | 262 |  | 263 |
Electricity delivered by Cachoeirão (5) |  | 143 |  | 143 |  | 143 |
Electricity delivered to the CCEE and other companies(2)(3) |  | 29,108 |  | 27,965 |  | 26,264 |
Losses |  | 6,317 |  | 5,712 |  | 5,716 |

(1) Discounting the losses attributed to generation (418 GWh in 2012) and the internal consumption of the generating plants.

(2) This amount refers to contracts, purchases and sales of electricity under the CCEE, including the Energy Reallocation Mechanism (Mecanismo de Realocação de Energia).

(3) Includes bilateral contracts with other agents of the CCEE.

(4) Includes electricity delivered to consumers outside the concession area.

(5) Includes 100% of electricity produced by Cachoeirão Hydro Power Plant. CEMIG has a 49% interest in the consortium, and is responsible for the sale of 100% of the physical guarantee of this Small Hydro Plant.

(6) It does not include Light, which manages its own electric energy balance.

Light

Total energy consumption in the concession area of Light Serviços de Eletricidade S.A. (“Light SESA”), which is controlled by our subsidiary Light S.A., (including captive customers and transport of Free Consumers) came to 23,384 GWh in 2012, a 2.0% increase over 2011. The commercial segment, which increased by 9.1%, was the best performer.

In 2012, the amount of energy produced was 4,290 MWh a volume 5.0% below the 4,518 MWh generated in 2011. All of Light’s energy is produced by hydropower plants, with a total capacity of 855MW (excluding energy produced by other companies).

In 2012, a total of 5,372.8 GWh was sold, a 2.7% decline from the amount sold in 2011. This result was primarily impacted by the spot market sales due to the poor hydrological conditions during 2012, especially in the last quarter. In the captive market (ACR), volume was down 2.0% from the previous year due to the reinstatement of Mechanism for the Offsetting of Surpluses and Deficits (MCSD). The reinstatement of MCSD resulted in the termination of contracts in the captive market (ACR), which offset the 20.5% increase in sales to the free market (ACL).

The table below shows the energy generated and sold by Light Energia for the periods and in the markets indicated below.

LIGHT ENERGIA (GWh) | 4Q 2012 | 4Q 2011 | % | 2012 | 2011 | %
ACR Sales | 1,069.4 | 1,082.0 | -1.2% | 4,103.0 | 4,185.7 | -2.0%
ACL Sales | 204.7 | 173.0 | 18.3% | 746.6 | 619.8 | 20.5%
Spot Sales (CCEE) | (4.9) | 125.4 | - | 523.2 | 717.5 | -27.1%
Total | 1,269.2 | 1,380.4 | -8.1% | 5,372.8 | 5,523.0 | -2.7%

In accordance with Aneel’s calculation methodology, Light’s commercial, or non-technical, losses in the year ended December 2012 totaled 6,007 GWh, representing 45.4% of billed energy in the low-voltage market, 2.3 and 5.0 percentage points up from September 2012 and December 2011, respectively. For more information, see “Energy Losses” section.

Light SESA’s total energy losses amounted to 8,584 GWh, or 23.6% of the grid load, in 2012, 1.9% up from 2011, due to high temperatures recorded during 2012, especially in the fourth quarter, that caused an increase of electric power theft by low-income consumers, and primarily by the initiative implemented at the beginning of the year related to the termination of contracts with clients presenting long-term default in areas where traditional collection initiatives are not effective, pursuant to ANEEL Resolution 414.

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LIGHT’S ELECTRIC ENERGY BALANCE

| Year ended December 31,
| 2012 | 2011 | 2010
Energy Balance (GWh) |  |  |
Grid Load | 36,409 | 34,983 | 35,201
Energy transported to utilities | 2,637 | 2,901 | 3,047
Energy transported to free consumers* | 5,018 | 4,664 | 5,206
Own Load | 28,755 | 27,418 | 26,948
Captive market consumption | 20,054 | 19,877 | 19,459
Low Voltage Market | 13,207 | 12,985 | 12,630
Medium Voltage Market | 6,847 | 6,891 | 6,829
Losses + Non Billed Energy | 8,701 | 7,542 | 7,489

* Including CSN and CSA

Generation

According to Aneel, at December 31, 2012, we were the fourth largest electric power generation group in Brazil as measured by total installed capacity. At December 31, 2012, we generated electricity at 64 hydroelectric plants, three thermoelectric plants and three wind farms and had a total installed generation capacity of 7,038 MW of which hydroelectric plants accounted for 6,805 MW, thermoelectric plants accounted for 184 MW and wind farms accounted for 49 MW. Eight of our hydroelectric plants accounted for approximately 77% of our installed electric generation capacity in 2012. During the year ended December 31, 2012, we recorded expenses totaling R$252.58 million relating to transmission charge payments made to the ONS and to transmission concession holders. See “—The Brazilian Power Industry” and “Item 5. Operating and Financial Review and Prospects.”

Transmission

We are engaged in the electric power transmission business, which consists of transporting electric power from the facilities where it is generated to the distribution networks for delivery to final users. We transport energy produced at our own generation facilities and that we purchase from Itaipu, and other sources, as well as the energy for the interconnected power system and other concessionaires. Our transmission network is comprised of power transmission lines with a voltage capacity equal to or greater than 230 kV and is part of the Brazilian Grid regulated by the ONS. See “—The Brazilian Power Industry.” As of December 31, 2012, our transmission network consisted of approximately 40 miles of upper 525 kV lines, 3,042 miles of 500 kV lines, 135 miles of 440kV lines, 1,286 miles of 345 kV lines and 1,343 miles of 230 kV lines, which were distributed, mainly, among the following companies :

· Cemig Generation and Transmission: 1,352 miles of 500 kV lines, 1,222 miles of 345 kV lines and 490 miles of 230 kV lines located in Minas Gerais.

· TAESA: Our proportional share of TAESA transmissions lines includes 1,159 miles of 500 kV lines, 135 miles of 440 kV lines and 303 miles of 230 kV lines in 16 different Brazilian States.

· TBE: Our proportional share of TBE transmissions lines includes 40 miles of upper 525 kV lines, 531 miles of 500 kV lines, one mile of 345 kV lines and 456 miles of 230 kV lines.

· Transmineiras* and Centroeste: Our proportional share of Transmineiras and Centroeste transmissions lines includes 63 miles of 345 kV lines and 9 miles of 230 kV lines.

· Light: Our proportional share of Light transmissions lines includes 23 miles of 230 kV lines.

· Transchile operates a total of 62 miles of 220 KV lines (the Charrúa – Nueva Temuco line) in the country of Chile.

* Transmineiras includes Transleste, Transudeste and Transirapé.

Distribution

Through Cemig Distribution, we have four distribution concession agreements in the State of Minas Gerais that grant us rights to supply electricity to consumers in that area, including consumers that may be eligible, under the legislation, to become Free Consumers (consumers with demand equal to or greater than 3 MW, or consumers with demand equal to or greater than 500 kW from

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alternative energy sources, such as wind, biomass or small hydroelectric plants). The concession area of Cemig Distribution covers approximately 219,103 square miles, or 96.7% of the territory of the state. As of December 31, 2012, through Cemig Distribution, we owned and operated approximately 308,466 miles of distribution lines, through which we supplied 24,633 GWh to approximately 7.5 million end-consumers.

Through Light Serviços de Eletricidade S.A. (“Light SESA”), which is controlled by our subsidiary Light S.A., as of December 31, 2012, we owned and operated 37 thousand miles of distribution lines, through which we supplied 23,384 GWh to approximately 4 million end-consumers, which represented a 2.0% increase in consumption over 2011. The concession area of Light SESA covers 31 cities of the State of Rio de Janeiro.

In 2012, a total of 5,018 GWh was carried and delivered by the electricity distribution system to the Free Consumers. The total amount of electricity supplied was 23,384 GWh, of which 35% was supplied to residential consumers, 29% to commercial consumers, 15% to other consumers, 14% to Free Consumers and 7% to industrial consumers.

Light S.A., with the operation of the Paracambi Small Hydro Plant (SHP) in May 2012, and Renova Energia, with the operation of its first wind farm in July 2013, combined to increase their collective installed capacity from 866 MW in 2011 to 942 MW in 2012.

Other Businesses

While our main business consists of the generation, transmission and distribution of electricity, we also engage in the following businesses: (i) distributing natural gas in Minas Gerais through our subsidiary, Gasmig, (ii) telecommunications through our consolidated subsidiary Cemig Telecomunicações S.A.; (iii) national and international energy solutions consulting business through our subsidiary Efficientia S.A.,; and (iv) implementation and management of systems for electricity sector companies through our subsidiary Axxiom Soluções Tecnológicas S.A.; (v) exploitation of natural gas through six consortia, listed as follows: (a) Consórcio de Exploração SF-T-104, (b) Consórcio de Exploração SF-T-114, (c) Consórcio de Exploração SF-T-120, (d) Consórcio de Exploração SF-T-127, (e) Consórcio de Exploração REC-T-163, and (f) Consórcio de Exploração POT-T-603, formed with several partners; and (vi) sale and trading of electricity, structuring and intermediating purchases and sale transactions, buying and selling electricity in the Free Market through our wholly-owned subsidiaries Cemig Trading S.A. and Empresa de Serviços de Comercialização de Energia Elétrica S.A.

Revenue Sources

The following table shows the revenues attributable to each of our principal revenue sources, in millions of reais, for the periods indicated:

|  | Year ended December 31, |
|  | 2012 |  | 2011 |  | 2010 |
Electricity sales to final consumers |  | 16,671 |  | 14,955 |  | 13,219 |
Revenue from wholesale supply to other concession holders and PROINFA |  | 1,942 |  | 1,613 |  | 1,469 |
Revenue from use of the basic electricity distribution system (TUSD) |  | 2,216 |  | 1,978 |  | 1,658 |
Revenue from use of the transmission system |  | 1,675 |  | 1,407 |  | 1,141 |
Indemnity transmission revenues |  | 192 |  | - |  | - |
Construction revenues |  | 1,631 |  | 1,541 |  | 1,341 |
Revenue from sale on the spot market |  | 427 |  | 269 |  | 133 |
Other operating revenues |  | 1,324 |  | 983 |  | 924 |
Tax on revenues |  | (7,618) |  | (6,997) |  | (6,095) |
Total |  | 18,460 |  | 15,749 |  | 13,790 |

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Power Generation and Trading

Overview

The following table sets forth certain operating information concerning our electric power generation plants as of December 31, 2012

| Installed | Assured | Year | Installed | Year | Cemig’s
| Capacit | Energy (1) | Commenced | Capacity | Concession or | Interest
Facility |  |  |  |  |  |
| (MW) | (average MW) | Operations | % of Total | Authorization |
|  |  |  |  | Expires |
Hydroelectric Plants |  |  |  |  |  |
São Simão | 1,710.00 | 1,281.00 | 1978 | 23.40% | jan/15 | 100%
Emborcação | 1,192.00 | 497.00 | 1982 | 16.31% | jul/25 | 100%
Nova Ponte | 510.00 | 276.00 | 1994 | 6.98% | jul/25 | 100%
Jaguara | 424.00 | 336.00 | 1971 | 5.80% | aug/13 | 100%
Miranda | 408.00 | 202.00 | 1998 | 5.58% | dec/16 | 100%
Três Marias | 396.00 | 239.00 | 1962 | 5.42% | jul/15 | 100%
Volta Grande | 380.00 | 229.00 | 1974 | 5.20% | feb/17 | 100%
Irapé | 360.00 | 206.30 | 2006 | 4.93% | feb/35 | 100%
Aimorés | 161.70 | 84.28 | 2005 | 2.21% | dec/35 | 49%
Salto Grande | 102.00 | 75.00 | 1956 | 1.40% | jul/15 | 100%
Funil | 88.20 | 43.61 | 2002 | 1.21% | dec/35 | 49%
Queimado | 86.63 | 47.85 | 2004 | 1.19% | jan/33 | 83%
Sá Carvalho | 78.00 | 58.00 | 1951 | 1.07% | dec/24 | 100%
Rosal | 55.00 | 30.00 | 1999 | 0.75% | may/32 | 100%
Itutinga | 52.00 | 28.00 | 1955 | 0.71% | jul/15 | 100%
Amador Aguiar I | 50.53 | 32.63 | 2006 | 0.69% | aug/36 | 21.05%
Baguari | 47.60 | 27.27 | 2009 | 0.65% | aug/41 | 34%
Camargos | 46.00 | 21.00 | 1960 | 0.63% | jul/15 | 100%
Amador Aguiar II | 44.21 | 27.58 | 2007 | 0.60% | aug/36 | 21.05%
Porto Estrela | 37.33 | 18.60 | 2001 | 0.51% | jul/32 | 33.33%
Igarapava | 30.45 | 19.72 | 1999 | 0.42% | dec/28 | 14.5%
Pai Joaquim | 23.00 | 2.41 | 2004 | 0.31% | apr/32 | 1
Piau | 18.01 | 13.53 | 1955 | 0.25% | jul/15 | 100%
Gafanhoto | 14.00 | 6.68 | 1946 | 0.19% | jul/15 | 100%
Cachoeirão | 13.23 | 8.02 | 2008 | 0.18% | jul/30 | 49%
Paracambi | 12.25 | 9.57 | 2012 | 0.17% | feb/31 | 49%
Pipoca | 9.80 | 5.83 | 2010 | 0.13% | sep/31 | 49%
Peti | 9.40 | 6.18 | 1946 | 0.13% | jul/15 | 100%
|  | 2.15 |  |  |  |

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Poço Fundo | 9.16 | 5.79 | 1949 | 0.13% | aug/25 | 100%
Tronqueiras | 8.50 | 4.14 | 1955 | 0.12% | jul/15 | 100%
Joasal | 8.40 | 5.20 | 1950 | 0.11% | jul/15 | 100%
Salto Voltão | 8.20 | 6.63 | 2001 | 0.11% | oct/30 | 100%
Martins | 7.70 | 2.52 | 1947 | 0.11% | jul/15 | 100%
Cajuru | 7.20 | 3.48 | 1959 | 0.10% | jul/15 | 100%
São Bernardo | 6.82 | 3.42 | 1948 | 0.09% | aug/25 | 100%
Paraúna | 4.28 | 1.90 | 1927 | 0.06% | N/A | 100%
Pandeiros | 4.20 | 1.87 | 1957 | 0.06% | sep/21 | 100%
Paciência | 4.08 | 2.36 | 1930 | 0.06% | jul/15 | 100%
Marmelos | 4.00 | 2.88 | 1915 | 0.05% | jul/15 | 100%
Other SHP (3) | 24.08 | 11.11 | N/A | 0.33% | N/A | N/A
Thermoelectric Plants |  |  |  |  |  |
Igarapé | 131.00 | 71.30 | 1978 | 1.86% | aug/24 | 100.0%
Ipatinga | 40.00 | 40.00 | 1986 (2) | 0.57% | dec/14 | 100.0%
Barreiro | 12.90 | 11.37 | 2004 | 0.18% | apr/23 | 100.0%
Wind Farms |  |  |  |  |  |
Praias de Parajuru | 14.11 | 4.11 | 2012 | 0.20% | sep/32 | 49.0%
Praia de Morgado | 14.11 | 6.47 | 2011 | 0.20% | dec/31 | 49.0%
Volta do Rio | 20.58 | 9.02 | 2011 | 0.29% | dec/31 | 49.0%
Light Hydroelectric Plants |  |  |  |  |  |
Fonte Nova | 34.40 | 27.10 | 1940 | 0.49% | jul/29 | 32.5%
Paracambi | 12.30 | 9.60 | 2012 | 0.17% | sep/31 | 51.0%
Ilha dos Pombos | 48.80 | 30.00 | 1924 | 0.69% | jul/29 | 32.5%
Nilo Peçanha | 99.00 | 87.30 | 1940 | 1.41% | jul/29 | 32.5%
Pereira Passos | 26.10 | 13.30 | 1962 | 0.37% | jul/29 | 32.5%
Santa Branca | 14.60 | 8.30 | 1999 | 0.21% | jul/29 | 32.5%
Cachoeira da Lixa | 14.80 | 8.26 | 2008 | 0.21% | dec/33 | 7.2%
Colino 1 | 11.00 | 7.34 | 2008 | 0.16% | dec/33 | 7.2%
Colino 2 | 16.00 | 10.49 | 2008 | 0.23% | dec/33 | 7.2%
TOTAL | 7,023.66 | 4,279.27 | - | 100% | - | -

(1) Assured Energy is the plant’s long-term average output, as established by the Ministry of Mines and Energy (MME) in accordance with studies conducted by the EPE. Calculation of Assured Energy considers such factors as reservoir capacity and connection to other power plants. Contracts with final consumers and other concessionaires do not provide for amounts in excess of a plant’s Assured Energy. MME Resolution 303/2004 changed the term Assured Energy to Physical Guarantee.

(2) Indicates our date of acquisition.

(3) Corresponds to 17 Small Hydroelectric Power Plants: Anil, Bom Jesus do Galho, Dona Rita, Jacutinga, Lages, Luiz Dias, Machado Mineiro, Pissarrão, Poquim, Rio de Pedras, Salto de Morais, Salto do Passo Velho, Salto do Paraopeba, Santa Luzia, Santa Marta, Sumidouro and Xicão.

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The following tables set forth certain additional operating information pertaining to our electricity generation operations as of the dates indicated:

Voltage of Connection Lines |  | Circuit Length of Generation Lines in Miles (from power plants to generation substations) |
|  | As of December 31, |
|  | 2012 |  | 2011 |  | 2010 |
500 kV |  | 7 |  | 7 |  | 7 |
345 to 230 kV |  | 108 |  | 108 |  | 108 |
161 to 138 kV |  | 114(1) |  | 112 |  | 112 |
69 to 13.8 kV |  | 187 |  | 187 |  | 187 |
Total |  | 416 |  | 414 |  | 63 |

|  | Step-Down Transformation Capacity(2) of Generation Substations |
|  | As of December 31, |
|  | 2012 |  | 2011 |  | 2010 |
Number of step-down substations |  | 64 |  | 63 |  | 63 |
MVA |  | 7,445 |  | 7,416 |  | 7,416 | (3)

(1) The circuit length of our 138 KV connection lines increased in 2012 because the Paracambi small Hydroelectric plant began its operations.

(2) This amount does not include the Light acquisition.

(3) Step-down transformation capacity refers to the ability of a transformer to receive energy at a certain voltage and release it at a reduced voltage for further distribution.

Generation Assets

We have incorporated the following subsidiaries in the State of Minas Gerais and other states of Brazil to operate certain of our generation facilities and to hold the related concessions:

Cemig Generation and Transmission S.A. — As of December 31, 2012, we have electricity generation capabilities in 57 hydroelectric plants, three thermoelectric plants and three wind farms, which totals a generation capacity of 6,761 MW, value of which hydroelectric plants accounted for 6,528 MW, thermoelectric plants accounted for 184 MW and wind farms accounted for 49 MW.

In addition to our own plants, Cemig Generation and Transmission participates in the following consortia:

· Igarapava Hydroelectric Power Plant — We have a 14.5% interest in this enterprise and our partners are Vale S.A. (38.2%), Votorantim Metais Zinco S.A. (23.9%), Companhia Siderúrgica Nacional S.A. (17.9%) and Anglogold Ashanti Córrego do Sítio Mineração S.A. (5.5%).

· Queimado Hydroelectric Power Plant — Our partner in this project is CEB Participações S.A. (CEBPar), a subsidiary of Companhia Energética de Brasília, or CEB, a state-controlled electricity company. As per the second Amendment to Concession Contract 006/1997, executed on July 17, 2009, CEB has a 17.5% interest and we have the remaining 82.5%.

· Aimorés Hydroelectric Power Plant —We have a 49% interest in this enterprise and our partner, Vale S.A., has the remaining 51% interest.

· Funil Hydroelectric Power Plant — We have a 49% interest in this enterprise and our partner, Vale S.A., has the remaining 51% interest.

· Porto Estrela Hydroelectric Plant — We have a 33.3% interest in this enterprise and our partners are Vale S.A. (33.3%) and Companhia de Tecidos Norte de Minas — Coteminas (33.3%).

Light S.A. — At December 31, 2012, we generated electricity at five hydroelectric plants with a total installed generation capacity of 866 MW.

Renova Energia S.A. — At December 31, 2012, we generated electricity at three small hydro plants with a total installed generation capacity of 42 MW. Usina Térmica Ipatinga S.A. — We operate the Ipatinga Thermoelectric Power Plant through our subsidiary.

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Usina Térmica Ipatinga S.A. — This plant is an SPP (self power producer) installed and operated within the premises of Usinas Siderúrgicas de Minas Gerais S.A.—USIMINAS, or Usiminas, a large Brazilian steel manufacturer. The plant supplies power to a large steel mill owned by Usiminas, located in eastern Minas Gerais. The plant currently has an installed capacity of 40 MW, generated by two units that began operating in 1986 and that use blast furnace gas as fuel.

Sá Carvalho S.A. — We operate the Sá Carvalho Hydroelectric Power Plant, located on the Piracicaba River in the municipality of Antônio Dias, in the State of Minas Gerais, through our subsidiary Sá Carvalho S.A.. The plant currently has an installed capacity of 78 MW.

Rosal Energia S.A. — In December 2004 we bought the Rosal hydroelectric plant, which has installed capacity of 55 MW, from Caiuá Serviços de Eletricidade S.A., or Caiuá, for a payment of R$134 million. The Rosal plant, the sole asset of Rosal Energia, is located on the Itabapoana River, which runs along the border between the States of Espírito Santo (Municipality of Guaçuí) and Rio de Janeiro (Municipality of Bom Jesus de Itabapoana).

Cemig Capim Branco Energia S.A. — We incorporated Cemig Capim Branco Energia S.A. (21.1%) to develop the Capim Branco Generating Complex in partnership with Vale S.A. (48.4%), a mining company, Comercial e Agrícola Paineiras (17.9%), an agricultural company, and Votorantim Metais Zinco S.A. (12.6%), or VMZ, a metallurgical company. On March 16, 2007, Aneel published Ruling No. 683 approving the change of the name of the Capim Branco Generating Complex to the Amador Aguiar Generating Complex. The project consists of the Amador Aguiar I and Amador Aguiar II Hydroelectric Power Plants, with installed capacity of 240 MW and 210 MW, respectively.

Horizontes Energia S.A. — We formed Horizontes Energia S.A., or Horizontes Energia, to generate and trade electricity as an IPP (independent power producer) through the commercial operation of the following of our smaller hydroelectric plants: the Machado Mineiro Small Hydro Plant (SHP), with an installed capacity of 1.72 MW; the Salto do Paraopeba SHP, with an installed capacity of 2.37 MW; the Salto Voltão SHP, with an installed capacity of 8.2 MW; and the Salto do Passo Velho SHP, with an installed capacity of 1.8 MW, as well as other generating projects to be acquired or built with our participation. The concession relating to the Machado Mineiro SHP expires on July 7, 2025; the concessions relating to the other plants expire on October 4, 2030. The Salto do Paraopeba SHP is currently out of service for refurbishment. We expect that this power plant will resume its operations in 2014.

Usina Termelétrica Barreiro S.A. — We formed Usina Termelétrica Barreiro S.A. to participate, in partnership with V&M do Brasil S.A., or Vallourec & Mannesmann, a metallurgic company, in the construction and operation of the 12.9 MW Barreiro Thermoelectric Power Plant, located on Vallourec & Mannesmann’s premises in the Barreiro neighborhood of the city of Belo Horizonte in Minas Gerais.

Cemig PCH S.A. — We formed Cemig PCH S.A. to generate and trade electric energy as an IPP. Its main activity is the production and sale of electricity through the Pai Joaquim SHP, as an IPP. This plant, located on the Araguari River, has an installed capacity of 23 MW.

Hidrelétrica Cachoeirão S.A. — We formed a special-purpose company named Hidrelétrica Cachoeirão S.A., to build and operate the Cachoeirão SHP. This plant, with an installed capacity of 27 MW, is located on the Manhuaçu River, in the eastern part of Minas Gerais. Cemig Generation and Transmission has a 49% ownership interest in Hidrelétrica Cachoeirão S.A. and Santa Maria Energética has a 51% ownership interest.

Paracambi Small Hydroelectric Power Plant — Cemig Generation and Transmission has also negotiated a stake in the construction and operation of the Paracambi Small Hydroelectric Power Plant, in partnership with Light to implement and operate the project. Cemig Generation and Transmission has a 49% interest in this project and Light has a 51% ownership interest. The plant, with an installed capacity of 25 MW, is located on the Lajes River, in the eastern part of the State of Rio de Janeiro. The concession relating to this plant expires on February, 2031. As of December 31, 2012, we had invested R$203 million in this project.

Baguari Energia S.A .— We operate the Baguari Hydroelectric Power Plant through the Baguari UHE Consortium, in which Baguari Energia has a 49% interest. The power plant has an installed capacity of 140 MW and is located on the Doce River, in the State of Minas Gerais. The energy generated is commercialized in the ACR. Initially, Cemig Generation and Transmission had a 34% interest in this consortium and Furnas Centrais Elétricas S.A. had a 15% interest. On February 2, 2010, Aneel transferred to Baguari Energia the Cemig Generation and Transmission and Furnas Centrais Elétricas S.A joint concession in the Baguari Hydroelectric Power Plant.

Hidrelétrica Pipoca S.A. — Cemig Generation and Transmission has also negotiated a stake in the construction and operation of the Pipoca SHP, in partnership with Omega Energia Renovável S.A., formed by the investment companies “Tarpon Investimentos” and “Warburg Pincus”, to implement and operate the project. Through Cemig Generation and Transmission, we have a 49% interest in

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Hidrelétrica Pipoca S.A. The plant, with an installed capacity of 20 MW, is located on the Manhuaçu River, in the eastern part of the State of Minas Gerais.

Wind Farms

Wind farms are becoming an important means of power generation for the near future. Besides its reduced environmental impact, this energy source is completely renewable and widely available in Brazil, according to recent prospective studies. Also, its fast technical development during recent decades resulted in a lower cost per MWh, compared to other means of power generation. CEMIG is monitoring the accelerated evolution of wind-based power generation and its inclusion in the Brazilian energy portfolio.

Our first wind farm, Morro do Camelinho, began operating in 1994. It is located in Gouveia, a town in northern Minas Gerais. This project is the first wind farm in Brazil to be connected to the national electricity transmission grid. With a total generation capacity of 1 MW, Morro do Camelinho was built through a technical and scientific cooperation agreement with the government of Germany. Taking into account the experimental nature of the facility, and the fact that the equipment used is now obsolescent, Cemig applied to Aneel for permission to de-activate the plant, which was granted on September 2, 2010. On August 15, 2009, Cemig Generation and Transmission’s purchased from Energimp S.A. a 49% interest in three wind farms located in the State of Ceará, for the amount of R$223 million. The three wind farms, named UHE Praia do Morgado, UHE Praias de Parajuru and UHE Volta do Rio, have a total installed capacity of 99.6 MW.

Central Eólica Praias de Parajuru S.A. is located in the city of Beberibe, in the State of Ceará. The commercial operation started in August 2009. All of its generation, totaling 73,525 MWh in 2012, has been sold to Eletrobras, under the Proinfa Program for a period of 20 years.

Central Eólica Praia do Morgado S.A is located in the city of Acaraú, in the State of Ceará. The commercial operation started in May 2010. All its generation, totaling 59.117 MWh in 2012, has been sold to Eletrobrás, under the Proinfa Program for a period of 20 years.

Central Eólica Volta do Rio S.A is located in the city of Acaraú, in the State of Ceará. The commercial operation started in September 2010. All its electricity, totaling 161,238 MWh in 2012, has been sold to Eletrobrás, under the Proinfa Program for a period of 20 years.

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The chart below sets forth the geographic distribution of majority of our generation plants, including subsidiaries and affiliates:

Expansion of Generation Capacity

We are currently involved in the construction of six hydroelectric power plants— Dores de Guanhães, Senhora do Porto, Fortuna II, Jacaré, Santo Antônio and Belo Monte —that will increase the installed generation capacity of our hydroelectric facilities by 1,280 MW over the next 6 years. The following is a brief description of these projects, the completion of which are subject to various contingencies, certain of which are beyond our control.

SPE Guanhães Energia S.A. — Cemig Generation and Transmission has negotiated an ownership interest in the construction and operation of the Small Hydro Plants, or PCHs, of Dores de Guanhães, Senhora do Porto, Fortuna II and Jacaré. In August 2012, Light Energia acquired from our partner in this project, Investminas Participações S. A., a wholly owned subsidiary of GlobalBank Participações e Investimentos S.A, 100% of its holdings in the company Guanhães Energia S.A, or Guanhães Energia. As a result, Cemig Generation and Transmission has a 49% ownership interest in Guanhães Energia, while Light Energia has the remaining 51%. The purpose of Guanhães Energia is to build and operate these four PCHs, namely: Dores de Guanhães, with 14 MW installed capacity; Senhora do Porto, with 12 MW capacity; Jacaré, with 9 MW; and Fortuna II, with 9 MW. Dores de Guanhães, Senhora do Porto and Jacaré are being built on the Guanhães River, located in the municipality of Dores de Guanhães, State of Minas Gerais, and Fortuna II is being built on the Corrente Grande River, located in the municipalities of Guanhães and Virginópolis, State of Minas Gerais. Construction began in September 2012, and commercial operation is expected to begin in the first half of 2014. The concessions relating to these plants expire in December 2031 with respect to Fortuna II, November 2032 with respect to Dores de Guanhães and October 2032 with respect to Senhora do Porto and Jacaré. As of December 31, 2012, we had invested R$29 million in this project.

Madeira Energia S.A. — MESA is a special-purpose company created to implement, build, operate and maintain the Santo Antônio hydroelectric plant, in the basin of the Madeira River, in the northern region of Brazil. This facility will have a generating capacity of 3,150 MW. The Santo Antônio hydroelectric plant began its operation in March 2012, nine months in advance of the

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original schedule. Cemig Generation and Transmission has a 10% interest in MESA, and based on our ownership interest, we expect to invest R$1,676 million in the development of the project.

Norte Energia S.A. — NESA Since October 2011 Cemig Generation and Transmission owns 74.5% of theAmazônia Energia SPE together with Light Energy, which owns the remaining 25.5%. Amazônia Energia holds 9.77% of a concession to implement, operate and maintain the Belo Monte Hydroelectric Plant, in the Xingu River, in the northern region of Brazil via another SPE, Norte Energia S.A. At the end of 2012 the Belo Monte Hydroelectric Plant was about 20% complete, putting it on schedule for completion in 01/31/2019, an important achievement given the start-up challenges of a 11,233MW hydroelectric power plant, the biggest currently under construction in the world, located in the Amazon Forest. More than 85% of the construction and the equipment required to complete the project have been contracted for, however, the project is still in its initial development phase. The Brazilian Government Development Bank (Banco Nancional de Desenvolvimento, or “BNDES”) along with two other financing banks loaned R$22.5 billion for the completion of the project, which we believe to be another significant milestone for the project. Cemig will invest R$ 603 million as equity capital in the project until 2016.

Consortium UHE Itaocara — In 2008, Cemig Generation and Transmission took part in a consortia (49% of interest) with Itaocara Energia Ltda, a special-purpose owned by Light S.A., created to implement, build, operate and maintain the Itaocara Hydroelectric Power Plant. The plant, with a generating capacity of 151 MW, is located on the Paraíba do Sul River, between the municipalities of Itaocara and Aperibé, in Rio de Janeiro state. Construction is expected to begin in 2013.

Renova Energia S.A. — Light Energia S.A., which is a subsidiary of Light S.A., holds 32.31% common shares and 21.99% of Renova’s total capital. Renova is a company generating electricity from renewable sources focused on wind farms and small hydroelectric plants (PCHs). Renova sold a total of 703MW of installed electricity generation capacity in the reserve energy auctions of 2009 and 2010, the A—3 auction of 2011 and the A-5 auction of 2012. Renova has a current portfolio of 2,051 MW of wind projects and 1,472 of PCHs and other projects in development. Renova is the first and sole company engaged in the generation of alternative electricity trading on the BM&FBovespa. Light’s investment in Renova was R$360 million, which was used for the installation of wind farms.

Co-generation Joint Ventures with Consumers

We intend to enter into joint ventures with industrial consumers to develop co-generation facilities. These facilities would be built on consumers’ premises and would generate electricity using fuel supplied by the consumers’ industrial processes. Each co-generation project would be funded in part through an agreement with the particular consumer to purchase the electricity generated in that consumer’s facility. We would assume the responsibility for operating and maintaining the co-generation facility.

Power Trading

Under the present regulations of the Brazilian electricity sector, power generation companies are allowed to operate in trading as well as the sale of their own production. CEMIG started intensifying this activity in 2009, which is complementary to the sale of its own generation, buying electricity for future sale through its power generation and trading subsidiaries, aiming further to increase the company’s results. CEMIG’s wholesale commercialization policy is approved by the Board of Directors and the transactions are individually approved by the Executive Board.

These transactions were previously submitted for analysis by the Energy Risks Management Committee, in which representatives of various areas of CEMIG — financial, legal, commercial, regulatory and planning — participate, for the purpose of determining the risks and results expected, using, for this, analysis of market conditions, hydrology simulation models, energy risk models, estimates of spot prices and calculation of the profit at risk.

The results of the trading activities depend on market conditions, which may be different from the company’s expectations. To mitigate this risk, CEMIG seeks to avoid carrying positions, selling the electricity bought as soon as possible.

Transmission

Overview

Our transmission business mainly consists of the transfer of electricity from generation power plants to consumer agents directly connected in the basic transmission grid, final consumers and distribution companies. The transmission system is comprised of transmission lines and step-down substations with voltages ranging from 230 kV to 500 kV.

During the year ended December 31, 2012, our transmission businesses recorded revenues totaling R$ 1,680 million. In turn, our usage of the basic transmission grid by connected generation power plants and distribution systems and electricity purchases from

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Itaipu and others suppliers requires us to pay scheduled rates to the ONS, and owners of different parts of the basic transmission grid. See “-The Brazilian Power Industry” and “Item 5. Operating and Financial Review and Prospects.”

Cemig Generation and Transmission transported 5,468 GWh in 2012 serving 15 high voltage industrial Free Consumers located in the State of Minas Gerais.

The following tables set forth certain operating information pertaining to our transmission capacity for the dates indicated:

|  | Circuit Length of Transmission Lines in Miles |
|  | As of December 31, |
Voltage of Transmission Lines |  | 2012 |  | 2011 |  | 2010 |
>525 kV |  | 40 |  | 55 |  | 38 |
500 kV |  | 3,042 |  | 3,155 |  | 2,663 |
440 kV |  | 135 |  | 177 |  | 177 |
345 kV |  | 1,286 |  | 1,223 |  | 1,347 |
230 kV |  | 1,343 |  | 1,197 |  | 909 |
Total |  | 5,847 |  | 5,807 |  | 5,134 |

|  | Transformation Capacity(1) of Transmission Substations |
|  | As of December 31, |
Voltage of Transmission Lines |  | 2012 |  | 2011 |  | 2010 |
Number of transmission substations |  | 60(2) |  | 60(2) |  | 58(2) |
MVA |  | 18,834 |  | 18,438 |  | 18,079 |

(1) Transformation capacity refers to the ability of a transformer to receive energy at a certain voltage and release it at a reduced voltage for further distribution.

(2) Does not consider the shared substations.

Transmission Assets

Montes Claros-Irapé (Transleste) — In September 2003, a consortium formed by Companhia Técnica de Engenharia Elétrica—ALUSA, or ALUSA (holding a 41% interest), Furnas (holding a 24% interest), Orteng Equipamentos e Sistemas Ltda., or Orteng (holding a 10% interest), and CEMIG (holding a 25% interest) won the concession auctioned by Aneel to the Montes Claros-Irapé transmission line. As required in the bidding process, the partners formed the Companhia Transleste de Transmissão, which is responsible for building and operating the transmission line. This 345 kV transmission line connects a substation located in Montes Claros, a city in northern Minas Gerais, and the substation of the Irapé Hydroelectric Power Plant, with a length of approximately 86 miles. Transmission line operations began in December 2005 and the concession expires in February 2034.

Itutinga-Juiz de Fora (Transudeste)— In September 2004, a consortium formed by ALUSA, Furnas, Orteng and CEMIG, with interests of 41%, 25%, 10%, and 24% respectively, won the concession auctioned by Aneel to the Itutinga-Juiz de Fora transmission line. As required in the bidding process, the partners formed the Companhia Transudeste de Transmissão, which is responsible for building and operating this transmission line. This 345 kV transmission line, with a length of approximately 89 miles, connects the substation of the Itutinga Hydroelectric Power Plant and a substation located in Juiz de Fora, a city in southeastern Minas Gerais. Commercial operations began in February 2007 and the concession expires in March 2035.

Irapé-Araçuaí (Transirapé) — In November 2004, a consortium formed by ALUSA, Furnas, Orteng and CEMIG with interests of 41%, 24.5%, 10% and 24.5% respectively, won the concession auctioned by Aneel to the Irapé-Araçuaí transmission line. As required in the bidding process, the partners formed the Companhia Transirapé de Transmissão, which is responsible for building and operating this transmission line. This 230 kV transmission line, with a length of approximately 38 miles, connects the substation of the Irapé Hydroelectric Power Plant and a substation in Araçuaí, a city located in northeastern Minas Gerais. Commercial operations began in May 2007 and the concession expires in March 2035.

Furnas-Pimenta (Centroeste) — In September 2004, a consortium formed by Furnas and CEMIG, with interests of 49%, and 51%, respectively, won the concession auctioned by Aneel to the Furnas-Pimenta transmission line. As required in the bidding process, the partners formed the Companhia de Transmissão Centroeste, which is responsible for building and operating the transmission line. This 345 kV transmission line, with a length of approximately 47 miles, connects the substation of the Furnas

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Hydroelectric Power Plant and a substation located in Pimenta, a city in the west-central region of Minas Gerais. Its commercial operation began in March 2010 and the concession expires in March 2035.

Charrúa—Nueva Temuco (Transchile) — In April 2005 a consortium formed by ALUSA and CEMIG, with interests of 51% and 49%, respectively, won the concession auctioned by Centro de Despacho Económico de Carga del Sistema Interconectado Central, or CDEC—SIC, of Chile to build, operate and maintain the Charrúa—Nueva Temuco 220 kV transmission line for 20 years. This was an important event in CEMIG’s history, as it was our first asset outside of Brazil. We and ALUSA formed Transchile Charrúa Transmisión S.A., an SPC incorporated in Chile and responsible for building and operating the transmission line. With a length of approximately 127 miles, the transmission line connects the substations of Charrúa and Nueva Temuco in central Chile. We began the project in June 2005 and construction began in April 2007. On July 18, 2007, Transchile Charrúa Transmisión S.A. entered into a project finance agreement with the Inter-American Development Bank in the amount of US$51.0 million related to the transmission line and substations. Commercial operation began in January 2010.

TAESA — On December 31, 2012, CEMIG had direct investments (jointly controlled) in TAESA, that owns the following assets:

Company | Miles | Capacity (kV) | Operation | Concession Contract | Concession Expiration Date
TSN- Transmissora Sudeste Nordeste S.A. | 664 | 500kV | April/03 | 097/2000 | 12/20/2030
| 4 | 230kV |  |  |
Munirah-Transmissora de Energia S.A. | 66 | 500kV | November/05 | 006/2004 | 02/18/2034
Gtesa- Goiânia Transmissora de Energia | 32 | 230kV | July/03 | 001/2002 | 01/21/2032
Patesa-Paraíso Açu Transmissora de Energia S.A. | 84 | 230kV | March/04 | 087/2002 | 12/11/2032
Novatrans Energia S.A. | 794 | 500kV | April/04 | 095/2000 | 12/20/2030
ETAU-Empresa de Transmissão Alto Uruguai S.A. | 117 | 230kV | May/05 | 082/2002 | 12/18/2032
ETEO- Empresa de Transmissão de Energia do Oeste S.A. | 312 | 440kV | October/01 | 040/2000 | 05/12/2030
Brasnorte Transmissora de Energia S.A. | 237 | 230kV | August/09 | 003/2008 | 03/17/2038
NTE - Nordeste Transmissora de Energia S.A. | 116 | 500 Kv | February/02 | 002/2002 | 01/21/2032
| 122 | 230 kV |  |  |
ATE Transmissora de Energia S.A. | 230 | 525 kV | February/04 | 003/2004 | 02/18/2034
ATE II Transmissora de Energia S.A. | 585 | 500 kV | March/05 | 011/2005 | 03/15/2035
ATE III Transmissora de Energia S.A. | 214 | 500 kV | March/06 | 001/2006 | 03/27/2036
| 68 | 230 kV |  |  |
STE – Sul Transmissora de Energia S.A | 242 | 230 kV | December/02 | 081/2002 | 12/19/2032
SGTE - São Gotardo Transmissora de Energia S.A. | 0 | 345 kV | Expected to start operating in Feb/2014 | 024/2012 | 08/2042

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On December 31, 2012, CEMIG had direct investments (jointly controlled) in EATE, ECTE, ENTE, ERTE, ETEP and EBTE, and indirect investments in STC, Lumitrans, and Empresa Santos Dumont de Energia S.A.(“ESDE”) as shown in the table below.

Company |  | Connection |  | Length (Miles) |  | Capacity (kV) |  | Operation |  | Concession contract (2) |  | Concession Expiration Date
EATE (1) |  | Tucuruí (Pará) to Presidente Dutra (Maranhão) |  | 576 |  | 500 |  | March/2003 |  | June 12, 2001 |  | June 12, 2031
ECTE (1) |  | Campos Novos (Santa Catarina) to Blumenau (Santa Catarina) |  | 157 |  | 525 |  | March/2002 |  | November 1, 2000 |  | November 1, 2030
ENTE (1) |  | Tucuruí (Pará) to Açailândia (Maranhão) |  | 285 |  | 500 |  | February/2005 |  | December 11, 2002 |  | December 11, 2032
ERTE (1) |  | Vila do Conde (Pará) to Santa Maria (Pará) |  | 96 |  | 230 |  | September/2004 |  | December 11, 2002 |  | December 11 2032
ETEP (1) |  | Tucuruí (Parã) to Vila do Conde (Pará) |  | 201 |  | 500 |  | August/2002 |  | June 12, 2001 |  | June 12, 2031
Lumitrans (1) |  | Machadinho – Campos Novos |  | 24.8 |  | 525 |  | October/2007 |  | February 18, 2004 |  | February 18, 2034
STC (1) |  | Barra Grande – Lajes- Rio do Sul |  | 114.3 |  | 230 |  | November/2007 |  | April 27, 2006 |  | April 27, 2036
|  | Brasnorte-Juba, Brasnorte-Parecis |  | 486 |  | 230 |  |  |  |  |  |
EBTE |  | Brasnorte- Juína,Nova Mutum-Sorriso, |  | 486 |  | 230 |  | June/2011 |  | October 16, 2008 |  | October 16, 2038
|  | Sorriso- Sinop |  |  |  |  |  |  |  |  |  |
ESDE |  | LT Barbacena 2 - Santos Dumont |  | 1.8 |  | 345 |  | Expected to start operating in Feb/2013 |  | November 19, 2009 |  | November 19, 2039
|  | LT Santos Dumont - Juiz de Fora I |  |  |  |  |  |  |  |  |  |

(1) The operation and maintenance of transmission lines of EATE, ENTE and ERTE are carried out by Eletronorte-Centrais Elétricas do Norte do Brasil S.A. or Eletronorte and of ECTE by Celesc and Eletrosul and of STC by Celesc and Lumitrans by Eletrosul.

(2) Right acquired for commercial operation of public electricity transmission services for 30 years, renewable for the same period of time.

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The chart below sets the geographic distribution of CEMIG’s transmission assets:

Expansion of Transmission Capacity

Empresa de Transmissão Serrana S.A. – A special-purpose company created in January, 2012 by ECTE, a jontly controlled company owned by CEMIG (19,09% interest), Alupar Investimento S.A. (42,51% interest), Centrais Elétricas de Santa Catarina S.A. (30,89% interest) and MDU Resources Luxembourg II LLC, S.à.r.l.. (7,51% interest) , to build and operate the substations Abdon Batista, with rated voltages of 525/230 kV and a projected transformation capacity of 1568 MVA, and Gaspar 2 , with rated voltages of 230/138 kV and a projected transformation capacity of 300 MVA, both in the state of Santa Catarina. ECTE won the concession auctioned by Aneel (Auction 006/2011). The substation aims to connect the power plants Garibaldi and São Roque to the Brazilian National Grid System (Sistema Integrado Nacional, or SIN), and expand the supply of electricity in the region of the Itajaí Valley. The works are scheduled to be completed by May 2014.

Empresa Santos Dumont de Energia S.A. – A special-purpose company created in November, 2009 by ETEP, a jontly controlled company owned by CEMIG (49,98% interest) and Alupar Investimento S.A. (50,01% interest), to build and operate the substations Santos Dumont 2, with rated voltages of 345/138 kV and a projected transformation capacity of 375 MVA and Satatic Var Compensator (“SVC”) of -88/+100 MVAr, both in the state of Minas Gerais. ESDE won the concession auctioned by Aneel (Auction 001/2009).

São Gotardo Transmissora de Energia S.A. –In June 2012, at Aneel Auction 005/2012, TAESA was awarded the Lot E concession for the construction, operation and maintenance of the São Gotardo 2 345/138 kV 300 MVA substation, in Minas Gerais, for a RAP of R$3.8 million.

Distribution and Purchase of Electric Power

Overview

Our distribution operation consists of electricity transfers from distribution substations to final consumers. Our distribution network is comprised of a widespread network of overhead and underground lines and substations with voltages lower than 230 kV. We supply electricity to small industrial consumers at the higher end of the voltage range and residential and commercial consumers at the lower end of the range.

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From January 1, 2012 through December 31, 2012, we invested approximately R$1,446 million in the construction and acquisition of property, plant and equipment used to expand our distribution system.

The following tables provide certain operating information pertaining to our distribution system, as of the dates presented:

|  | Circuit Length of Distribution Lines in Miles - High Voltage (from distribution substations to final consumers) |
|  | As of December 31, |
Voltage of Distribution Lines |  | 2012 |  | 2011 |  | 2010 |
161 kV |  | 34.2 |  | 34.2 |  | 34.2 |
138 kV |  | 7,158.5 |  | 7,073.3 |  | 7,012.8 |
69 kV |  | 3,059.9 |  | 3,009.9 |  | 2,980.7 |
34.5 kV + Others |  | 593.4 |  | 593.4 |  | 593.4 |
Total |  | 10,710.8 |  | 10,710.8 |  | 10,621.1 |

|  | Circuit Length of Distribution Lines in Miles - Medium and Low Voltage (from distribution substations to final consumers) |
|  | As of December 31, |
Type of Distribution Lines |  | 2012 |  | 2011 |  | 2010 |
Overhead urban distribution lines |  | 58,109.26 |  | 56,931.3 |  | 56,406.7 |
Underground urban distribution lines |  | 426.97 |  | 426.9 |  | 426.9 |
Overhead rural distribution lines |  | 239,381.83 |  | 234,785.0 |  | 225,227.8 |
Total |  | 297,864.46 |  | 292,143.2 |  | 282,061.4 |

|  | Step-Down Transformation Capacity(1) of Distribution Substations |
|  | As of December 31, |
|  | 2012 |  | 2011 |  | 2010 |
Number of substations |  | 370 |  | 366 |  | 364 |
MVA |  | 9,178.0 |  | 8,623.5 |  | 8,427.0 |

(1) Step-down transformation capacity refers to the ability of a transformer to receive energy at a certain voltage and release it at a reduced voltage for further distribution.

Expansion of Distribution Capacity

Our distribution expansion plan for the next five years is based on projections of market growth. For the next five years, we anticipate an increase of approximately 1.22 million new urban consumers and 45,000 rural consumers. In order to accommodate this growth, we expect that we will need to add 159,562 medium-voltage poles, 736 miles of transmission lines and 14 step-down substations, adding 656 MVA to our distribution network, increasing the network’s installed capacity by 1,258 MVA, including reinforcement. The investment forecasts for the five year period from 2013 to 2017 presented above were prepared on the basis of our budget availability, however, our future budget is still in the process of approval by our Budget Prioritization Committee, which is considering the structural changes as a result of recent regulatory changes in the energy sector. Ongoing projects for development of our distribution capacity include the following:

Cresce Minas — The Grow Minas (Cresce Minas) project was launched in 2007 to revitalize and expand the distribution system of the State of Minas Gerais, improving the reliability of the system and increasing the quality of service to consumers. The project is expected to benefit approximately 340 municipalities (41% of the total) of Minas Gerais, encompassing a total population of approximately 4.1 million, including approximately 1.1 million consumers. In 2012, Cemig invested R$9 million in capital expenditures exclusively to strengthen the medium-voltage distribution system, out of a total of R$270 million projected. Cemig also invested R$56 million in 2012 to strengthen the sub-transmission system, out of a total of R$480 million projected. The Grow Minas project finished in 2012 and the aggregate amount invested was R$750 milion as planned.

Purchase of Electric Power

During the year ended December 31, 2012, we purchased 8.421,503 GWh of electricity from Itaipu, which represented approximately 27.3% of the electricity we sold to final users, and 667.23GWh (2.2%) of electricity from Proinfa. In addition to the electricity purchased from Itaipu and Proinfa, we have two other basic types of supply arrangements: (i) purchases through public auctions, which accounted for approximately 64.7% of the electricity purchased for resale during the year ended December 31, 2012,

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and (ii) long-term agreements existing prior to the New Industry Model Law, which represented approximately 5.8% of the electricity purchased in 2012.

Itaipu — Itaipu is one of the largest operating hydroelectric plants in the world, with an installed capacity of 14,000 MW. Centrais Elétricas Brasileiras S.A., or Eletrobrás, a holding company controlled by the Federal Government, owns a 50% interest in Itaipu, while the remaining 50% is owned by the government of Paraguay. Brazil, pursuant to its 1973 treaty with Paraguay, has the option to purchase all of the electricity generated by Itaipu that is not consumed by Paraguay. Brazil generally purchases more than 95% of the electricity generated by Itaipu.

We are one of the power distribution companies operating in the south, southeast and west-central regions of Brazil that are jointly required to purchase all of Brazil’s portion of the electricity generated by Itaipu, in accordance with the Law 5.899/1973. The Federal Government allocates Brazil’s portion of Itaipu’s power among these electric companies in amounts proportionate to their respective historical market share of total electricity sales. Aneel enacted Resolution 1240/2011 requiring Cemig Distribution and Light Serviçoes de Eletricidade S.A. to purchase 13.31% and 8.46%, respectively, of the total amount of electricity purchased by Brazil from Itaipu during 2012, at rates fixed to defray Itaipu’s operating expenses and payments of principal and interest on Itaipu’s dollar-denominated borrowings and the cost in reais of transmitting such power to the interconnected power system. These rates have been above the national average for bulk supply of power and are calculated in U.S. dollars. Therefore, fluctuations in the U.S. dollar/real exchange rate affect the cost, in real terms, of electricity we are required to purchase from Itaipu. Historically, we have been able to recover the cost of such electricity by charging supply rates to consumers. According to our concession agreement, increases in the supply rates may be transferred to the final consumer upon approval by Aneel. Like Cemig Distribution, Light, is located in the Southeast / Midwest Interconnected National System, and therefore shares the same obligation to purchase energy from Itaipu.

Since 2007, Aneel publishes at the end of each year the amount of electricity to be purchased from Itaipu by each of the electric power distribution companies for the following year, as a guidance for the five subsequent years. Based on this, the distribution companies can estimate their remaining energy needs in advance of the next public auctions.

Auction Contracts — We purchased electricity in public auctions at the CCEE. These contracts were formalized between CEMIG and the several sellers in accordance with the terms and conditions established in the invitation to bid. The following table sets forth the amounts of electricity contracted, average original tariff and prices related to the CCEAR contracts arising from the electricity acquired by CEMIG. See “—The Brazilian Power Industry” for more information on CCEE and CCEAR.

Average Tariff(R$/MWh)) |  | Electricity Contracted (MW — average per year) |  | Term of the Contract |
57.51 |  |  | 530.17 |  |  | 2005 to 2012 |
67.33 |  |  | 919.14 |  |  | 2006 to 2013 |
83.13 |  |  | 105.47 |  |  | 2008 to 2015 |
79.99 |  |  | 18.15 |  |  | 2012 to 2014 |
106.95 |  |  | 4.47 |  |  | 2008 to 2037 |
132.27 |  |  | 35.31 |  |  | 2008 to 2022 |
114.28 |  |  | 3.16 |  |  | 2009 to 2038 |
126.77 |  |  | 60.41 |  |  | 2009 to 2038 |
129.26 |  |  | 40.36 |  |  | 2009 to 2023 |
132.39 |  |  | 31.02 |  |  | 2009 to 2023 |
115.05 |  |  | 91.77 |  |  | 2010 to 2039 |
134.99 |  |  | 20.12 |  |  | 2010 to 2039 |
121.81 |  |  | 88.98 |  |  | 2010 to 2024 |
138.85 |  |  | 61.23 |  |  | 2010 to 2024 |
134.67 |  |  | 431.17 |  |  | 2010 to 2024 |
120.86 |  |  | 24.71 |  |  | 2011 to 2040 |
137.44 |  |  | 23.24 |  |  | 2011 to 2025 |
128.42 |  |  | 63.89 |  |  | 2011 to 2025 |
129.14 |  |  | 56.57 |  |  | 2012 to 2041 |
128.37 |  |  | 126.34 |  |  | 2012 to 2026 |
78.87 |  |  | 122.83 |  |  | 2012 to 2041 |
77.97 |  |  | 457.75 |  |  | 2015 to 2044 |
102.00 |  |  | 52.76 |  |  | 2014 to 2044 |
80.10 |  |  | 336.40 |  |  | 2014 to 2033 |
99.48 |  |  | 46.80 |  |  | 2015 to 2044 |
67.31 |  |  | 136.73 |  |  | 2015 to 2044 |

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Cemig Generation and Transmission was involved in the A-1 Auction sponsored by Aneel in 2011 trading 85 average-MW per year at the price of R$80.00/MWh.

The operational strategy of Cemig Generation and Transmission in energy auctions on the ACR is based on assumptions set by its management such as approved futures price curve and the balance of power structure, which defines availability to be directed to agents in this market, aiming to maximize revenue and net income while minimizing the volatility of operating cash flow.

Bilateral Agreements — Cemig Distribution entered into bilateral agreements with various suppliers prior to the enactment of the New Industry Model Law in 2004. Such agreements are valid under their original terms but cannot be renewed. During the year ended December 31, 2012, Cemig Distribution purchased 1.803,346 GWh pursuant to these agreements, which represented 5.8% of the total electricity purchased by Cemig Distribution during 2012.

Other Businesses

Natural Gas Distribution

Gasmig was established in Minas Gerais, Brazil, in 1986 for the purpose of developing and implementing the distribution of natural gas in Minas Gerais. CEMIG holds approximately 60% of Gasmig while Petrobras, through its subsidiary Gaspetro—Petrobras Gas S.A., holds 40%. The remaining shares are owned by the city of Belo Horizonte. In July 1995, the State Government granted Gasmig an exclusive 30-year concession (counting from January 1993) for distribution of natural gas covering the entire State of Minas Gerais and consumers located within it. Gasmig’s marketing efforts focus on its ability to provide a more economically efficient and environmentally friendly alternative to oil, liquefied petroleum gas, or LPG, and wood. In 2012, Gasmig supplied approximately 3.6 million cubic meters of natural gas per day to 313 consumers in thirty cities: 111 large and medium industrial plants, 106 small industrial plants and commercial consumers, 86 retail distribution stations for natural gas vehicles, 2 thermal power plants, and 8 distributors of compressed natural gas, or CNG. Additionaly 40 residential units have been connected to the gas network and are ready for use. In 2012, Gasmig distributed approximately 6.3% of all natural gas distributed in Brazil.

Gaspetro acquired its 40% equity interest in Gasmig pursuant to an Association Agreement dated August 25, 2004, among CEMIG, Gasmig, Gaspetro and Petrobras. Under the terms of the Association Agreement, Petrobras agreed to make investments to expand the capacity of the current pipelines connected to the Gasmig distribution network and to construct new pipelines, and CEMIG and Gaspetro agreed to fund Gasmig’s capital expenditure plan to expand its distribution network.

The transaction was implemented on December 15, 2004 when Petrobras, through its subsidiaries Gaspetro and TSS, concluded its acquisition of a 40% equity interest in Gasmig. On July 26, 2006, TSS was merged into Gasmig. As a condition to such investment, Petrobras and CEMIG entered into a Shareholders Agreement in which CEMIG agreed with Petrobras and its subsidiaries to share in the management of Gasmig. On December 15, 2004, Gasmig executed an additional supply contract with Petrobras which guarantees a gradual increase in supply of up to 5.1 million m³/day of natural gas, within a period of 20 years, in addition to the 3.5 million m³/day that was previously contracted for. This additional supply agreement is for the supply of natural gas to the regions of the Vale do Aço (Steel Valley) in Minas Gerais and in the south of Minas Gerais, and also for the expansion of service to the regions of the Greater Belo Horizonte area, the Zona da Mata (in the southeast of Minas Gerais) and the Campos das Vertentes (historic region), in the industrial, commercial, automotive and residential markets. The additional supply agreement (Contrato de Suprimento Adicional – CSA) has a term of 20 years, and we began commercial supply pursuant to the agreement in May 2010. Under this agreement the price is established based on a basket of oil prices in the international market. Our association with Petrobras expanded Gasmig’s distribution capacity and from May 2010 to December 2012, Gasmig’s natural gas sales increased by approximately 47%. We expect that Gasmig’s capital expenditures for 2013 will be mostly used for the expansion of our distribution network and growth of CNG and in the residential segment. Gasmig has already completed the necessary expansion to serve the regions of the Vale do Aço (Steel Valley) and the southern region of the State of Minas Gerais.

Our relationship with Petrobras is governed by two long term agreements, expiring in 2020 and 2030. The price Gasmig charges its consumers is based on the price charged by Petrobras plus a margin. Therefore, all cost increases in Gasmig’s purchase of natural gas are passed on to its consumers through rates increases.

Many energy-intensive industries such as cement, steel, ferroalloys and metallurgy have significant operations in Minas Gerais. We estimate that the total demand for natural gas in Minas Gerais will amount to nearly 3.8 million cubic meters of gas per day by 2013. Gasmig’s key strategy is to expand its distribution network in order to serve the portion of the demand not yet reached. Gasmig is engaged in the development of new projects to extend its natural gas distribution grid to reach consumers in other areas of Minas Gerais, mainly in heavily industrialized areas. In 2006, Gasmig began supplying natural gas to three industrial companies, in the region of the Vale do Aço (Steel Valley) in Minas Gerais, thus concluding the first phase of service to that region of the State of Minas Gerais. The average volume of natural gas distributed in the first phase was approximately 200,000 cubic meters/day. The

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second phase, which began in 2009, was concluded in 2010, adding 155 miles to Gasmig’s networks, and approximately 1 million m³ per day to Gasmig’s market in 2012.

In 2012, Gasmig invested approximately R$41.7 million in the expansion of its gas pipeline network to serve more consumers in the State of Minas Gerais. The funds to finance the expansion came primarily from its own cash flow and loans from the BNDES. The capacity of the natural gas pipeline which brings natural gas from the Campos oil basin (State of Rio de Janeiro, Brazil) was increased in 2010 through an expansion carried out by Petrobras.

Exploration and Production of Crude Oil and Natural Gas

On December 18, 2008, CEMIG and its partners, Companhia de Desenvolvimento Econômico de Minas Gerais - Codemig, (“Codemig”), Imetame Energia S.A. (“Imetame”, formerly called Comp Exploração e Produção de Petróleo e Gás S.A.), Sipet Agropastoril Ltda. (“Sipet”) and Orteng Equipamentos e Sistemas Ltda. (“Orteng”), participated in the Brazil Round 10 Auction carried out by the National Agency of Oil, Natural Gas and Biofuels (Agência Nacional do Petróleo, Gás Natural e Biocombustíveis), or ANP, and was granted the execution of concession agreements for four exploratory blocks in the São Francisco Basin, one block in the Potiguar Basin, and one block in the Recôncavo Basin. On June 30, 2009, the consortia formed by CEMIG, Codemig, Imetame, Sipet, and Orteng signed the concession agreements regarding three blocks. The participation of both CEMIG and Codemig is 24.5% each. The total participation of Imetame, Sipet, and Orteng is 51%, but the individual participation of these three companies varies, depending on the block. On July 7, 2010, CEMIG, Codemig and Imetame formed three consortia to be responsible for the concession agreements regarding three other blocks. The three consortia have the same composition: CEMIG – 24.5%, Codemig – 24.5%, and Imetame – 51%. These consortia signed the concession agreements regarding these three blocks on October 7, 2011. CEMIG’s projected investment is not expected to exceed R$30 million in the exploration phase.

Telecommunications, Internet and Cable Television

On January 13, 1999, Cemig Telecomunicações S.A., or Cemig Telecomunicações, was incorporated in Minas Gerais, Brazil, as a joint venture with AES Força Empreendimentos Ltda., an affiliate of AES Corporation Group. Currently, we own an equity interest of 99.9% in the capital stock of Cemig Telecomunicações.

Cemig Telecomunicações started its business operations in January 2001. The main telecommunication services provided by Cemig Telecomunicações S.A. through its network are signal transportation and access, both for point-to-point and point-to-multipoint applications, delivered mainly to telecommunications operators and Internet service providers on a clear channel basis. Cemig Telecomunicações is also extending its broadband Internet services.

Cemig Telecomunicações provides the network for cable television service in 12 cities in Minas Gerais pursuant to a 15-year service agreement, that expires on December 31, 2015, with WAY TV Belo Horizonte S.A. (“OITV”), and Brasil Telecomunicações, each a holder of concessions to provide cable television and Internet service in certain cities in Minas Gerais, under which Cemig Telecomunicações allows these companies to use its network infrastructure. In return, Brasil Telecomunicações is obligated to deliver to Cemig Telecomunicações a percentage of the revenues derived from their cable television and Internet services and OITV pays per kilometer of the network used.

Cemig Telecomunicações also provides intra-company data transmission services to us pursuant to a five-year agreement signed in 2001 and renewed in October 2007. We use this service for internal communications as well as for certain communications with our consumers.

On June 30, 2010, the Board of Directors of Cemig Telecomunicações approved the execution of the share purchase and sale agreement for the acquisition by Cemig Telecomunicações of 49% of the common shares issued by Ativas Data Center S.A., or Ativas. Ativas provides infrastructure services for Information and Communication Technology (ICT), including hosting, placement, storage and database site backup, professional services, information security and availability.

In September, 2010 Cemig Telecomunicações signed an agreement with AlgarTelecom to provide services in GPON (Gigabit Passive Optical Network). The GPON Project consists of a Triple Play (Data, Voice and Video) service, to be offered first to condominiums in the greater Belo Horizonte area, through an ultra-high band FTTH (Fiber To The Home) network using the GPON technology. This technology offers enormous data transmission capacity, simple and low-cost installation and maintenance.

Consulting and Other Services

We provide consulting services to governments and public utility companies in the electricity industry in order to derive additional revenues from the technology and expertise we have developed through our operations. During the past ten years, we have

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provided such services to government agencies and utilities in ten countries, including Canada, Paraguay, Honduras, El Salvador, and to the government of Panama.

In 2012 Efficientia concluded implementation of seven energy efficiency projects under its management, in industry, commerce and services in the areas of motive power, compressed air and illumination. The total energy saved as a result of these projects was 20,271.71 MWh/year. A total of R$ 5.39 million was invested in implantation of these projects. Efficientia earned sales revenue of R$ 13 million, and net profit of R$ 7.2 million, in this period, an increase of 18.8% from the previous year. Efficientia’s budget for 2013–2015 includes planned average annual investment of R$ 40 million in projects of this nature.

Sale and Trading of eletricity

We provide services related to the sale and trading of electricity in the Brazilian electricity sector, such as evaluation of scenarios, representation of consumers in the CCEE, structuring and intermediating of electricity purchase and sale transactions, and consultancy and advisory services, besides services related to the purchase and sale of electricity in the Free Market through our wholly-owned subsidiaries conmpanies Cemig Trading S.A. and Empresa de Serviços de Comercialização de Energia Elétrica S.A.

Energy Losses

We recognize energy losses in connection with our operations on the national basic grid, which is operated by the ONS, referred to as the Basic Grid. These energy losses are divided into “technical” and “non-technical losses”.

According to Cemig’s Electric Energy Balance table, Cemig’s Distribution total energy losses in 2012 were 6,317 GWh and increased 10.6% from 2011 (5,712 GWh). The Electric Energy Trading Chamber (Câmara de Comercialização de Energia Elétrica), or CCEE, attributed to Cemig Distribution 418 GWh as losses in the national basic grid in 2012. The remaining energy losses, 5,899GWh, include both technical and non-technical losses in the local distribution system.

Light Serviços de Eletricidade S.A. total energy losses in 2012 were 8,584 GWh, compared to 7,582 GWh in 2011, representing 23.6% of the total energy that passed through the local distribution system, including both technical and non-technical losses. The non-technical losses, totaled 6,007 GWh, which corresponds to 45.4% of the energy invoiced in the low voltage market (the criteria followed by Aneel), or 16.5% of the grid load.

Besides these losses in 2012, 530.1 GWh were related to losses in the national basic grid attributed to Light Serviços de Eletricidade by the Electric Energy Trading Chamber (Câmara de Comercialização de Energia Elétrica), or CCEE.

Technical losses accounted for approximately 81.3% of Cemig Distribution’s and 6.9% of Light’s energy losses in the local distribution system in 2012. These losses are the inevitable result of the step-down transformation process and the transportation of electric energy. We attempt to minimize technical losses by performing rigorous and regular evaluations of the quality of our electricity supply and our facilities. We routinely upgrade and expand our transmission and distribution system in order to maintain quality and reliability standards, and consequently, reduce technical losses. In addition, we operate our transmission and distribution system at certain specified voltage levels in order to minimize losses.

Technical losses are not comparable. Longer stretches of distribution (for example in rural areas) naturally have more technical losses.

Non-technical losses accounted for the remaining approximately 18.7% of Cemig Distribution’s and 16.7% of Light’s energy losses in 2012 in the distribution system and result from fraud, illegal connections, metering errors and meter defects. In order to minimize non-technical losses, we regularly take preventive actions, including inspection of consumers’ meters and connections, modernization of metering systems, training of meter-reading personnel, standardization of meter installation and inspection procedures, installation of meters with quality control warranties, consumer database updating and development of a theft-protected distribution network. Additionally, we have developed an integrated system designed to help detect and measure controllable losses in all parts of our distribution system.

Non-technical losses are partially comparable between electricity companies because they indicate a sector’s inefficiencies and the social complexities within the concession area. At the end of 2012, the indicators that measure the quality of supply by Cemig Distribution, DEC—Consumer Outage Duration in hours per year and FEC—Number of Outages Per Year, were 14.73 and 7.03 , respectively, compared to 14.32 and 7.01 in 2011. At the end of 2012, the DEC and FEC of Light were 18.15 and 8.39, respectively, compared to 16.73 and 7.76 in 2011.

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Consumers and Billing

Consumer Base

CEMIG trades energy in the market in which it operates through its subsidiaries, Cemig Generation and Transmission, Hidroeletric Cachoeirão, Hidroelectric Pipoca, Cemig Baguari Energia, Centrais Eólicas Praias de Parajuru, Praia do Morgado and Volta do Rio and its affiliates (Horizontes Energia, Termelétrica Ipatinga, Sá Carvalho, Termelétrica Barreiro, Cemig PCH, Rosal Energia, Cemig Capim Branco Energia), and (ii) Light companies, Light, Light Electric Services, Energy and Light Lightger.

This market is comprised of the energy sales to captive consumers in the concession areas in Minas Gerais and Rio de Janeiro and out of these states, the trading of electricity to other power agents in ACR - Regulated Contracting Environment, and to the Free Consumers in the ACL - Free Contracting Environment, the sales in PROINFA - Incentive Program for Alternative Sources of Electric Energy and CCEE - Chamber of Electric Energy Trading.

We sold a total of 63,350 GWh of electricity in 2012, a decrease of 1.6% over 2011. Electricity sales to final consumers in 2012 totaled 46,216 MWh, an increase of 2.1% over 2011, due to the expansion in the residential, commercial/services and rural consumer segments.

Electricity supplied to captive consumers in 2012 was 24,634 GWh, a 1.5% increase over 2011, and the electricity sold to Free Consumers was 21,582 GW H, a 2.7% increase over 2011.

Sales of electricity to other agents of the electricity sector in the Regulated Contracting Environment (ACR) and Free Contracting Environment (ACL) (traders and generators) totaled 13,368 GWh in 2012, a reduction of 7.1% from 2011, due to: (i) an increase in sales to the Regulated Contracting Environment of 1.8%, due in particular to the start of the “new energy” contract in 2012; and (ii) a decrease in sales in the Free Contracting Environment of 28.3%.

“New supply” contracts result from “new supply auctions” held by the Mining and Energy Ministry (Ministério de Minas e Energia, or MME). These auctions are for new generation projects which have not yet started commercial operation, and will increase the system’s total of installed capacity. Cemig GT’s contract for sale of new supply, which began in 2012, refers to the Funil-Grande hydroelectric plant, which although it started commercial operation some years before, was qualified by the MME to participate in new supply auctions.

The reduction in sales to other agents in the Free Contracting Environment was the result of Cemig Generation and Transmission’s commercial strategy which gave priority to serving final users (Free Consumers and consumers of incentive-bearing electricity supply), with participation in the Regulated and Free Contracting Environment, conditional on availability of CEMIG’s own supply.

Incentive-bearing consumers are a class of free consumers that have demand between 500 and 3,000 kW. They can buy electricity from alternative sources (small hydroelectric plants, biomass-fired thermal plants, and wind plants), for which the distribution companies charge a discounted tariff for use of their electricity networks. When buying electricity from alternative sources, these consumers also receive the same benefit of discount on the tariffs for use of the system

Electricity sales to the CCEE in 2012 were 3,639 GWh, a decreased of 21.0% from 2011, mainly due to the lower availability of secondary supply in 2012 than in 2011.

Electricity sales under the PROINFA program in 2012 were 127 GWh, a 5.0% increase over 2011, primarily resulting from significantly higher levels of winds in 2012 than in 2011, exceeding projections .

Sales are detailed in the table below broken down by the energy sold to each market in which CEMIG operates for the years 2011 and 2012.

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Sales in G Wh |  | 2012 |  | 2011 |  | Change, % |
|  | G Wh |  | % |  | G Wh |  | % |  | 2012–2011 |
Cemig Consolidated (1) |  | 63,350 |  | 100.0 |  | 64,402 |  | 100.0 |  | (1.6) |
Sales to final consumers |  | 46,216 |  | 73.0 |  | 45,283 |  | 70.3 |  | 2.1 |
Residential |  | 8,871 |  | 14.0 |  | 8,548 |  | 13.3 |  | 3.8 |
Industrial |  | 25,473 |  | 40.2 |  | 25,581 |  | 39.7 |  | (0.4) |
Captive consumers |  | 4,174 |  | 6.6 |  | 4,719 |  | 7.3 |  | (11.5) |
Free consumers |  | 21,298 |  | 33.6 |  | 20,862 |  | 32.4 |  | 2.1 |
Commercial |  | 5,723 |  | 9.0 |  | 5,340 |  | 8.3 |  | 7.2 |
Captive consumers |  | 5,438 |  | 8.6 |  | 5,181 |  | 8.0 |  | 5.0 |
Free consumers |  | 284 |  | 0.4 |  | 159 |  | 0.2 |  | 78.2 |
Rural |  | 2,857 |  | 4.5 |  | 2,633 |  | 4.1 |  | 8.5 |
Other categories |  | 3,293 |  | 5.2 |  | 3,182 |  | 4.9 |  | 3.5 |
Wholesale sales |  | 13,368 |  | 21.1 |  | 14,393 |  | 22.3 |  | (7.1) |
Regulated market - CCEAR contracts |  | 10,329 |  | 16.3 |  | 10,151 |  | 15.8 |  | 1.8 |
Free and “bilateral” contracts |  | 3,039 |  | 4.8 |  | 4,242 |  | 6.5 |  | (28.3) |
Sales under the Proinfa program |  | 127 |  | 0.2 |  | 121 |  | 0.2 |  | 5.0 |
Sales on the CCEE |  | 3,639 |  | 5.7 |  | 4,605 |  | 7.1 |  | (21.0) |

(1) Consolidated sales of Cemig Distribution and Cemig Generation and Transmission.

Light sold a total of 5,373 GWh in 2012, an increase of 2.7% over 2011. Electricity supplied to captive consumers totaled 4,103 GWh, a decrease of 2% over 2011, and electricity sold to Free Consumers was 746.6 GWh, a decrease of 20.5% from 2011.

Total energy consumption in Light SESA’s concession area (including both captive consumers and transporting to Free Consumers) amounted to 23,384 GWh in 2012, an increase of 2.0% over 2011. If we consider the consumption of the Free Consumers CSN and CSA (CSA in the first quarter of 2011 only) is taken into account, total consumption would have been 25,003 GWh in 2012, as compared to 24,658 GWh in 2011.

The sales of Light SESA are detailed in the table below broken down by the energy sold to each market in which the group operates for the years 2011 and 2012.

Number of clients |  | December 2012 |  | December 2011 |  | Change, % |
|  | GWh |  | % |  | GWh |  | % |  | 2011–2012 |
Light SESA |  | 20,054 |  | 100.0 |  | 19,877 |  | 100.0 |  | 0.9 |
Residential |  | 8,149 |  | 40.6 |  | 8,418 |  | 42.4 |  | (3.2) |
Industrial |  | 1,528 |  | 7.6 |  | 1,731 |  | 8.7 |  | (11.7) |
Commercial |  | 6,856 |  | 34.2 |  | 6,310 |  | 31.7 |  | 8.7 |
Rural |  | 53 |  | 0.3 |  | 53 |  | 0.3 |  | 0.0 |
Other categories |  | 3,468 |  | 17.3 |  | 3,365 |  | 16.9 |  | 3.1 |

The number of customers billed for CEMIG’s group peaked at 7,535 million in December 2012, an increase of 2.7% compared to December 2011.

In 2012, through the expansion of our transmission and distribution system, Cemig Generation and Transmission added 87 Free Consumers and Cemig Distribution billed 198,753 new End Consumers, representing an increase of 2.71% compared to 2011. However, Light SESA billed 98 thousand fewer End Consumers, representing a decrease of 2.4% compared to 2011. This result is due to the change in Light’s policy towards clients with long-term default, and began terminating their contracts, in compliance to ANEEL’s Resolution 414.

The number of clients billed by Cemig Distribution and Cemig Generation and Transmission are detailed in the table below broken down by the energy sold to each market in which the groups operate for the years 2011 and 2012.

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Number of clients |  | December 2012 |  | December 2011 |  | Change, % |
|  | Clients |  | % |  | Clients |  | % |  | 2011–2012 |
Cemig Consolidated (1) |  | 7,535,180 |  | 100.0 |  | 7,336,343 |  | 100.0 |  | 2.7 |
Retail supply |  | 7,535,124 |  | 100.0 |  | 7,336,284 |  | 100.0 |  | 2.7 |
Residential |  | 6,032,910 |  | 80.1 |  | 5,862,612 |  | 69.9 |  | 2.9 |
Industrial |  | 77,455 |  | 1.0 |  | 77,230 |  | 1.0 |  | 0.3 |
Captive consumers |  | 77,170 |  | 1.0 |  | 77,002 |  | 1.0 |  | 0.2 |
Free consumers |  | 285 |  | 0.0 |  | 228 |  | 0.0 |  | 25.0 |
Commercial |  | 690,692 |  | 9.2 |  | 670,102 |  | 9.1 |  | 3.1 |
Captive consumers |  | 690,627 |  | 9.2 |  | 670,067 |  | 9.1 |  | 3.1 |
Free consumers |  | 65 |  | 0.0 |  | 35 |  | 0.0 |  | 85.7 |
Rural |  | 660,138 |  | 8.8 |  | 653,657 |  | 8.9 |  | 1.0 |
Other categories |  | 73,929 |  | 1.0 |  | 72,683 |  | 1.0 |  | 1.7 |
Wholesale sales |  | 56 |  | 0.0 |  | 59 |  | 0.0 |  | (5.1) |
Regulated market - CCEAR contracts |  | 36 |  | 0.0 |  | 35 |  | 0.0 |  | 2.9 |
Free and “bilateral” contracts |  | 20 |  | 0.0 |  | 24 |  | 0.0 |  | (16.7) |
(1) Number of consolidate clients of Cemig Distribution and Cemig Generation and Transmission. |  |  |

The number of clients billed for Light SESA are detailed in the table below broken down by the energy sold to each market in which the group operates for the years 2011 and 2012.

Number of clients |  | December 2012 |  | December 2011 |  | Change, % |
|  | Clients |  | % |  | Clients |  | % |  | 2011–2012 |
Light SESA |  | 4,030,124 |  | 100.0 |  | 4,128,295 |  | 100.0 |  | (2.4) |
Residential |  | 3,683,953 |  | 91.4 |  | 3,814,841 |  | 92.4 |  | (3.4) |
Industrial |  | 10,277 |  | 0.3 |  | 10,992 |  | 0.3 |  | (6.5) |
Commercial |  | 310,417 |  | 7.7 |  | 277,671 |  | 6.7 |  | 11.8 |
Rural |  | 11,448 |  | 0.3 |  | 11,361 |  | 0.3 |  | 0.8 |
Other categories |  | 14,029 |  | 0.3 |  | 13,430 |  | 0.3 |  | 4.5 |

The following table sets forth the names and related industries of Cemig’s ten largest industrial customers in 2012 in terms of revenue, which represented 10.4% of total revenue for year.

Ten Largest Cemig’s Industrial Consumers |  | Industry
Usiminas |  | Steel
White Martins |  | Chemical
Arcelor Mittal Brasil S.A. |  | Steel
Fiat S.A. |  | Transport
Vale S.A. |  | Mining
Samarco Mineração S.A. |  | Mining
Kinross Brasil Mineração S.A. |  | Mining
Gerdau Group |  | Steel
Votorantim Metais Zinco S.A. |  | Minerals
Companhia Brasileira de Metalurgia e Mineração |  | Ferroalloys

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The following table shows Cemig’s industrial energy sales volumes by type of industrial consumer as of December 31, 2012.

Industrial Consumers |  | Energy Sales Volume in GWh |  | Consumption as a Percentage of Total Industrial Energy Volume |
Steel industry |  | 5,947 |  | 23.3 |
Ferroalloy industry |  | 4,989 |  | 19.6 |
Mineral extraction |  | 2,956 |  | 11.6 |
Chemical |  | 2,607 |  | 10.2 |
Food processing industry |  | 1,615 |  | 6.3 |
Cement industry |  | 952 |  | 3.7 |
Transportation materials |  | 893 |  | 3.5 |
Mechanical |  | 699 |  | 2.7 |
Other non-metalic minerals |  | 675 |  | 2.7 |
Textiles |  | 666 |  | 2.6 |
Others |  | 3,476 |  | 13.6 |
Total |  | 25,473 |  | 100.0 |

The following table sets forth the names and related industries of Light’s ten largest industrial customers in 2012 in terms of revenue, which represented 3.13% of Light’s total revenue for the year.

Light’s Ten Largest Industrial Consumers |  | Industry
Companhia Siderurgica Nacional |  | Metallurgy
Votorantim Siderurgia SA |  | Metallurgy
Sociedade Michelin de Participações |  | Rubber and Plastic Material
Fábrica Carioca de Catalisadores S.A. |  | Others
Gerdau Açco Longos S.A. |  | Metallurgy
Bayer S.A. |  | Chemistry
Casa da Moeda do Brasil |  | Others
Industria de Produtos Alimenticios |  | Food
Cimento Tupi S.A. |  | Cement Industry
Pan-Americana S.A. Industrias Químicas |  | Chemistry

The following table shows Light’s industrial energy sales volumes by type of industrial consumer as of December 31, 2012.

Industrial Consumers |  | Energy Sales Volume in GWh |  | Consumption as a Percentage of Total Industrial Energy Volume |
Metallurgy |  | 2,847 |  | 51.4 |
Chemical |  | 674 |  | 12.2 |
Rubber and Plastical Material |  | 417 |  | 7.5 |
Non Metallic Minerals |  | 246 |  | 4.4 |
Food |  | 209 |  | 3.8 |
Drink |  | 156 |  | 2.8 |

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Metal, except machinery and equipment |  | 121 |  | 2.2 |
Pharmo_chemical and Pharmacy |  | 99 |  | 1.8 |
Pulp and Paper |  | 90 |  | 1.6 |
Parts and accessories for motor vehicles |  | 64 |  | 1.1 |
Leather good, travel items and footwear |  | 62 |  | 1.1 |
Machinery and equipment |  | 59 |  | 1.1 |
Printing and reproduction of recorded |  | 57 |  | 1.0 |
Construction of buildings |  | 44 |  | 0.8 |
Others |  | 398 |  | 7.2 |
Total Industrial consumption (ACR+ACL) |  | 5,543 |  | 100.0 |

Billing

Our monthly billing and payment procedures for electricity supply vary by levels of voltage. Our large consumers with direct connections to our transmission network are generally billed within five weekdays after their meter reading and receive their bills by e-mail. Payment is required within five weekdays after delivery of the bill.

Other consumers receiving medium voltage electricity (approximately 12,000 consumers supplied at a voltage level equal to or greater than 2.3 kV or connected by underground distribution lines) are billed within one or two days of their meter reading and payment is required within five weekdays after delivery of the bill. This group of consumers will start receiving their bills by e-mail until December 2013.

We are automating our meter reading system for customers who use medium voltage, with completion of this automation scheduled to be completed by June 2013. Currently, approximately 9,000 consumer units in the medium voltage category are already being measured automatically.

Our remaining consumers are billed within five weekdays of their meter reading and payment is required within five weekdays after delivery of the bill or 10 weekdays after delivery of the bill in the case of public sector entities. Bills are prepared from meter readings or on the basis of estimated consumption.

Seasonality

CEMIG’s sales of electricity are affected by seasonality. Historically, an increase in consumption by industrial and commercial consumers occurs in the fourth fiscal quarter due to increases in their activities. The seasonality of rural consumption is usually associated with rainfall periods. During the dry season, between the months of May and November, more electricity is used to irrigate crops. Certain figures representing our fiscal quarterly consolidated consumption by final consumers, captive and Free Consumers, from 2010 through 2012, in GWh, are set forth below:

Year | First Quarter | Second Quarter | Third Quarter | Fourth Quarter |  |
2010 | 10,740 | 11,704 | 12,173 | 12,510 |  |
2011 | 12,415 | 12,456 | 12,828 | 12,705 |  |
2012 | 11,014 | 11,488 | 11,825 | 11,889 |  |

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Competition

Contracts with Free Consumers

We had 415 contracts with Free Consumers as of December 31, 2012. Of these contracts, 92 are with companies located outside the distribution company’s concession area and represent 3,386 GWh of energy per year. These contracts with Free Consumers, including Special Consumers, have terms of three to eighteen years and represented a total volume of approximately 20,570 GWh in 2012.

CEMIG’s strategy in the Free Market has been to establish contracts of longer duration, thereby establishing and promoting a long-term relationship with our consumers. We seek to differentiate ourselves in consumer market based on the quality of our service and the added value of Cemig Generation and Transmission. This strategy, together with a sales strategy that seeks to minimize exposure to short-term prices and contracts with a large minimum demand on a take or pay basis, translates into lower risk and greater predictability of the Company’s results.

At the end of 2012 we were the largest seller of energy to Free Consumers in the Free Market, with approximately 21.8% of the sales in this segment of the CCEE.

Concessions

Each concession that we currently hold is subject to a competitive bidding process upon its expiration. However, in accordance with the Concessions Law, existing concessions could be extended by the Federal Government without a bidding process for an additional period of up to 20 years upon application by the concessionaire, provided that the concessionaire has met minimum performance standards and that the proposal is otherwise acceptable to the Federal Government. On September 22, 2004, we applied to Aneel for a 20-year extension of the concessions of the Emborcação and Nova Ponte hydroelectric plants. On June 14, 2007, the Federal Government approved the extension of the concessions of these power plants for a period of 20 years from July 24, 2005. The related concession contract was amended on October 22, 2008 to reflect the extension granted to Cemig Generation and Transmission.

However, with the enactment of PM 579 converted into Law No. 12,783, the concessions granted after Law No. 9,074 of July 7, 1995, may be extended only once for a period of up to 30 years, at the discretion of the concession-granting authority, from September 12, 2012 onward.

On September 11, 2012 the Brazilian government issued PM 579, which governs the extension of the concessions granted before Law No. 9074 of July 9, 1995. Under PM 579, these concessions can be extended only once, for up to 30 years, at the option of the concession-granting authority.

We believe the renewal of our distribution concessions pursuant to Law No. 12,783 will have no impact on the tariffs charged by those concessions.

On December 4, 2012, the Company signed the second amendment to Transmission Concession Contract 006/1997, which extended concession for 30 years under the terms of PM 579 from January 1, 2013. We extended the concessions of certain of our transmission utilities by the terms of Law No. 12,783, which resulted in an adjustment to the RAP of those concessions, lowering the revenue we will receive from such concessions. The Brazilian Government compensated us for a reduction in the RAP of a portion of these concessions, but the assets in operation before 2000 have not yet been compensated. According to Law No. 12,783, we will be compensated for the reduction in the RAP of the assets in operation before 2000 in 30 years, adjusted by the IPCA.

However, the Company opted not to request extension of the generation concessions that expire within the period 2013 to 2017. For the plants that would have had a first extension before PM579, which include the Jaguara, São Simão and Miranda plants, we believe the Generation Concession Contract 007/1997 allows for the extension of the concession of those plants for an additional 20 years, subject to no additional conditions. For the other generation plants the have concessions that expire over the period from 2015 to2017, which includes Três Marias, Salto Grande, Itutinga, Camargos, Piau, Gafanhoto, Peti, Tronqueiras, Joasal, Martins, Cajuru, Paciência, Marmelos, Sumidouro, Anil, Poquim, Dona Rita and Volta Grande, we have opted, under the terms of PM579, not to apply for an extension of their concessions. Because we decided not to renew our generation concessions under Law No. 12,783, the tariffs charged by those concessions will not be negatively affected until the expiration of those concessions.

Raw Materials

Fluvial water is our main raw material used for the hydroelectrical generation of energy, representing approximately 90% of the total raw materials used. We do not have to pay a price for usage of fluvial water in hydroelectric plants.

Environmental Matters

Overview

Our generation, transmission and distribution of electricity as well as the distribution of natural gas are subject to comprehensive federal, state and local legislation relating to the preservation of the environment. The Brazilian Constitution gives the Federal Government, states and municipalities powers to enact laws designed to protect the environment and issue enabling

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regulations under these laws. While the Federal Government has the power to promulgate general environmental regulation, state governments have the power to enact specific and even more stringent environmental regulation and municipalities also have the power to enact laws in their local interest. A violator of applicable environmental laws may be subject to administrative and criminal sanctions, and will have an obligation to repair and/or provide compensation for environmental damages. Administrative sanctions may include substantial fines (from R$50 thousand to R$50 million) and suspension of activities. Criminal sanctions applicable to legal entities may include fines and restriction of rights, whereas, for individuals, they may include imprisonment, which can be imposed against executive officers and employees of companies that commit environmental crimes.

We believe that we are in compliance with the relevant laws and regulations in all material aspects.

In accordance with our environmental policy, we have established various programs for prevention and control of damage, aiming to limit our risks related to environmental issues.

Environmental Licensing

Brazilian law requires that licenses be obtained for construction, installation, expansion and operation of any facility that utilizes environmental resources, causes environmental degradation, or pollutes or has the potential to cause environmental degradation or pollution or to harm archaeological heritage.

Failure to obtain an environmental license to construct, implement, operate, expand or enlarge an enterprise that causes significant environmental impact, such as the energy plants operated and in implementation by CEMIG, is subject to administrative sanctions, such as the suspension of activities and the payment of a fine, ranging from R$500 thousand to R$50 million, as well as criminal sanctions, which include the payment of a fine, imprisonment for individuals and restriction of rights for legal entities.

The State of Minas Gerais Environmental Policy Council (Conselho de Política Ambiental) (“COPAM”) Regulatory Ordinances Nos. 17, of December 17, 1996, and 23, of October 21, 1997, provide that operational licenses shall be renewed from time to time for periods of four to eight years, depending on the size and pollution potential of the facility.

The validity of the operational environmental licenses is controlled by a specific system and is verified yearly.

Corrective Environmental Operation Licensing

Resolution No. 1, of January 23, 1986, issued by the Environmental National Council (Conselho Nacional do Meio Ambiente) or CONAMA, requires environmental impact assessment studies to be undertaken, and a corresponding environmental impact assessment report to be prepared, for all major electricity generation facilities built in Brazil after February 1, 1986. Facilities built prior to February 1, 1986 do not require these studies, but must obtain corrective environmental operation licenses, which may be acquired by filing a form containing certain information regarding the facility in question. Obtaining the corrective licenses for the projects which began operations before February 1986, according to the Resolution No. 6, of September 16, 1987, requires presentation to the competent environmental body of an environmental report containing the characteristics of the project, the environmental impacts of the construction and operation, and also the mitigating and compensatory measures adopted or that are in the process of being adopted by the organization carrying out the project.

Federal Law No. 9,605, of February 12, 1998, sets penalties for facilities that operate without environmental licenses. In 1998, the Federal Government issued Provisional Measure 1,710 (currently Provisional Measure 2,163/41), which allows project operators to enter into agreements with the relevant environmental regulators for the purpose of coming into compliance with Federal Law No. 9,605/98. Accordingly, we have been negotiating with the Environmental and Natural Renewable Resources Brazilian Institute (Instituto Brasileiro do Meio Ambiente e dos Recursos Naturais Renováveis) (“IBAMA”) and the Environmental Foundation (Fundação Estadual do Meio Ambiente) (“FEAM”) of the State of Minas Gerais to obtain the corrective environmental operation licensing for all our plants that began operating prior to February 1986. Generation facilities located within the State of Minas Gerais fall within the jurisdiction of FEAM for purposes of corrective licensing. We have agreed with FEAM to bring our facilities located in Minas Gerais into compliance on a gradual basis. We do not currently anticipate any costs and commitments in connection with any recommendations that may be made by IBAMA and FEAM.

Currently, the facilities of Cemig Generation and Transmission that started operations before the Brazilian environmental legislation was enacted, and which have not obtained corrective licensing, have filed applications before the appropriate environmental bodies, prepared the required studies and submitted them for analysis.

Of the 46 plants built prior to the Brazilian environmental legislation, 11 already have operating licenses, and 35 have their licenses under the analysis phase in either the Federal or State level, depending on their location. All the relevant studies have been prepared and presented to the appropriate regulatory body. Some of the renewal, and corrective processes of our environmental

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licenses conducted at the environmental agency of the State of Minas Gerais depend on the decisions regarding Legal Forest Reserves and Permanent Protection Areas. See “—Legal Forest Reserves.”

Distribution of natural gas by Gasmig through pipelines in Minas Gerais is also subject to environmental control. We believe that all licenses for the regular operation of Gasmig’s activities have been obtained.

The environmental licenses issued by state or federal bodies are subject to certain conditions imposed in light of foreseen environmental impacts. In extreme circumstances, failure to comply with these conditions may result in revocation of the license. We believe we are in compliance with the requirements mentioned in our licenses. Environmental licenses are obtained subject to conditional requirements that have to be met during the period of their validity. Non-compliance with these conditional requirements can result in administrative penalties, including fines and the repeal of the environmental license. CEMIG has been complying with the demands of the environmental conditions of its licenses and periodically sends reports to the environmental regulatory authorities.

Legal Forest Reserves

Under Article No. 12 of Federal Law No. 2,651, of May 25, 2012 (the “new Brazillian Forest Code”), a Legal Forest Reserve is an area located inside a rural property or holding that is necessary for the sustainable use of natural resources, conservation or rehabilitation of ecological processes, conservation of biodiversity and for shelter or protection of native fauna and flora. As a general rule, all owners of rural properties have to preserve an area as a legal reserve. However, the Article 12, §7 of the new Brazilian Forest Code establishes that a Legal Forest Reserve will not be required for areas acquired or expropriated by the holder of the concession, permission or authorization to exploit hydropower potential, in which work projects for electric power generation, substations or transmission and distribution lines of electricity are installed.

In addition, in Minas Gerais, where the greater part of CEMIG’s undertakings is located, State Law No. 14,309, of June 19, 2002, regulated by Decree No. 43,710, of January 8, 2004, which instituted the Forest and Biodiversity Protection Policy, establishes the general obligation contained in the Federal Forest Code, requiring the constitution of a Legal Forest Reserve corresponding to 20% of the total area of a rural property, as an instrument for protection of biodiversity and shelter for flora and fauna in the state. We expect a possible revision of the legislation of Minas Gerais as a result of the enactment of the new Brazilian Forest Code, at which time we will evaluate the impact of Legal Forest Reserves on our projects located in the State of Minas Gerais.

In the federal sphere, IBAMA’s technical licensing team, in the corrective licensing of CEMIG’s plants, expressed an opinion, in correspondence sent to the Company, on July 29, 2008, taking a position against the need for the constitution of a Legal Forest Reserve.

In the State of Minas Gerais, with the objective of deciding whether the obligation to constitute a Legal Forest Reserve applies to the electricity sector, a legal opinion was issued by the Office of the General Attorney of the State of Minas Gerais, or AGE, on October 30, 2008, in response to a consultation from the Minas Gerais State Environment and Sustainable Development Department, or SEMAD, and the State’s Economic Development Department, or SEDE, presenting the opinion that “allocation of a Legal Forest Reserve is obligatory for undertakings of the electricity sector, both for those under construction and for those to be put in place in the future.”

Supported by several legal opinions, SEDE expressed a position against the applicability of the obligation to constitute Legal Reserves to undertakings of the electricity sector located in rural areas, and resumed their discussions with the SEMAD about this obligation.

In agreement with the opinion put forward by SEDE, CEMIG supports the view that it is not legally obligated to constitute a Legal Forest Reserve for its undertakings, based on the following arguments:

1. The undertakings of the electricity sector are public utility activities, operating commercially under federal concession or authorization, for commercial operation of hydroelectric potential, and transmission and distribution of electricity, and are certainly not characterized as being a rural property or possession.

2. The acquisition of the real estate properties for putting in place the undertakings occurs as a function of the concession authorization by the grantor, through Aneel as an intermediary, and is carried out on a temporary basis, since at the end of the concession or authorization, the assets revert to public ownership.

3. The environmental impacts caused to biodiversity by the implementation of the electricity sector’s undertakings have already been compensated. Examples of the environmental compensation specified in Brazilian legislation, already applying to the sector, are: (I) the Environmental Compensation specified by Federal Law No. 9,985, of July 18, 2000 (the SNUC Law); (II) the Forest Compensation for suppression of vegetation or intervention in an area of permanent preservation; (III) the

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Environmental Compensation for cutting or suppression of the Atlantic Forest biome, under Federal Law No. 11,458, of December 22, 2006; and (IV) the Forest Charge for removal of vegetation for installation of the undertakings, as specified in State Law No. 4,747, of May 9, 1968.

4. The principle of non bis in idem cannot thus be violated. Such an obligation could characterize a double charge imposed on concession holders. CEMIG referred his understanding to SEDE, presenting arguments against the Legal Reserves provision obligation.

SEMAD, in a letter to the AGE dated as of May 14, 2010, requested reconsideration of AGE’s legal opinion dated October 30, 2008. The AGE has not yet replied to SEMAD’s letter.

In 2012, the new Brazilian Forest Code (Law No. 12,651 of May 25, 2012, amended by Law No. 12,727 of October 17, 2012, converted the Provisional Measure No. 571/2,012) was approved. As mentioned above, Article 12, §7 of the new Brazilian Forest Code establishes that a Legal Forest Reserve will not be required on areas acquired or expropriated by the holder of the concession, permission or authorization to exploit hydropower potential, in which work projects of electric power generation, substations or transmission and distribution lines of electricity are installed.

However, in January 2013 the Attorney General proposed an Unconstitutionality Claim No. 4,901 alleging the unconstitutionality of several provisions of the new Brazilian Forest Code, including Article No. 12, §7. As of the date of this report, there has been no manifestation by the Brazilian Supreme Court, as a result, Article No. 12, §7 of the new Brazilian Forest Code remains in force.

Permanent preservation areas

Brazilian law also requires the mandatory establishment of permanent preservation areas in and around artificial reservoirs and preparation of an Environmental Plan of Conservation of Surrounding Artificial Reservoir (PACUERA) in order to regulate the conservation, restoration, usage and occupation around the artificial reservoirs. We have established certain contingencies related to the area around our reservoirs, which suffers frequent irregular invasions and occupations, requiring constant vigilance and entering claims for repossession of areas that have been invaded. As a result, even though we may not be responsible for environmental damage caused by such invasions, we could be held responsible for the restoration of permanent preservation areas.

Compensation Measures

According to Federal Law No. 9,985, of July 18, 2000, and corresponding Decree No. 4,340, of August 22, 2002, the companies whose activities are deemed to cause high environmental impacts are required to invest in protected areas in order to offset those impacts. Each company shall have its environmental compensation stipulated by the relevant environmental agency, depending on the specific degree of pollution or harm to the environment resulting from its activities.

Federal Decree No. 6,848/2009, issued on May 14, 2009, and State of Minas Gerais Decree No. 45.175, issued on September 17, 2009, regulate the methodology for defining compensation measures. Accordingly up to 0.5% of the total amount invested in the implementation of a project that causes significant environmental impact must be reverted for compensation measures. The exact amount of compensation measures will be defined by the environmental agency, based on the project’s specific degree of pollution and environmental harm.

State Decree No. 45.175/2009, of September 17, 2009 also indicated that the compensation charge shall apply retroactively to projects implemented before the enactment of the current legislation.

State Decree No. 45.175/2009 was amended by Decree No. 45.629/2011, which established the reference value of projects that cause significant environmental impact will be defined as follows:

I - projects implemented prior to the publication of Federal Law No. 9985 of 2000 will consider the net book value, excluding revaluations., If the net book value is not available, will be considered the value of investment presented by the legal representative of such project, and

II - compensation for environmental projects implemented after the publication of Federal Law No. 9985 of 2000 will consider the benchmark value established in item IV of article. 1 of Decree No. 45175, 2009, calculated at the time of implementation of the project and updated based on an inflation adjustment rate.

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Fish Management – Peixe Vivo Program

Construction of hydroelectric plants can cause a risk for fish that inhabit rivers which have been dammed, due to various changes in the aquatic environment. One of our environmental area’s principal activities is to ensure that environmental accidents involving the native fish population do not occur at our hydroelectric power plants. Also, to mitigate the impacts caused by operation of our hydroelectric power plants, we are developing a methodology for evaluating the risk of fish deaths at our plants. We also carry out research projects in partnership with universities to develop scientific knowledge to serve as a basis for more effective fish population conservation programs to be implemented by us.

In spite of these efforts, one incident occurred in 2007, at the Três Marias Hydroelectric Power Plant, resulting in the death of approximately 17 tons of fish as estimated by the Enviromental Police (8.2 tons by our estimate). The volume of dead fish was not estimated or measured As a result, the State Forests Institute imposed two fines on us, totaling approximately R$5.5 million, which currently corresponds to R$7.7 million. We paid 50% of the fine and the rest is being negotiated with the environmental authority for application in research projects. On April 8, 2010, CEMIG and the Public Attorneys’ Office of Minas Gerais State signed a Conduct Adjustment Commitment (TAC), corresponding to the amount of R$6.8 million, providing for compensatory measures for environmental improvement in the area of influence of the Três Marias power plant, in Três Marias, Minas Gerais.

Within this context, one of the main objectives of the company, as of 2007, was the establishment of preventive and mitigation measures against fish mortality caused by the operation of hydroelectric power plants. ‘Our management believed that the correct assessment of risks and the subsequent adoption of efficient control measures would mean a decrease in economic and environmental losses, as well as image-related losses, which the company had been suffering in previous years. Therefore we implemented an environmental program, named Peixe Vivo (Live Fish) in the affected region as a way of responding to the event and reaffirming our commitment to economic and social development of the regions where we operate and where our projects are located.

CEMIG has spent,on average, R$6.4 million per year for the development of research projects linked to the Peixe Vivo program from 2007 until 2012, and more than R$6 million were invested on physical barriers to prevent fish from entering the draft tube and modernization of the main hatchery station at the Volta Grande Environmental Station.

In spite of all the advances in fish management achieved by our Peixe Vivo (“Fish Alive”) program, there are still many challenges to be studied and understood. In 2012, an estimated 1.8 tons of fish died in the vicinity of the Três Marias hydroelectric power plant. This was unexpected and the cause of the deaths is still unknown as thks particular situation is without precedent. However, with the adoption of measures to control environmental accident and as a result of our prompt reporting to the environmental authorities, the fine that we were charged for the accident, R$ 50 thousand, was reduced by 45% under the law that provides for a reduction in environmental damages fines in the event immediate notice of the environmental damage is given to the environmental authority and for having collaborated with the environmental authorities to solve the problem arising from our conduct. The fine imposed in 2012 was 40 times greater (per kilogram of fish killed) than the one applied by the Minas Gerais State Forests Institute (Instituto Estadual de Florestas) in the 2007 accident. The Peixe Vivo program is currently studying the circumstances of the accident, to structure better forms of control.

There has been no final decision by the environmental authorities regarding the obligation of building fishway projects at CEMIG’s hydroelectric plants, however, there is a possibility that future decisions by the environmental authorities, changes in the environmental legislation, or even new information obtained from the studies that are currently in progress may lead to a need for the construction of fishways at all of ‘our hydroelectric plants, which may result in additional operating costs ‘that have not yet been assessed.

Urban Occupation of Rights of Way and Reservoir Banks

Gas Pipelines — Our piped natural gas distribution networks are underground, crossing through inhabited areas and using public rights of way in common with underground piping utilities operated by other public concession holders and public agencies. This increases the risk of unauthorized work without prior communication and consultation of our natural gas distribution network registers, and there is a possibility accidents that could cause potential significant personal, property and environmental damage in case of ignition or a leak. However, all our gas networks are explicitly, and intensively, marked and signaled. Gasmig has several inspectors monitoring its network daily, to prevent illegal or non-notified excavations in urban roads, invasions or constructions, erosions or any other problem that might cause risk to the pipeline. Gasmig, through its Dig Safely (Escave com Segurança) program, has been building partnerships with the community, mainly with public authorities and holders of concessions, to disclose their registrations to companies that perform excavation on urban roads, to ensure that before digging close to the natural gas network, they call Gasmig’s 24-hour helpline, and request guidance and support for safe execution of their work.

In 2012, Gasmig had two incidents related to natural gas emissions, caused by an accident with a directional drill and an unauthorized excavation without prior analyses of our gas network maps. Both incidents resulted in smalls gas leaks, but because

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Gasmig closed the valves and isolated the areas involved in the accident without ignitions, the environmental damage was substantially reduced

Transmission Lines — We have easements for our transmission network over land with approximately 13,670 miles in length. A significant portion of such land is occupied by unauthorized constructions, including residential constructions. This type of occupation causes risks of electric shock and accidents involving local residents, and constitutes an obstacle to maintenance of our electricity system. We are currently seeking a solution for this problem, which could involve either removal of these occupants, or improvements that would make it possible to maintain our electricity system safely and efficiently. The Invasion Risk in the Transmission Path Monitoring Committee was created to mitigate these risks by monitoring and recording invasions and by taking action to prevent invasions on the safety paths of the transmission lines. A number of measures have been adopted, including: contracting of a company for systematic inspection and implementation of security measures and works to minimize risks; education of the communities about the risks of accidents involving electricity and our transmission lines; creation of community vegetable gardens in the transmission line paths; and removal of occupation of the transmission paths through working agreements with local housing and other authorities.

Reservoir Areas — We have implemented safety measures to protect our electricity generation facilities against invasions, using security posts, mobile patrols to control the banks of reservoirs and electronic vigilance systems (SVE) to monitor the generation power plant instalations, as appropriate. Invaders located inside the facilities are detained and taken to police stations, where police complaints are filed. There are signs on the banks of the reservoirs of our hydroelectric generation facilities, indicating ownership. Invaders of the banks of the reservoirs are reported by periodic inspections by the mobile patrol units operating on the reservoir banks. We frequently have to take legal action to recover possession of invaded areas. Due to the vast area and number of reservoirs, we are continually subjected to new trespasses and occupation of the banks of the reservoirs by unauthorized constructions. However, we are employing our best efforts to prevent these invasions and any environmental damage to the Permanent Preservation Areas (Áreas de Preservação Permanente), or APPs, around the reservoirs.

The Carbon Market

We believe Brazil has significant potential to generate carbon credits arising from clean energy projects that comply with the Clean Development Mechanism, CDM, or the Voluntary Markets. Every year, we seek to quantify our emissions and to publish our main initiatives in reduction of greenhouse gas emissions, by means, for example, of the Carbon Disclosure Project.

CEMIG group takes part in CDM projects at various stages of development, including seven Small Hidroeletric Plants with a capacity of 116MW and a hydroeletric plant with a capacity of 140MW and several wind plants which totaled 668MW and a solar plant with a capacity of 3 MW. So far no carbon credits have been commercialized, since these projects have not yet reached the stage of issuance of Reduced Emission Certificates (Certificados de Emissão Reduzuida), or CERs.

Operational Technologies

We continue to invest in automated monitoring and control equipment in connection with our strategy of increasing efficiency and further modernizing and automating our generation, distribution and transmission grids.

Load Dispatch Center

CEMIG’s System Operation Center (Centro de Operação do Sistema), or COS, located at our head office in Belo Horizonte, is the nerve center of our operations. It coordinates the operations of our entire electricity and energy system, in real time, providing operational integration of the generation and transmission of our energy. It also provides the link with other generation, transmission and distribution companies. The supervision and control executed by the COS now extends to more than 49 extra high and high voltage substations, approximately 29 major generating power plants and 7 Small Hidroeletric Plants.

Through its activities the COS permanently guarantees the security, continuity and quality of our supply of electricity. The activities of the COS are supported by up-to-date telecommunications, automation and information technology resources, and executed by highly qualified personnel. The COS has a Quality Management System, with ISO 9001:2008 certification.

Distribution Operation Center

Our distribution network is managed by a Distribution Operation Center (Centro de Operações de Distribuição), or COD, located in Belo Horizonte. The COD monitors and coordinates our distribution network operations in real time. The COD is responsible for the supervision and control of 379 distribution substations, 297,467 miles of medium voltage distribution lines, 10,601 miles of sub-transmission lines and 7.39 million consumers in our concession area, comprising 774 municipalities of Minas Gerais.

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We provided an average of 13,150 services a day in 2012. The COD is certified according to ISO Quality Standard 9001: 2000. There are various systems in use to automate and support the COD’s processes including: trouble call, field crew management, distribution substation supervision and control, restoration of power, emergency switching, network disconnection, and inspection. Technologies including a geographic information system and satellite data communication help to reduce consumer service restoration time and provide better consumer service. These are devices, installed along our distribution network, that sense and interrupt fault currents, and automatically restore service after momentary outages, improving operational performance and reducing restoration time and costs.

Geospatial Information & Technology

The operational and engineering processes of our business are strongly supported by geo-referenced information management technologies, making the planning, construction, operation and maintenance of the generation, transmission and distribution network more efficient. Additionally, the use of mobile technologies reduces costs and allows us to provide more efficient services to our consumers.

Internal Telecommunications Network

We believe we have one of the largest telecommunication networks among Brazilian electric power companies. It includes high performance microwave links with more than 261 communication stations, an optical system with 1,746.8 miles of optical fibers and a mobile communication system with 897 radios including 644 trunking and VHF radios and 253 UHF and VHF portable radios. A total of 420 mobile radios have data interface to mobile terminals installed in vehicles for dispatch systems (operation and maintenance), which also have 1,320 mobile terminals connected through satellites and General Packet Radio Services (GPRS).

Corporate Data Network

Our corporate data network has 303 sites in 143 towns in Minas Gerais. The physical and logical architecture of the network employs security resources such as firewalls, Intrusion Prevention Systems (IPSs), Data Loss Prevention Systems (DLP) and anti-virus and anti-spam systems, which are continually updated to protect information against unauthorized access, in compliance with ISO 27002. A system of event logs makes it possible to investigate occurrences and also guarantee a historical record base to meet legal requirements.

IT Governance Program

Our Information Technology Governance Program aims to continually align IT with our business, adding value by applying technology information, proper management of resources, risk management and compliance with legal, regulatory and Sarbanes-Oxley requirements.

Since 2008, our information technology Project Management Office (or PMO) is responsible for ensuring that the management of information technology projects is systematic, using dedicated software methodology, processes and tools.

Considering the central role of Information Technology Governance in our business, a dedicated management unit was created in 2009 for concentrating, planning and carrying out all the actions that are specific to information technology governance, including strategic planning, legal and regulatory compliance, quality management, budget and financial management, services management and project management.

Customer Relationship Channels

We have one call center, in Belo Horizonte. Our customers can call a toll-free number to obtain information about their accounts and order services from our call center. The call center is integrated with the Distribution Operation Center - COD systems and the Customer Relationship Management - CRM system of the SAP platform, allowing consumers to provide updated information on emergency and commercial services. The call center has modern facilities and includes an efficient electronic service through the Interactive Voice Response - IVR, and a staff of over 1,250 professionals, being able to receive about 60,000 calls on a typical day and up to 250,000 calls on an unusual day. As an indication of the quality of service, our call center has the ISO 9001 Quality Certification since 1999. We also have a representative of stores and service centers in all 774 municipalities in the concession area, to meet the customer in person when necessary. Others important customer relationship channel is the customer service provided by the Government, through the agents available for each city of the concession area and the Cemig Plus - a dedicated contact center to clients served in medium voltage. Consumers can also contact us by e-mail, chat, fax, SMS, Social Networks like Twitter, YouTube, Linkedin and Facebook or through our website - the Virtual Agency, with over 23 online services available to customers.

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Commercial Management System

We have consolidated an efficient customer care system, based on our CCS/CRM platform and totally integrated into our ERP and BI that support our decision-making processes. The CCS serves approximately 7 million consumers of high, medium and low voltage. The system is a competitive tool, adding safety, quality and productivity to CEMIG’s business processes, and adapts itself with great efficiency and speed to legal, regulatory and market changes and requirements.

Maintenance and Repair Systems

The 10,601,367 miles of high voltage distribution lines in Cemig Distribution’s network, operating at 34.5 kV to 161 kV, are supported by approximately 53,837 structures, mainly made of metal. Cemig Generation and Transmission’s network has 3,064 miles of high voltage transmission lines, supported by approximately 11,526 structures. The majority of the service interruptions to our distribution and transmission lines are due to lightning, fire, vandalism, wind, and corrosion. The entire high voltage transmission line systems of both Cemig Distribution and Cemig Generation and Transmission are inspected once a year, using a helicopter equipped with a “Gimbal”, which is a gyro-stabilized system consisting of conventional and infra-red cameras, allowing for simultaneous visual and thermographic (infra-red) inspections. Land-based inspections are also carried out at intervals of between one and three years, depending on the line characteristics, such as time in operation, number of outages, type of structure, and the line’s importance to the electricity system as a whole.

We use modern modular aluminum structures to minimize the impact of emergencies involving fallen structures. Most of our maintenance work on transmission lines is done using live-wire methods. Being the first company in Brazil to use bare-hand, live-wire techniques in the maintenance of transmission lines and substations, we have accumulated over 33 years of experience in this area. We have a well-trained staff and special vehicles and tools to support live- and dead-wire activities.

Our set of spare equipment (transformers, breakers, arresters etc) and mobile substations are of great importance in the prompt reestablishment of power to our customers in case of emergencies involving failed substations.

The Plant Overhaul and Modernization Program that was scheduled for execution over the next 15 years, with investment of R$1.7 billion, was cancelled after promulgation of Provisional Measure 579 (Medida Provisória 59, or MP 579), which was subsequently converted into Law 12783. The principal reason for the cancellation was Cemig not having accepted the conditions proposed by the Federal Government for renewal of the concessions of the plants that were included in the program and for a lack of definition on the form of remuneration for these investments in the future.

Information Security Management

Information security, a permanent concern of ours, is ensured by a management system based on the Brazilian Standard (ABNT) NBR ISO/IEC 27001:2006, and aligned with the best market practices. Our information security management system includes processes for policy, risk, communication, information classification and information security management and control. In addition, recurring actions for improvement in processes, communication, awareness and training strengthen the Company’s information security practices.

Management Tools

During 2012, Cemig continued to improve and adapt the SAP Integrated Management System, or ERP, which includes the processes related to finances, procurement, sales, materials, services and human resources, for the changes and requirements of legislation, regulations and market standards. We have made significant progress in relation to capitalization of assets, works and materials, logistics planning, maintenance and processes related to regulations on electronic tax invoices, including other obligations related to electronic payment of taxes. Also, in 2012, we implemented the SAP LMS (Learning Management System) in”Portal Cemig,” our intranet portal.

These advances and solutions implemented in ERP also assist us in obtaining the information that is necessary for planning, control and decision-making, and making that information available to our Board of Directors and Executive Board.

Risk Management

With the assistance of a leading consulting firm, we began establishment of a Corporate Risk Management System in 2003, which was consolidated during the period of 2004 through 2006, in connection with our unbundling process. As holder of a concession in the Brazilian electricity sector, we operate in environments where factors such as corporate restructurings, regulations issued by energy sector government agencies, technological development, globalization and changes in the consumer market generate uncertainties and risks.

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The implementation of a coherent risk vision and strategy at the corporate level is a new management trend, encouraged not only by the requirements of the Sarbanes-Oxley Act and the methods recommended by the Committee of Sponsoring Organizations, or COSO II, but also by the perception that risk management is an essential part of a sustainable development philosophy that aims to create value for shareholders.

Our Corporate Risk Management System aims to achieve the following: compliance with the objectives set by the strategic plan; create awareness among shareholders of the possible events that could constitute a risk of loss of value; structure the company to be able to take proactive stances in relation to its risk environment; provide the company’s executives with a methodology and tools for effective management of risk, including the ability to aggregate individual risks, the ability to compare risks in different business units and a tool to accurately evaluate the measures introduced to minimize risks; provide other areas of strategic management with input concepts and procedures, and factors that strengthen the company’s organizational control infrastructure.

CEMIG is working to achieve the major risk management objective of an open environment conducive to effective communications about risks and risk management up, down and across the enterprise, so that a truly holistic, integrated, proactive, forward-looking and process-oriented approach is taken to assess all key business risks and opportunities, not only those of a financial nature.

CEMIG’s Electricity Risks Management Committee, or CGRE, created in 2003, continues to propose policies and procedures for approval by the executive officers, according to corporate risk policy, to minimize risks in the contracting (purchase and sale) of energy. The members of the committee come from numerous areas of the Company, including generation, distribution, sales, legal and financial. The CGRE gives support to the decisions of the executive officers in relation to the Company’s energy commercialization to Free Consumers and participation in the CCEE auctions. Based on risk analyses, the CGRE proposes the maximum volumes that could be sold and the amounts purchased by distributors in the auctions.

CEMIG’s risk management also has the benefit of a Financial Risk Management Committee, which was created (i) to monitor the financial risks related to volatility and trends of the inflation indices, exchange rates and interest rates that affect our financial transactions, and which could negatively affect the Company’s liquidity and profitability, and (ii) to implement guidelines for proactive operation in relation to the environment of financial risks when implementing action plans.

The next step we intend to take is to improve the Corporate Risk Management System, with the assistance of a consulting firm, by developing new products and mathematical and statistical methods used to calculate and monitor the Corporate Risks Matrix’s risk positions, thereby increasing transparency and safety in strategic decisions.

Properties, Plant, Equipment and Intangible Assets

Our principal properties consist of the power generation plants and transmission and distribution facilities described in this Item 4. Our net book value of total property, plant and equipment and intangible assets, including our investment in certain consortia that operate electricity generation projects, including projects under construction, was R$13,284 million at December 31, 2012. Generation facilities represented55.87% of this net book value, intangible assets represented 32.88% of this net book value (distribution facilities on intangible assets represented 24.42% and other intangible and other miscellaneous property and equipment, including transmission and telecommunication facilities, represented 43.13%. The average annual depreciation rate applied to these facilities was2.35 % for hydroelectric generation facilities, 7.59 % for administration facilities, 6.68 % for telecommunication facilities and 3.66% for thermoelectric facilities. Apart from our distribution network, no single one of our properties produced more than 10% of our total revenues in 2012. Our facilities are generally adequate for our present needs and suitable for their intended purposes. We have rights of way for our distribution lines, which are our assets and do not revert to the landowner upon expiration of our concessions.

The Brazilian Power Industry

General

Traditionally, in the Brazilian electricity sector, generation, transmission and distribution activities were conducted by a small number of companies that had always been owned by either the Federal Government or State Governments. In the past, several companies controlled by the state were privatized, in an effort to increase efficiency and competition. The Fernando Henrique Cardoso administration (1995–2002) stated its objective to privatize the state-controlled part of the electricity sector, but the Luis Inácio Lula da Silva administration (2003-2010) ended this process and implemented a “New Industry Model” for the Brazilian electricity sector as set forth in Law No. 10,848, of March 15, 2004, or The New Industry Model Law.

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The New Industry Model

The main objectives of the New Industry Model are to guarantee security of supply and reasonableness of rates. To guarantee supply, The New Industry Model Law requires (a) that distributors contract their entire loads, and be responsible for making realistic projections of demand requirements and (b) that the construction of new hydroelectric and thermal plants be determined in ways that best balance security of supply and reasonableness of rates. To achieve reasonable rates, The New Industry Model Law requires (a) all purchases of electricity by distributors occur by auction, based on the lowest-price criterion; (b) contracting be through the ACR, or the Pool system; and (c) contracting of load be separated into two types of transactions which will always be by auction: (i) contracting of the electricity of the new plants, which targets expansion; and (ii) contracting of the electricity of the existing plants, which targets the existing electricity demand.

The New Industry Model created two environments for the purchase and sale of electricity: (i) the ACR, or the Pool, which contemplates the purchase by distribution companies through public auctions of all energy necessary to supply their consumers; and (ii) the ACL, which encompasses purchase of electricity by non-regulated entities (such as Free Consumers and energy traders). Distributors will be allowed to operate only in the regulated environment, whereas generators may operate in both, maintaining their competitive characteristics.

Expansion requirements of the sector are evaluated by the Federal Government through the Ministry of Mines and Energy, or MME. In order to better organize the electric energy sector, two entities have been created: (i) the Energy Research Company, or EPE, a state-controlled company responsible for planning the expansion of generation and transmission; and (ii) the Electric Energy Trading Chamber (Câmara de Comercialização de Energia Eléctrica), or CCEE, a private company responsible for the accounting and settlement of short-term energy sales. The CCEE is also responsible, through delegation by Aneel, for organizing and conducting the Pool public power auctions, in which all distributors purchase energy.

The New Industry Model eliminated self-dealing, forcing distributors to purchase electricity at the lowest available prices rather than buying electricity from related parties. The New Industry Model also exempted contracts executed prior to the enactment of the law, in order to provide regulatory stability to transactions carried out before it was enacted.

The electricity arising from (1) low capacity generation projects located near the consumption points (such as certain co-generation plants and the Small Hydroelectric Power Plants), (2) plants qualified under the Proinfa Program, (3) Itaipu, (4) purchase and sale agreements entered into before the New Industry Model Law and (5) the concessions extended by Law No. 12,783, are not subject to the public auctions for the supply of electricity at the Pool. The electricity generated by Itaipu, located on the border of Brazil and Paraguay, is traded by Eletrobrás and the Federal Government, through Aneel, and determines the volumes that shall be mandatorily purchased by each distribution concessionaire. The rates at which the Itaipu generated electricity is traded are denominated in U.S. dollars and established by Aneel pursuant to a treaty between Brazil and Paraguay. As a consequence, Itaipu rates rise or fall in accordance with the variation of the U.S. Dollar/real exchange rate. Changes in the price of Itaipu generated electricity are, however, neutralized by the Federal Government which buys all the energy credits from Eletrobras. The electricity generated by the concessions extended by Law No. 12,783 is allocated by Aneel to the Regulated Market through the distribution companies in the Pool.

Challenges to the Constitutionality of the New Industry Model Law

The New Industry Model Law is currently being challenged on constitutional grounds before the Brazilian Supreme Court. The Federal Government moved to dismiss the actions arguing that the constitutional challenges were moot because they related to a provisional measure that had already been converted into law. To date, the Brazilian Supreme Court has not reached a final decision upon the merits of such lawsuit and we do not know when such decision may be reached. Therefore, the New Industry Model Law is currently in force. Regardless of the Supreme Court’s final decision, certain portions of the New Industry Model Law relating to restrictions on distributors performing activities unrelated to the distribution of electricity, including sales of energy by distributors to Free Consumers and the elimination of agreements between related parties are expected to remain in full force and effect.

Coexistence of two Electricity Trading Environments

Under the New Industry Model Law, electricity purchase and sale transactions are carried out in two different market segments: (1) the regulated market, or the Pool, which contemplates the purchase by distribution companies through public bids of all electricity necessary to supply their consumers and (2) the free market, which encompasses purchase of electricity by non-regulated entities (such as the Free Consumers, energy traders and energy importers).

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The Regulated Market (the ACR or the Pool)

In the regulated market, distribution companies purchase electricity for their captive consumers through public auction regulated by Aneel and conducted by CCEE.

Energy purchases will take place through two types of bilateral contract: (i) Energy Agreements (Contrato de Quantidade de Energia) and (ii) Capacity Agreements (Contratos de Disponibilidade de Energia). Under an Energy Agreement, a generator commits to supply a certain amount of electricity and assumes the risk that electricity supply could be adversely affected by hydrological conditions and low reservoir levels, among other conditions, that could interrupt the supply of electricity, in which case the generator will be required to purchase the electricity elsewhere in order to comply with its supply commitments. Under a Capacity Agreement, a generator commits to make a certain amount of capacity available to the ACR. In this case, the revenue of the generator is guaranteed and the distributor must assume the hydrological risk. However potential additional costs of the distributors are passed on to consumers. Together, these agreements comprise the energy purchase agreements in the ACR (Contratos de Comercialização de Energia no Ambiente Regulado), or CCEARs.

The regulation under the New Industry Model Law stipulates that distribution companies that contract less than 100% of their total captive consumption may be subject to fines. There are mechanisms to reduce this possibility, such as the purchase of energy from other distribution companies whose energy purchases exceeded forecasted demand, or purchase energy in auctions during the year. Any remaining shortfall from 100% of total captive consumption can be bought at the spot market price and the concessionaire would be subject to a penalty payment equivalent to the shortfall. If a company contracts more than 103% of its captive consumption, it would be subject to price risk if it sells this energy in the spot market in the future. To reduce such price risk, a company may reduce the purchase contracts in the “existing energy” auction by up to 4% each year, and reduce those contracts due to loss of consumers that became free and are supplied by generators directly.

The Free Market (the “ACL”) — In the free market, electricity is traded between generation concessionaires, IPPs (Independent Power Producer), self-generators, energy traders, importers of energy and Free Consumers. The free market also includes existing bilateral contracts between generators and distributors until they expire. Upon expiration, such contracts must be executed under the New Industry Model Law.

Potentially Free Consumers are those whose demand exceeds 3 MW at a voltage equal to or higher than 69kV or at any voltage level, so long as the supply began after July 1995. In addition, consumers with contracted demand equal to or greater than 500kW may be serviced by suppliers other than their local distribution company if they move to energy from alternative energy sources, such as wind, biomass or Small Hydroelectric Plants.

Once a consumer has opted for the free market, it may only return to the regulated system once it has given the distributor of its region five years notice, provided that the distributor may reduce such term at its discretion. This extended notice period seeks to assure that, if necessary, the distributor can purchase additional energy to supply the re-entry of Free Consumers into the regulated market. In addition, distributors may also reduce the amount of energy purchased according to the volume of energy that they will no longer distribute to Free Consumers. State-owned generators may sell electricity to Free Consumers, but as opposed to private generators, they are obliged to do so through an auction process.

Restricted Activities of Distributors

Distributors in the National Interconnected Power System (Sistema Interligado Nacional), or SIN, or the Brazilian Grid, are not permitted to (1) develop activities related to the generation or transmission of electricity, (2) sell electricity to Free Consumers, except for those in their concession area and under the same conditions and rates maintained with respect to captive consumers in the ACR, (3) hold, directly or indirectly, any interest in any other company, except interest in entities incorporated for raising, investment and management of funds necessary for the distributor or its controlled, controlling or under common control companies, corporation or partnership or (4) develop activities that are unrelated to their respective concessions, except for those permitted by law or in the relevant concession agreement.

Contracts Executed prior to the New Industry Model Law

The New Industry Model Law provides that the contracts executed by electricity distribution companies and approved by Aneel before the enactment of the New Industry Model Law will not be amended to reflect any extension in their terms or modification in prices or volumes of electricity already contracted.

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Reduction of the Level of Contracted Electricity

Decree No. 5,163/04, which regulates the trade of electricity under the New Industry Model Law, allows distribution companies to reduce their CCEARs: (1) to compensate for the exit of Potentially Free Consumers from the regulated market, pursuant to a specific declaration delivered to MME, (2) by up to 4.0% per year of the initial contracted amount due to market deviations from the estimated market projections, at the distribution companies’ discretion, beginning two years after the initial electricity demand was declared and (3) in the event of increases in the amounts of electricity acquired pursuant to contracts entered into before March 17, 2004. This reduction can be made only with CCEARs of existing power plants.

The circumstances in which the reduction of the level of contracted electricity will occur will be duly set forth in the CCEARs, and may be exercised at the sole discretion of the distribution company and in compliance with the provisions described above and Aneel regulations.

Pursuant to Aneel’s regulations, the reduction of the level of contracted energy under the CCEARs of existing energy shall be preceded by the so-called Mechanism of Compensation of Surplus and Deficits, or MCSD, by means of which distribution companies which have contracted energy in excess of their demand may assign a portion of their CCEARs to distribution companies which have contracted less energy than needed to meet their consumer’s demand.

Limitation on Pass-Through

The New Industry Model now also limits the pass-through of costs of electricity to final consumers. The Annual Reference Value corresponds to the weighted average of the electricity prices in the “A-5” and “A-3” auctions, calculated for all distribution companies, and creates an incentive for distribution companies to contract for their expected electricity demands in the “A-5” auctions, where the prices are expected to be lower than in “A-3” auctions. The Annual Reference Value will be applied in the first three years of the power purchase agreements from new power generation projects. After the fourth year, the electricity acquisition costs from these projects will be allowed to be fully passed-through. The decree establishes the following limitations on the ability of distribution companies to pass through costs to consumers:

· no pass-through of costs for electricity purchases that exceed 103% of regulatory demand;

· limited pass-through of costs for electricity purchases made in an “A-3” auction, if the volume of the acquired electricity exceeds 2.0% of the demand verified in “A-5” auctions;

· limited pass-through of electricity acquisition costs from new electricity generation projects if the volume re-contracted through CCEARs of existing generation facilities is below a “Contracting Limit” defined by Decree No. 5,163;

· electricity purchases from existing facilities in the “A-1” auction are limited to 0.5% of distribution companies’ demand and frustrated purchases in previous “A-1” auctions and involuntary exposure to captive consumer´s demand, plus the “replacement,” defined as the amount of energy needed to replace the power from power purchase contracts that expire in the current year(“A-1”), according to Aneel Resolution 450/2011. If the acquired electricity in the “A-1” auction exceeds the limit, pass-through of costs of the exceeding portion to final consumers is limited to 70.0% of the average value of such acquisition costs of electricity generated by existing generation facilities. The MME will establish the maximum acquisition price for electricity generated by existing projects;

· electricity purchases in “market adjustment” auctions are limited to 1.0% of a distribution concessionaire’s total demand (except for the years 2008 and 2009, when the limit was 5%) and pass-through of costs is limited to Annual Reference Value; and

· if distributors fail to comply with the obligation to fully contract their demand, the pass-through of the costs from energy acquired in the short-term market will be the equivalent to the lower of the PLD or the Annual Reference Value.

Rationing Under The New Industry Model Law

The New Industry Model Law establishes that, in a situation where the Federal Government decrees a compulsory reduction in the consumption of electricity in a certain region, all energy amount agreements in the regulated market, registered within the CCEE in which the buyer is located, shall have their volumes adjusted in the same proportion to the consumption reduction.

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Rates

Electric energy rates in Brazil are set by Aneel, which has the authority to readjust and review rates in accordance with the provisions under the relevant concession contracts. Each distribution company’s concession contract provides for an annual rate adjustment (reajuste anual). In general, Parcel A costs are fully passed through to consumers. Parcel A costs are the portion of the regular rate calculation formula, which provides for the recovery of certain costs that are not within the control of the distribution company. Parcel B costs, which are costs that are under the control of the distributors, are restated for inflation in accordance with the General Market Price Index (Indice Geral de Preços do Mercado), or IGP-M index. The average annual rate adjustment includes components such as the inter-year variation of Parcel A costs (CVA) and other financial adjustments, which compensate for changes in the company’s costs that were not previously taken into account in the rate we charged the year before. Since this inter-year variation is to reimburse changes in costs that took place in the previous year, it should not be part of next year’s annual adjustment.

Concessionaires of electricity distribution are also entitled to periodic revisions (revisão periódica). Our concession agreements establish a five-year period between periodic revisions. These revisions are aimed at (i) assuring necessary revenues to cover efficient Parcel B operational costs and adequate compensation for investments deemed essential for the services within the scope of each company’s concession and (ii) determining the X factor, which is calculated based on the average productivity gains from increases in scale and labor costs. There is another factor, Factor XQ, that punishes or reward the distribution company depending on the quality of the service provided. The last component of the X Factor, called Factor Xt, has the objective of reducing or increasing the regulatory operational costs during the five year period between the rates revisions to reach the level defined for the last year of the revision cycle.

In 2011, Aneel finalized Public Hearing 040/2010, in which it dealt with the methodology for the third periodic revision. To calculate the rate of return Aneel uses the methodology of Weighted Average Cost of Capital (WACC), which resulted in a rate of 7.50% after taxes compared to the rate of 11.25% applied in the last cycle.

Aneel also decided to change the methodology used to calculate the X-Factor from the discounted cash flow methodology to the Total Factor Productivity (TFP) method, which consists in defining potential productivity gains for each company based on the average productivity gains. Its is expected that this will result in an increase in the X Factor. These changes in methodology will take effect on 2013.

Aneel has also issued regulations that govern the access to the distribution and transmission facilities and establish the rate for use of the local distribution system, or Distribution Usage Rates, or TUSD, and the rate for the use of the transmission grid, or Transmission Usage Rates, or TUST. The rates to be paid by distribution companies, generators and Free Consumers for use of the interconnected power system are reviewed annually. The review of the TUST takes into account the revenues that are permitted of transmission concessionaires pursuant to their concession contracts. For more detailed information regarding the rate-setting structure in Brazil, see “—The Brazilian Power Industry—Rates for the Use of the Distribution and Transmission Systems.”

Land Acquisition

The concessions granted to us by the Federal Government do not include a grant of the land upon which the plants are located. Electricity concessionaires in Brazil typically have to negotiate with the individual landowners to obtain needed land. However, in the event that a concessionaire is unable to obtain needed land in this way, such land may be condemned for the concessionaire’s use through specific legislation. In cases of governmental condemnation, the concessionaires may have to participate in negotiations relating to the amount of compensation with landowners and the resettlement of communities to other locations. We make all efforts to negotiate with the communities before applying to the judiciary.

The Brazilian Electricity System Overview

Brazil’s power production and transmission is a large-scale hydroelectric and thermal system made up predominantly of hydroelectric power stations, with multiple owners. The Brazilian Grid is comprised of companies in the southern, southeastern, west-central, and northeastern regions and part of the northern region of Brazil. Approximately 2% of the country’s electricity production capacity is not connected to the Brazilian Grid, in small isolated systems located mainly in the Amazon region. Brazil’s abundant hydrological resources are managed through storage reservoirs. It is estimated that Brazil has a hydroelectric power generation potential close to 244,976 MW, of which only 35.4% has been developed or is under construction, according to Eletrobrás studies consolidated in December 2012.

Brazil has an installed capacity in the interconnected power system of 109.416 GW as of December 2012, approximately 76.3% of which is hydroelectric, according to the Operation Plan for 2013 from the ONS. This installed capacity includes half of the installed capacity of Itaipu—a total of 14,000 MW owned equally by Brazil and Paraguay. There are approximately 61,000 miles of transmission lines with voltages equal to or higher than 230 kV in Brazil.

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Approximately 36% of Brazil’s installed generating capacity and 56% of Brazil’s high voltage transmission lines are operated by Eletrobrás, a company owned by the Federal Government. Eletrobrás has historically been responsible for implementing electric policy, conservation and environmental management programs. The remaining high voltage transmission lines are owned by state-controlled or local electric power companies. Distribution is conducted by approximately 60 state or local utilities, a majority of which have been privatized by the Federal Government or state governments.

Historical Background

The Brazilian Constitution provides that the development, use and sale of energy may be undertaken directly by the Federal Government or indirectly through the granting of concessions, permissions or authorizations. Since 1995, the Federal Government has taken a number of measures to restructure the power industry. In general, these measures were aimed at increasing the role of private investment and eliminating foreign investment restrictions, thus increasing overall competition in the power industry.

In particular, the Federal Government has taken the following measures:

· The Brazilian Constitution was amended in 1995 to authorize foreign investment in power generation. Prior to this amendment, all generation concessions were held either by a Brazilian individual or an entity controlled by Brazilian individuals or by the Federal or state governments.

· The Federal Government enacted Law No. 8,987 on February 13, 1995, or the Concessions Law, and Law No. 9,074 on July 7, 1995, or the Power Concessions Law, that together:

· required that all concessions for the provision of energy-related services be granted through public bidding processes;

· gradually allowed certain electricity consumers with significant demand (generally greater than 3 MW), referred to as Free Consumers, to purchase electricity directly from suppliers holding a concession, permission or authorization;

· provided for the creation of generation entities, or Independent Power Producers, which, by means of a concession, permission or authorization, may generate and sell all or part of their electricity to Free Consumers, distribution concessionaires and trading agents, among others;

· granted Free Consumers and electricity suppliers open access to all distribution and transmission grids; and

· eliminated the need for a concession to construct and operate power projects with capacity from 1 MW to 30 MW, or “Small Hydroelectric Power Plants” , which was amended on May 28, 2009 by Law No. 11,943, raising the limit from 30 MW to 50 MW, independently of being a Small Hydroelectric Power Plant or not.

· The creation of Aneel and of the CNPE, in 1997.

· In 1998, the Federal Government enacted Law No. 9,648, or the Power Industry Law, to overhaul the basic structure of the electricity industry. The Power Industry Law provided for the following:

· the establishment of a self-regulated body responsible for the operation of the short-term electricity market, or the Wholesale Energy Market, which replaced the prior system of regulated generation prices and supply contracts;

· the creation of the ONS, a non-profit, private entity responsible for the operational management of the generation and transmission activities of the interconnected power system; and

· the establishment of public bidding processes for concessions for the construction and operation of power plants and transmission facilities, in addition to the bidding process requirements under the Concessions Law and the Power Concessions Law.

· On March 15, 2004, the Federal Government enacted Law No. 10,848, or the New Industry Model Law, in an effort to further restructure the power industry with the ultimate goal of providing consumers with secure electricity supplies combined with low rates. On July 30, 2004 the Federal Government published Decree 5,163, governing the purchase and sale of electricity under the New Industry Model Law, as well as the granting of authorizations and concessions for electricity generation projects. These include rules relating to auction procedures, the form of power purchase agreements and the method of passing costs through to final consumers.

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· On September 12, 2012 the Federal Government enacted PM 579, converted into the Law No. 12,783, aiming to decrease tariffs on generation, transmission and distribution of energy and enact regulatory charges on the Brazilian energy market. PM 579 alters the revision and extension of certain concessions and implements new bidding process rules for certain utilities, as well as adjustments to tariffs, changes to regulation regarding the industry participant’s mobility between the ACR and ACL and the allocation of energy offered to both markets.

Rationing and Extraordinary Rate Increases

Below average rainfall in the years preceding 2001 resulted in low reservoir levels and low hydroelectric capacity in the Southeast, Central West and Northeast regions. A program known as the Electricity Rationing Program, that lasted from June 2001 until February 2002, was designed to solve this problem and establish normal levels for reservoirs. As a result of the end of the rationing measures, the Federal Government created the Electricity Sector Management Committee (Câmara de Gestão do Setor Elétrico), or CGSE, as coordinator of the electricity sector revitalization measures. The General Agreement of the Electricity Sector was created to provide for compensation for rationing-related losses to generation and distribution companies in Brazil and restore the economic equilibrium of the concession agreements. An extraordinary rate increase, or RTE, applicable to final consumers would compensate both generators and distributors for such rationing-related losses. The RTE also covers financial losses from January 2001 to October 2001, resulting from those costs that are beyond the control of the distributor, referred to as Parcel A costs, as well as losses of generators incurred as a result of payment of free energy costs above the Initial Contract average price.

BNDES created a special program to finance 90% of the amounts recoverable by means of the RTE. The loans are repayable over the rate increase collection period.

In April 2003, the Federal Government, fearing that rate increases may contribute to overall inflation in Brazil, decided to delay a rate increase to which distribution companies were entitled under Aneel resolutions to recover intra-annual variation of Parcel A costs.

Concessions

The companies or consortia that wish to build or operate facilities for generation, transmission or distribution of electricity in Brazil must apply to the MME or to Aneel, by delegation of MME, as granting authority, for a concession, permission or authorization, as the case may be. Concessions grant rights to generate, transmit or distribute electricity in the relevant concession area for a specified period. This period is usually 35 years for new generation concessions, and 30 years for new transmission or distribution concessions. For the renewal of existing concessions, the period was usually 20 years for distribution, 20-30 years for transmission, depending on the contract, and the period for generation depended on the contracts. An existing concession, granted prior to the publication of Law 10,848 of March 15, 2004 may be renewed once at the granting authority’s discretion. Concessions granted after the publication of Law 10,848 could not be extended further.

However, with the enactment of PM 579, converted into Law No. 12,783, the concessions granted pursuant to Law No. 9074 of July 7, 1995, may be extended only once for a period of up to 30 years, at the discretion of the grantor, from September 12, 2012 onward.

On December 4, 2012, the Company signed the second amendment to Transmission Concession Contract 006/1997, which extended concession for 30 years under the terms of PM 579 from January 1, 2013. However, the Company opted not to request extension of the generation concessions that expire within the period 2013 to 2017. For the plants that would have had a first extension before PM579, which include the Jaguara, São Simão and Miranda plants, we believe the Generation Concession Contract 007/1997 allows for the extension of the concession of those plants for an additional 20 years, subject to no additional conditions. For the other generation companies the have concessions that expire over the period from 2015 to2017, which includesTrês Marias, Salto Grande, Itutinga, Camargos, Piau, Gafanhoto, Peti, Tronqueiras, Joasal, Martins, Cajuru, Paciência, Marmelos, Sumidouro, Anil, Poquim, Dona Rita and Volta Grande, we have opted, under the terms of PM579, not to apply for an extension of their concessions.

The Concession Law establishes, among other things, the conditions that the concessionaire must comply with in rendering electricity services, the consumer’s rights and the obligations of the concessionaire and the granting authority. Furthermore, the concessionaire must comply with regulations in force governing the electricity sector. The main provisions of the Concession Law are summarized as follows:

Adequate Service — The concessionaire must render an adequate service to satisfy, among other things, regularity, continuity, efficiency, safety and accessibility of the service.

Use of Land — The concessionaire may use public land or request the granting authority to declare the public interest of private real estate, so as to benefit the concessionaire. In such case the concessionaire shall compensate the affected owners.

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Strict Liability — The concessionaire is strictly liable for all damages arising from the performance of its services and caused to consumers, to third parties or to the granting authority.

Changes in Controlling Interest — The granting authority must previously approve any direct or indirect change in the concessionaire’s controlling interest.

Intervention by the Granting Authority — The granting authority may intervene in the concession, by means of a presidential decree, to ensure the concessionaire’s adequate performance of services, as well as the full compliance with applicable contractual, regulatory and legal provisions in case the concessionaire fails to do so. Within 30 days after the decree date, the granting authority’s representative is required to commence an administrative proceeding in which the concessionaire is entitled to due process of law. During the term of the administrative proceeding, a person appointed by the granting authority’s decree becomes responsible for carrying on the concession. If the administrative proceeding is not completed within 180 days after the decree date, the intervention ceases and the concession is returned to the concessionaire. The concession is also returned to the concessionaire if the granting authority’s representative decides not to terminate the concession and the concession term has not yet expired.

Termination of the Concession — The concession termination agreement may be terminated through expropriation and/or forfeiture. Expropriation is the early termination of a concession for reasons related to the public interest that must be expressly declared by law and based on public interest grounds. Following the expropriation, the concessionaire is entitled to receive an indemnification, which may or may not adequately compensate investments made by the concessionaire in expropriated assets that have not been fully amortized or depreciated by the time of the expropriation. Forfeiture must be declared by the granting authority after Aneel, or MME, has made a final administrative ruling that the concessionaire has failed to adequately perform its obligations under the concession agreement. The concessionaire is entitled to due process of law in the administrative proceeding declaring the forfeiture of the concession and can resort to the courts. The concessionaire is entitled to receive an indemnification for the investments made by the concessionaire in expropriated assets that have not been fully amortized or depreciated, after deduction of any amounts corresponding to outstanding fines and damages due by the concessionaire.

Expiration — When the concession expires, all assets, rights and privileges that are materially related to the rendering of the electricity services revert to the Brazilian government. Following the expiration, the concessionaire is entitled to receive an indemnification for the investments made by the concessionaire in expropriated assets that have not been fully amortized or depreciated by the time of the expiration, net of special obligation.

Penalties — Aneel’s Resolution 63, enacted on May 12, 2004, as amended governs the imposition of sanctions against the operators in the electricity sector, defines conduct constituting violations of the law and classifies the appropriate penalties based on the nature and gravity of the violation (including warnings, fines, temporary suspension from the right to participate in bidding procedures for new concessions, licenses or authorizations and forfeiture). Depending on the violation, the fines can be up to two per cent of the amount invoiced by the concessionaires in the 12-month period preceding any assessment notice. Some infractions that may result in fines relate to the failure of the operator to request Aneel’s approval in case of:

· Execution of contracts with related parties in the cases provided by regulation;

· Sale or assignment of the assets or revenues related to the services rendered as well as the imposition of any encumbrances (including any security, bond, guarantee, pledge and mortgage) on them or any other assets related to the concession or the revenues of the electricity services; and

· Changes in controlling interest of the holder of the authorization or concession.

Principal Regulatory Authorities

National Energy Policy Council—CNPE

In August 1997, the National Energy Policy Council (Conselho Nacional de Política Energética), or CNPE, was created to advise the Brazilian president regarding the development and creation of the national energy policy. The CNPE is presided over by the MME, and the majority of its members are officials of the Federal Government. The CNPE was created to optimize the use of Brazil’s energy resources and to assure the supply of electricity to the country.

Ministry of Mines and Energy—MME

The MME is the Federal Government’s primary regulator of the power industry. Following the adoption of the New Industry Model Law, the Federal Government, acting primarily through the MME, undertook certain duties that were previously under the

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responsibility of Aneel, including the drafting of guidelines governing the granting of concessions and the issuance of directives governing the bidding process for concessions relating to public services and public assets.

National Electric Energy Agency—Aneel

The Brazilian power industry is regulated by Aneel, an independent federal regulatory agency. After enactment of the New Industry Model Law, Aneel’s primary responsibility is to regulate and supervise the power industry in line with the policy to be dictated by MME and to respond to matters which are delegated to it by the Federal Government and or MME.

National System Operator—ONS

The ONS was created in 1998 as a non-profit private entity comprised of Free Consumers and energy utilities engaged in the generation, transmission and distribution of electricity, in addition to other private participants such as importers and exporters. The New Industry Model Law, granted the Federal Government the power to appoint three directors of the ONS, including the Director-general. The primary role of the ONS is to coordinate and control the generation and transmission operations in the interconnected power system, subject to Aneel’s regulation and supervision.

Electric Energy Trading Chamber—CCEE

One of the main roles of the CCEE is to conduct public auctions in the regulated market, including the auction of existing electricity and new electricity. Additionally, the CCEE is responsible, among other things, for (1) registering the volume of all the energy purchase agreements within the regulated market (Contratos de Comercialização de Energia no Ambiente Regulado), or CCEAR, and the agreements resulting from the free market, and (2) the accounting for and clearing of short-term transactions.

Under the New Industry Model Law, the price of electricity bought or sold in the spot market, known as the Price of Liquidation of Differences (Preço de Liquidação de Diferenças), or PLD, takes into account factors similar to the ones used to determine the Wholesale Energy Market spot prices prior to the New Industry Model Law. Among these factors, the variation of the PLD will be mainly linked to the equilibrium between the market supply and demand for electricity as well as the impact that any variation on this equilibrium may have on the optimal use of the electricity generation resources by the ONS.

The CCEE is comprised of power generation, distribution, trading agents and Free Consumers, and its board of directors is comprised of four members appointed by these agents and one by the MME, who is the chairman of the board of directors.

Energy Research Company—EPE

On August 16, 2004, the Federal Government enacted the decree that created the Electricity Research Company, or EPE, a state-owned company, which is responsible for conducting strategic research on the energy industry, including, among others, electric energy, oil, gas, coal and renewable energy sources. EPE is responsible for (i) studying projections of the Brazilian energy matrix, (ii) preparing and publishing the national energy balance, (iii) identifying and quantifying energy resources and (iv) obtaining the required environmental licenses for new generation concessionaires. The research carried out by EPE will be used to subsidize MME in its policymaking role in the domestic energy industry. EPE is also responsible for approving the technical qualification of new electric energy projects to be included in the related auctions.

The Electricity Sector Monitoring Committee—CMSE

Decree 5,175, of August 9, 2004, established the Electricity Sector Monitoring Committee, or CMSE, which acts under the direction of the MME. The CMSE is responsible for monitoring and permanently evaluating the continuity and security of the electricity supply conditions and for indicating necessary steps to correct identified problems.

Ownership Limitations

On November 10, 2009, Aneel issued Resolution No. 378, which established that Aneel, upon identifying an act that may cause unfair competition or may result in relevant market control, must notify the Secretariat of Economic Law (Secretaria de Direito Econômico) (“SDE”) of the Ministry of Justice, pursuant to art. 54 of Law No. 8,884 of June 11, 1994. After the notification, the SDE must inform CADE. On November 30, 2011 Law No. 8,884 was revoked and replaced by Law 12,529. This new law extinguished SDE and replaced it with the General Superintendency (Superintendência Geral). If necessary, the General Superintendency will require Aneel to analyze the aforementioned acts. CADE will decide if there should be any punishment regarding those acts, which may vary from pecuniary penalties to the split of the company, pursuant to articles 37 and 45 of the abovementioned law.

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Incentives for Alternative Sources of Power

In 2000, a Federal decree created the Thermoelectric Priority Program (Programa Prioritário de Termeletricidade), or PPT, for purposes of diversifying the Brazilian energy matrix and decreasing its strong dependency on hydroelectric plants.

In 2002, the Proinfa was established by the Federal Government to create certain incentives for the development of alternative sources of energy, such as wind energy projects, Small Hydroelectric Power Plants and biomass projects.

Law 9,427/96, as amended by Law 10,762/03, further established that hydroelectric plants with an installed capacity of 1MW or less, generation plants classified as Small Hydroelectric Plants, and those with qualifying solar, wind, biomass or cogeneration sources, with an injected capacity of 30MW or less, used for independent production or self-production, will have the right to a discount of at least 50% on the rates for use of the transmission and distribution system, charged on production and consumption of the energy sold. This legal provision was regulated by Aneel through its Resolutions 077/2004, 247/2006 and 271/2007.

Also the government promoted two alternative energy generation auctions and four backup regulated auctions where the plants that are allowed to sell energy on pursuant to these auctions are either wind energy projects, SHP projects or biomass projects.

Regulatory Charges

Global Reversion Fund and Public Use Fund—RGR and UBP

In certain circumstances, power companies are compensated for assets used in connection with a concession if this concession is eventually revoked or is not renewed. In 1971, the Brazilian Congress created a Global Reversion Fund (Reserva Global de Reversão), or RGR, designed to provide funds for such compensation. In February 1999, Aneel revised the assessment of a fee requiring all distributors and certain generators operating under public service regimes to make monthly contributions to the RGR at an annual rate equal to 2.5% of the company’s fixed assets in service, but not to exceed 3.0% of total operating revenues in any year. In recent years, the RGR has been used principally to finance generation and distribution projects.

The Federal Government has imposed a fee on IPPs reliant on hydrological resources, except for Small Hydroelectric Power Plants and generators under the public services regime, similar to the fee levied on public-industry companies in connection with the RGR. IPPs are required to make contributions to the Public Use Fund (Fundo de Uso de Bem Público), or UBP, according to the rules of the corresponding public bidding process for the granting of concessions. Eletrobrás received the UBP payments until December 31, 2002. All payments to the UBP since December 31, 2002 are paid directly to the Federal Government.

Since January 2013, the Global Reversion Fund is not charged to any (i) distribution company; (ii) transmission and generation utilities that extended its concessions granted under Law No. 12,783; and (iii) any transmission utility which had commenced its bidding procedure from September 12, 2012 onward.

Fuel Consumption Account—CCC

The Fuel Consumption Account (Conta de Consumo de Combustível), or CCC, was created in 1973 to generate financial reserves to cover elevated costs associated with the use of thermoelectric energy plants, especially in the northern region of Brazil given the higher operating costs of thermoelectric energy plants compared to hydroelectric energy plants. Each energy company is required to contribute annually to the CCC. The annual contributions were calculated on the basis of estimates of the cost of fuel needed by the thermoelectric energy plants in the following year. The CCC, in turn, was used to reimburse energy companies for a substantial portion of the fuel costs of their thermoelectric energy plants. The CCC was administered by Eletrobrás.

Since January 2013, the Fuel Consumption Account is not charged to any kind of utility and or market participant due to the provisions of Law No. 12,783

Charge for the Use of Water Resources

With the exception of Small Hydroelectric Power Plants, all hydroelectric utilities in Brazil must pay fees to Brazilian states and municipalities for the use of hydrological resources. Such amounts are based on the amount of electricity generated by each utility and are paid to the states and municipalities where the plant or the plant’s reservoir is located.

Energy Development Account— CDE

In 2002, the Federal Government instituted the Energy Development Account (Conta de Desenvolvimento Energético), or CDE, which is funded through annual payments made by concessionaires for the use of public assets, penalties and fines imposed by

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Aneel and, since 2003, the annual fees to be paid by agents offering electricity to final consumers, by means of a charge to be added to the rates for the use of the transmission and distribution system. These fees are adjusted annually. The CDE was created to support the (1) development of electricity production throughout the country, (2) production of electricity by alternative energy sources, (3) universalization of energy services throughout Brazil, and (4) with the enactment of Law No. 12,783, to set off the effect of non-compliance by concessionaires to Law No. 12,783 in decreasing the electricity tariffs. The CDE shall be in effect for 25 years and shall be managed by Eletrobrás.

The New Industry Model Law establishes that the failure to pay the contribution to RGR, Proinfa Program, the CDE or payments due by virtue of purchase of electricity in the regulated market will prevent the non-paying party from receiving a rate readjustment (except for an extraordinary revision) or receiving resources arising from the RGR or CDE.

Aneel Inspection Charge

Energy Services Inspection Charge, or TFSEE, is an annual tax charged by Aneel for its administrative and operational costs. The tax is calculated based on the type of service provided (including independent production), and is proportional to the size of the concession, permission or authorization. The TFSEE is limited to 0.4% of the annual economic benefit, considering the installed capacity, earned by the concessionaire, permit holder or authorized party and must be paid directly to Aneel in 12 monthly installments.

Energy Reallocation Mechanism

The Energy Reallocation Mechanism (Mecanismo de Realocação de Energia), or MRE, attempts to mitigate the risks involved in the generation of hydroelectric power by mandating that all hydrogenerators share the hydrological risks within the Brazilian Grid. Under Brazilian law, the revenue arising from the energy sales by generators does not depend on the amount of energy they in fact generate, but rather on Guaranteed Energy or Assured Energy of each plant. The Guaranteed or Assured Energy is indicated in each concession agreement.

Any imbalances between the power energy actually generated and the Assured Energy is covered by the MRE. In other words, the MRE reallocated the energy, transferring surplus from those who generated in excess of their Assured Energy to those who generated less than their Assured Energy. The volume of electricity actually generated by the plant, either more or less than the Assured Energy, is priced pursuant to an “Energy Optimization Tariff” which covers the operation and maintenance costs of the plant. This revenue or additional expense will be accounted for on a monthly basis by each generator.

Although the MRE is efficient to mitigate the risks of individual plants that have adverse hydrological conditions in a river basin, it does not succeed in mitigating this risk when low hydro levels affect the National Interconnected System (“System”) as a whole or large regions of it. In extreme situations, even with the MRE, generation of the entire System won’t attain the level of the Assured Energy and hydro generators may be exposed to the spot market. In these situations, the shortage in hydro resources is going to be compensated by greater use of thermal generation and spot prices will be higher

Rates for the Use of the Distribution and Transmission Systems

Aneel oversees rate regulations that govern access to the distribution and transmission systems and establish rates (i) for the use of the local distribution system, or Distribution Usage Rates, or TUSD, and (ii) for the use of the interconnected transmission grid, or Transmission Usage Rates, or TUST. Additionally, distribution companies of the South, South-East and Midwest interconnected system pay specific charges for the transmission of electricity generated at Itaipu. The increase in transmission rates and charges paid by distribution concessionaires are passed on to their respective consumers through Annual Rate Adjustments. All this rates are set by Aneel. The following is a summary of each rate or charge:

TUSD

The TUSD is paid by generation companies and customers for the use of the distribution system to which they are connected. It is readjusted annually according to an inflation index and the variation of costs for the transmission of energy and regulatory charges.

TUST

The TUST is paid by generation companies and Free Consumers for the use of the basic transmission grid to which they are connected. It is adjusted annually according to an inflation index and the annual revenue of the transmission companies adjustment. According to criteria established by Aneel, owners of the different parts of the transmission grid were required to transfer the coordination of their facilities to the ONS in return for receiving regulated payments from the transmission system users.

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Distribution

Distribution rates are subject to review by Aneel, which has the authority to adjust and review rates in response to changes in electricity purchase costs and market conditions. When adjusting distribution rates, Aneel divides the costs of distribution companies between (1) costs that are beyond the control of the distributor, or Parcel A costs, and (2) costs that are under the control of the distributor, or Parcel B costs. The rate adjustment is based on a formula that takes into account the division of costs between the two categories.

Parcel A costs include, among others, the following:

· Regulatory Charges (RGR, CCC, CDE, TFSEE and Proinfa);

· Costs of electricity purchased for resale (CCEAR, Itaipu’s Energy and bilateral agreements); and

· Transmission’s charge (TUST, TUSD, Transport of Electricity from Itaipu, Use of Sites for Connection and ONS).

Parcel B costs are those that are within our control and include:

· return on investment;

· taxes;

· regulatory default;

· depreciation costs; and

· operation costs of the distribution system.

In general, Parcel A costs are fully passed through to consumers. Parcel B costs, however, are restated for inflation in accordance with General Market Price Index (Indice Geral de Preços do Mercado), or IGP-M index, adjusted by an X Factor. Electricity distribution companies, according to their concession contracts, are also entitled to periodic revisions (revisão periódica). These revisions are aimed at (1) assuring necessary revenues to cover efficient Parcel B operational costs and adequate compensation for investments deemed essential for the services within the scope of each company’s concession and (2) determining the X factor.

The X factor is used to adjust the proportion of the change in the IGP-M index that is used in the annual adjustments and to share the company’s productivity gains with final consumers.

In addition, concessionaires of electricity distribution are entitled to extraordinary review of rates (revisão extraordinária), on a case by case basis, to ensure their financial equilibrium and compensate them for unpredictable costs, including taxes, that significantly change their cost structure.

Item 4A. Unresolved Staff Comments

Not Applicable.

Item 5. Operating and Financial Review and Prospects

You should read the information contained in this section together with our financial statements contained elsewhere in this annual report. The following discussion is based on our financial statements, which have been prepared in accordance with IFRS and presented in reais.

Statement of Compliance

Our consolidated financial statements have been prepared in accordance with International Financial Reporting Standards (“IFRS”), as issued by the International Accounting Standards Board (IASB).

Basis of measurement

The consolidated financial statements have been prepared based on the historical cost basis except for the following material items in the statement of financial position:

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· Financial instruments and derivative financial instruments measured at fair value

· Non-derivative financial assets measured at fair value through profit or loss

· Financial assets held for trading measured at fair value.

· Financial assets of the Concession measured by the New Replacement Value (VNR), equivalent to fair value.

The consolidated financial statements are presented in reais, which is the Company’s functional currency.

Critical Accounting Estimates

The following discussion describes those areas that require the most judgment or involve a higher degree of complexity in the application of the accounting policies that currently affect our financial condition and results of operations. The accounting estimates we make in these contexts require us to make assumptions about matters that are highly uncertain. The discussion addresses only those estimates that we consider most important based on the degree of uncertainty and the likelihood of a material impact if we used a different estimate. There are many other areas in which we use estimates about uncertain matters, but the reasonably likely effect of changed or different estimates is not material to our financial presentation. For more detailed information about our Critical Accounting Policies and Estimates, please refer to Note 2 to our audited consolidated financial statements as of December 31, 2012.

Allowance for Doubtful Accounts

We record an allowance for doubtful accounts in an amount that we estimate to be sufficient to cover presently foreseeable losses as follows: (i) for consumers with material debts, an individual analysis of the balance is made, taking into account the history of default, negotiations in progress and the existence of real guarantees; (ii) for other consumers, the debts that are more than 90 days past due for residential consumers, or more than 180 days past due for commercial consumers, or more than 360 days past due for the other consumer types, are provisioned at 100%. These criteria are the same as those established by Aneel.

We continuously monitor collections and payments from consumers and review and refine our estimation process. A future change in our estimates could result in an increase in the allowance for doubtful accounts which could have a material adverse impact on our operating results and financial condition.

Deferred income tax and social contribution

We account for income taxes in accordance with IFRS. IFRS requires an asset and liability approach to recording current and deferred taxes. Accordingly, the effects of differences between the tax basis of assets and liabilities and the amounts recognized in our consolidated financial statements have been treated as temporary differences for the purpose of recording deferred income tax.

We regularly review our deferred tax assets for recoverability and establish a valuation allowance based on historical taxable income, projected future taxable income, and the expected timing of the reversals of existing temporary differences. If we are unable to generate sufficient future taxable income, or if there is a material change in the actual effective tax rates or time period within which the underlying temporary differences become taxable or deductible, we could be required to establish a valuation allowance against all or a significant portion of our deferred tax assets resulting in a substantial increase in our effective tax rate and a material adverse impact on our operating results.

Depreciation and Amortization

Depreciation and Amortization is computed using the straight-line method, at annual rates based on the estimated useful lives of the assets, in accordance with Aneel regulations and industry practice in Brazil.

Our accounting treatment for amortization of intangible assets depends on the nature of the intangible asset. Intangible assets linked to a service concession agreement, net of residual value, are amortized in accordance with IFRIC 12 on a straight-line basis over the concession period stipulated in the concession contract. Other intangible assets are amortized on a straight-line basis over the estimated useful economic lives of the assets in conformity with the amortization rates established by Aneel.

To the extent that the actual lives differ from these estimates, there would be an impact on the amount of depreciation and amortization accrued in our consolidated financial statements. A significant decrease in the estimated useful life of a material amount of property, plant and equipment, intangibles, or in the assets of the electricity generation project consortium in which we are a partner, could have a material adverse impact on our operating results in the period in which the estimate is revised and in subsequent periods.

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Employee Post-Retirement Benefits

We sponsor a defined-benefit pension plan and defined-contribution pension plan covering substantially all of our employees. Our jointly controlled, Light, also sponsor a defined-benefit pension plan and defined-contribution pension plan.

The determination of the amount of our obligations for pension and other post-retirement benefits depends on certain actuarial assumptions. These assumptions are described in Note 21 to our consolidated financial statements and include, among others, the expected long-term rate of return on plan assets and increases in salaries and healthcare costs. While we believe that our assumptions are appropriate, significant differences in actual results or significant changes in our assumptions may materially affect our pension and other post-retirement obligations.

Provision for Contingencies

We are party to certain legal proceedings in Brazil arising in the normal course of business regarding tax, labor, civil and other issues.

Such provisions are estimated based on historical experience, the nature of the claims, as well as the current status of the claims. Accounting for contingencies requires significant judgment by management concerning the estimated probabilities and ranges of exposure to potential liability. Management’s assessment of our exposure to contingencies could change as new developments occur or more information becomes available. The outcome of the contingencies could vary significantly and could materially impact our consolidated results of operations, cash flows and financial position.

Unbilled electric power supplied

Unbilled retail supply of electric power, from the period between the last billing and the end of each month, is estimated based on the billing from the previous month and is accrued for at the end of the month. While we believe that our accruals are appropriate, significant differences in actual results or significant changes in our assumptions may materially affect our consumers receivables.

Derivative Instruments

Accounting for derivative transactions requires us to employ judgment to compute fair market values, which are used as the basis for recognition of the derivative instruments in our consolidated financial statements. Such measurement may depend on the use of estimates such as long term interest rates, foreign currencies and inflation indices, and becomes increasingly complex when the instrument being valued does not have counterparts with similar characteristics traded in an active market. For more detailed information about Derivative Instruments please refer to Note 28 to our audited consolidated financial statements as of December 31, 2012.

Recently Issued IFRS Standards

We will be required to adopt certain revised IFRS accounting standards beginning on January 1, 2013. These new IFRS standards that we believe will be applicable to our operations are described below in more detail.

IFRS 9 – Financial Instruments

IFRS 9 – Financial instruments, issued in November 2009 and altered in October 2010, introduces new requirements for the classification, measurement and write-off of financial assets and liabilities. IFRS 9 is applicable for annual periods starting on or after January 1, 2015.

IFRS 9 establishes that all the financial assets recognized that are within the scope of IAS 39 - Financial instruments: Recognition and measurement (equivalent to CPC 38) must be subsequently measured at amortized cost or fair value.

The most significant effect of IFRS 9 relates to the accounting for changes in fair value of a financial liability (designated at fair value through profit or loss) attributable to changes in the credit risk of that liability. Specifically, under IFRS 9, in relation to the financial liabilities recognized at fair value through profit or loss, the amount of the change in the fair value of the financial liability attributable to changes in the credit risk of that liability is recognized in “Other comprehensive income”, unless the recognition of the effects of the change in the credit risk of the liability in “Other components of comprehensive income” results in or increases the

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accounting mismatch in the profit and loss account. Variations in fair value attributable to the credit risk of a financial liability are not reclassified in the profit and loss account. Previously, under IAS 39 and CPC 38, the total amount of the variation in the fair value of the financial asset recognized at fair value through profit or loss was recognized in the profit and loss account.

Our management expects our adoption of IFRS 9 will have a significant effect on the balances reported in relation to our financial assets and liabilities (for example, the financial assets of the concession currently classified as investments available for sale will be measured at fair value at the end of the subsequent reporting periods, and the alterations in fair value will be recognized in profit or loss). However, it is not possible to provide a reasonable estimate of this effect until a detailed review is carried out.

Consolidation, participation agreements, affiliates and related disclosures

In May 2011 five new standards on consolidation, participation agreements, affiliates and disclosures were issued, including IFRS 10, IFRS 11, IFRS 12, IAS 27 (revised in 2011) and IAS 28 (revised in 2011). These five rules , together with the respective changes related to the rules for transition, are applicable to annual periods starting on or after January 1, 2013.

The main requirements of these five rules are as follows:

IFRS 10 replaced parts of IAS 27 – Consolidated and separate financial statements – that dealt with consolidated financial statements. SIC–12 Consolidation: Special Purpose Entities – will be withdrawn when IFRS 10 is applied. Under IFRS 10, there is only one basis for consolidation, namely, control. Additionally, IFRS 10 will include a new definition of control which contains three elements: (a) power over an investee; (b) exposure, or rights, to variable returns from the holding in the investee; and (c) capacity to use its power over the investee to effect the value of the returns to the investor.

IFRS 11 replaces IAS 31 – Interests in joint ventures. IFRS 11 deals with how a participation agreement in which two or more parties have joint control should be classified. SIC-13 – Jointly Controlled Entities – Non-Monetary Contributions by Venturers – will be withdrawn when IFRS 11 is applied. Under IFRS 11, participation agreements are classified as joint operations or joint ventures, depending on the rights and obligations of the parties to the agreements. Additionally, under IFRS 11, joint ventures must be accounted for under the equity method, while jointly-controlled subsidiaries, under the previous criteria of IAS 31, could be accounted for under the equity method or by the proportional consolidation method.

IFRS 12 is a disclosure standard applicable to entities that have holdings in subsidiaries, participation agreements, affiliates and/or structured entities that are not consolidated. In general, the requirements for disclosure under IFRS 12 are more wide-ranging than the present rules.

Our management believes that the application of these five rules will cause a significant effect on the amounts reported in our consolidated financial statements. All the entities that are jointly-controlled by us listed in Note 3 (c) of our audited financial statements are proportionately consolidated in these financial statements and qualify as joint ventures under the requirements of IFRS 11. Thus, they will be presented by the equity method starting in 2013.

If these five rules had been adopted as of December 31, 2012, the consolidated financial statements would have been effected as follows: (i) a reduction of total assets and total liabilities in the amount of R$ 7,629,666; (ii) a reduction in Operational profit before Financial revenue (expenses) and taxes of R$ 1,212,689; and (iii) a reduction in net revenue in the amount of R$ 3,850,380. The profit for the year, and Stockholders’ equity, would not be affected by the adoption of the new rules.

IFRS 13 - Measurement at fair value

IFRS 13 presents a single source of orientation for measurements of fair value and disclosures on measurements of fair value. The rule defines fair value, presents a structure of measurement of fair value and requires disclosures of the measurements of fair value. The scope of IFRS 13 is wide-ranging, applying to items of financial and non-financial instruments, for which other IFRS standards call for or allow measurements of fair value and disclosures of measurements of fair value, except in certain cases. For example, quantitative and qualitative disclosures, based on the three-level hierarchy of fair value currently required for financial instruments only in accordance with IFRS 7 – Financial Instruments – Disclosures, will be complemented by IFRS 13 so as to include all assets and liabilities in their scope.

IFRS 13 is applicable for annual periods starting on or after January 1, 2013.

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Our management expects that the adoption of this new rule could affect certain amounts reported in our financial statements and result in more wide-ranging disclosures in our financial statements.

IAS 1- Presentation of Financial Statements

The changes to IAS 1 allow for the presentation of the Profit and loss account and the Statement of comprehensive income in a single statement or in two separate and consecutive statements. However, the changes to IAS 1 call for additional disclosures in Other comprehensive income, in such a way that the items of Other comprehensive income are grouped into two categories: (a) items which will not be subsequently reclassified in the profit and loss account; and (b) items which will be subsequently reclassified in the profit and loss account in accordance with certain conditions. The income tax on the items of Other comprehensive income will be allocated in the same way.

The changes to IAS 1 are applicable for annual periods starting on or after July 1, 2012. The presentation of the items of Other comprehensive income will be appropriately modified as and when the changes are adopted in future accounting periods.

IFRS 7 and IAS 32 – Offsetting Financial Assets and Financial Liabilities and related disclosures

The changes to IAS 32 clarify questions of adoption existing in relation to the requirements for offsetting of financial assets and liabilities. Specifically, these alterations clarify the meaning of “at present has the legal right to offset” and “simultaneous realization and settlement”.

The alterations to IFRS 7 require that entities disclose the information on the rights of offsetting and related agreements (such as requirements for guarantees) for the financial instruments that are subject to offsetting or similar contracts.

The changes to IFRS 7 are applicable for annual periods beginning on or after January 1, 2013 and periods intermediate to these annual periods. The disclosures should be made retroactively for all the periods compared. However, the changes to IAS 32 are not applicable to annual periods starting before January 1, 2014.

Our management believes that the adoption of these changes to IAS 32 and IFRS 7 could result in additional disclosures in relation to offsetting of financial assets and liabilities in the future.

IAS 19 – Employee benefits

The changes to IAS 19 change the accounting of defined-benefit plans and severance benefits. The most significant change relates to accounting of the changes in the defined-benefit obligations and assets of the plan in the year itself, with the elimination of the “corridor approach” permitted in the previous version of IAS 19 and early recognition of the cost of past services. The changes require that all actuarial gains and losses be recognized immediately through Other comprehensive income so that the net assets or liabilities of the pension plan are recognized in the consolidated Statement of financial position to reflect the full value of the plan’s deficit or surplus. In addition, the expenses on interest and the expected return on the plan’s assets used in the previous version of IAS 19 have been replaced by a value of “net interest”, calculated on the basis of the discount rate on the assets or liabilities of the net defined benefit.

The effect arising from the adoption of the new accounting practices for recording of actuarial obligations with post-employment benefits will represent a reduction in stockholders’ equity on January 1, 2013 in the amount of R$ 497 million (R$ 106 million on January 1, 2012). The impact on the profit and loss account for 2013 arising from the review of the pronouncement will represent a reduction of R$ 18 million in the expense on post-employment benefits in comparison with the expense which would be registered in accordance with the former accounting practice.

This net effect represents various adjustments, including the effect of income tax on: (a) the full recognition of the actuarial gains through Other comprehensive income and reduction of the net deficit of the pension fund; (b) the immediate reduction of the cost of past services in the profit and loss account and increase of the net deficit of the pension fund; and (c) the reversal of the difference between the gain resulting from the expected rate of return on the pension plan’s assets and the discount rate, through Comprehensive income.

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Annual Improvements 2009–2011 Cycle (May 2012)

The annual improvements to the 2009–2011 cycle of IFRS include various alterations to numerous IFRS standards. The changes to IFRS are applicable for annual periods starting on or after January 1, 2013, and include:

Changes to IAS 16 – Property, plant and equipment;

· Alterations to IAS 32 – Financial instruments: presentation.

Alterations to IAS 16

The changes to IAS 16 set out that replacement parts, equipment and service equipment should be classified as property, plant and equipment to the extent that they are in accordance with the definition of Property, Plant and Equipment of IAS 16 and, otherwise, as inventories. Our management has not determined whether the changes to IAS 16 will have a significant effect on our accounting statements.

Changes to IAS 32

The changes to IAS 32 state that the income tax related to distributions to holders of equity instruments and to costs of equity transactions must be accounted in accordance with IAS 12 – Income taxes. Our management believes that the changes to IAS 32 will not have a significant effect on our accounting statements.

Principal Factors Affecting our Financial Condition and Results of Operations

Analysis of Electricity Sales and Cost of Electricity Purchased

Electricity rates in Brazil, related to electricity distribution companies sales to captive customers, are set by Aneel, which has the authority to readjust and review rates in accordance with the applicable provisions of the concession contracts. See “Item 4. The Brazilian Power Industry—Rates.”

We charge captive consumers for their actual electricity consumption during each 30-day billing period at specified rates. Certain large industrial consumers are charged according to the electricity capacity contractually made available to them by us, with adjustments to those rates according to consumption during peak demand time as well as capacity requirements that exceed the contracted amount.

In general, rates on electricity that we purchase are determined by reference to the capacity contracted for as well as the volumes actually used.

The following table sets forth the average rate (in reais per MWh) and volume (by GWh) components of electricity sales and purchases for the periods indicated. The term “average rate” refers to revenues for the relevant class of consumers divided by the MWh used by such class and does not necessarily reflect actual rates and usage by a specific class of end-users during any particular period.

|  | Year ended December 31, |
|  | 2012 |  | 2011 |  | 2010 |
Electricity Sales: |  |  |  |  |  |  |
Average rate to final consumers (R$/MWh) |  |  |  |  |  |  |
Industrial rate |  | 176.40 |  | 167.59 |  | 158.53 |
Residential rate |  | 540.61 |  | 507.52 |  | 485.98 |
Commercial rate |  | 445.58 |  | 435.99 |  | 436.44 |
Rural rate |  | 273.18 |  | 267.56 |  | 256.18 |
Public services rate and others |  | 335.94 |  | 328.06 |  | 319.92 |
Total sales to final consumers (GWh) |  |  |  |  |  |  |
Industrial consumers |  | 25,969 |  | 26,029 |  | 24,826 |
Residential consumers |  | 11,518 |  | 10,742 |  | 9,944 |
Commercial consumers |  | 7,950 |  | 6,985 |  | 6,227 |
Rural consumers |  | 2,874 |  | 2,646 |  | 2,467 |

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Public services and other consumers |  | 4,358 |  | 4,001 |  | 3,664 |
Average rate (R$/MWh) |  | 316.15 |  | 296.71 |  | 280.49 |
Total revenues (millions of R$) |  | 16,671 |  | 14,955 |  | 13,219 |
Sales to distributors: |  |  |  |  |  |  |
Volume (GWh) |  | 13,868 |  | 14,458 |  | 14,205 |
Average rate (R$/MWh) |  | 137.22 |  | 109.07 |  | 101.72 |
Total revenues (millions of R$)(1) |  | 1,903 |  | 1,577 |  | 1,445 |

(1) Does not include R$ 39 million, R$ 36 million and R$ 24 million relating to Proinfa Program during 2012, 2011 and 2010 respectively.

Distribution Rates

Our results of operations in the past have been significantly affected by fluctuations in the levels of rates that Cemig Distribution and Light are permitted to charge for the generation and distribution of electricity. The rate-setting process in Brazil has historically been influenced by government attempts to control inflation. With the restructuring of the electric power sector in Brazil that commenced in 1995 and under the terms of the renewal of the concession agreement that we signed with Aneel in 1997, the process by which rates are set has changed to a significant degree.

Each year, in April, Aneel issues a Resolution that establishes the average annual rate adjustment for Cemig Distribuition. In 2010 this rate was 7.58%, in 2011 was 10.47% and in 2012 was 5.24%.

On January, 2013, the federal government published Law No. 12.783 removing some taxes on electricity rates, reducing the prices for the energy sold by generator that had their concession agreements renewed and reducing the prices for the transmission of electricity. On January, 24 th, ANEEL established new rates for the distributors to pass through to the consumers the impact of this Law. This readjustment was made under a Extraordinary Rate Revision to all the distributors. The rate adjustment for Cemig represented a decrease of 22%. This adjustment did not impact the profits because it changed only Parcel A costs. On April 8, 2013 Aneel established Cemig Distribution’s average annual rate adjustment of 2.99%. The components of this increase were as follows: (i) a 0.47% increase due to the Rate Adjustment Index; (ii) a 1.03% decrease due to intra-annual variation of fixed costs; (iii) a 1.45% increase related to the advancement of subsidies on rates applicable to certain consumers and (iv) a 0.11% increase due to other financial adjustments.

The 2013, 2012, 2011 and 2010 average annual rate adjustments and revision for Cemig Distribution with their respective components are presented in the table below:

|  | 2013 |  | 2012 |  | 2011 |  | 2010 |
Average annual/periodic rate adjustment |  | 2.99 | % | 5.24 | % | 10.47 | % | 7.58 | %
Components |  |  |  |  |  |  |  |  |
Rate adjustment index |  | 0.47 | % | 2.90 | % | 8.08 | % | 3.41 | %
Intra-annual variation of fixed costs (CVA) |  | 1.03 | % | -2.70 | % | -1.06 | % | -1.46 | %
Advancement of subsidies on rates |  | 1.45 | % | 3.57 | % | 5.03 | % | 6.35 | %
Other financial adjustments |  | 0.11 | % | 1.47 | % | -1.58 | % | -0.72 | %

Each year, in November, Aneel issues a Resolution that establishes the average annual rate adjustment for Light. In 2010 this rate was 6.88%, in 2011 was 6.57%.

On November 6, 2012 Aneel established Light’s average annual rate adjustment of 10.77%. The components of this increase were as follows: (i) a 7.17%, increase due to the Rate Adjustment Index; (ii) a 2.71%, increase due to intra-annual variation of fixed costs; (iii) a 1.23%, increase related to the advancement of subsidies on rates applicable to certain consumers, and (iv) a 0.33%, decrease due to other financial adjustment.

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The 2012, 2011 and 2010 average annual rate adjustments and revision for Light with their respective components are presented in the table below:

|  | 2012 |  | 2011 |  | 2010 |
Average annual/periodic rate adjustment |  | 10.77 |  | 6.57 | % | 6.88 | %
Components |  |  |  |  |  |  |
Rate adjustment index |  | 7.17 |  | 7.21 | % | 8.21 | %
Intra-annual variation of fixed costs (CVA) |  | 2.71 |  | 0.20 | % | 0.76 | %
Advancement of subsidies on rates |  | 1.23 |  | 2.01 | % | 1.65 | %
Other financial adjustments |  | -0.33 |  | -2.85 | % | -3.74 | %

Transmission Rates

The revenue adjustment of the electricity transmission grids owned by CEMIG, as specified by the concession contract, occurs annually in June. The concession contract used to establish a four-year period between periodic revisions. After the implementation of Law 12,783/2013 - Extension of Concessions, from 2013 onward, the amended concession contracts establish a five-year period between periodic revisions.

In 2010, Aneel approved the results for the second periodic revision, again with a reassessment of the entire asset base of Cemig Generation and Transmission. The results were released through Resolution No. 988, on June 18, 2010 defining a decrease in the annual revenue of 15.88%. The readjustment is retroactive to 2009, since the regulator had been working on the definition of the rules to be applied for this revision.

The concession contract provides that the revenue requirements are restated for inflation annually. Until January 2013, the index used to restate the annual inflation was the General Market Price Index, IGP-M. This IGP-M index rose 4.26% from June 2011 to May 2012 increasing the revenue for the 2012-2013 cycle. In June 2011, Aneel approved an increase in the transmission revenue of 5.0%. After the implementation of Law 12,783/2013 - Extension of Concessions, from 2013 onward, the amended concession contracts establish the IPCA as the inflation index considered to readjust the RAP annually.

By the end of 2012, the Federal Government renewed Cemig’s trasnmission concession and reduced the revenue from January 2013 to R$148 millon per year, which does not include Heritage Training Programme for Civil Servants (Programa de Formação do Patrimônio do Servidor Público, or “PASEP”) and Social Security (Contribuição para o Financiamento da Seguridade Social, or “COFINS”) taxes.

Power Rationing and Government Measures to Compensate Electric Utilities

Low rainfall in 2000 and early 2001, vigorous growth in demand for energy and Brazil’s significant dependence on electricity generated from hydrological resources resulted in abnormally low water levels in many reservoirs that are used to power Brazil’s major hydroelectric generation facilities. In May 2001, the Federal Government announced several measures requiring reductions in electricity consumption in response to these conditions (the “Electricity Rationing Plan”). The power rationing measures ultimately ceased on February 28, 2002.

Nevertheless, the New Industry Model (that has as one of its main objectives to guarantee the supply of energy) created the auctions to the regulated market (ACR), where it is possible to purchase energy from new plants to guarantee the supply of energy. Since the New Industry Model, approximately 47 GMW of capacity were negotiated on these auctions, which is being installed from 2008 to 2017. Of this amount, 5.97 GW were negotiated on the backup auctions, that is, this energy is not compromised with any contracts or any minimum supply.

On December 12, 2001, the Federal Government authorized the creation of the General Agreement of the Electricity Sector. The General Agreement of the Electricity Sector provides that electric power distribution and generation companies in Brazil, such as us, will be compensated for revenue losses caused by the reduction in amounts of energy sold and the purchase of energy on the CCEE, as applicable, due to the Federal Government-mandated rationing measures. Compensation is made by means of an

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extraordinary increase in the energy rate applicable to future power sales and companies are entitled to use this increased rate for an average period of 74 months, which ended in March 2008.

Early Settlement of Account Receivable from the Minas Gerais State Government

We had an account receivable from the State Government, referred to as the CRC Account, referred to as the CRC Agreement, related to some credits against the Federal Government that were transferred to the State Government, that totaled R$ 2,422 million as of December 31, 2012.

On November 20, 2012, a commitment agreement was signed between Cemig and the State of Minas Gerais, subsequently ratified by the Board of Directors of Cemig (CRCA 124/2012, of December 21, 2012), under which the board agreed to an early payment by the State of Minas Gerais of the outstanding balance due under the CRC Agreement. On January 25, 2013, the commitment agreement was amended to rectify the amount of the debt, as authorized by the Board of Directors (CRCA 001/2013, of January 18, 2013).

Under the commitment agreement, as amended, the State of Minas Gerais recognized its obligation for the outstanding balance of the CRC Agreement debt in the total amount of R$ 6,283 million, including accrued interest up to October 31, 2012, resulting, after application of an agreed upon 35% discount for the early settlement, in an updated debt obligation of R$ 4,084 million as of the same October 31, 2012 base date.

The account receivable has been settled with the State of Minas Gerais through a payment to CEMIG of R$ 4,211million in some dates from December 18, 2012 to March 11, 2013.

In light of the early settlement of the CRC Account, Cemig decided to buy back the senior units of the FIDC to which Cemig had assigned all its receivables under the CRC Account and, once in possession of all the units, terminate the FIDC, with payment by assignment of the credit rights that comprise the FIDC portfolio , at the price recorded in the FIDC. We believe the repurchase of the outstanding units of the FIDC was necessary so that the CRC settlement agreement would be negotiated and entered into by State of Minas Gerais and Cemig, with no need to involve the FIDC.

On December 5, 2012, Cemig repurchased, in the secondary market, the outstanding balance of the senior units of the FIDC owned by Banco Itaú BBA, Bradesco and two Bradesco mutual funds (Bradesco FI Multimercado CP Invest no Exterior and Bradesco FI Multimercado Pioneiro), for the amount of approximately R$ 711.3 million. This amount represents the sum of the installment payments not yet due, adjusted by the accumulated CDI rate from the date of issuance of the senior units of the FIDC up to the date of the purchase, as per the criteria established in Article 38, Paragraph 7 of the Regulations of the FIDC for the eventuality of extraordinary amortization of the senior units, as authorized by the Board of Directors through Board Spending Decision (CRCA) 101/2012, of December 5, 2012.

Cemig, as holder of the totality of the subordinated units and senior units of the FIDC, liquidated the FIDC on December 17, 2012, by redeeming the totality of the senior and subordinated units issued by the FIDC in circulation, and subsequently terminated the activities of the FIDC, with the simultaneous termination of the senior units and subordinated units, with payment by assignment of the credit rights that comprised the FIDC portfolio, at the price registered in the FIDC of approximately R$ 1,785 billion.

Exchange Rates

Substantially all of our revenues and operating expenses are denominated in reais. However, we have foreign currency-denominated debt. As a result, in reporting periods when the real declines against the dollar or other foreign currencies in which our debt is denominated, our operating results and financial position are adversely affected. Foreign exchange gain or loss and monetary variation gain or loss may impact our results of operations in periods in which there are wide swings in the value of the real relative to the dollar or high inflation. We have a number of financial and other contracts under which we owe, or are entitled to, amounts in respect of monetary variation as measured by an index of price inflation in Brazil. In 2012, we used financial instruments such as interest rate swaps in order to reduce the risk from exchange rate fluctuations. As of December 31, 2012, we had entered into swap agreements in the notional amount of US$8 million in order to change the original interest rate of certain financing from an interest rate calculated based on the U.S. dollar variation to an interest rate calculated based on the Interbank Certificates of Deposit rate (Certificado de Depósito Interbancário), or CDI rate. See Notes 2.6(b), 19, 23, 28 and 29 to our consolidated financial statements.

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Year Ended December 31, 2012 Compared to Year Ended December 31, 2011

Net Operating Revenues

Net operating revenues increased 17.2% from R$15,749 million in 2011 to R$18,460 million in 2012.

|  | 2012 |  | % of net operating revenues |  | 2011 |  | % of net operating revenues |  | 2012 versus 2011 % |
|  | (in millions of R$) |  |  |  | (in millions of R$) |  |  |  |  |
Electricity sales to final consumers |  | 16,671 |  | 90.4 |  | 14,955 |  | 95.0 |  | 11.5 |
Revenue from wholesale supply to other concession holders and PROINFA) |  | 1,942 |  | 10.5 |  | 1,613 |  | 10.2 |  | 20.4 |
Revenue from use of the electricity distribution grid (TUSD |  | 2,216 |  | 12.0 |  | 1,978 |  | 12.6 |  | 12.0 |
Revenue from use of the concession transmission system) |  | 1,675 |  | 9.1 |  | 1,407 |  | 8.9 |  | 19.0 |
Transmission indemnity revenue |  | 192 |  | 1.0 |  | - |  | - |  | - |
Construction revenues |  | 1,631 |  | 8.8 |  | 1,541 |  | 9.8 |  | 5.8 |
Transactions in electricity on the CCEE |  | 427 |  | 2.3 |  | 269 |  | 1.7 |  | 58.7 |
Other operating revenues |  | 1,324 |  | 7.2 |  | 983 |  | 6.2 |  | 34.7 |
Taxes on revenue and regulatory charges |  | (7,618 | ) | (41.3 | ) | (6,997 | ) | (44.4 | ) | 8.9 |
Total net operating revenues |  | 18,460 |  | 100.0 |  | 15,749 |  | 100.0 |  | 17.2 |

Electricity sales to final consumers

Revenue from electricity sales to final consumers (excluding CEMIG’s own consumption) increased R$1,716 million or 11.5% from R$14,955 million in 2011 to R$16,671 million in 2012.

This variation was primarily due to:

· an increase of 4.49% in the volume of electricity invoiced to final consumers (excluding internal consumption);

· tariff rate adjustments in Cemig Distribution’s concessions, w hich increased by an average rate of 7.24%1 on April 8, 2011 and increased by an average rate of 3.85% on April 8, 2012, respectively;

· tariff rate adjustment in Light SESA’s concession, which increased by an average rate of 7.82%2 on November 7, 2011 and increased by an average rate of 10.77% on November 6, 2012;

· readjustments of the rates on contracts for sale of energy to Free Consumers, indexed mostly to the variation of IGP-M, that increased 7.8% in 2012.

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Revenue from wholesale supply to other concession holders and PROINFA

Revenue from wholesale supply to other concession holders and PROINFA increased by R$329 million or 20.4% from R$1,613 million in 2011 to R$1,942 million in 2012. The average price for these sales increased 25.4%, from R$110.64/MWh in 2011 to R$138.77/MWh in 2012. This was partially offset by a reduction in the volume of electricity sold to other concession holders of 253,360 MWh, or 4.0%, from 14,578,717 MWh in 2011 to 13,994,737 MWh in 2012.

Revenue from use of the electricity distribution grid (TUSD)Revenue from the use of the electricity distribution system (TUSD) increased R$238 million, or 12.0%, from R$1,978 million in 2011 to R$2,216 million in 2012. This revenue comes from charges for energy sold to Free Consumers located in CEMIG’s and Light’s concession areas, and the increase in 2012 is due to rate adjustments and a higher volume of energy transported to Free Consumers by CEMIG, resulting from the recovery of industrial activity and the migration of captive consumers to the Free Market in 2012.

Revenue from use of the concession transmission system

Revenue from use of the basic transmission system increased R$268 million, or 19.0%, from R$1,407 million in 2011 to R$1,675 million in 2012. This revenue is from the transmission capacity of Cemig Generation and Transmission made available to the national system, and also from the jointly-controlled transmission subsidiaries, particularly TBE and Taesa. This increase in 2012 resulted primarily from the acquisition of Abengoa by TAESA in the second semester of 2011, taking full effect in 2012, among other acquisitions.

Transmission indemnity revenues

We recorded in 2012 an estimated gain in the amount of R$192 million related to the indemnity of Cemig’s transmission assets, which was included under the indemnity transmission revenues, according to the criteria established by the M 579. The indemnity transaction revenue refers to the difference between the accounting values and the estimated amount of compensation of transmission assets that had the early renewal in accordance with the criteria of the MP 579. The company recorded a gain in 2012 based on estimated indemnity values, using as a reference the Aneel technical note No. 387/2012, in which studies are presented for definition of the VNR of the transmission facilities that had the Concession Contracts renewed. For more information see Note 04 to our consolidated financial statements.

Construction revenues

Construction revenues increased R$90 million, from R$1,541 million in 2011 to R$1,631 million in 2012, due to greater investment in 2012 in concession assets. Those revenues represent the investments in concession assets and include in some cases the profit margin recorded in each operation. The major portion of construction revenues were offset by the construction costs See Note 25 to our consolidated financial statements.

Sales on the Spot Market

Cemig GT had positive exposure of 2,967.742 GWh to the spot market in 2012. Of this total, 99.4% was sale of secondary electricity supply, made available by the system through the Electricity Reallocation Mechanism (Mecanismo de Realocação de Energia, or MRE). This positive exposure in 2012 in the stock market generated revenue of R$ 180 million. From the results as shown, it can be seen that sales in firm bilateral contracts represented almost the totality of the electricity available for sale, both from the company’s own plants and for electricity from third parties. Practically the only energy accounted as short-term market exposure was secondary supply, since this supply cannot be sold in bilateral contracts, because it arises from an operative dispatching decision by the national system operator (Operador Nacional do Sistema, or ONS).

Cemig D’s total exposure to the short-term market in 2012 was practically null, with some months of negative exposure balanced out by others with positive exposure. Over the year, there were situations in which Cemig D had involuntary exposure due to delays in commercial startup of plants that had sold electricity to distributors in MME auctions, and also due to loss of contracts of plants that were not built but sold electricity in MME auctions. Any financial amounts that Cemig D loses or gains on short-term exposure are accounted by Aneel for pass-through to the tariffs of the company’s final consumers.

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Other operating revenues

Other operating revenue increased by R$341 million, or 34.7%, from R$983 million in 2011 to R$1,324 million in 2012. Our other operating revenues are:

|  | 2012 |  | 2011 |
|  | (in millions of reais) |
Supply of gas |  | 755 |  | 579 |
Charged services |  | 18 |  | 14 |
Telecomunication services |  | 162 |  | 158 |
Rendering services |  | 118 |  | 98 |
Low-income subsidy |  | 176 |  | 56 |
Other |  | 95 |  | 78 |
|  | 1,324 |  | 983 |

The increase in other operating revenues in 2012 compared to 2011 is largely due to the increase of revenues related to supply of gas by 30.4%, from R$579 million in 2011 to R$755 million in 2012. This increase was due to the higher demand in 2012 due to the expansion of our pipeline in the State of Minas Gerais

Tax on revenues and regulatory charges

Taxes on revenues increased R$621 million, or 8.9%, from R$6,997 million in 2011 to R$7,618 million in 2012. Taxes on revenues consist of: (i) VAT, assessed at an average rate of 21% on electricity sales to final consumers; (ii) COFINS, assessed at a rate of 7.6%; and (iii) PASEP, assessed at a rate of 1.7%. See Note 24 to our consolidated financial statements.

Operating Costs and Expenses

Operating costs and expenses increased R$3,194 million, or 27.9%, from R$11,445 million in 2011 to R$14,639 million in 2012. This increase was mainly due to electricity purchased for resale that increased R$1,673 million, or 39.1%, from R$4,278 million in 2011 to R$5,951 million in 2012. For more information refer to Note 25 to our consolidated financial statements.

|  | 2012 |  |  |  | % of net operating revenues |  |  |  | 2011 |  |  |  | % of net operating revenues |  |  |  | 2012 versus 2011 % |
|  | (in millions of R$) |  |  |  | (in millions of R$) |  |  |  |  |
Electricity purchased for resale |  | (5,951 | ) | (32.2 | ) | (4,278 | ) | (27.2 | ) | 39.1 |
Charges for the use of transmission facilities of the basic grid |  | (1,011 | ) | (5.5 | ) | (830 | ) | (5.3 | ) | 21.8 |
Depreciation and amortization |  | (1,001 | ) | (5.4 | ) | (983 | ) | (6.2 | ) | 1.8 |
Personnel |  | (1,361 | ) | (7.4 | ) | (1,249 | ) | (7.9 | ) | 9.0 |
Employee’ and managers’ profit sharing |  | (244 | ) | (1.3 | ) | (221 | ) | (1.4 | ) | 10.4 |
Outsourced services |  | (1,127 | ) | (6.1 | ) | (1,031 | ) | (6.5 | ) | 9.3 |
Post-employment obligations |  | (134 | ) | (0.7 | ) | (124 | ) | (0.8 | ) | 8.1 |
Materials |  | (82 | ) | (0.4 | ) | (98 | ) | (0.6 | ) | (16.3 | )
Royalties for usage of water resources |  | (186 | ) | (1.0 | ) | (154 | ) | (1.0 | ) | 20.8 |
Provisions for operating losses |  | (782 | ) | (4.2 | ) | (257 | ) | (1.6 | ) | 204.3 |
Gas purchased for resale |  | (495 | ) | (2.7 | ) | (329 | ) | (2.1 | ) | 50.5 |
Construction costs |  | (1,630 | ) | (8.8 | ) | (1,529 | ) | (9.7 | ) | 6.6 |
Other operating expenses, net |  | (634 | ) | (3.4 | ) | (362 | ) | (2.3 | ) | 75.1 |

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|  | 2012 |  |  |  | % of net operating revenues |  |  |  | 2011 |  |  |  | % of net operating revenues |  |  |  | 2012 versus 2011 % |
|  | (in millions of R$) |  |  |  | (in millions of R$) |  |  |  |  |
Total operating costs and expenses |  | (14,638 | ) | (79.3 | ) | (11,445 | ) | (72.7 | ) | 27.9 |

Electricity purchased for resale consists primarily of purchases from Itaipu through Eletrobrás and competitive biddings sponsored by the Federal Government. We are required under applicable regulations to purchase part of Itaipu’s capacity at U.S. dollar denominated prices. We also purchase electricity from the CCEE and through bilateral contracts. Electricity purchased for resale increased R$1,673 million, or 39.1%, from R$4,278 million in 2011 to R$5,951 million in 2012. The increase in costs was primarily due to higher energy prices in 2012 as a result of the low reservoir levels in Brazil requiring the operation of thermoelectric plants at higher costs. This is a non-controllable cost for the distribution business and the difference between the amounts used as a reference for calculation of tariffs and the cost actually incurred is compensated for in the next tariff adjustment. For a breakdown of this expense, see Note 25 to our consolidated financial statements.

Charges for the use of transmission facilities of the basic grid mainly correspond to the cost of transporting electricity in the Brazilian basic transmission network which is prorated among the Brazilian distribution companies, according to the Brazilian regulatory legislation. Charges for use of the transmission network, which are defined by Aneel, increased R$181 million, or 21.8%, from R$830 million in 2011 to R$1,011 million in 2012. These charges, set by an Aneel resolution, are payable by electricity distribution and generation agents for use of the facilities that are components of the national grid. This is a non-controllable cost and the difference between the amounts used as a reference for the calculation of tariffs and the cost actually incurred is compensated for in the next tariff adjustment.

Depreciation and amortization expense increased R$18 million, or 1.8%, from R$983 million in 2011 to R$1,001 million in 2012. This result is mainly due to the increase in our assets due to a higher investment in our distribution programs in 2012.

Personnel expenses increased R$112 million, or 9.0%, from R$1,249 million in 2011 to R$1,361 million in 2012. This increase is due to the average increase in salaries of 8.2% and 4.5% agreed in November 2011 and November, 2012, respectively, in the negotiations for the annual Collective Work Agreement, partly offset by a reduction of 3.8% in our aggregate number of employees from 2011 to 2012.

Employees’ and managers’ profit sharing increased R$23 million, or 10.4%, from R$221 million in 2011 to R$244 million in 2012.This increase is primarily due to the increase in our net income in 2012.

Outsourced services increased R$96 million, or 9.3%, from R$1,031 million in 2011 to R$1,127 million in 2012. This is primarily due to the higher amount of costs related to communication services and maintenance of electric equipment. For a breakdown of the provisions see Note 25 to our consolidated financial statements.

Post-employment obligations expenses increased R$10 million, or 8.1%, from R$124 million in 2011 to R$134 million in 2012. These expenses primarily represent our actuarial obligations related to the net interest accruals in 2012. The increase in 2012 is mainly due to the effect of the present value adjustment in our actuarial obligations. For more information see Note 21 to our consolidated financial statements.

Provisions for operating losses increased R$525 million, or 204.3%, from R$257 million in 2011 to R$782 million in 2012. The main components of this increase were as follows:

· the creation of an allowance for doubtful accounts in the amount of R$159 million related to ICMS (value-added tax) on use of the basic electricity distribution system (TUSD); and

· the creation of provision in the amount of R$403 million in 2012 related to an agreement established between Cemig and the Federal Government related to CRC Account in connection with the early settlement of the CRC Account.

Gas purchased for resale increased R$166 million, or 50.5%, from R$329 million in 2011 to R$495 million in 2012. This is a result of the larger quantity of gas purchased by Gasmig in 2012 to service its industrial clients.

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As a result of the foregoing, we had an operating profit before financial expenses of R$4,083 million in 2012 compared to an operating profit before financial expenses of R$4,303 million in 2011.

Financial revenues (expenses), net Financial revenues (expenses), net, includes (i) financial income, which is mainly comprised of interest and a monetary restatement of our account receivable from the State Government, investment income earned, late charges on overdue electricity bills and foreign exchange gains and (ii) financial expenses, which are mainly comprised of interest expense on loans and financing, foreign exchange losses, monetary restatement losses, charges and adjustments for inflation on post-employment obligations paid to pension funds and other expenses.

Net financial revenues were R$1,252 million in 2012 compared to net financial expenses of R$970 million in 2011. The main factors that impacted our net financial results in 2012 were:

· Lower revenue from cash investments: decrease of R$114 million, or 27.8%, from R$410 million in 2011 to R$296 million in 2012 as a result of a lower volume of cash invested in 2012.

· Revenue of R$2,383 million from monetary variation of accounts receivable from the Minas Gerais State Government. See Note 12 to our consolidated financial statements.

· Revenue from arrears penalty payments on electricity bills: increase of R$28 million, or 18.54%, from R$151 million in 2011 to R$ 179 million in 2012.

· Foreign exchange gains: increase of R$24 million, or 120.0%, from R$20 million in 2011 to R$44 million in 2012 due to financial investments of Taesa denominated in foreign currency.

· Foreign exchange losses: increase of R$42 million, or 105.0%, from R$40 million in 2011 to R$82 million in 2012 from loans and financings denominated in foreign currency.

· Loans and financing expenses: decrease of R$68 million, or 5.2%, from R$1,311 million in 2011 to R$1,243 million in 2012. This decrease was mainly due to lower variation in the CDI rate, the main index to which our loans and financing contracts are linked to, reflecting the decrease in Brazilian benchmark interest rate (SELIC) in 2012.

For a breakdown of financial revenues and expenses, see Note 26 to our consolidated financial statements.

Income Tax expense

Income tax expense represented an expense of R$1,063 million on pre-tax income of R$5,335 million in 2012, or 19.9%, compared to an expense of R$918 million on pre-tax income of R$3,333 million in 2011, or 27.50%. The lower effective rate of income tax in 2012 was due to payment of part (R$1.7 billion) of the remuneration to stockholders as Interest on Equity (Juros sobre Capital Próprio, or JCP), which is an instrument for payment to stockholders that is deductible for the Company as an expense reducing net profit. Income tax on it is paid by the stockholder receiving it, at the rate of 15%. The effective tax rates are reconciled with the nominal rates in Note 10 to our consolidated financial statements.

Net Income

As a result of the foregoing, we had net income of R$4,272 million in 2012 compared to net income of R$2,415 million in 2011.

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Year Ended December 31, 2011 Compared to Year Ended December 31, 2010

Net Operating Revenues

Net operating revenues increased 14.2% from R$13,790 million in 2010 to R$15,749 million in 2011.

|  | 2011 |  | % of net operating revenues |  | 2010 |  | % of net operating revenues |  | 2011 versus 2010 % |
|  | (in millions of R$) |  |  |  | (in millions of R$) |  |  |  |  |
Electricity sales to final consumers |  | 14.955 |  | 95.0 |  | 13.219 |  | 95.9 |  | 13.1 |
Revenue from wholesale supply to other concession holders and PROINFA |  | 1.613 |  | 10.2 |  | 1.469 |  | 10.7 |  | 9.8 |
Revenue from use of the electricity distribution grid(TUSD) |  | 1.978 |  | 12.6 |  | 1.658 |  | 12.0 |  | 19.3 |
Revenue from use of concessionthe transmission system |  | 1.407 |  | 8.9 |  | 1.141 |  | 8.6 |  | 17.5 |
Construction revenues |  | 1.541 |  | 9.8 |  | 1.341 |  | 9.7 |  | 14.9 |
Transactions in electricity on the CCEE |  | 269 |  | 1.7 |  | 133 |  | 1.0 |  | 102.3 |
Other operating revenues |  | 983 |  | 6.2 |  | 924 |  | 6.7 |  | 6.4 |
Tax on revenues and regulatory charges. |  | (6,997 | ) | (44.2 | ) | (6,095 | ) | (44.0 | ) | 14.8 |
Total net operating revenues |  | 15,749 |  | 100.0 |  | 13,790 |  | 100.0 |  | 14.2 |

Electricity sales to final consumers

Revenue from electricity sales to final consumers (excluding CEMIG’s own consumption) increased R$1,736 million or 13.1% from R$13,219 million in 2010 to R$14,955 million in 2011.

This variation was primarily due to:

· an increase of 6.95% in the volume of electricity invoiced to final consumers (excluding internal consumption);

· tariff rate adjustments in Cemig Distribution’s concessions, w hich increased by an average rate of 1.67% on April 8, 2010 and increased by an average rate of 7.24% on April 8, 2011, respectively;

· tariff rate adjustment in Light SESA’s concession, which increased by an average rate of 7.82% on November 7, 2011 and increased by an average rate of 10.77% on November 6, 2012;

· readjustments of the rates on contracts for sale of energy to Free Consumers, indexed mostly to the variation of IGP-M, that increased 5.1% in 2011.

Revenue from wholesale supply to other concession holders and PROINFA

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Revenue from wholesale supply to other concession holders and PROINFA increased by R$144 million or 9.8% from R$1,469 million in 2010 to R$1,613 million in 2011. The volume of electricity sold to other concession holders increased 253,360 MWh, or 1.8%, from 14,204,530 MWh in 2010 to 14,457,890 MWh in 2011. The average price for these sales increased 7.2%, from R$101.72/MWh in 2010 to R$109.08/MWh in 2011.

Revenue from the use of the electricity distribution grid (TUSD)

Revenue from the use of the electricity distribution system (TUSD) increased R$320 million, or 19.3%, from R$1,658 million in 2010 to R$1,978 million in 2011. This revenue comes from charges for energy sold to Free Consumers located in CEMIG’s and Light’s concession areas, and the increase in 2011 is due to rate adjustments and a higher volume of energy transported to Free Consumers by CEMIG, resulting from the recovery of industrial activity and the migration of captive consumers to the Free Market in 2011.

Revenue from the use of theconcession transmission system

For concessions granted prior to 2000 or later, revenue Network Usage refers to the rate charged for electric sector agents, including Free Consumers connected at high voltage due to the use of our transmission network connected to the Brazilian interconnected transmission network.

For new concessions, granted in 2000 or later, the revenue represents the portion received from the power agents related to the operation and maintenance of transmission lines and also the monetary variation revenue on financial transmission assets recorded during the construction period of the transmission lines. The rates used for readjustment of such assets correspond to the remuneration of the capital invested in those projects, varying in accordance with the model of the enterprise and the cost of capital of the investor.

Revenue from the use of the basic transmission system increased R$266 million, or 23.3%, from R$1,141 million in 2010 to R$1,407 million in 2011. This revenue is from the transmission capacity of Cemig Generation and Transmission made available to the national system, and also from the jointly-controlled transmission subsidiaries, particularly TBE and Taesa. This increase in 2011 resulted primarily from CEMIG recording R$178 million related to the monetary variation of TAESA’s transmission assets recorded. This was due to readjustments in TAESA’s rates as from July 2011 of 9.77%. For more information on rates updates see “The Brazilian Power Industry—Rates for the Use of the Distribution and Transmission Systems”.

Construction revenues

Construction revenues increased R$200 million, from R$1,341 million in 2010 to R$1,541 million in 2011, due to greater investment in 2011 in concession assets. Those revenues represent the investments in concession assets and include in some cases the profit margin recorded in each operation. The major portion of construction revenues were offset by the construction costs. See Note 24 to our consolidated financial statements.

Other operating revenues

Other operating revenue increased by R$59 million, or 6.4%, from R$924 million in 2010 to R$983 million in 2011. Our other operating revenues are:

|  | 2011 |  | 2010
|  | (in millions of reais)
Supply of gas |  | 579 |  | 398
Charged service |  | 14 |  | 16
Telecom service |  | 158 |  | 131
Other services provided |  | 98 |  | 179
Low-income subsidy |  | 56 |  | 133
Other |  | 78 |  | 67
|  | 983 |  | 924

The increase in other operating revenues in 2011 compared to 2010 is largely due to the increase of revenues related to supply of gas by 45.5%, from R$398 million in 2010 to R$579 million in 2011. This increase was due to the expansion of our pipeline to Vale do Aço (Steel Valley) and to the south of Minas Gerais, allowing the Company to service large clients in those regions. The Vale do Aço (Steel Valley) pipeline started operations in September 2010.

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Tax on revenues and regulatory charges

Taxes on revenues increased R$902 million, or 14.8%, from R$6,095 million in 2010 to R$6,,997 million in 2011. Taxes on revenues consist of: (i) VAT, assessed at an average rate of 21% on electricity sales to final consumers; (ii) COFINS, assessed at a rate of 7.6%; and (iii) PASEP, assessed at a rate of 1.7%. See Note 24 to our consolidated financial statements.

Operating Costs and Expenses

Operating costs and expenses increased R$1,214 million, or 12.2%, from R$10,231 million in 2010 to R$11,445 million in 2011. This increase was mainly due to electricity purchased for resale that increased R$556 million, or 14.9%, from R$3,722 million in 2010 to R$4,278 million in 2011. For more information refer to note 25 to our consolidated financial statements.

|  | 2011 |  | % of net operating revenues |  | 2010 |  | % of net operating revenues |  | 2011 versus 2010 %
|  | (in millions of R$) |  |  |  | (in millions of R$) |  |  |  |
Electricity purchased for resale |  | (4.278) |  | (27.2) |  | (3.722) |  | (27.0) |  | 14.9
Charges for the use of transmission facilities of the basic grid |  | (830) |  | (5.3) |  | (729) |  | (5.3) |  | 13.9
Depreciation and amortization |  | (983) |  | (6.2) |  | (927) |  | (6.7) |  | 6.0
Personnel |  | (1.249) |  | (7.9) |  | (1.212) |  | (8.8) |  | 3.1
Employee’ and managers’ profit sharing |  | (221) |  | (1.4) |  | (325) |  | (2.4) |  | (32.0)
Outsourced services |  | (1.031) |  | (6.5) |  | (923) |  | (6.7) |  | 11.7
Post-employment obligations |  | (124) |  | (0.8) |  | (107) |  | (0.8) |  | 15.9
Materials |  | (98) |  | (0.6) |  | (134) |  | (1.0) |  | (26.9)
Royalties for usage of water resources |  | (154) |  | (1.0) |  | (140) |  | (1.0) |  | 10.0
Provisions for operating losses |  | (257) |  | (1.6) |  | (138) |  | (1.0) |  | 86.2
Gas purchased for resale |  | (329) |  | (2.1) |  | (225) |  | (1.6) |  | 46.2
Construction costs |  | (1.529) |  | (9.7) |  | (1.328) |  | (9.6) |  | 15.1
Other operating expenses, net |  | (362) |  | (2.3) |  | (321) |  | (2.3) |  | 12.8
Total operating costs and expenses |  | (11.445) |  | (72.7) |  | (10.231) |  | (74.2) |  | 11.9

Electricity purchased for resale consists primarily of purchases from Itaipu through Eletrobrás and competitive biddings. We are required under applicable regulations to purchase part of Itaipu’s capacity at U.S. dollar denominated prices. We also purchase electricity from the CCEE and through bilateral contracts. Electricity purchased for resale increased R$556 million, or 14.9%, from R$3,722 million in 2010 to R$4,278 million in 2011. The increase in costs was primarily due to higher energy trading activity by Cemig Generation and Transmission and the increase in our interest in Light in 2011, resulting in the consolidation of a greater portion of this cost in our financial statements. This is a non-controllable cost and the difference between the amounts used as a reference for calculation of tariffs and the cost actually incurred is compensated for in the next tariff adjustment. For a breakdown of this expense, see Note 25 to our consolidated financial statements.

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Charges for the use of transmission facilities of the basic grid mainly correspond to the cost of transporting electricity in the Brazilian basic transmission network which is prorated among the Brazilian distribution companies, according to the Brazilian regulatory legislation. Charges for use of the transmission network, which are defined by Aneel, increased R$101 million, or 13.9%, from R$729 million in 2010 to R$830 million in 2011. These charges, set by an Aneel resolution, are payable by electricity distribution and generation agents for use of the facilities that are components of the national grid. This is a non-controllable cost and the difference between the amounts used as a reference for the calculation of tariffs and the cost actually incurred is compensated for in the next tariff adjustment.

Depreciation and amortization expense increased R$56 million, or 6.0%, from R$896 million in 2010 to R$927 million in 2011. This result is mainly due to the increase in our assets due to a higher investment in our distribution programs in 2011.

Personnel expenses increased R$37 million, or 3.1%, from R$1,212 million in 2010 to R$1,249 million in 2011. This increase is due by the average salary increase of 7% and 8.2% agreed in November 2011, in the negotiations for the annual Collective Work Agreement for 2011–12, being partly offset by the reduction of our aggregate number of employees from 2010 to 2011.

Employee’ and managers’ profit sharing decreased R$104 million, or 32.0%, from R$325 million in 2010 to R$221 million in 2011.This decrease is primarily the result of a labor agreement entered into between Cemig and the labor unions in November 2010 and 2011. In 2010 we also recognized an additional amount of R$30 million related to the 2009 labor agreement.

Outsourced services increased R$108 million, or 11.7%, from R$923 million in 2010 to R$1,031 million in 2011. This is primarily due to the higher amount of costs related to communication services, meter reading and delivery of electricity bills and consulting and readjustments in the contracts with the suppliers. The increases were primarily due to readjustments in the contracts with our suppliers. For a breakdown of the provisions see Note 25 to our consolidated financial statements.

Post-employment obligations expenses increased R$17 million, or 15.9%, from R$107 million in 2010 to R$124 million in 2011. These expenses primarily represent our actuarial obligations related to the net interest accruals in 2011. The increase in 2011 is mainly due to the increase in our interest in Light in 2011, resulting in the consolidation of a greater portion of this cost in our financial statements . For more information see Note 21 to our consolidated financial statements.

Provisions for operating losses increased R$119 million, or 86.2%, from R$138 million in 2010 to R$257 million in 2011. The components of this increase were as follows:

· increase of R$58 million or 55.2% in the allowance for doubtful accounts from R$105 million in 2010 to R$163 million in 2011. This was mainly due to revaluations of the installments made for recovery of debts owed by many consumers;

· the constitution of a provision for allowance for administrative proceedings brought by Aneel of R$4 million in 2011 compared to a reversion provision of R$47 million in 2010 due to a process ended by Aneel related to low-income subsidies which ended in December 2010;

· the constitution of a provision for judicial contingencies in the amount of R$48 million in 2011 compared to a reversion provision of R$54 million in 2010, based on the opinion of our legal counsel ;

· partially offset by civil actions for tariffs which decreased R$130 million, from R$139 million recorded in 2010 to R$9 million in 2011. The amount recorded in 2010 was the result of a substantial agreement concluded to end a lawsuit with respect to the industrial consumer tariff increase related to DNAEE Ministerial Order 045/86 .

Gas purchased for resale increased R$104 million, or 46.2%, from R$225 million in 2010 to R$329 million in 2011. This is a result of the larger quantity of gas purchased by GASMIG in 2011 to service its industrial clients.

As a result of the foregoing, we had an operating profit before financial expenses of R$4,303 million in 2011 compared to an operating profit before financial expenses of R$3,559 million in 2010.

Financial Revenues Expenses, Net

Financial revenues expenses, net, includes (i) financial income, which is mainly comprised of interest and a monetary restatement of our account receivable from the State Government, investment income earned, late charges on overdue electricity bills and foreign exchange gains and (ii) financial expenses, which are mainly comprised of interest expense on loans and financing, foreign exchange losses, monetary restatement losses, charges and adjustments for inflation on post-employment obligations paid to pension funds and other expenses.

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Net financial expenses increased R$217 million, or 28.8%, from R$753 million in 2010 to R$970 million in 2011. The main factors that impacted our net financial expenses in 2011 were:

· Loans and financing expenses: increase of R$235 million, or 21.8%, from R$1,076 million in 2010 to R$1,311 million in 2011. This increase was mainly due to greater variation in the CDI rate, the main index of our loans and financing contracts, reflecting the increasing in Brazilian benchmark rate (SELIC) in the first half of 2011.

· Monetary variation expense of post-employment obligations: increase of R$21 million, or 14.8%, from R$142 million in 2010 to R$163 million in 2011. This increase was mainly due to greater variation in the IPCA, to which the contract between Cemig and Forluz is indexed.

· Monetary variation on advance for future capital increase in the amount of R$66 million due to the readjustment of the balance that was reimbursed to the State Government.

Net financial expenses were partially offset by the following increases in financial income:

· Monetary variation on tax credit of a judicial deposit in the amount of R$68 million based on a court decision made in 2011 in favor of CEMIG which deemed certain state inheritance and donation taxes (ITCD) to be refundable.

· Revenue from monetary variation on Finsocial Tax collected during the period between 1989 and 1991 in the amount of R$67 million due to a favorable judicial outcome. This resulted from a judicial decision made which stated that there was no legal foundation requiring the Company to pay its federal tax obligations based on the tax rate increases established in tax code effective during the abovestated period. This amount has been updated by the interest earned through year-end.

For a breakdown of financial revenues and expenses, see Note 26 to our consolidated financial statements.

Income Tax Expense

Income tax represented an expense of R$918 million on pre-tax income of R$3,333 million in 2011, or 27.5%, compared to an expense of R$548 million on pre-tax income of R$2,806 million in 2010, or 19.5%. We recognized tax credits in 2011 and 2010 in the amounts of R$120 million and R$281 million, respectively. These tax credits were not recognized in the financial statements due to uncertainty regarding their ultimate realization and were recorded based on projected profits that indicated the realization of such credits. The effective tax rates are reconciled with the nominal rates in Note 10 to our consolidated financial statements.

Net Income

As a result of the foregoing, we had net income of R$2,415 million in 2011 compared to net income of R$2,258 million in 2010.

Liquidity and Capital Resources

Our business is capital intensive. Historically, we have required capital to finance the construction of new generation facilities and the expansion and modernization of existing generation, transmission and distribution facilities. Our liquidity requirements are also affected by our dividend policy. See “Item 8. Financial Information—Dividend Policy and Payments.” We have funded our liquidity and capital requirements primarily with cash provided by operations and, to a lesser extent, with proceeds of financings. We believe that our current cash reserves, cash provided by operations and anticipated proceeds from financings will be sufficient during the next 12 months to meet our liquidity requirements.

Cash and Cash Equivalents

Cash and cash equivalents as of December 31, 2012 were R$2,486 million compared to R$2,862 million as of December 31, 2011 and R$2,980 million as of December 31, 2010. None of our cash or cash equivalents was held in currencies other than reais as of December 31, 2012. The reasons for this decrease are presented below.

Cash Flow from Operating Activities

Net cash provided by operating activities in 2012, 2011 and 2010 totaled R$3,114 million, R$3,898 million and R$3,376 million, respectively. The decrease in cash provided by operating activities in 2012 compared to 2011 was due mainly to an increase

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in payment for purchased energy. The increase in cash provided by operating activities in 2011 compared to 2010 was due mainly to increases in net income liabilities in 2011 compared to 2010, adjusted for the items that do not affect cash and cash equivalents.

Cash Flow used in Investment Activities

Net cash used in investing activities during 2012, 2011 and 2010 amounted to R$2,100 million, R$4,017 million and R$4,444 million, respectively. The decrease in cash used in investment activities in 2012 compared to 2011 was mainly due to the net cash received for the early redemption of CRC Account amounting R$1,498 million and the dilution of jointly-controlled subsidiaries amounting to R$668 million.

The decrease in cash used in investing activities in 2011 compared to 2010 was due mainly to higher investments in power transmission assets in the previous year, with the investments in 2011 being mostly concentrated in the distribution business, such as Light, amounting R$0.4 billion and related to the acquisition of transmission assets from Abengoa Group, amounting R$0.7 billion.

Cash Flow from/used in Financing Activities

Net cash used in financing activities during 2012 was R$1,391 million, which was comprised of the repayment of R$6,838 million of real and foreign currency denominated financings and the payment of R$1,748 million in dividends and interest on capital, offset by the proceeds from financings in the amount of R$7,195 million.

Net cash from financing activities during 2011 was R$1 million, which was comprised of the proceeds from financings in the amount of R$4,255 million offset by the repayment of R$2,218 million of real and foreign currency denominated financings and the payment of R$2,036 million in dividends and interest on capital.

Net cash used in financing activities during 2010 was R$377 million, which was comprised of the repayment of R$4,775 million of real and foreign currency denominated financings and the payment of R$1,829 million in dividends and interest on capital, largely offset by the proceeds from financings in the amount of R$6,227 million.

Indebtedness

Our indebtedness from loans, financings and debentures as of December 31, 2012 was R$16,170.3 million, composed of R$7,106 million of current debt and R$9,064 million of current debt. This compares with indebtedness from loans, financings and debentures as of December 31, 2011 of R$15,779 million, composed of R$7,958 million of non-current debt and R$7,821 million of current debt. Of our debt at December 31, 2012, R$528.0 million was denominated in foreign currencies (R$481.2 million of which was U.S. dollar-denominated) and R$15,642.3 million was denominated in reais. See Note 19 to our consolidated financial statements.

Our main financial contracts, on a consolidated basis, as of December 31, 2012, are shown in the following table:

Amounts in thousands of reais:

Facility/Security |  | Maturity |  | Interest Rate (%) |  | Currency |  | Outstanding balance as of December 31, 2012
Foreign Currency |  |  |  |  |  |  |  |
BID (1) |  | 2022 |  | Libor+ Spread 1.7 to 2.2 |  | US$ |  | 84
BID (1) |  | 2023 |  | Libor+ Spread 1.5 to 1.88 |  | US$ |  | 143
Citibank |  | 2018 |  | 2.46 |  | US$ |  | 119
Others |  | 2013-2019 |  | Various |  | Various |  | 182
Total debt in foreign currency |  |  |  |  |  |  |  | 528
Brazilian currency |  |  |  |  |  |  |  |
Banco do Brasil |  | 2017 |  | 108.33% of CDI |  | R$ |  | 206
Banco do Brasil |  | 2012 |  | 109.80% of CDI |  | R$ |  | 447
Banco do Brasil |  | 2013 |  | 104.08% of CDI |  | R$ |  | 664
Banco do Brasil |  | 2013 |  | 105.00% of CDI |  | R$ |  | 1,083

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Banco do Brasil |  | 2013 |  | 107.60 of CDI |  | R$ |  | 133
Banco do Brasil |  | 20 14 |  | 104.10 of CDI |  | R$ |  | 1,114
Banco do Brasil |  | 2013 |  | 10.83 |  | R$ |  | 793
Banco do Brasil |  | 2014 |  | 98.5% of CDI |  | R$ |  | 476
Banco Itaú BBA / Votorantim |  | 2013-2014 |  | CDI + 1.70 |  | R$ |  | 107
BNDES |  | 2026 |  | TJLP+2.34 |  | R$ |  | 104
Bradesco |  | 2013 |  | 102.5/103.00% of CDI |  | R$ |  | 601
Debentures (2) |  | 2014 |  | IGP-M + 10.50 |  | R$ |  | 401
Debentures (2) |  | 2017 |  | IPCA+7.96 |  | R$ |  | 530
Debentures |  | 2015 |  | IPCA+7.68 |  | R$ |  | 1,445
Debentures |  | 2017 |  | CDI+0.90 |  | R$ |  | 518
Debentures |  | 2022 |  | IPCA+6.20 |  | R$ |  | 739
Debentures |  | 2019 |  | IPCA+6.00 |  | R$ |  | 220
Private Debentures (BNDESPAR) |  | 2016 |  | TJLP + 3.12 |  | R$ |  | 113
Eletrobrás |  | 2023 |  | Ufir + 6.00 to 8.00% |  | R$ |  | 390
Debentures VII (3) |  | 2016 |  | CDI + 1.35 |  | R$ |  | 214
Debentures VIII (3) |  | 2026 |  | CDI + 1.18 |  | R$ |  | 153
Debêntures LIGHT ENERGIA II (4) |  | 2019 |  | CDI + 1.18 |  | R$ |  | 142
CCB Bradesco (3) |  | 2017 |  | CDI + 0.85 |  | R$ |  | 124
BNDES – Finem (3) |  | 2019 |  | TJLP |  | R$ |  | 406
Debêntures (5) |  | 2016 |  | CDI+1.30% |  | R$ |  | 296
BNDES (6) |  | 2033 |  | TJLP + 2.40 |  | R$ |  | 379
Debentures (6) |  | 2013 |  | IPCA inflation index |  | R$ |  | 160
BNDES – Onlending (6) |  | 2033 |  | TJLP |  | R$ |  | 391
CEF (7) |  | 2021-2022 |  | TJLP + 3.50 |  | R$ |  | 202
BNDES (8) |  | 2019 |  | Various |  | R$ |  | 231
Debentures (8) |  | 2017 |  | Various |  | R$ |  | 1,954
Others |  | 2013-2025 |  | Various |  | R$ |  | 907
Debt in Brazilian currency |  |  |  |  |  |  |  | 15,642
Overall total, consolidated |  |  |  |  |  |  |  | 16,170

____________________

(1) Loan contracted for the jointly-controlled subsidiary Taesa;

(2) Loan contracted for the jointly-controlled subsidiary Hidrelétrica Pipoca S.A.;

(3) Loan contracted for the jointly-controlled subsidiary ECTE;

(4) Loans, financings and debentures of Light;

(5) Loan contracted for the jointly-controlled subsidiary Taesa;

(6) Loan and financing of Gasmig;

(7) Loan contracted for the jointly-controlled subsidiaries ENTE, EATE and ETEP;

(8) Loan contracted for the jointly-controlled subsidiary Taesa

In 2013, we entered into the following financial agreements and made the following issuances:

On January 31, 2013, CEMIG entred into a loan agreement with Banco do Brasil in the amount of R$200 million for the purpose of purchasing energy. The maturity is in 720 days, with interest at 99.5% of the CDI rate per annum.

On February 15, 2013, Cemig Distribution made its third issuance of debentures in the Brazilian market, in the total amount of R$2.16 billion, with an interest rate of: (i) the Interbank Deposit Rate plus 0.69% per annum for the debentures with maturity of 5 years; (ii) the IPCA rate plus 4.70% per annum for the debentures with maturity of 8 years; and (iii) the IPCA rate plus 5.10% per annum for the debentures with maturity of 12 years. The proceeds were used to redeem both the fifth and the sixth issuances of commercial papers and the remaining proceeds were used to invest in distribution infrastructure. The debentures were guaranteed by CEMIG.

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In 2012, we entered into the following financial agreements and made the following issuances:

On December 21, 2012, CEMIG entered into a loan agreement with Banco do Brasil in the amount of R$1,088 million. The proceeds of which were used to redeem CEMIG’s fourth issuance of commercial papers. The maturity date was February 19, 2013, which was extended to April 20, 2013. The loan bears interest at 105% of the CDI rate per annum. The outstanding balance as of December 31, 2012 was R$1,083.2 million. The loan was repaid on February 28, 2013.

On May 28, 2012, CEMIG Distribution entered into a loan agreement with Banco do Brasil in the amount of R$200 million, the proceeds of which were used to roll over existing debt. The loan will be paid in instalments due on May 2015, May 2016 and maturing on May 2017, at an interest rate at 108.33% of the CDI rate per annum. This loan is guaranteed by CEMIG. The outstanding balance as of December 31, 2012 was R$ 206.2 million.

On July 2, 2012, Cemig Distribution made its fifth issuance of commercial paper in the Brazilian market, in the total amount of R$640.0 million, with an interest rate at 104.08% of the CDI rate per annum, due on June 27, 2013. The proceeds were used for investment needs, payment of existing debts and working capital. The commercial papers were guaranteed by CEMIG. The outstanding balance as of December 31, 2012 was R$ 664.1 million.

On December 21, 2012, Cemig Distribution made its sixth issuance of commercial paper in the Brazilian market, in the total amount of R$600.0 million, with an interest rate at 102.5% of the CDI rate per annum for the first 120 days and an interest rate at 103% of the CDI rate per annum thereafter, due on June 19, 2013. The proceeds were used to recover the cash used for the investments made through the year and for the payment of outstanding debt through the year. The commercial papers were guaranteed by CEMIG. The outstanding balance on December 31, 2012 was R$ 600.8 million.

On January 13, 2012, Cemig Generation and Transmission made its fourth issuance of commercial paper in the Brazilian market, in the total amount of R$1 billion, with an interest of (i) 103% of the CDI rate per annum until the 60th day counted as from the issuance date; (ii) 104% of the CDI rate per annum from the 61st until the 120th day counted as from the issuance date; and (iii) 105% of the CDI rate per annum, from the 121st until the 180th day counted as from the issuance date, due on July 11, 2012. The proceeds were used to partially redeem the first tranche of the second issuance of debentures of Cemig Generation and Transmission. These commercial papers were guaranteed by CEMIG and were paid in full in March 31, 2012 with the proceeds of the third issuance of debentures.

On February 15, 2012, Cemig Generation and Transmission made its third issuance of debentures in the Brazilian market, in the total amount of R$1.35 billion, with an interest rate of: (i) the Interbank Deposit Rate plus 0.90% per annum for the debentures with maturity of 5 years; (ii) the IPCA rate plus 6.00% per annum for the debentures with maturity of 7 years; and (iii) the IPCA rate plus 6.20% per annum for the debentures with maturity of 10 years. The proceeds were used to redeem the fourth issuance of commercial papers. The debentures were guaranteed by CEMIG. The outstanding balance as of December 31, 2012 was R$ 1,476.5 million.

On October 24, 2012, Cemig Generation and Transmission made amendments to existing loans with Banco do Brasil, postponing the maturity of these loans. Certain loans contracted in 2006, maturing after 2012, in the amount of R$300 million, were amended to extend their maturity to 2013, maintaining the same interest rate of 104.1% of the CDI rate per annum. Other loans contracted in 2009, in the amount of R$442 million, maturing in 2012, were amended to extend their maturity to 2015, 2016 and 2017, bearing a new interest rate, from the date of the amendment, of 108% of the CDI rate per annum. The loans continued to be guaranteed by CEMIG. The outstanding balance of these loans on December 31, 2012 was R$1,358.7 million.

In 2011, we entered into the following financial agreements and made the following issuances:

On April 20, 2011 Cemig Distribution raised R$410 million from Banco do Brasil with maturity dates in April 2013 and April 2014 and interest rate at 98.5% of the CDI rate per annum. The outstanding balance on December 31, 2012 was R$ 475.9 million.

On December 28, 2011, Cemig Distribution made its fourth issuance of commercial paper in the Brazilian market, in the total amount of R$100.0 million, with an interest rate of 106% of the CDI rate per annum, due on December 22, 2012. The use of proceeds was for working capital purposes. The commercial papers were paid in full on December 22, 2012.

On December 28, 2011, CEMIG made its fourth issuance of commercial paper in the Brazilian market, in the total amount of R$1,000.0 million, with an interest rate of 106% of the CDI rate per annum, due on December 22, 2012. The commercial papers were paid in full on December 22, 2012.

In 2010, we entered into the following financial agreements and made the following issuances:

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On March 10, 2010 Cemig Generation and Transmission issued 270,000 non-convertible, nominal, book-entry, unsecured debentures, in two series, comprising 156,600 Debentures of the First Series and 113,400 Debentures of the Second Series, of the Issuer’s Second Issuance, in the aggregate amount of R$2.7 billion. The proceeds were used to prepay the outstanding balance of the 3rd issuance of Promissory Notes of Cemig Generation and Transmission. The Debentures of the First Series, with an outstanding balance of R$1,755 million as of December 31, 2011, accrue interest at accumulated variation of the average daily rate of the DI – Interbank Deposit, plus a spread of 0.90% per year. The Debentures of the Second Series, with an outstanding balance of R$ 1,444.6 million as of December 31, 2012, are adjusted from the Issue Date, by the variation in the IPCA rate and accrue interest corresponding to 7.6796% per year. These debentures are guaranteed by CEMIG.

On May 27, 2010 Cemig Distribution raised R$600 million from Banco do Brasil with a maturity in May 2013. The outstanding balance as of December 31, 2012 was R$ 793.2 million

During the last quarter of 2010 Cemig Generation and Transmission and Cemig Distribution, amended several loan agreements entered into with Banco do Brasil S.A in order to (i) postpone the maturity date of the installments payable in 2010, in the total amount of R$242.1 million with respect to Cemig Generation and Transmission and R$48.9 million with respect to Cemig Distribution, and (ii) change the interest rate from 110.0% of the CDI rate per annum to 109.8% of the CDI rate per annum. CEMIG is a guarantor of these loans and the total outstanding balance of these agreements on December 31, 2012 was R$ 447.2 million (as to Cemig Generation and Transmission). The agreements executed with Cemig Distribution were paid in full during the last quarter of 2012.

On December 23, 2010, CEMIG made its third issuance of Commercial Paper in the Brazilian market, in the total amount of R$350.0 million, with an interest rate of105.5% of the CDI rate per annum, due on December 18, 2011. The commercial papers were prepaid on August 4, 2011.

We are subject to financial covenants contained in some of our debt agreements that require us to maintain certain financial ratios. These ratios are computed based on our financial statements prepared in accordance with accounting practices adopted in Brazil. These and other covenants could limit our ability to support our liquidity and capital requirements. As of December 31, 2012, we were in non-compliance with some ratios contained in a credit instrument among Cemig Distribution and Santander (originally ABN Amro Bank). Such ratios were the following:

Cemig D

· Debt/EBITDA was 3.68x, when it was required to be equal or less than 2.5x

Cemig (as guarantor)

· EBTIDA/Interests was 2.8 x, when it was required to be equal or above 3.0x

· Debt/EBITDA was 2.7x, when it was required to be equal or less than 2.5x

Cemig D and Cemig obtained a waiver from Santander Bank on December 18, 2012.

As of December 31, 2012, we were in non-compliance with some ratios contained in a credit instrument among Cemig Distribution and Banco ItaúBBA. Such ratios were the following:

Cemig D

· Debt/EBTIDA was 4.58 x, when it was required to be equal or less than 3.36x

· Debt/(Shareholder’s equity + Debt) was 65.2%, when it was required to be equal or less than 62%

· Short term Debt/EBITDA was 266.1%, when it was required to be equal or less than 200%

· Capex/EBITDA was 120.2%, when it was required to be equal or less than 96%

The company had obtained the waiver from Banco ItaúBBA on December 18, 2012, considering preliminary figures and some actual figures ended up being not compatible with the obtained waiver. As another waiver was not obtained prior to December 31, 2012, not only the loan, but others with cross-default conditions had to be recognized as a current liability as contracts whose terms have not been met are recognized in current liabilities. The amount transferred to current liabilities as a result of non-compliance with the covenant was R$ 1,206 million, including the loans with cross-default clauses. The waiver is expected to be obtained in May/2013.

See “Item 13. Defaults, Dividend Arrearages and Delinquencies”

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Given the current portion of our financings in the amount of R$5,913 million due in 2013 (not considering the effect of the above mentioned transfer of R$ 1,206), we need funds in the short term to pay and refinance these obligations.

As a state-controlled company, we are subject to restrictions under current financing laws and regulations in Brazil on our ability to obtain financing in certain situations. For example, we must obtain approval from the Brazilian Ministry of Finance and the Central Bank prior to certain international financial transactions and such approval is typically granted only if the purpose of the transaction is to finance the import of goods or to roll over our external debt. In addition, financial institutions in Brazil are subject to risk exposure restrictions with regard to state governments, governmental agencies and state-controlled companies such as us. These restrictions have not prevented us from obtaining financing, although there is no assurance that our ability to obtain financing will not be hindered in the future. See “Item 3. Key Information—Risk Factors—Risks Relating to CEMIG— We are subject to rules and limits applied to levels of public sector borrowing and to restrictions on the use of certain funds we raise, which could prevent us from obtaining financing.”

Recent changes in the regulation of the energy sector, especially those introduced to the generation and transmission business by Law No. 12,783, and Cemig Distribution’s tariff review (held in April 2013) have required more precise budget planning. As of the date of this report, our Capital Expenditure and Investment Plan for 2013 had not yet been approved by us. In 2012, we funded our capital expenditures and investments in acquisitions and met our liquidity requirements through a combination of cash flow from operations and financings. We expect that we will fund our proposed capital expenditures and acquisitions and meet our other liquidity requirements in 2013 through a combination of cash flow from operations and financings. Because we rely primarily on cash generated from operations to fund our liquidity and capital requirements, factors that cause our revenues and net income to increase or decrease could have a corresponding effect on our access to sources of liquidity.

Over the long term, we anticipate that it will be necessary to make significant capital expenditures in connection with the maintenance and upgrading of our generation, transmission and distribution facilities, and we expect to employ a variety of liquidity sources, such as cash flow from operations and financings, in connection with such requirements. See “Item 3. Key Information—Risk Factors” for a discussion of certain matters that might adversely affect our liquidity position.

Research and Development

We are engaged in projects that explore technological advances not only in electric power systems but in all energy-related fields such as the development of the use of alternative energy sources, environmental control and power system performance, and safety optimization.

In 2012, we spent R$47 million on research and development and transferred R$41 million to the Fundo Nacional de Desenvolvimento Científico e Tecnológico, or FNDCT, a federal research and development fund, and R$21 million to Empresa de Pesquisa Energética, or EPE (the federal power planning company). In 2011, we spent R$37 million on research and development and transferred R$32 million to the Fundo Nacional de Desenvolvimento Científico e Tecnológico, or FNDCT, a federal research and development fund, and R$16 million to Empresa de Pesquisa Energética, or EPE (the federal power planning company). In 2010, we spent R$39 million on R&D. Additionally, R$34 million was transferred to FNDCT and R$17 million to EPE. We conduct these efforts in accordance with Federal Law No. 9,991/2000, as amended, which requires Brazilian power utilities to spend at least 1% of their net revenue on research and development projects and energy efficiency programs (including transfers to FNDCT and EPE), as well as in accordance with our strategic corporate plans.

In accordance with Aneel instructions, we have recorded as liability in 2012 for future expenditures on research and development programs and energy efficiency programs in the amount of R$174 million relating to amounts that had already been included in the billing we charge our consumers.

We have dedicated a substantial portion of our research and development activities to the development of the use of renewable energy sources, including wind, solar and biomass power generation.

Trends

As a public service utility, we are subject to regulations issued by the Federal Government as described in “Item 4. Information on the Company—The Brazilian Power Industry.” Therefore, any change in the regulatory framework may affect us significantly either with respect to our revenue if the change relates to prices or with respect to our operating expenses if the change relates to costs incurred to provide service to consumers.

We do not anticipate any significant change in revenues with respect to the transmission and distribution businesses since the regulation in place meets the plans of the Federal Government administration and was recently modified by Law No. 12,783.

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With respect to expansion, we believe that the extension of electricity services to all potential consumers represents a significant trend in our industry. Utilities are currently required to provide service to all potential consumers according to a schedule established by Aneel. Pursuant to Federal Law No. 10,438 of April 26, 2002, as amended, and the relevant Aneel resolution, financing for this extension of electricity services has come from the funds of the Energy Development Account (Conta de Desenvolvimento Energético), or CDE, and the Global Reversion Fund (Reserva Global de Reversão), or RGR.

As to the question of reliability of supply of electricity, the structural capacity of the system is adequate to meet the market’s needs for consumption of electricity, and the expansion of generation and transmission capacity currently in development will be able to meet the expected demand for consumption from the market. Rates of growth of electricity consumption in recent years have been 7.9% (2009–2010), 3.28% (2010–2011) and 4.19% (2011–2012). The Brazilian government has been successful with the “new supply” auctions starting in 2005 – which have made possible the construction of new projects such as the Santo Antônio hydroelectric plant (3,150.4 MW) and the Jirau hydroelectric plant (3,750 MW) hydroelectric plants, on the Madeira River; the Belo Monte plant (11,233 MW) on the Xingu River; and the Teles Pires plant (1,820 MW) on the Teles Pires River, in accordance with the needs of the distribution companies for purchase of electricity.

Commitments

In one of the agreements that regulates the partnership of Cemig Generation and Transmission with FIP Coliseu in the acquisition of the shares in Terna held by Terna S.p.A, Cemig Generation and Transmission granted FIP Coliseu the right to sell all of its interest in TAESA to Cemig Generation and Transmission, in the fifth year after its becoming a shareholder, upon payment of the amounts of capital invested net of the dividends and benefits received by FIP Coliseu in the acquisition of Terna adjusted by the variation in the IPCA +7% p.a.

In one of the contracts that regulate the partnership of CEMIG with FIP Redentor in the acquisition of 100% of the shares in Light indirectly held by both Enlighted and FIP PCP, CEMIG has granted FIP Redentor the right to sell all of its shares in Parati to CEMIG, in the fifth year after FIP Redentor’s acquisition of such shares, for a price equal to the amount of capital invested by FIP Redentor in the acquisition of these shares, adjusted in accordance with the variation of the CDI plus 0.9% p.a. net of the dividends and benefits received by FIP Redentor.

Contractual Obligations

We have outstanding contractual obligations and commitments which include principal debt payment provisions, the obligation to purchase electricity for resale from Itaipu, the obligation to transfer and transport electric power from Itaipu as well as construction commitments. The following table provides information, as of December 31, 2012, about our contractual obligations and commitments in thousands of reais.

|  | 2013 |  | 2014 |  | 2015 |  | 2016 |  | 2017 |  | 2018 and beyond |  | Total
Long-term debt (1) |  | 5,912,346 |  | 2,415,726 |  | 1,703,318 |  | 1,154,719 |  | 1,655,603 |  | 3,328,598 |  | 16,170,310
Purchase of electricity from Itaipu (2) |  | 970,559 |  | 987,811 |  | 984,382 |  | 947,985 |  | 962,996 |  | 32,526,764 |  | 37,380,497
Transportation of electric power from Itaipu (2) |  | 27,248 |  | 24,561 |  | 25,927 |  | 25,988 |  | 28,785 |  | 1,464,731 |  | 1,597,240
Electricity power purchase (3) |  | 2,248,795 |  | 2,102,150 |  | 2,210,399 |  | 2,325,517 |  | 2,422,252 |  | 63,180,091 |  | 74,489,204
“Quotas” PM 579 (4) |  | 334,163 |  | 214,985 |  | 785,129 |  | 736,021 |  | 684,104 |  | 36,185,497 |  | 38,939,899
Other electricity power purchase (5) |  | 1,931,805 |  | 1,976,670 |  | 1,666,778 |  | 1,572,917 |  | 2,030,629 |  | 41,265,737 |  | 50,444,536

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Pension plan debt—Forluz |  | 51,227 |  | 54,301 |  | 57,559 |  | 61,012 |  | 64,673 |  | 526,098 |  | 814,870
Total |  | 11,476,143 |  | 7,776,204 |  | 7,433,492 |  | 6,824,159 |  | 7,849,042 |  | 178,477,516 |  | 219,836,556

______________

(1) In the event of our non-compliance with certain covenants in our loan agreements, the total principal, future interest and any penalties due under these agreements may become immediately due and payable. See Item 13. “Defaults, Dividend Arrears and Delinquencies.” These amounts do not include interest payments on debt or payments under interest rate swap agreements. The Company expects to pay approximately R$610 million in interest payments on debt in 2013. The Company does not believe projections of interest payments and payments under interest rate swap agreements would be meaningful. Through March, 2013, the Company has already made R$3,446 million of debt payments.

(2) Contract with Furnas, denominated in U.S. dollars, to supply electric power purchased from Itaipu until May 2013. Amounts are calculated based on the U.S. dollar exchange rate as of December 31, 2012.

(3) Includes spot market purchases through auctions.

(4) Compensation to be received by the company by antecipation of the expiration of transmission concession agreements in accordance with MP 579 (Federal Law No.12,783).

(5) Includes spot market purchases through bilateral agreements

Item 6. Directors, Senior Managers and Employees

Directors and Senior Management

CEMIG is managed by our Board of Directors, which has 14 members, each with his or her respective substitute member, and by our Executive Board, which consists of 11 Chief Officers. Since it is the majority shareholder, the Minas Gerais State Government has the right to elect the majority of the members of our Board of Directors . Every holder of CEMIG common shares has the right to vote in an election for members of our Board of Directors. Under the Brazilian Corporate Law, any shareholder holding at least 5% of our common shares in circulation may request the adoption of a multiple vote procedure, which confers upon each share a number of votes equal to the present number of members of our Board of Directors and gives the shareholder the right to accumulate his or her votes in one sole candidate, or distribute them among several.

Under the Brazilian Corporate Law, holders of preferred shares representing at least 10% of our voting capital, and also holders of common shares representing at least 15% of our registered capital (other than the controlling shareholder) have the right to appoint a member of the Board of Directors and his or her respective substitute member. If none of the holders of common shares or preferred shares qualifies under the minimum limits specified above, shareholders representing, in the aggregate, a minimum of 10% of our registered capital may combine their holdings to appoint a member of the Board of Directors, and his or her respective substitute member.

CEMIG and its wholly-owned subsidiaries Cemig Generation and Transmission and Cemig Distribution all have the same Board of Directors, Fiscal Council and Executive Board, except that, in its wholly-owned subsidiaries’ Executive Board, only Cemig Distribution has a Chief Distribution Sales Officer, and only Cemig Generation and Transmission has a Chief Generation and Transmission Officer.

Board of Directors

Our Board of Directors meets, ordinarily, once a month and, extraordinarily, whenever called by its Chairman, Vice-Chairman, one third (1/3 of its members or by our Board of Executive Officers. Its responsibilities include, among others, setting the corporate strategy, general orientation of our businesses and election, approval of several relevant transactions and dismissal and monitoring of our Chief Officers.

Each member of the Board of Directors, permanent or substitute is elected by the General Meeting of Shareholders. The substitute members shall replace their respective permanent members whenever there is a temporary absence of such permanent members, or whenever there is a vacancy on the Board of Directors, and shall remain in such position until the appointment of a permanent member to fill the vacancy. No member of the Board of Directors, permanent or substitute, has any employment contract with our Company or with any subsidiary that provides for any benefit in the event of termination of the employment contract.

According to our by-laws, the members of our Board of Directors are elected for an unified period of two years, and may be re-elected. Our Board of Directors is made up of 14 permanent members, and their respective substitutes,, of whom eight are elected

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by the Minas Gerais State Government, five by AGC Energia S.A. (“AGC Energia”), and one by the holders of preferred shares. The period of office of the present members of our Board of Directors expires at the Ordinary General Shareholders Meeting to be held in April 2014. The names, positions and dates of original appointment of our present board members and their respective substitute members are as follows:

Name |  | Position |  | Date of original appointment
Dorothea Fonseca Furquim Werneck |  | Chairman |  | January 20, 2011
Paulo Sérgio Machado Ribeiro |  | Substitute Member |  | April 25, 2008
Djalma Bastos de Morais |  | Vice-Chairman |  | January 14, 1999
Lauro Sérgio Vasconcelos David |  | Substitute Member |  | April 28, 2006
Arcângelo Eustáquio Torres Queiroz |  | Board Member |  | December 10, 2009
Franklin Moreira Gonçalves |  | Substitute Member |  | February 27, 2003
Wando Pereira Borges |  | Board Member |  | December 18, 2012
Marco Antonio Rodrigues da Cunha |  | Substitute Member |  | February 27, 2003
Joaquim Francisco de Castro Neto |  | Board Member |  | December 21, 2011
Adriano Magalhães Chaves |  | Substitute Member |  | December 10, 2009
Francelino Pereira dos Santos |  | Board Member |  | February 27, 2003
Leonardo Maurício Colombini Lima |  | Substitute Member |  | May 12, 2011
Fuad Jorge Noman Filho |  | Board Member |  | August 29, 2012
Luiz Augusto de Barros |  | Substitute Member |  | August 29, 2012
João Camilo Penna |  | Board Member |  | April 25, 2008
Guilherme Horta Gonçalves Junior |  | Substitute Member |  | February 27, 2003
Eduardo Borges de Andrade (1) |  | Board Member |  | August 4, 2010
Tarcísio Augusto Carneiro (1) |  | Substitute Member |  | August 4, 2010
Otávio Marques de Azevedo (1) |  | Board Member |  | August 4, 2010
Bruno Magalhães Menicucci (1) |  | Substitute Member |  | December 21, 2011
Paulo Roberto Reckziegel Guedes (1) |  | Board Member |  | August 4, 2010
Marina Rosenthal Rocha (1) |  | Substitute Member |  | December 18, 2012
Ricardo Coutinho de Sena (1) |  | Board Member |  | August 4, 2010
Newton Brandão Ferraz Ramos (1) |  | Substitute Member |  | August 4, 2010
Saulo Alves Pereira Junior (1) |  | Board Member |  | August 4, 2010
José Augusto Gomes Campos (1) |  | Substitute Member |  | December 21, 2011
Guy Maria Villela Paschoal (2) |  | Board Member |  | April 25, 2008
Christiano Miguel Moysés (2) |  | Substitute Member |  | April 27, 2012

(1) Elected by AGC Energia.

(2) Elected by the preferred shareholders.

Below is some brief biographical information about each member of the Board of Directors:

Arcângelo Eustáquio Torres Queiroz - Mr. Queiroz graduated with a degree in History from the University Center of Belo Horizonte – UNIBH. Since 1988 he has worked for the Cemig Group, first at CEMIG, and then, at Cemig Distribution, where he currently occupies the position of Technical Administrator. From 2006 to 2010, he was a regular member of the Committee of Prosaúde Forluminas Social Security – Forluz, pension fund of some of the Cemig Group’s companies. Currently, he is Director of the Intermunicipal Union of Industrial Energy Workers of Minas Gerais and Fuel Gas Industry Workers of the State of Minas Gerais – SINDIELETRO/MG. Mr. Queiroz is a member of our Career and Compensation Committee and, since 2009, has been an effective member of our Board of Directors and also the Board of Directors of Cemig Distribution and Cemig Generation and Transmission.

Djalma Bastos de Morais - Mr. Morais holds a bachelor’s degree in engineering from the Military Institute of Engineering and has completed post-graduate studies in telephony and computers at the same institute. From 1995 to 1998, Mr. Morais was the Vice-President of Petrobras Distribuidora S.A. and, from 1993 to 1994, he served as Brazilian Minister of Communications. He has also held various other positions, such as Chief Executive Officer of Telecomunicações de Minas Gerais S.A. — Telemig; manager of Telecomunicações Brasileiras S.A.—Telebrás; Chief Operating Officer of Telecomunicações de Mato Grosso — Telemat; Chief Operating Officer of Telecomunicações do Amazonas—Telemazon; and manager of Telefônica Municipal S.A. — Telemusa. Mr. Morais is an executive officer and a member of the Board of Directors of several companies of the Cemig Group and, since 1999, he has been our Chief Executive Officer and Vice President of our Board of Directors. Since 2004 he has been the Chief Executive Officer and Vice-Chairman of Cemig Distribution and Cemig Generation and Transmission. Since 2006, he has been a member of Light S.A and Light Serviços de Eletricidade S.A.’s Board of Director and, since 2009, President of Transmissora Aliança de Energia Elétrica S.A. – TAESA’s Board of Directors.

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Dorothea Fonseca Furquim Werneck - Ms. Werneck holds a bachelor degree in Economics and completed the Master’s Degree from the Postgraduate School of the Getúlio Vargas Foundation in Rio de Janeiro, and a Doctorate Course from the Boston College. She was Brazil’s Minister of Industry, Trade and Tourism from 1995 to 1996, and Employment Minister from 1989 to 1990. She was a Senior Manager of the Export Promotion Agency – Apex from 1990 to 1992, Executive Secretary of the Finance Ministry in 1992, National Economy Secretary from 1991 to 1992, Economic and Social Planning Secretary from 1988 to 1989, Employment and Salaries Secretary from 1985 to 1988; and a member of the technical staff of IPEA from 1975 to 2003. Among other positions, she has also been Director of the National Quality Awards Foundation (from 1993 to 1994 and from 1998 to 1999); and a member of the Councils of Funcex and AEB, from 1999 to 2005. Since 2011 she has been secretary of Development for the State of Minas Gerais and Chairwoman of our Board of Directors and also of Cemig Distribution and Cemig Generation and Transmission.

Eduardo Borges de Andrade - Mr. Andrade has a degree in civil engineering from Minas Gerais Federal University, and completed postgraduate studies in financial administration at the Getúlio Vargas Foundation in São Paulo. He began his career at Construtora Andrade Gutierrez S.A. in 1961, where he occupied several positions such as Buildings Chief Officer and Operations Chief Officer and, from 1978 to 2001, as Chief Executive Officer. Currently, Mr. Andrade is a regular member of the Board of Directors of Andrade Gutierrez S.A. and Companhia de Concessões Rodoviárias S.A. – CCR, and Chief Officer of AGC Participações Ltda. He is also a member of the Board of Trustees of the Dom Cabral Foundation. Since 2010, Mr. Andrade is a regular member of our Board of Directors, and that of Cemig Distribution’s and Cemig Generation and Transmission’s Boards of Directors.

Francelino Pereira dos Santos - Mr. Santos has a law degree from Federal University of Minas Gerais. He was the Senator for Minas Gerais from 1995 to 2002 and Governor of Minas Gerais from 1979 to 1983. He also was a congressman for four consecutive terms from 1963 to 1979 and alderman of the city of Belo Horizonte from 1951 to 1954. From 1961 to 1966 he was the Chief of Cabinet of the Minas Gerais State Secretary of Internal Affairs and Justice, Chief of the Minas Gerais State General Management Department and Chief Counsel of Municipalities Affairs of the Cabinet of the Governor. From 1985 to 1990, he was the Vice-President of Management of Banco do Brasil S.A. and the Chief Executive Officer of Acesita from 1983 to 1984. He is a member of the Brazilian Academy of Letters (Academia Brasileira de Letras) and also a regular member of the National Academy of Agriculture (Academia Nacional de Agricultura). Since 2003, Mr. Santos is a regular member of our Board of Directors and, since 2004, is member of Cemig Distribution’s and Cemig Generation and Transmission’s Boards of Directors.

Fuad Jorge Noman Filho - Mr. Noman Filho has a degree in economics by the Unified Teaching Center of Brasilia (CEUB) and has completed a postgraduate degree in Economic Programming and Budget Execution by the University of Brasília (UnB). He was executive secretary and deputy secretary of Assets and Risks of the National Treasury Secretariat, in the Ministry of Finance; Executive Secretary of the Presidency of the Republic of Consultant International Monetary Fund (IMF). He was also Secretary for Finance of Minas Gerais - (2003 - 2007) and Secretary for Transport and Public Works of Minas Gerais (2007 - 2010). Between 2007 and 2011, he was a member of the Board of Directors of Minas Gerais State Development Bank (Banco de Desenvolvimento do Estado de Minas Gerais S.A. - BDMG). Since 2008, he is a member of the Board of Directors of Marcopolo S.A., a publicly-held company which main activity is the bus manufacture and development and implementation of solutions for public transportation. Between March 2011 and August 2012, he was the CEO and member of the Board of Directors of Gasmig, and our Gas Officer. Since August 2012 Mr. Noman Filho has been Minas Gerais State Secretary for Coordination of Investments and also Minas Gerais State Secretary for Soccer World Cup Affairs.

Guy Maria Villela Paschoal - Mr. Paschoal holds a degree in mechanical and electrical engineering from the Federal University of Minas Gerais and has completed courses in Electricity Sector Law at the Law School of Belo Horizonte, and in Management for Electric Utility Executives, at Rensselaer Polytechnic Institute in Troy, New York, USA. Mr. Paschoal joined the Company in 1984, and reached several positions including Chief Executive Director, Vice President, Chief Executive Officer and Chairman of the Board of directors. He has served as consultant and advisor to the Executive Board of Eletrobrás, and as a member of the Board of Directors of Itaipu Binacional. As Secretary-General of the Ministry of Mines and Energy, he was on several occasions Acting Minister of Mines and Energy. From 2003 to 2008 he was a member of the Infrastructure Chamber of the Minas Gerais Industries Federation (FIEMG). He served as consultant in Furnas Centrais Elétricas, involved in the Rio Madeira’s hydroelectric projects. In the same period, he worked in Eletrobras, as the Presidency’s Consultant and as a member of the Directory Using the Belo Monte Hydroelectric Plant. In the period 2008/2012, he was the Chairman and Director of the Brazilian Association of the Electricity Distributors - ABRADEE. Since 2008, is an effective member of our Board of Directors and the Board of Cemig Distribution and Cemig Generation and Transmission. Currently, is a member of the Advisory Board of the Memory of Electricity in Brazil (Rio de Janeiro) and the Superior Council of the Foundation Selice Rosso (Hospital Felício Rocho).

João Camilo Penna - Mr. Penna earned his degree in engineering in 1948 from Minas Gerais Federal University. He served as Finance Secretary of Minas Gerais State from 1975 to 1979, as Brazil’s Trade and Industry Minister from 1979 to 1984, and was CEO of Furnas Centrais Elétricas from 1985 to 1989. He was interim Administration Secretary of Minas Gerais State, a Member of the National Monetary Council (CMN), member of the Board of Directors of Eletrobras, Vice-President of the Brazilian Technical Standards Association, Director of the Large Dams Committee, and of the Brazilian Group for the World Energy Conference. He was

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a member of the President of Republic’s Ethics Committee, from 2000 to 2005, and from 2004 to 2005 was a member of the Public Ethics Committee of the Minas Gerais State Government. Since 2008, he is a regular member of our Board of Directors and of the Cemig Distribution’s and of Cemig Generation and Transmission’s Boards of Directors.

Joaquim Francisco de Castro Neto - Mr. Castro Neto earned his degree in Business from the Getulio Vargas Foundation and completed a specialization course in Selling Business, Marketing and New Product Development from the IMEDE in Lausanne, Switzerland. Since 2008, Mr. Castro Neto is member of the Board of Directors of ABodyTech and of Magazine Luiza, having been its Chairman from the last one, from 2008 to 2010 he was the Redecard Chief Executive Officer. He was CEO of Unibanco – União de Bancos Brasileiros S.A from 1974 to 2004. Since 2011, he is a member of the Board of Directors of Jereissati Participações S.A. , and he’s a regular member of our Board of Directors and also of Cemig Distribution and Cemig Generation and Transmission.

Otávio Marques de Azevedo - Mr. Azevedo has a degree in Electrical Engineering from Pontifical Catholic University of Minas Gerais (PUC-MG), having completed postgraduate studies in Economic Engineering at the Federal University of Minas Gerais, and in Strategic Planning at Getúlio Vargas Foundation in Rio de Janeiro. Mr. Azevedo was Vice President of Telebras from 1991 to 1993, CEO of Tele Norte Leste Participacoes SA, from 1998 to 1999, and Chairman of its Board of Directors from 2003 to 2004. He was Chairman of the Anatel (National Telecommunication Agency) from 2001 to 2002 and since 1993 is Executive Chairman of Andrade Gutierrez SA and Andrade Gutierrez Telecomunicações Ltda.. Mr. Azevedo is also a member of the Board of Directors of several companies of this group, having held the chair of several of these Councils. Mr. Azevedo was also a member of the Strategic Council of the Federation of Industries of Minas Gerais - Fiemg, Council of the Commercial Association of Rio de Janeiro - ACRJ and the Board of Directors of the Federation of Industries of São Paulo (Fiesp). Since 2010, Mr. Azevedo is an effective member of our Board of Directors and also of Cemig Distribution and Cemig Generation and Transmission.

Paulo Roberto Reckziegel Guedes - Mr. Guedes has a degree in Civil Engineering from Universidade Federal do Rio Grande do Sul, having completed the Corporate MBA at Fundação Dom Cabral. Mr. Guedes joined Andrade Gutierrez Group in 1993 as assistant engineer, then supervisory engineer, general manager of operations and project manager, and since 2000, he is the Chief Officer of Andrade Gutierrez S.A Concessões, a listed company of concessions of public works and services, representing also the Andrade Gutierrez S.A Concessões on the Board of Directors of several subsidiaries of the group. Since 2010, Mr. Guedes is an effective member of our Board of Directors and also of Cemig Distribution and Cemig Generation and Transmission. He is also a member of the Board of Directors of Light S.A and Light Electrical Services S.A.

Ricardo Coutinho de Sena - Mr. Sena has a degree in Civil Engineering from Universidade Federal de Minas Gerais, and completed his postgraduate studies in Financial Administration at the Getulio Vargas Foundation in Rio de Janeiro. Mr. Sena worked in M. Roscoe, a construction company, between 1972 and 1981, joining Andrade Gutierrez in 1981, as Head of Budgets and, since 1993, the General Manager of New Business Unit. Since 2000 he is the CEO of Andrade Gutierrez and a member of its Board of Directors. He represents Andrade Gutierrez S.A Concessões on the Board of Directors of several of its subsidiaries. Since 2010, Mr. Sena is an effective member of our Board of Directors and the Board of Cemig Distribution and Cemig Generation and Transmission.

Saulo Alves Pereira Junior - Mr. Pereira Junior has a degree in Electrical Engineering from Pontifical Catholic University of Minas Gerais (PUC-MG), post-graduate degree in Works and Services Budget Planning from Instituto de Educação Continuada of PUC–MG and Business Administration from the Federal University of Bahia. He also concluded a Corporate MBA from Dom Cabral Foundation. Mr. Pereira began his career in 1993 as an intern in our Operations Center. In 1995 he joined Construtel Projetos e Construções Ltda, as an engineer in planning and budget coordination, and in 1998 he became General Manager of that company’s Business Unit in Bahia. In 2000, he joined Andrade Gutierrez Group, and since 2004 he is Commercial Officer of Construtora Andrade Gutierrez S.A. Since 2007 he has been working in Andrade Gutierrez Concessões S.A., actively participating in the group’s consolidation in the electricity sector. Since 2010, Mr. Pereira Junior is a member of our Board of Directors, and also of Cemig Distribution and of Cemig Generation and Transmission.

Wando Pereira Borges - Mr. Borges has a degree in economics and business administration from the Federal University of Minas Gerais (UFMG), and completed postgraduate studies at the Getúlio Vargas Foundation in Rio de Janeiro, and at Yale University, in the United States. From 1962 to 1966 he was Chief Economist of the Projects Department of the Minas Gerais Development Bank (BDMG). From 1967 to 1969 he was a special advisor to the Director-General of DNER, the Brazilian National Highways Department and from 1969 to 1970 he was a Consultant to the World Bank in Chile and in Washington D.C.. From 1970 through 1976 he was a director of TRNSCON++, a Brazilian transport consultancy. From 1977 to 1979 he was CEO of Digibrás. In 1979–1982 he was General Secretary of the Brazilian Transport Ministry. From 1982 to 1984 he was CEO of GEIPOT – Empresa Brasileira de Planejamento de Transportes. From 1984 to 1992 he was consultant to Cia. do Jari, Caemi and subsidiaries. From 1993 to 1995 he was Transport Consultant and Director of ABCE, the Brazilian Engineering Consultants’ Association. In 1995 and 1996 he was an advisor to the Mining and Energy Committee of the Chamber of Deputies in the Brazilian lower house of Congress. From 1997 to 1999 he was Planning, Industry and Trade Secretary for the city of Patos de Minas. From 2000 to 2001 he was a consultant to the Brazilian National Transport Federation (CNT). Since 2002 he has worked as a consultant for transport projects and for holders of

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highway concessions. From 2008 to 2010 he was a member of the Board of Directors of Bozel Mineração S.A., from 2008 to 2009 he was CEO of Eleja – Elétrica Jacuí S.A., from 2008 to 2009 he was Administrator of Powerbras Energia Holding Ltda. Since December 18, 2012 he has been a member of the Boards of Directors of Cemig, Cemig Distribution and Cemig Generation and Transmission.

Board of Executive Officers

Our Executive Board, made up of eleven Executive Officers is responsible for putting into effect the decisions of our Board of Directors and for day-to-day management. The members of the Executive Board, the Chief Officers, have individual responsibilities established in our by-laws and hold their positions for a period of office of three years. The period of office of the present Chief Officers expires at the first Meeting of the Board of Directors following the Ordinary General Shareholders Meeting to be held in April 2015. The Chief Officers are elected by our Board of Directors. Usually, ordinary meetings are held at least twice per month, with extraordinary meetings held whenever called by the Chief Executive Officer, or CEO, or by two Chief Officers other than the CEO.

The Executive Officers shall exercise their positions as full-time occupations in exclusive dedication to the service of the Company. They may at the same time exercise non-remunerated positions in the management of the Company’s wholly-owned or other subsidiaries or affiliated companies, at the option of the Board of Directors. They shall, however, obligatorily hold and exercise the corresponding positions in the wholly-owned subsidiaries Cemig Distribution and Cemig Generation and Transmission.

The Executive Board is responsible for the current management of the Company’s business, subject to the obligation to obey the Long-Term Strategic Plan, the Multi-year Strategic Implementation Plan and the Annual Budget.

Some decisions, as outlined in section 4, clause 21, of our by-laws require approval of our Executive Board.

In the event of absence, leave, resignation or vacancy of the post of the Chief Executive Officer, the Deputy Chief Executive Officer shall exercise the duties of the Chief Executive Officer, for whatever period the absence or leave may last, and, in the event of vacancy or impediment or resignation, until the post is filled by the Board of Directors. In the event of absence, leave, resignation or vacancy of the post of any of the other members of the Executive Board, the Executive Board may, by approval of a majority of its members, attribute the exercise of the respective functions to another Executive Officer, for as long as the period of absence or leave – or, in the event of vacancy, the impediment or resignation – lasts, until the post is filled by the Board of Directors. The Chief Executive Officer or a member of the Executive Board elected in the way described above shall hold the position for the period of time remaining in the substituted officer’s term.

The names, positions and dates of initial appointment of our executive officers are as follows:

Name |  | Position |  | Date of original appointment
Djalma Bastos de Morais |  | Chief Executive Officer (CEO) |  | January 14, 1999
Arlindo Porto Neto |  | Deputy CEO |  | January 20, 2009
Ricardo José Charbel |  | Chief Energy Distribution and Commercialization Officer |  | November 23, 2012
Luiz Henrique de Castro Carvalho |  | Chief Generation and Transmission Officer |  | August 18, 2008
Fernando Henrique Schüffner Neto |  | Chief Officer for Business Development |  | January 9, 2007
Luiz Fernando Rolla |  | Chief Officer for Finance and Investor Relations |  | January 9, 2007
Frederico Pacheco de Medeiros |  | Chief Corporate Management Officer |  | January 20, 2011
José Raimundo Dias Fonseca |  | Chief Trading Officer |  | January 20, 2011
José Carlos de Mattos |  | Chief Officer for the Gas Division |  | January 9, 2007
Maria Celeste Morais Guimarães |  | Chief Counsel |  | January 3, 2011
Luiz Henrique Michalick |  | Chief Institutional Relations and Communication Officer |  | January 20, 2011

Below is brief biographical information about each member of the Executive Board.

Arlindo Porto Neto - Mr. Porto Neto has a degree in business administration and accounting from the Federal University of Uberlândia. He served as Senator for the State of Minas Gerais from 1995 to 2003, and was Brazil’s Minister of Agriculture and Supply from 1996 to 1998. From 1991 to 1994 he was Deputy Governor of the State of Minas Gerais. From 1983 to 1988 he was Mayor of Patos de Minas. Since 2004 he is Vice-President of the Minas Gerais Development Company (Companhia de Desenvolvimento de Minas Gerais – Codemig). Since 2009, he serves as Deputy CEO of CEMIG and of Cemig Distribution and Cemig Generation and Transmission.

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Djalma Bastos de Morais - For biographical information regarding Mr. Morais, see “— Board of Directors.”

Fernando Henrique Schuffner Neto - Mr. Schuffner Neto holds a degree in Electrical Engineering from Pontifical Catholic University of Minas Gerais, and also master degree in Automation and Control from Unicamp and a MBA from Ibmec. Mr. Schuffner Neto has been working for CEMIG since 1985, holding varied positions as of General Manager of Coordination, Planning and Expansion of Distribution, General Manager of Executive Coordination of the “Luz para Todos” Program including as our Generation and Transmission Officer and as our Energy Distribution and Commercialization Officer. Mr. Schufnner Neto is also a professor and researcher. He is a substitute member of our Board of Directors (BOD) and of the BOD of Cemig Telecomunicações S.A., Cemig Distribution and Cemig Generation and Transmission, Light S.A. and Light Serviços de Eletricidade S.A.. Since 2010, he is Business Development Officer of CEMIG, of Cemig Distribution and of Cemig Generation and Transmission.

Frederico Pacheco de Medeiros – Mr. Medeiros has a law degree from the Federal University of Minas Gerais. He acted as Legal Advisor to the Minas Gerais State Court of Appeal from 1989 to 1998, and was Parliamentary Secretary of the House of Representatives of the Brazilian Congress from 1993 to 2002. He was Deputy Secretary of State of Minas Gerais from 2003 to 2008, and General Secretary to the Governor of Minas Gerais in 2008–2010. Since 2011 he is the Chief Corporate Management Officer of CEMIG, of Cemig Distribution and of Cemig Generation and Transmission.

José Carlos de Mattos -. Mr. Mattos was born in 1946, and received a degree in Bussiness Administration and was a licensed Portuguese teacher . Mr. Mattos was a regional Superintendent for Minas Gerais, São Paulo and Rio de Janeiro from 1983 to 1992 and Financial Director from 1992 to 1994 of Caixa Econômica Federal – CEF (Federal Savings Bank). During that same period, from1992 to 1994, he was Chief Officer of Banco Interamericano de Poupança e Empréstimo – BIAPE (Inter-American Savings and Loan Bank). From 1995 to 1996 he was Deputy CEO of Banco do Estado de Minas Gerais – BEMGE (State Bank of Minas Gerais). From 2003 to 2005, he was the Financial Director of Companhia de Desenvolvimento de Minas Gerais – CODEMIG (Minas Gerais Development Company). From 2005 to 2006, he was the CEO of Fundação de Seguridade Social de Minas Gerais – PREVIMINAS (Minas Gerais Social Security Foundation). From 2007 to 2009, he was CEO and Administrative Counselor of Gasmig. At Cemig, Cemig Distribution and Cemig Generation and Transmission, he was Director of Planning, Design and Construction from January to April 2007, Director of New Business Development from April 2007 to December 2010, Director of Gas from February to September 2009 and Director of Distribution and Commercialization from December 2010 to November 2012. Since November 23, 2012, he has been Director of Gas of Cemig, Cemig Distribution and Cemig Generation and Transmission, and the CEO of Gasmig.

José Raimundo Dias Fonseca - Mr. Fonseca has a degree in electrical engineering from the Federal University of Juiz de Fora. He has completed the specialization course in Maintenance Engineering at the Federal Engineering School of Itajubá (Fupai/Efei); the postgraduate course in Strategic Business Management of the Getúlio Vargas Foundation; and the specialization course in Management of Electric Power Utilities at the University of Stockholm (Sweden). He is a member of the Council of CCEE – the Brazilian National Electricity Trading Chamber; and Vice-president of Abraceel, the Brazilian Association of Electricity Traders. Mr. Fonseca joined us in 1982, holding varied posts from engineer to Control and Settlement Officer for Electricity Trading Transactions. From 2007 to 2011 he was General Manager for Wholesale Electricity Transactions. Since 2011, he is our Chief Trading Officer and also of Cemig Distribution and Cemig Generation and Transmission.

Luiz Fernando Rolla - Mr. Rolla holds a degree in Electrical Engineering from Minas Gerais Federal University and has completed specialization in engineering economics and data processing. He joined us in 1974 in the coordination of the electrical system planning and, later, in the coordination of projects funding by World Bank, Inter-American Development Bank, Kreditanstalt für Wiederaufbau banking group and Eletrobras. He also participated in the process of raising funds in international markets with emphasis on the placement of Eurobonds and blocktrade stock. In 1987 he became our Investor Relations Manager being responsible for the formulation and implementation of our investor relations strategy including the structuring of the Level I and II ADR programs, implementation of Corporate Governance Level 1 in BM&FBovespa, and listing in Latibex, Madri Stock Excchange. Since 2009 he is the Chairman of the Brazilian Institute of Investors Relation (Instituto Brasileiro de Relações com Investidores – IBRI). Mr. Rolla is an executive officer and director of several companies of our group and, since 2007, he is our Finance and Investors Relations Officer and also of Cemig Distribution and Cemig Generation and Transmission. He is a member of the Board of Directors of Light SA and Light SESA.

Luiz Henrique de Castro Carvalho - Mr. Carvalho has a degree in electrical engineering from Minas Gerais Federal University, having completed a postgraduate degree from the same institution in Systems Analysis with emphasis on Mainframe Support and an international executive MBA in business administration and information technology management from the Getúlio Vargas Foundation. Mr. Carvalho joined us in 1984 as a support analyst in the Software and Support Group. Since then he has occupied several positions as of Manager in the Personal IT Terminal Users Support Division, Superintendent of Telecommunications and IT, and as Superintendent for Material, Logistics and Services. He is Chief Officer and member of the Board of Directors of several companies of our group. Since 2008, Mr. Carvalho is our Generation and Transmission Officer and also of Cemig Generation and Transmissions, and also Chief Officer of Cemig Distribution.

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Luiz Henrique Michalick - Mr. Michalick has a degree in journalism from the Pontifical University of Minas Gerais. In his career in the press, he was a journalist in the Belo Horizonte office of the Folha de São Paulo newspaper, from 1979 to 1985, and economics editor in the Estado de Minas newspaper, from 1986 to 1987. He joined the Company in 1985, working as a journalist and as General Manager for Press, Public Relations and Advertising, before becoming General Manager for Corporate Communications, a position he held from 2003 to 2011. Since 2011, Mr. Michalick has been our Institutional Relations and Communications Officer, and also, the Institutional Relations and Communications Officer of Cemig Distribution and of Cemig Generation and Transmission.

Maria Celeste Morais Guimarães - Mrs. Guimarães has a degree in accounting and business administration from the Pontifical Catholic University of Minas Gerais and a law degree from the Law Faculty of the Universidade Federal de Minas Gerais, having completed a specialization in commercial law and a master’s and doctorate from the same university. She was Auditor-General of the State of Minas Gerais from 2003 to 2010 and Chairwoman of Magistrates Council of Executive State Entities (Conselho de Corregedores dos Órgãos e Entidades do Poder Executivo Estadual – CONREGE) from 2004 to 2010. Between 2005 and 2010, she was a member of the College of Social Defense Organizations , and between 2007 and 2009 of the National Council of the Entities of Internal Control of the Brazilian states and Federal District (Conselho Nacional dos Órgãos de Controle Interno dos Estados Brasileiros e do Distrito Federal – CONACI). From 2007 to 2010, Mrs. Guimarães was a member of Board of General Coordination, Planning, Management and Finance of the Minas Gerais State and, from 2008 to 2010, of the Corporate Governance Committee of the Minas Gerais State. She also was a member of Energy Rights Commission and Corporate Lawer Commission of the Brazilian Bar Association (Ordem dos Advogados do Brasil – OAB-MG) and since 2011, she has been our Legal Officer, and also, the Legal Office of Cemig Distribution and Cemig Generation and Transmission.

Ricardo José Charbel - Mr. Charbel has degrees in electrical engineering from PUC University of Minas Gerais and in electricity distribution maintenance and operation engineering from Mackenzie University of São Paulo, with postgraduate studies in data processing from Minas Gerais Federal University (UFMG) and an Executive MBA from the Ibmec Business School of Minas Gerais. Mr. Charbel is a career Cemig executive, and has held several positions at Cemig, including General Manager for Distribution Expansion Planning, Studies and Projects, from 2010 to 2012, Manager, and Executive Coordination General Manager for the Light for All (Luz Para Todos) distribution expansion programfrom 2007 to 2010 and Customer Relationship Manager, and Division Manager from 1999 to 2007. He started his career with Cemig working as a systems analyst and engineer, from 1983 to 1990. Since November 2012, Mr. Charbel has been our Chief Energy Distribution and Commercialization Officer.

Compensation of Directors and Executive Officers

The global amount of the remuneration of the Executive Board and the Members of Board of Directors and Fiscal Council, including benefits of any type, shall be fixed by the General Meeting of Stockholders, in accordance with the legislation from time to time in force.

In the year ended December 31, 2012 the total compensation paid to our directors and officers and the directors and officers of Cemig Distribution and Cemig Generation and Transmission, including health insurance, paid leave, bonuses, post-employment and other benefits, amounted to approximately R$12 million.

The following chart shows the compensation paid to our Board Directors, Executive Officers, Fiscal Council and Support Committee members in 2012:

Compensation in the year ended December 31, 2012 (in Thousands of Reais)
| Board of Directors | Support Committee(1) | Executive Officers | Fiscal Council
Number of members (2) | 13 | 6 | 11 | 10
Total compensation | 1,186.5 | 563.1 | 9,984.5 | 459.8

(1) The Support Committee is a body with no executive function, composed of members of our Board of Directors, responsible for evaluating and making recommendations on the matters to be discussed at the Board meeting, prioritizing issues, checking the documentation for better understanding of the Board Directors and other issues necessary for the objectivity of the Board meetings.

(2) The number of members corresponds to the average monthy number of members, divided by twelve (12). The Fiscal Council includes the substitutes members according with the decision of the 2011 Ordinary Genereal Meeting of Stockholders.

There is no contract between the Company or its wholly-owned subsidiaries, subsidiaries or affiliated companies and any director or officer of the Company that grants any kind of post-employment benefits, other than the retirement plan of Forluz, which is applicable to executive officers, as long as they are qualified in accordance with the rules and regulations of Forluz and which is also applicable to other employees in the same way.

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Fiscal Council

According to our by-laws, our Fiscal Counsel shall be permanent. Our Fiscal Council is required to meet once every quarter, but in practice it has been meeting once a month. Our Fiscal Council consists of three to five members and their respective alternates elected by our shareholders at the Ordinary General Meeting for a term of one fiscal year. Holders of the preferred shares as a group are entitled to elect one member of the Fiscal Council and a corresponding alternate. Minority shareholders holding shares representing at least 10%, individually or in the aggregate, are entitled to elect one member of the Fiscal Council and a corresponding alternate. The primary responsibility of the Fiscal Council, which is independent from management and from the independent public accountants appointed by the Board of Directors, is to review our financial statements and report on them to our shareholders. The Fiscal Council is also entitled to give opinions on any proposals from our management to be submitted to the shareholders’ meeting related to (i) changes in our share capital, (ii) issuances of debentures or rights offerings entitling the holder to subscribe for equity (bonus de subscrição), (iii) investment plans and capital expenditures budgets, (iv) distribution of dividends, (v) changes to our corporate form and (vi) corporate restructurings such as mergers, consolidations and spin-offs. The Fiscal Council also examines the activities of management and reports these activities to the shareholders.

The current members of the Fiscal Council, and their substitute members, all of whose terms expire at the Ordinary General Meeting of Shareholders to be held in 2013, for the approval of the 2012 fiscal year financial statements are as follows:

Name |  | Position |  | Date of initial appointment
Aristóteles Luiz Menezes Vasconcellos Drummond |  | Member |  | April 27, 1999
Marcus Eolo de Lamounier Bicalho |  | Substitute Member |  | February 27, 2003
Luiz Guarita Neto |  | Member |  | February 27, 2003
Ari Barcelos da Silva |  | Substitute Member |  | April 29, 2005
Thales de Souza Ramos Filho |  | Member |  | February 27, 2003
Aliomar Silva Lima |  | Substitute Member |  | February 27, 2003
Helton da Silva Soares (1) |  | Member |  | August 4, 2010
Vicente de Paulo Barros Pegoraro (2) |  | Member |  | April 29, 2009
Newton de Moura (2) |  | Substitute Member |  | April 29, 2009

(1) Elected by AGC Energia.

(2) Elected by the holders of the preferred shares.

Below is a brief biographical information about each member of our Fiscal Council:

Aristóteles Luiz Menezes Vasconcellos Drummond – Mr. Drummond is a professional who acts in the journalistic, public relations and business administration area. Since 1973, he has been a chief officer of Irad Assessoria e Consultoria Ltda., a company dedicated to assisting large companies with the management of their marketing budgets. Mr Drummond is a certified member of fiscal councils according to the Brazilian Institute of Corporate Governance (Instituto Brasileiro de Governança Corporativa - IBGC). Between 1987 and 1996, Mr. Drummond was a managment Chief Office of Light. He was the CEO of COGE - Comitê de Gestão Empresarial no Setor de Energia Elétrica (Business Managment Committee of Eletricty Industry).between 1994 and 1996. Between 1996 and 2003, Mr. Drummond was a member of the Eletronorte’s Board of Directors. Since 2006, Mr. Drummond has been a member of the Fiscal Council of Light S.A. and a member of CEMAT’s Board of Directors. Since 1999, Mr. Drummond has been a member of our Fiscal Council and, since 2004, he has also been a member of Cemig Distribution’s and Cemig Generation and Transmission’s Fiscal Councils.

Helton da Silva Soares – Mr. Soares holds an accounting degree and a Law degree from the Pontifical Catholic University of Minas Gerais (PUC-MG) and completed his MBA in Finance from the IBMEC (Belo Horizonte). Mr. Soares joined the Andrade Gutierrez Group in 1998, and since 2008, he has worked as an executive at Construtora Andrade Gutierrez S.A. Since 2010, Mr. Soares has been a member of our Fiscal Council and also a member of Cemig Distribution’s and Cemig Generation and Transmission’s Fiscal Council. Luiz Guaritá Neto – Mr. Guaritá Neto holds a degree in Civil Engineering from Faculdades Integradas de Uberaba in 1978, having completed the basic courses of Business Administration, O&M and Marketing from Getúlio Vargas Foundation in Rio de Janeiro. He was the Major of Uberaba from 1993 to 1996. From 2003 to 2010, Mr. Guaritá Neto served as the first substitute to Senator Eduardo Brandão de Azeredo. Mr. Guaritá Neto is a shareholder and chief officer of several companies. Since 2003 Mr. Guaritá Neto has been a member of our Fiscal Council and, since 2004, he has also been a member of Cemig Distribution’s and Cemig Generation and Transmission’s Fiscal Council.

Thales de Souza Ramos Filho – Mr. Ramos Filho holds a degree in Medicine from the Federal University of Juiz de Fora (UFMG) and a Business Administration degree from Machado Sobrinho College, of Juiz de Fora. He is a chief officer of Hospital Dr. João Felício, a hospital located in the city of Juiz de Fora, in the state of Minas Gerais. He is also a shareholder and chief officer of

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Zenite Empreendimentos Imobiliários. Mr. Ramos Filho was a member of Furnas’ Board of Directors between 1990 and 1996 Since 2003, Mr. Ramos Filho has been a member of our Fiscal Council and, since 2004, he is also a member of Cemig Distribution’s and Cemig Generation and Transmission’s Fiscal Council.

Vicente de Paulo Barros Pegoraro – Mr. Pegoraro holds a Business Administration degree and Accountting degree from Brasília University (UnB) and a Law degree from the Federal University of Paraná. Mr. Pegoraro was a member of the Fiscal Council of Banco do Brasil S.A. from 2001 to 2003 and a member of the Fiscal Council and an Audit Committee member of Telecom Italia Mobile (Tim Participações S.A.) - TIM. Since 2009, Mr. Pegoraro has been a member of our Fiscal Council and of the Fiscal Council of Cemig Distribution and Cemig Generation and Transmission.

Consumer Council

We have established a Consumer Council pursuant to Brazilian law, which is comprised of representatives of consumer groups and advocacy organizations, but not members of our Board of Directors. The Consumer Council advises us as to service and other concerns of our consumers.

Audit Committee

Our Fiscal Council acts as our audit committee for purposes of the Sarbanes-Oxley Act of 2002. Under Section 10A-3 of the SEC rules on Audit Committees of listed companies, non-U.S. issuers are permitted not to have a separate Audit Committee made up of independent members if there is a Fiscal Council established and chosen in accordance with the legal rules of its origin country, expressly requiring or allowing that such council follow certain obligations. Also in accordance with this exemption, a Fiscal Council may exercise the obligations and responsibilities of an Audit Committee of the United States up to the limit permitted by Brazilian Law. The financial experts of our Fiscal Council are Helton da Silva Soares and Ari Barcelos da Silva.

Employees

As of December 31, 2012 we had 8,368 employees at CEMIG, Cemig Distribution and Cemig Generation and Transmission, of which 230 were at management level, and we had an average of 488 temporary employees in 2012. As of December 31, 2011, we had 8,706 employees at CEMIG, Cemig Distribution and Cemig Generation and Transmission, of which 238 were at management level, and we had an average of 350 temporary employees in 2011. As of December 31, 2010, we had 8,859 employees, of which 239 were at management level, and we had an average of 452 temporary employees in 2010. This table shows the breakdown of our employees by type on those dates:

|  | Number of Employees at
|  | December 31, 2012 |  | December 31, 2011 |  | December 31, 2010
Managers |  | 230 |  | 238 |  | 239
Professional staff |  | 1,215 |  | 1,249 |  | 1,281
Operational technical staff and office employees |  | 6,923 |  | 7,219 |  | 7,339
Total |  | 8,368(1) |  | 8,706(1) |  | 8,859(1)

(1) These numbers reflect only those employees of Cemig Generation and Transmission, Cemig Distribution and CEMIG.

In 2012, 4 employees were hired and 341 employees left our Company.

Unions

Annual meetings are held for collective negotiation with the unions that represent the employees. The Collective Work Agreement that results from this includes salary adjustments, benefits, and rights and duties governing employment relationships, and comes into effect for the subsequent period of 12 months, starting on November 1 of each year.

In 2012, due to the changes in the regulations of the electricity sector, with the potential to cause significant changes in Cemig’s results, the negotiations between us and the unions for the 2012/2013 Collective Work Agreement were frustrated, preventing an agreement from being reached between the parties as of the date of this form 20-F. At present the Regional Employment Appeals Court (“TRT”) of Minas Gerais is mediating the negotiation of the agreement. As a gesture of good faith the Cemig increased salaries on the base-date (November 2012), in accordance with the index that it had proposed, prior to any decision from TRT. We increased salaries with the intention of reducing the effects of a possible lengthy negotiation, which might have been detrimental to our employees. In the event of a change in the salary adjustment index after completion of the negotiation process, the difference in wages will be paid retroactively.

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In December 2011, after negotiations with the unions, the Collective Work Agreement was signed with 13 union entities, comprising a salary adjustment of 8.2%, benefits, rights and duties, valid for the period between November 1, 2011 to October 31, 2012. In addition, another collective agreement governing specifically profit sharing (“PLR”) was also signed for the payment of sharing in profit and results, valid for two years, obeying the targets agreed between us and our employees, as detailed below.

In 2011, during the negotiations to reach agreement on the Collective Work Agreement and the specific collective agreement, there were five intermittent days of stoppages by the employees. The Operational Emergency Committee, created for the basic purpose of establishing a Contingency Plan for maintaining the Company’s essential services in the event of strikes, was activated and there were no adverse events.

In December 2010, two collective agreements with the same general terms were entered into with 17 unions, which established wage increases ranging between 6.50% and 7.55%, according to the salary level of each employee. In addition to these agreements, an amendment regarding the distribution of profits and economic results was agreed to with respect to the specific PLR, for a single one-time extraordinary distribution, paid in April 2011, equivalent to 2.64 times each employee’s monthly remuneration.

Remuneration

The Careers and Remuneration Plan (PCR) was put in place in 2004, aiming to provide us with instruments of remuneration deemed necessary for maintaining an equitable and competitive payment structure and establishing criteria for promotions. An internal committee, with representatives of both our Company and the unions, was created for the implementation of such plan.The criteria for concession of career advancement include the employee’s performance, among other factors. In the 2011-2012 cycle of Performance Management, 2,387 employees, or 28% of all the employees evaluated, benefited from individual salary alterations.

Remuneration surveys are carried out annually to adapt the salaries of the employees to the market context. The results of the most recent survey, held in May 2012, indicated that approximately 93% of the employees are remunerated above the market average.

This table shows the average of Base Salary and of Remuneration, per month, by functional category:

| Average Base Salary as of December 31, 2012 | Average Remuneration as of December 31, 2012
Managers | R$13,863.31 | R$22,622.11
Professional staff | R$7,254.69 | R$10,100.33
Operational technical staff and office employees | R$3,293.08 | R$5,328.04

Program for Sharing in Profit, Results, and Productivity: In 1995, CEMIG established a profit sharing program for the employees in accordance with the applicable Brazilian employment legislation. Under the program, in a single business year CEMIG may not contribute more than 25% of the total of the proposed dividends for the business year to the profit sharing program.

With respect to the results for 2012, the amount to be received by our employees as profit sharing can vary between 70% and 120% of the remuneration multiple attributed to their work category, depending on the extent the targets established by us are being met. No profit sharing payment will, however, be made to any employee who does not reach the minimum level of 70% of the established targets.

In 2012 we anticipated the payment of part of the profit shares to employees for 2012 of approximately R$138.5 million, with the remaining portion scheduled to be paid by April, 2013. In 2011 the payment of profit shares to the employees, including the obligatory charges and payments based on payroll, totaled approximately R$221 million, with 70%, or R$155 million, being paid in December 2011 and the remaining 30%, or R$66 million, scheduled to be paid in April 2012. In 2010, the payment of employees’ profit shares, including the obligatory charges and payments based on payroll, totaled R$325 million, and the payment was made in December 2010 and in March 2011.

Benefits

As of January 1, 2003, we implemented changes to our existing employee health care plans. The changes are a result of an agreement we entered into with our employees’ labor unions, most of which are represented by Sindieletro. The changes modified the contributions that we, our employees and our retirees are responsible for and the types of benefits covered by each plan. In 2012, a total of R$208 million was paid in benefits to employees, consisting of R$72 million in pension plan contributions and R$136 million in assistance benefits.

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Voluntary Retirement Program

We operated the PPD Voluntary Retirement Program (Programa Prêmio de Desligamento), from 2008 through to October 2011. That program was replaced by the first Incentive Retirement Program (Programa de Desligamento Premiado), or PDP, which we operated from October 2011 to January 2013. The financial incentives of the PDP program were (i) payment of up to four times the employee’s gross monthly remuneration (ii) payment of six months of contributions to our health benefit plan after leaving the Company, (iii) deposit of an extra payment of 40% of the balance of the employee’s accumulated funds under the Unemployment Guarantee Fund (Fundo de Garantia por Tempo de Serviço), or FGTS, system (which would be obligatory if termination were to be made by the employer), and (iv) payment of up to 24 months of contributions to our pension fund and the Brazilian National Social Security Institute (Instituto Nacional de Seguridade Social), or INSS after termination of the contract, in accordance with certain criteria established in the PDP program. In 2013, 122 employees accepted the terms of our PDP program compared to 283 employees in 2012 and 51 employees in 2011 (49 of which accepted the terms of our PPD Voluntary Retirement Program).

Voluntary Dismissal Program

In April 2009, CEMIG implemented a Voluntary Dismissal Program, or PDV, which remained in effect until 2010, setting rules and conditions applicable to free and voluntary termination of employment contracts by employees, and also establishing the criteria applicable to employees who met certain retirement requirements. Employees who subscribed to the PDV received a financial incentive varying between three and 16 times their monthly remuneration, according to criteria established in the program’s regulations, the principal one being the time of contribution remaining for full retirement entitlement under the National Social Security Institute (Instituto Nacional de Seguridade Social), or INSS. The incentive included payment of the contributions to the pension fund and the INSS\ up to the date when the employee would have complied with the requirements for applying for retirement benefit under the INSS (limited to five years), and deposit of the obligatory “penalty” payment (applicable to dismissals without cause) of 40% on the balance of the employee’s accumulated funds under the Unemployment Guarantee Fund (Fundo de Garantia por Tempo de Serviço), or FGTS, system. Additionally, CEMIG guaranteed full payment of the costs of the group life insurance plan for six months, and of the health plan for twelve months, commencing on the date the employee leaves the Company.

In January 2013, we introduced a new retirement incentive program (Programa Incentivado de Desligamento), or PID, to which our employees may subscribe to by March 27, 2013. On March 27, 2013, a total of 1,071 employees (the application of 346 of which are still under analysis) had subscribed to the plan. This plan was launched in response to the regulatory changes in the energy sector, and is targeted at employees who fully qualifys for retirement in or would fully qualify for retirement during 2013.

In order to be eligible for our PID program, employees must have over 20 years (i) of employment at Cemig and (ii) of contributions to Forluz. Employees must already be retired per the INSS or prove that they will be retired and be able to claim their benefits under Forluz by December 31, 2013. Employees that subscribe to the PID will receive (i) four times their monthly salaries (exempt from income tax) and (i) a deposit of the obligatory “penalty” (applicable to dismissals without cause) of 40% on the balance of the employee’s accumulated funds under the FGTS, system. Employees must agree that they have no other rights to retirement benefits based on their employment with us. Additionally, Cemig guaranteed full payment of the costs of the group life insurance plan and of the health plan for six months commencing on the date the employee leaves the Company.

Health and Safety

In 2012, our index of frequency of accidents causing absence from work (Taxa de Frequência de Acidentes) was reduced by 30.15% from 2011, our best result in the last 10 years. This decrease was the result of a slight reduction in accidents to our own employees and a significant reduction in accidents to third party contractors.

The accidents causing absence from work mostly related to traffic accidents, failures in planning and incomplete preliminary risk analyses.

Share Ownership

Each of our directors and executive officers beneficially owns less than 0.001% of our preferred shares and less than 0.003% of our common shares.

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Item 7. Major Shareholders and Related Party Transactions

Principal Shareholders

As of December 31, 2012, the State Government owned, directly or indirectly, 190,041,861 common shares, or 50.97% of our outstanding voting stock, and 8,821,839 preferred shares, or approximately 1.84% of those outstanding. As of the same date, AGC Energia, our second largest shareholder, owned 122,901,990 common shares, or approximately 32.96% of those outstanding. AGC Energia is a subsidiary of Andrade Gutierrez Concessões S.A. (“AGC”), an AG Group affiliated. AG Group is one of the largest private groups in Latin America, with a presence in the engineering, construction, telecommunications, energy and public grants sectors. Our principal shareholders do not have different voting rights with respect to the shares they own.

The following table sets forth certain information regarding the ownership of our outstanding common shares and preferred shares at December 31, 2012.

Shareholder |  | Common Shares |  | % of Class |  | Preferred Shares |  | % of Class
State Government (1) |  | 190,041,861 |  | 50.97% |  | 8,821,839 |  | 1.84%
AGC Energia S.A. |  | 122,901,990 |  | 32.96% |  | --- |  | ---
All directors and executive officers as a group |  | 2,909 |  | --- |  | 1,822 |  | ---
Other |  | 59,890,325 |  | 16.06% |  | 470,993,832 |  | 98.09%
Total of outstanding shares |  | 372,837,085 |  | 100% |  | 479,817,493 |  | 99.92%
Treasury shares |  |  |  | --- |  | 363,650 |  | 0.08%
Total of authorized and issued shares |  | 372,837,085 |  | 100% |  | 480,181,143 |  | 100%

_______________________

(1) The shares in this line item attributed to the State Government include shares held by MGI, other State Government agencies and state-controlled companies.

Since our incorporation, our operations have been influenced by the fact that the State Government controls us. Our operations have had and will continue to have an important impact on the development of business and industry in Minas Gerais and on social conditions in the state. The State Government has from time to time in the past directed us to engage in certain activities and make certain expenditures designed primarily to promote the social, political or economic goals of the State Government and not necessarily designed with a view to our profitability, and it may direct us to do so in the future. See, “Item 3. Key Information—Risk Factors—Risks Relating to CEMIG—We are controlled by the State Government.”

As of December 31, 2012, we had 37 common shareholders of record in the United States, holding a total of 4,208,837 common shares. We also had 297 preferred shareholders of record in the United States, holding a total of 208,914,524 preferred shares. These numbers do not include the 183,612,259 preferred shares and 878,614 common shares converted into ADRs.

Although our by-laws do not provide any restrictions concerning a change in our control, a state law authorizing a change of control would be required for a change of control to take place. Because we are a state-controlled company, the sale of more than 50% of the voting stock of CEMIG by the State Government (or any other transaction that may transfer the control of the company, either totally or partially) requires the passage of specific authorizing legislation by the legislature of Minas Gerais, approved by at least 60% of the members of the State Assembly. The aforementioned authorization must also be approved by local citizens in a referendum.

On December 17, 2009, BlackRock, Inc., as investment manager on behalf of some of its consumers, notified that as a result of the merger between BlackRock and Barclays Global Investors, on December 1, 2009, it has achieved the total of 12,410,905 preferred shares and 20,411,225 American Depositary Receipts (“ADRs”) for preferred shares, representing a total of approximately 9.39% of the total preferred shares in CEMIG. Blackrock Inc. has notified that the objective of the above-mentioned stockholdings is strictly for investment purposes, and it has no intention of altering the stockholding control or management structure of the Company. In addition, it has also notified that it holds no debentures issued by CEMIG that are convertible into shares, and that no agreements have been entered into by BlackRock that regulate the exercise of the right to vote or the purchase or sale of securities issued by CEMIG.

On April 15, 2010, Lazard Asset Management LLC notified us that it has acquired 17,497,213 shares, or 5.01% of the total of the shares issued by CEMIG. On February 4, 2011, Lazard Asset Management LLC notified us that it increased its interest in CEMIG to 7.46%, representing a total of 28,673,232 shares.

On June 18, 2010, AGC Energia notified that a share transfer occurred pursuant to a share purchase and sale agreement signed between Southern and AGC Energia, with AGC as the consenting party, dated November 12, 2009. AGC Energia acquired from Southern 98,321,592 common shares of CEMIG, representing 32.96% of the voting stock and 14.41% of the total capital. AGC

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Energia emphasizes that such transaction does not change the structure of the stockholding control, nor the management structure, of CEMIG.

On August 1, 2011, AGC Energia and the State of Minas Gerais entered into a shareholders’ agreement (acknowledged by CEMIG and with BNDESPar as a third-party beneficiary), pursuant to which AGC Energia has the right, among others, to nominate our Chief Officer of Business Development, subject to approval by the State of Minas Gerais. For more information, see Note 23 to our consolidated financial statements.

On January 20, 2012, Lazard Asset Management LLC notified us that it holds 28,266,233 shares, or 4.14% of our outstanding shares.

We are not aware of any other significant changes in the percentage ownership of any shareholders that held 5% or more of our outstanding voting shares during the past three years.

Related Party Transactions

We are party to the following related-party transactions:

· Our agreement with the State Government with respect to the CRC Account and related financial income and provision for loss and VAT advance payments, expenses, assets and liabilities;

· Our agreement with Forluz, the entity responsible for managing our employee pension fund, pertaining to the fund and related balances; and

· Our agreement with COPASA, a Minas Gerais state-controlled company, related to accounts receivable from energy sales.

· Our agreement with Construtora Andrade Gutierrez S.A for construction of the Santo Antônio Hydroelectric Plant, and, for its transmission facilities.

· Our agreement with Iluminas Consortium, of which Andrade Gutierrez is a member, to implement one lot of the Light for Everyone (Luz Para Todos) rural electrification program.

For a more detailed discussion of these and other related party transactions, see Notes 9, 12, 18, 19, 21, 24 and 25 to our consolidated financial statements.

Item 8. Financial Information

Consolidated Financial Statements and Other Financial Information

Please refer to our financial statements that appear beginning on page F-1 of this document as well as “Item 3. Key Information—Selected Consolidated Financial Data.”

Legal Proceedings

We are a party to certain administrative and court proceedings involving tax, regulatory, consumer, administrative, environmental and other liabilities relating to our business. In accordance with IFRS, we record and disclose the aggregate amounts of the proceedings that we have determined a loss to “probable”, and disclose the aggregate amounts of the proceedings that we have determined a loss to be “possible”; – in both cases, to the extent these amounts can be reasonably estimated. For more information regarding such contingencies, see Notes to our consolidated financial statements.

Regulatory Matters

Prior to 1993 Brazilian electricity concession holders were guaranteed, by law, a rate of return on investment in assets used in the provision of electricity services to clients. Rates charged to users were uniform all over the country, and the profits generated by the more profitable concession holders were reallocated to less profitable concession holders, in such a way that the rate of return of all the companies was equal to the national average. The deficits which the majority of the Brazilian electricity concession holders suffered were accounted in the “CRC Account” of each company. When the CRC Account and the guaranteed-return concept were abolished, Cemig used its positive balances in the CRC Account to offset its liabilities to the Federal Government.

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Aneel filed an administrative action against us, contesting a credit relating to those positive balances and on October 31, 2002, issued a final administrative decision. On January 9, 2004, the Office of the National Treasury issued a collection notice in the amount of R$516.2 million, to be settled by us on or before January 30, 2004. We filed a writ for an order of mandamus to challange the legality of the collection and to suspend inclusion of the credit in the register of debtors delinquent on credits to the federal government (Cadin). The mandamus was denied by the lower court, however an appeal was made to the Federal Court of the First Region, which granted us a temporary injunction suspending the inclusion of the credit in the Cadin. On December 11, 2012, the writ of mandamus and the appeal were dismissed with the approval of the agreement entered into on October 17, 2012, by and among the National Treasury and Cemig, to settle the collection in the amount of approximately R$403 million. For more information regarding such agreement, see Note 22 to our consolidated financial statements.

Cemig and Cemig Distribution are parties in several lawsuits seeking to nullify the clause in the Electricity Supply Contracts for public illumination, signed between us and the various municipalities in our concession area. The claim also seeks restitution of the difference representing the amounts charged in the last 20 years, in the event that the courts recognize that these amounts were unduly charged. The proceeding is based on an alleged mistake in estimating time used for the calculation of the consumption of electricity by public illumination paid for by the Public Illumination Contribution (CIP). On December 31, 2012, the amount involved in this action was, approximately, R$1.16 billion, and we have assessed the chances of loss as “possible”.

Cemig Generation and Transmission filed an application for an order of mandamus to be included as a defendant party in a lawsuit brought by AES Sul against Aneel, seeking the annulment of Aneel Dispatch 288/2002 which sets the guidelines for interpretation of Aneel Resolution 290/2000, and thus change the situation of AES Sul Distribuidora, from creditor to debtor of Mercado Atacadista de Energia (MAE), predecessor of CCEE. Our application to be joined as a defendant was based on the fact that if AES Sul were to be successful in this lawsuit and were found to be a creditor of CCEE, Cemig Generation and Transmission will have to pay the amount applied for by AES Sul. Cemig Generation and Transmission obtained an interim remedy to suspend the deposit that had been ordered in the process of financial settlement, for the historic amount, and was also admitted as a defendant party. As of December 31, 2012, the amount involved in this action was R$135.1 million, and we have assessed the chances of loss as “possible”.

Rate Increases

Cemig Distribution is a party, together with Aneel, in a civil public action brought by the Public Attorneys’ Office seeking to prevent the exclusion of consumers from being classified in the Low Income Residential Tariff’s subclass and also to require Cemig Distribution to pay double the amount overpaid by the low income consumers. The lower court found in favor of the Public Attorney’s Office, and Cemig Distribution and Aneel appealed to the Regional Federal Appeals Court (Tribunal Regional Federal). The decision of the appeals court on the proceeding has been pending since March 2008. On December 31, 2012, the amount involved in this action was, approximately, R$132.6 million, and we have assessed the chance of loss as “possible”.

Cemig Distribution is a defendant in a public civil action brought by the Municipal Association for Protection of the Consumer and the Environment (Associação Municipal de Proteção ao Consumidor e ao Meio Ambiente – Amprocom), which is challenging the tariff readjustment applied after 2002 and its methodology and seeking the restitution, to all consumers who were damaged in the processes of periodic review and annual adjustment of electricity tariffs in the period from 2002 to 2009, of the amounts that were allegedly unduly charged. On December 31, 2012, the amount involved in this action was R$158.4 million, and we have assessed the chances of loss as “possible”.

Taxes and Other Contributions

CEMIG and its subsidiaries are parties in several administrative and judicial tax-related proceedings concerning the imposition of state sales tax (Imposto Sobre a Circulação de Mercadorias e Serviços, or ICMS), rural real estate ownership tax (Imposto Sobre a Propriedade Territorial Rural, or ITR), contribution for social integration (Programa de Integração Social, or PIS), PASEP and COFINS (which are taxes on gross sales revenue), the Social Contribution on Net Profit (Contribuição Social Sobre o Lucro Líquido, or CSLL), and federal income tax (Imposto de Renda da Pessoa Jurídica, or IRPJ), among others.

In 2006, CEMIG, Cemig Generation and Transmission and Cemig Distribution advanced funds to some of their employees in exchange for their rights to future payments, referred to as the “Anuênio.” No income tax or social security contributions were collected in connection with those payments, since it is our opinion that they are not applicable. The Brazilian Federal Revenue Service, however, has initiated an administrative proceeding seeking to levy taxes on such payments. In order to avoid the risk of imposition of penalties, we filed two writs of mandamus which were decided unfavorably to us in the lower court. We filed the appropriate appeals and are still waiting for resolution from the upper court. On December 31, 2012, the amount involved in these actions was, approximately, R$204.3 million, and we have assessed the chance of loss as “possible”, in view of the indemnity nature of the advance payments made to the employees and the absence of specific case law in the upper court. We emphasize that, in

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relation to Income Tax, both the Superior Court of Justice (“STJ”) and the Regional Federal Court (“TRF”) adopt the position that there is tax levied on payments arising from the suppression of employees’ collective bargaining rights when agreed through a collective agreement, since such amounts are considered indemnities.

The INSS initiated an administrative proceeding against CEMIG in 2006 alleging non-payment of the social security contribution on the amounts paid to the Company’s employees and directors as profit shares in the period 2000 to 2004. In 2007, we filed a writ of mandamus seeking declaration that such profit-sharing payments were not subject to social security contributions. We received a partially favorable decision in 2008 only with regards to the contribution of social security payments subject to profit sharing for employees. We have appealed the decision and are waiting for the upper court to decide. On December 31, 2012, the amount involved in this action was approximately R$519 thousands, which relates only to the payment of social security contributions on profit sharing paid to directors, and we have assessed the chance of loss as “possible”.

We are party in some proceeding in connection with PIS and COFINS contributions. On December 31, 2012, the amount involved in these actions were, approximately, R$1.04 billion, of which R$1.02 billion are related to proceeding where we are a creditor and we have assessed the chances of loss as “possible”. If we do not succeed in these proceedings, there will be no disbursement of money, as the amount deposited will be converted into revenue for the Federal Government. The remaining R$0,02 billion are related to proceedings we have assessed the chances of loss as “remote” in which the plaintiffs demand suspension of pass-through of the PIS and COFINS contributions, on the grounds that the imposition of such contributions in the context of electricity invoices is illegal. Plaintiffs allege that they are entitled to the reimbursement of all such amounts, plus interest and restatement for inflation. Some of these legal proceedings seek reimbursement of 200% of the amount charged.

The Brazilian Federal Revenue Service has initiated several administrative proceedings against CEMIG, Cemig Generation and Transmission and Cemig Distribution, in relation to the social security contributions allegedly owed in connection with employee profit share payments, the Workers’ Food Program (PAT), the auxiliary contribution for education, overtime payments, risk exposure compensation payments, Sest/Senat, and compensation penalty payments. We have presented defenses and await judgment. On December 31, 2012, proceedings where we assessed the chances of loss as “possible” totaled, approximately, R$923 million, and proceedings where we assessed the chances of loss as “probable” totaled, approximately, R$1.4 million.

Cemig and Cemig Distribution are parties in various administrative and judicial proceedings filed by the State Tax Department of Minas Gerais, jointly with various consumers, in connection with charging ICMS matters. On December 31, 2012 proceedings where we assessed the chances of loss as “possible” totaled, approximately, R$356 million, and proceedings where we assessed the chances of loss as “probable” totaled, approximately, R$33.6 million. The principal procedings administrative and judicial proceedings filed by the State Tax Department of Minas Gerais are as described below.

Some of the issues discussed in these proceedings are related to the non-applicability of ICMS over unused portions of hired electricity availability. On December 31, 2012, proceedings where we assessed the chances of loss as “possible” totaled, approximately, R$37,2 million. We have requested exclusion from these proceedings, as it won’t be affected by the final decision, since it is not CEMIG who has the alleged obligation to pay the ICMS in these cases; we have been excluded from some of these proceedings.

Cemig and Cemig Distribution are also -parties in cases that discuss the impact of ICMS on TUSD. On December 31, 2012, proceedings where we assessed the chances of loss as “probable” totaled, approximately, R$6.8 million, and proceedings where we assessed the chances of loss as “possible” totaled, approximately, R$275.9 million.

Cemig and Cemig Distribution are parties, jointly with various consumers, in various administrative and court proceedings brought by the State Tax Department of Minas Gerais, claiming ICMS tax on the transfer of excess electricity in the period of rationing of electricity. Although we are only secondarily liable for such charges, unfavorable administrative decisions were rendered, considering the imposition of such tax as valid. The State of Minas Gerais has been carrying out tax foreclosures in relation to these charges, usually against the primary debtors. These claims, however, may be an obstacle for certification of tax clearance. We have filed lawsuits seeking preliminary injunctions to suspend these collection proceedings. On December 31, 2012, proceedings where we assessed the chances of loss as “probable” totaled, approximately, R$26.6 million, and proceedings where we assessed the chances of loss as “possible,” totaled, approximately, R$29.4 million.

Cemig Distribution is a defendant in a public consumer action brought by the Minas Gerais Consumer Defense Institute (Instituto Mineiro de Defesa do Consumidor, or IMIDEC) applying for a declaration that there is no legal relationship that obligates consumers to pay the rate of ICMS tax on electricity bills in the manner in which it is currently calculated. On December 31, 2012, the amount involved in this action was, approximately, R$74 million and we have assessed the chances of loss as “remote”.On February 14, 2013, Cemig received a favorable decision in the lower court.

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Cemig is a party in two lawsuits with regards to the Finsocial tax. On December 31, 2012, the total amount involved in these actions was approximately R$99.3 million, and we have assessed the chances of loss as “possible”. In January 2013, the assessment of the chances of loss in one of these actions, which represented R$ 73.7 million on December 31, 2012, was reclassified from “possible” to “remote”.

CEMIG, Cemig Generation and Transmission and Cemig Distribution are parties in several administrative proceedings the final decisions in which have refused offsetting of credits of IRPJ, CSLL, PIS and COFINS. We are contesting the related tax postings made by the federal tax authority. On December 31, 2012, the amount involved in these proceeding was, approximately, R$371 million, and we have assessed the chances of loss as “possible”.

CEMIG is a party in judicial proceeding concerning applications for restitution and offsetting of tax credits for the corporate tax returns for 1997 to 2000, and overpayments shown in the corresponding tax receipts and tax returns filed. On December 31, 2012, the amount involved in this judicial proceeding was approximately R$337.2 million, and we have assessed the chances of loss as “possible”.

Additionally, our subsidiary Light is party in several administrative and judicial tax-related proceedings concerning the imposition of ICMS, CSLL and IRPJ among others. On December 31, 2012, the amount involved in these proceedings with chances of loss assessed as “probable” totaled, approximately, R$64 million, and proceedings where we assessed the chances of loss as “possible” totaled, approximately, R$1.06 billion (proportionally to the percentage of our ownership interest in Light).

Labor Obligations

CEMIG, Cemig Generation and Transmission and Cemig Distribution are defendants in several claims filed by employees and outsourced workers. Most of these claims relate to overtime and compensation for occupational hazards. In addition to these actions, there are others relating to outsourcing of labor, readjustment of retirement pension payments by Forluz, and salary adjustments. Under Brazilian employment laws, claimants must file any claim for unpaid services whithin two years after the termination of the contract (limited to rights which arose no more than five years prior to the claim). On December 31, 2012, proceedings where we assessed the chances of loss as “probable” totaled, approximately, R$80 million, and proceedings where we assessed the chances of loss as “possible” totaled, approximately, R$259 million.

In June 2007 a judgment was rendered against Cemig in a public civil action, brought by the Public Attorneys’ Office for Employment Matters in early 2003, to prevent the Company from using outsourced labor for its end-activities. The judgment gave the Company nine months to cease to contract employees through outsourced companies as intermediaries. In March 2008 the Higher Appeals Court gave an interim decision suspending the effects of the previous judgment until a final decision had been given. In October 2012, Higher Appeals Court reversed the judgment and the judgment of the Regional Labor Court absolving Cemig from paying moral damages and collective fines fixed. However, since the issue involves interpretation on the constitutionality of an article of the Concessions Law (Law 8987/95) there is a possibility of reversal of the decision in the Higher Appeals Court’s Employment Issies Session (Seção de Dissídios Individuais), as well as in the Federal Supreme Court (“STF”). On December 31, 2012, the amount involved in this action, in the event we do not comply with the order for specific performance, moral damages and fees was, approximately, R$55 million and we have assessed the chances of loss as “possible”. It should be added that the amount stated will be payable only upon reversal of the decision and if the Company does not comply with the order to replace outsourced labor within the specified period, of nine months. We believe it is unlikely that any payment obligations will be imposed.

Additionally, our subsidiary Light is a defendant in labor-related proceedings. On December 31, 2012, the amount involved in these proceedings with chances of loss assessed as “probable” totaled, approximately, R$58 million, and proceedings where we assessed the chances of loss as “possible” totaled, approximately, R$95 million (proportionally to the percentage of our ownership interest in Light).

Environmental Matters

CEMIG, Cemig Generation and Transmission, Southern Electric and FEAM are defendants in a public civil action filed on February 5, 2007 by the Regional Environmental Association of Patrocínio, which involves a claim for indemnifying and redressing environmental damages caused by the Nova Ponte Hydroelectric Power Plant. We have presented a defense and are awaiting judgement. As of December 31, 2012, the amount involved in this action was R$1.6 billion, and we assessed the chance of loss as “possible”.

The Minas Gerais Public Attorney filed seven class actions against CEMIG and Cemig Generation and Transmission seeking an order against the companies to invest at least 0.5% of its total operational revenue per year from 1997 onward, on the protection and environmental preservation of the water tables of the municipalities in which our generation plants are located and indemnify the States proportionaly for the environmental damage caused as a result of Cemig’s failure to comply with the law of the State of Minas

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Gerais No. 12.503/97. In three of these actions, judgment was granted partly in favor of the Public Attorneys’ Office of Minas Gerais, in the lower courts, with CEMIG and Cemig Generation and Transmission being ordered to invest 0.5% per year of the gross operational revenue since 1997 on measures for environmental preservation and protection of the water tables in Ouro Preto, Uberaba, Água Comprida, Campo Florido, Delta, Veríssimo and Araxá. We have filed an appeal with the STJ and the STF, since the actions involve Federal Law and constitutional matters. On December 31, 2012, the amount involved in these actions was R$94 million, and we assessed the chance of loss as “possible”.

We are party to another number of administrative and judicial proceedings and claims involving environmental matters, regarding certain protected areas, environmental licenses and remediation of environmental damages, among others. On December 31, 2012, the amount involved in these proceedings where we assessed the chance of loss as “probable” totaled, approximately, R$5.4 million, and where we assessed the chance of loss as “possible” (i.e. on the date of the financial statements an obligation was assessed as being more unlikely than likely) totaled, approximately, R$7.2 million. These proceedings also include several other public civil actions in which the amounts involved cannot be precisely assessed, in our view, most of these lawsuits are related to alleged environmental damages and require indemnity, remediation of damaged areas and compensation measures that will be defined in the course of the proceedings, often requiring the expertise to carry out verification of the values involved. Also, since public civil actions relate to collective rights, individual actions may be filed seeking reparations or damages arising from judicial decisions to be issued under the these civil suits.

Property and liability

CEMIG, Cemig Generation and Transmission and Cemig Distribution are party in several administrative and judicial proceedings and claims, mainly as a defendant, relating to real property and indemnification due to accidents taking place in the ordinary course of the business. On December 31, 2012, proceedings where we assessed the chances of loss as “probable” (i.e. for which on the date of the financial statements an obligation were assessed as being more likely than not) totaled, approximately, R$50.4 million, and proceedings where we assessed the chances of loss as “possible” (i.e. on the date of the financial statements an obligation was assessed as being more unlikely than likely) totaled, approximately, R$79.1 million.

Additionally, Cemig Distribution is a defendant in four legal actions in which the plaintiffs seek indemnity for pain and suffering and property damages related to the accident that took place on February 27, 2011, in the town of Bandeira do Sul, which resulted from coiled metal carnival decorations being thrown over electricity distribution cables, causing a short-circuit which severed medium-voltage cables and resulted, when the cables hit the ground, in the death of 16 people, with dozens of other people injured. The legal actions filed involve 29 family members of 14 of the people who died and 2 that were injuried. In spite of the fact that the accident did not arise from any action or position taken by the Company, on December 31, 2012, we have assessed the chances of loss in two of the actions as “probable” (i.e. for which on the date of the financial statements an obligation were assessed as being more likely than not) and the amount involved totaled, approximately, R$4.9 million. On December 31, 2012, the amount involved in the two other actions was approximately R$1.0 million, and we have assessed the chances of loss as “possible” (i.e. on the date of the financial statements an obligation was assessed as being more unlikely than likely). The greater significance of these actions for CEMIG is not related to their financial impacts, but to the negative exposure of the Company’s image, since the accident was widely publicized by the media.

Consumer claims

Cemig Distribution is a defendant in several administrative and judicial proceedings, on subjects related to the provision of electricity distribution service in actions brought by consumers, by the Federal Public Attorneys’ Office and by other consumer defense bodies, with claims varying from finding of irregularities in consumer electricity consumption metering to disconnection for lack of payment of bills, to arrangements to pay bills by installment, indemnity for pain and suffering and property damages due to accidental disconnections, indemnity for material damages arising from burns by domestic electrical appliances and others. On December 31, 2012, the amount involved in these proceedings where we assessed the chance of loss as “probable” (i.e. for which on the date of the financial statements an obligation were assessed as being more likely than not) totaled, approximately, R$66 million, and where we assessed the chances of loss as “possible” (i.e. on the date of the financial statements an obligation was assessed as being more unlikely than likely) totaled, approximately, R$30 million.

Claims in the Ordinary Course of Business

Additionally, our subsidiary Light is party to several administrative and judicial proceedings and claims in the ordinary course of business, mainly as a defendant. On December 31, 2012, the amount involved in these proceedings where we assessed the chances of loss as “probable” (i.e. for which on the date of the financial statements an obligation was assessed as being more likely than not) totaled, approximately, R$60 million, and proceedings where we assessed the chances of loss as “possible,” (i.e. on the date of the financial statements an obligation was assessed as being more unlikely than likely) totaled, approximately, R$67 million (proportionally to the percentage of our ownership interest in Light).

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Dividend Policy and Payments

Obligatory Dividend—Priority and Amount of Dividends

Under our by-laws, we are required to pay to our shareholders, as obligatory dividends, 50% of the net income of each fiscal year ending December 31, determined in accordance with IFRS. Our preferred shares have priority in the allocation of the obligatory dividend for the period in question. The order of priority of the dividends distribution is as follows:

· The annual minimum dividend for the preferred shares: These have preference in the event of reimbursement of shares, and have an annual minimum dividend equal to the greater of the following:

· 10% of their par value; or

· 3% of the shareholders’ equity associated with it.

· The dividends on the common shares, up to the minimum percentage for the preferred shares.

If a portion of the obligatory dividend remains after the payment of the common dividend, the remaining funds are to be distributed on an equal, pro rata basis with respect to all preferred shares and common shares.

Without prejudice to the obligatory dividend, beginning in fiscal year 2005, every two years, or shorter period if the Company’s cash position permits, we will distribute extraordinary dividends, up to the limit of the cash available, as determined by the Board of Directors, under the Company’s Strategic Guidelines Plan and the dividend policy specified in that plan.

The annual dividends declared shall be paid in two equal installments, the first by June 30 and the second by December 30 of each year. The extraordinary dividends shall be paid as decided by the Board of Directors.

Under the Brazilian Corporate Law, the Board of Directors may declare interim dividends, in the form of interest on capital, to be paid from retained earnings, income reserves or income reported in semi-annual or quarterly financial statements. Any interim dividend paid may be set off against the amount of the obligatory dividend payable for the fiscal year in which the interim dividend was paid.

In the fiscal years in which we do not have sufficient income to pay dividends to our preferred and common shareholders, the State of Minas Gerais guarantees a minimum dividend of 6% of the par value of the preferred or common shares, respectively, per year to all shares of the Company issued up to August 5, 2004 and held by individuals.

Amounts Available for Distribution

The amount available for distribution is calculated on the basis of the financial statements prepared in accordance with accounting practices adopted in Brazil and the procedures described below.

The obligatory dividend is calculated on the basis of adjusted net income, defined as net income after addition or subtraction of: (a) amounts allocated to the legal reserve, (b) amounts allocated to the formation of the contingency reserves and reversal of these reserves formed in previous fiscal years, and (c) any unrealized income transferred to the unrealized income reserve account, and any amounts previously posted to this reserve account which have been realized in the fiscal year and used to offset losses.

We are obliged to maintain a legal reserve, to which 5% of the net income of each fiscal year must be allocated until the reserve’s total value is equal to 20% of the Company’s total paid-in capital. However, we are not obliged to make any allocation to the legal reserve in relation to any fiscal year in which the sum of the legal reserve and the other established capital reserves exceeds 30% of the Company’s total paid-in capital. Any net losses may be charged against the legal reserve.

Under the Brazilian Corporate Law, income in subsidiaries or affiliated companies reported by the equity method, and income on term sales, realizable after the end of the next fiscal year, are also considered to be unrealized income.

The total of income reserves (with the exception of the reserve for contingencies relating to expected losses and the unrealized income reserve), the legal reserve, the special reserves, the reserve for investment projects, and retained earnings may not

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be greater than the Company’s registered capital. The amount in excess of our registered capital must be used to increase our registered capital or be distributed as cash dividends.

Under the Brazilian Corporate Law and our by-laws, dividends not claimed within three years from the date on which they are distributed revert to us.

Interest on Capital

Under Brazilian law we may pay interest on capital as an alternative for the distribution of dividends to shareholders. Funds distributed as interest on equity qualify within the calculation of minimum dividend established in the by-laws. These amounts may be paid in cash; and the Company may treat them as an expense for purposes of the calculation of the income tax and social contribution. The total amount paid in interest on capital is limited to the result of application to the Company’s shareholders’ equity of the Long Term Interest Rate (TJLP), published by BNDES and may not exceed the greater of (i) 50% of the net income (before taxes for social contribution on net profits, income tax, and the deduction of the interest attributable to shareholders’ equity) for the period in respect of which the payment is made or (ii) 50% of retained earnings as of the date of the beginning of the period in respect of which the payment is made. Shareholders who are not resident in Brazil must register with the Brazilian Central Bank so that the foreign currency proceeds of their dividend, interest on equity payments, or of sale or other amounts relating to their shares, may be remitted to them outside Brazil. The preferred shares underlying our Preferred ADSs and the common shares underlying our Common ADSs are held in Brazil by the custodian bank, as agent for the depositary bank, which is the registered owner of the shares.

Currency Exchange

Payments of cash dividends and distributions, if any, will be made in reais to the custodian on behalf of the depositary bank, which will then convert such proceeds into U.S. dollars and will cause such U.S. dollars to be delivered to the depositary bank for distribution to holders of ADRs. In the event that the custodian is unable to immediately convert the reais received as dividends into U.S. dollars, the amount of U.S. dollars payable to holders of ADRs may be adversely affected by devaluations of the real that occur before such dividends are converted and remitted. The real depreciated approximately 9.93% relative to the U.S. dollar in 2012. See “Item 3. Key Information—Risk Factors—Risks Relating to Brazil— The Federal Government exercises significant influence on the Brazilian economy. Political and economic conditions can have a direct impact on our business.”

Dividends in respect of the preferred shares and common shares paid to holders who are not Brazilian residents, including holders of Preferred ADSs and Common ADSs, are generally not subject to Brazilian withholding tax, although in general payments of interest on capital are subject to withholding tax. See “Item 10. Additional Information—Taxation—Brazilian Tax Considerations—Taxation of Dividends” and “—U.S. Tax Considerations—Taxation of Distributions.” There is no specific record date upon which the depositary bank will determine the exchange rate to be used in connection with converting cash dividends or other cash distributions. Pursuant to the Deposit Agreements, the depositary bank will arrange for the funds to be converted into U.S. dollars upon receipt of notice of cash dividends or other cash distributions.

History of Dividend Payments

The following table sets forth the recent history of declarations of dividends and interest on capital on our common shares and preferred shares. For each year in the table, the payment of the dividends occurred during the year following declaration. For the periods indicated, the dividends paid per common share and per preferred share were the same. See “Item 3. Key Information—Selected Consolidated Financial Data.”

Declaration History of Dividends and Interest on Capital (1)

Dividend Year |  | Common Shares |  | Preferred Shares
|  | (R$)(2) |  | (US$)(3) |  | (R$)(2) |  | (US$)(3)
2010 |  | 493,480,655 |  | 313,659,604 |  | 635,507,345 |  | 403,932,718
2011 |  | 894,679,142 |  | 491,096,246 |  | 1,151,394,858 |  | 632,009,473
2012(4) |  | 1,275,989,756 |  | 635,611,335 |  | 1,642,117,243 |  | 817,991,154

___________________

(1) In accordance with the accounting practices adopted in Brazil, dividends and interest on capital are accounted in the dividend year in which they are proposed, if such dividends or interest on capital were formally approved by a shareholders’ meeting in the following year.

(2) Real amounts are expressed in nominal reais.

(3) U.S. dollar amounts are calculated by dividing the amount of dividends paid, expressed in nominal reais, by the Federal Reserve Board’s rate on respective Record Dates (April 29, 2011, April 27, 2012 and April 30, 2013).

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(4) The 2012 dividends were approved at the ordinary and special general shareholders’ meetings held on April 19, 2013. The 2012 dividends will be paid in two equal installments in June 2013 and December 2013.

Significant Changes

Subsequent events:

a) Issue of Debentures by Cemig Distribution

In March 2013 Cemig Dintribution concluded its third public issuance of debentures by issuing 2,160,000 unsecured, non-convertible debentures, in three series, with a nominal unit value of R$1,000 on the issue date (February 15, 2013), for a total of R$2.16 billion. The net proceeds from the issuance were used to fully redeem the commercial Promissory Notes of Cemig Distribution’s fifth and sixth issuances, placed on January 13, 2012, for their total nominal value plus interest to be paid, and for investments in distribution infrastructure. Cemig Distribution issued 410,817 debentures of the first series, 1,095,508 debenture of the second series and 653,675 debentures of the third series, with maturities of 5, 8 and 12 years, respectively, from the issue date. The debentures of the first series will pay interest equal to the CDI rate plus 0.69%, debentures of the second and third series will have their nominal value updated by the IPCA, published by the Brazilian Geography and Statistics Institute (Instituto Brasileiro de Geografia e Estatística – IBGE), and will pay interest at 4.70% and 5.10% per year, respectively. The controlling stockholder, Cemig, provided a surety guarantee for the 3rd debenture issue by Cemig D.

On February 1, 2013 the Company issued a Bank Credit Note (CCD) in favor of Banco do Brasil, in the amount of R$200 million, of the proceeds of which are to be used in the purchase of electricity. The note has maturity of 721 days and annual interest of 99.5% of the CDI rate, secured by receivable of the Company’s sales invoices.

b) Transfer of control

Authorizing Resolution No. 3845 of January 15, 2013, published in federal Official Gazette No. 12 of January 17, 2013, authorized the stockholding restructuring of Taesa, the jointly-controlled subsidiary of Cemig Generation and Transmission, through absorption of STE and ATE into Unisa, and immediately subsequently absorption of NTE and Unisa into Taesa, resulting in the transfer of the respective concessions of the absorbed companies, and the transfer of control of ATE II and ATE III, held by Unisa, to Taesa. The holders of the concessions have 120 days to implement the transfers; 30 days after implementation, documention proving the transfer must be presented, and the parties have 60 days to sign the amendments to the related Concession Contracts affected by the authorized transactions.

c) Acquisition of the interest held by Suzano in the Capim Branco Energia Consortium

On March 12, 2013 Cemig Capim Branco, a wholly-owned subsidiary, signed the final contract with Suzano for the sale of Suzano’s interest in the Capim Branco Energia Consortium. The total price agreed, subject to any adjustments, for Suzano’s 17.8947% interest in the Consortium was R$ 320 million. Of this total, the percentage that pertains to Cemig Capim Branco, of 30.3030%, represents approximately R$97 million.

d) Approval of the Stockholding Restructuring with Taesa

Complementing the Material Announcement of May 17, 2012, on April 9, 2013, Aneel (National Electricity Agency) approved the transfer of stockholding control, to Transmissora Aliança de Energia Elétrica S.A. (Taesa), of the following companies holding electricity transmission concessions:

(1) Transfer of direct stockholding control:

Empresa Catarinense de Transmissão de Energia S.A. | – | ECTE,
Empresa Regional de Transmissão de Energia S.A. | – | ERTE,
Empresa Norte de Transmissão de Energia S.A. | – | ENTE,
Empresa Paraense de Transmissão de Energia S.A. | – | ETEP,
Empresa Amazonense de Transmissão de Energia S.A. – | EATE and
Empresa Brasileira de Transmissão de Energia S.A. | – | EBTE;

(ii) Transfer of indirect stockholding control (by Cemig and its wholly-owned subsidiary Cemig Geração e Transmissão S.A. – Cemig GT)

Sistema de Transmissão Catarinense S.A. | – | STC,

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Lumitrans – Companhia Transmissora de Energia, |  |
Empresa Santos Dumont de Energia S.A. | – | ESDE, and
Empresa de Transmissão Serrana | – | ETSE,

Final conclusion of the transfer of the assets in this Restructuring is still subject to consent from the financing banks, including in particular the Brazilian Development Bank (BNDES).

On the date of completion of the Restructuring, Taesa will disburse R$ 1.732 billion, updated by the CDI rate from December 31, 2011, less dividends and/or Interest on Equity already declared, whether already paid or not.

e) Result of the Third Tariff Review of Cemig D

At a public meeting held on April 5, 2013 the Brazilian electricity sector regulator, Aneel (Agência Nacional de Energia Elétrica), published the result of the Third Tariff Review of Cemig D (Cemig Distribuição S.A.), which will result in positive repositioning of Cemig D’s tariffs. These tariffs will take effect from April 8, 2013. The average effect for consumers will be an increase of 2.99%. This effect comprises one part reflecting the revision per se, and one part comprising the associated financial components.

In this decision, Aneel is already applying the effects of Decree 7945/12, which governs the use of the funds from the Energy Development Account (Conta de Desenvolvimento Energético, or CDE) to attenuate distributors’ costs of acquisition of electricity in the Electricity Trading Chamber (Câmara de Comercialização de Energia Elétrica, or CCEE) as a result of the unfavorable hydrological conditions, which have led to the dispatching of thermal generation plants, and as a result to reduce the impact of the tariff adjustment, limiting it to 3%. The amount that exceeds this percentage will be passed through in a single payment, within 10 business days from the date of publication of the Aneel Homologating Resolution. The amount of these funds coming from the CDE will be reimbursed by consumers in up to 5 years, updated by the IPCA inflation index.

According to the statement of calculation received by Cemig after the homologation of the result of the Tariff Review at the meeting of the Council of Aneel, the Net Regulatory Remuneration Base was R$ 5,512 million, and the Gross Regulatory Remuneration Base was R$ 15,356 million.

f) Increase of share capital of Cemig, with stock dividend

We hereby advise our stockholders that the Board of Directors, at its meeting held on March 26, 2013, decided to propose to the General Meeting of Stockholders to be held on April 30, 2013:

Approval of increase in the Share Capital, from R$ 4,265 million to R$ 4,813 million, through issuance of 109,654,157 new shares, each with par value of R$ 5.00 (five Reais), through capitalization of R$ 548 million from the Capital Reserve – Donations and Subsidies for Investments, with consequent distribution to the holders of preferred and common shares of a stock bonus of 12.85%, in new shares, of the same type as those held, each with par value of R$ 5.00 (five Reais).

All holders of shares on April 30, 2013 will be entitled to this benefit. The shares will trade “ex-” the right to the stock dividend on the day immediately following the date on which the said Meeting is held. The shares of the stock bonus will be credited on May 7, 2013 and will not have the right to the dividends proposed for the business year 2012.

Item 9. The Offer and Listing

Trading Market

The principal trading market for our preferred shares is the BM&FBovespa. Our Preferred ADSs, each representing one preferred share as of December 31, 2012, have traded on the NYSE under the symbol “CIG” since September 18, 2001. Prior to that date, our Preferred ADSs were traded in the over-the-counter, or OTC, market in the United States. The Preferred ADSs are evidenced by Preferred ADRs issued by Citibank, N.A., as depositary, pursuant to a Second Amended and Restated Deposit Agreement, dated as of August 10, 2001, as amended on June 11, 2007, by and among us, the depositary and the holders and beneficial owners of Preferred ADSs evidenced by Preferred ADRs issued thereunder. As of December 31, 2012, there were approximately 135,382,355 Preferred ADSs outstanding (each representing one preferred share), representing approximately 28.76% of our 470,993,832 outstanding preferred shares (Free Float).

The principal trading market for our common shares is the BM&FBovespa. Our Common ADSs, each representing one common share as of December 31, 2012, have traded on the NYSE under the symbol “CIG.C” since June 12, 2007, when we

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established an American Depositary Shares program for our common shares. The Common ADSs are evidenced by Common ADRs issued by Citibank, N.A., as depositary, pursuant to a Deposit Agreement, dated as of June 12, 2007, by and among us, the depositary and the holders and beneficial owners of Common ADSs evidenced by Common ADRs issued thereunder. As of December 31, 2012, there were approximately 1,059,917 Common ADSs outstanding (each representing one common share), representing 0.58% of our 182,792,315 outstanding common shares (Free Float).

On April 19, 2013, the closing price per preferred share on the BM&FBovespa was R$24.99 and the closing price per Preferred ADS on the NYSE was US$14.47.

On April 19, 2013, the closing price per common share on the BM&FBovespa was R$24.61 and the closing price per Common ADS on the NYSE was US$11.66.

The following table sets forth the reported high and low closing sale prices for the preferred and common shares on the BM&FBovespa and the Preferred and common ADSs on the NYSE for the periods indicated.

|  | Common Shares (1) |  | Common ADSs (1) |  | Preferred Shares(2) |  | Preferred ADSs (2)
Period |  | Price in Nominal R$ |  | Price in US$ |  | Price in Nominal R$ |  | Price in US$
|  | High |  | Low |  | High |  | Low |  | High |  | Low |  | High |  | Low
2008 |  | 11.69 |  | 7.34 |  | 12.84 |  | 6.08 |  | 15.27 |  | 9.65 |  | 16.16 |  | 7,91
2009 |  | 12.03 |  | 7.73 |  | 11.54 |  | 5.90 |  | 16.82 |  | 11.49 |  | 15.36 |  | 7.69
2010 |  | 12,29 |  | 9,97 |  | 10.99 |  | 7.72 |  | 17.06 |  | 13.72 |  | 14.22 |  | 10.24
2011 |  | 17.19 |  | 11.56 |  | 13.59 |  | 7.59 |  | 21.27 |  | 15.46 |  | 16.04 |  | 11.11
2012 |  | 29.19 |  | 16.99 |  | 17.20 |  | 10.48 |  | 33.94 |  | 19.27 |  | 20.08 |  | 10.80
2011 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
1Q |  | 13.91 |  | 11.56 |  | 10.56 |  | 9.32 |  | 18.51 |  | 15.46 |  | 14.16 |  | 12.16
2Q |  | 15.68 |  | 13.79 |  | 12.09 |  | 11.75 |  | 19.93 |  | 18.16 |  | 16.04 |  | 14.34
3Q |  | 15.74 |  | 13.22 |  | 12.61 |  | 7.90 |  | 19.86 |  | 16.73 |  | 15.96 |  | 11.34
4Q |  | 17.64 |  | 13.15 |  | 13.59 |  | 7.59 |  | 21.85 |  | 16.09 |  | 13.90 |  | 11.11
2012 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
1Q |  | 24.49 |  | 16.99 |  | 15.79 |  | 11.71 |  | 28.79 |  | 20.96 |  | 18.67 |  | 14.43
2Q |  | 28.65 |  | 24.14 |  | 17.17 |  | 11.88 |  | 32.78 |  | 28.77 |  | 20.08 |  | 16.89
3Q |  | 29.19 |  | 18.18 |  | 17.20 |  | 14.63 |  | 33.94 |  | 20.82 |  | 19.86 |  | 12.12
4Q |  | 21.90 |  | 18.00 |  | 12.74 |  | 10.48 |  | 23.00 |  | 19.27 |  | 12.87 |  | 10.80
2013 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
1Q |  | 22.74 |  | 20.90 |  | 11.35 |  | 10.30 |  | 23.68 |  | 20.61 |  | 11.87 |  | 10.17
November 2012 |  | 19.42 |  | 18.00 |  | 11.23 |  | 10.48 |  | 21.74 |  | 19.27 |  | 11.84 |  | 10.80
December 2012 |  | 21.90 |  | 18.46 |  | 12.74 |  | 10.53 |  | 21.90 |  | 18.46 |  | 12.87 |  | 10.80
January 2013 |  | 22.26 |  | 20.90 |  | 11.28 |  | 10.30 |  | 23.68 |  | 20.61 |  | 11.48 |  | 10.17
February 2013 |  | 22.74 |  | 21.00 |  | 11.35 |  | 10.57 |  | 23.54 |  | 21.70 |  | 11.87 |  | 11.01
March 2013 |  | 24.80 |  | 22.29 |  | 13.00 |  | 11.25 |  | 25.85 |  | 22.20 |  | 13.09 |  | 11.22
April 2013 (3) |  | 24.61 |  | 22.85 |  | 12.05 |  | 11.58 |  | 24.99 |  | 23.22 |  | 12.47 |  | 11.54

______________________

(1) On May 2, 2008, a 2.02% stock dividend was paid on the common shares, resulting in an adjustment to the price per common share. On May 8, 2008, a corresponding adjustment was made to the Common ADSs through the issuance of additional Common ADSs, resulting in an adjustment to the price per Common ADS. On April 29, 2009, a 25.00% stock dividend was paid on the common shares, resulting in an adjustment to the price per common share. On May 14, 2009, a corresponding adjustment was made to the Common ADSs through the issuance of additional Common ADS, resulting in an adjustment to the price per Common ADS. On April 29, 2010, a 10.00% stock dividend was paid on the common shares, resulting in an adjustment to the price per common share. On May 10, 2010, a corresponding adjustment was made to the Common ADSs through the issuance of additional Common ADS, resulting in an adjustment to the price per Common ADS. On April 30, 2012, a 25.00% stock dividend was paid on the common shares, resulting in an adjustment to the price per common share. On May 11, 2012, a corresponding adjustment was made to the Common ADSs through the issuance of additional Common ADSs, resulting in an adjustment to the price per Common ADS. On May 7, 2013, subject to the approval of the shareholders at the General Meeting to be held on April 30, 2013, a 12.85% stock dividend will be paid on the common shares, resulting in an adjustment to the price per common share. On May 14, 2013, subject to the approval of the shareholders at the General Meeting to be held on April 30, 2013, a corresponding adjustment will be made to the Common ADSs through the issuance

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of additional Common ADS, resulting in an adjustment to the price per Common ADS. The common share prices and Common ADS prices have been adjusted to reflect all of the above items.

(2) On May 2, 2008, a 2.02% stock dividend was paid on the preferred shares, resulting in an adjustment to the price per preferred share. On May 8, 2008, a corresponding adjustment was made to the Preferred ADSs through the issuance of additional Preferred ADS, resulting in an adjustment to the price per Preferred ADS. On April 29, 2009, a 25.00% stock dividend was paid on the preferred shares, resulting in an adjustment to the price per preferred share. On May 14, 2009, a corresponding adjustment was made to the Preferred ADSs through the issuance of additional Preferred ADS, resulting in an adjustment to the price per Preferred ADS. On April 29, 2010, a 10.00% stock dividend was paid on the preferred shares, resulting in an adjustment to the price per preferred share. On May 10, 2010, a corresponding adjustment was made to the Preferred ADSs through the issuance of additional Common ADS, resulting in an adjustment to the price per Common ADS. On April 30, 2012, a 25.00% stock dividend was paid on the preferred shares, resulting in an adjustment to the price per preferred share. On May 11, 2012, a corresponding adjustment was made to the Preferred ADSs through the issuance of additional Preferred ADSs, resulting in an adjustment to the price per Preferred ADS. On May 7, 2013, subject to the approval of the shareholders at the General Meeting to be held on April 30, 2013, a 12.85% stock dividend will be paid on the preferred shares, resulting in an adjustment to the price per preferred share. On May 14, 2013, subject to the approval of the shareholders at the General Meeting to be held on April 30, 2013, a corresponding adjustment will be made to the Preferred ADSs through the issuance of additional Preferred ADS, resulting in an adjustment to the price per Preferred ADS. The preferred share prices and Preferred ADS prices have been adjusted to reflect all of the above items.

(3) Through April 19, 2012.

Since July 12, 2002, our depositary receipts have been traded on the LATIBEX, under the ticker symbol “XCMIG.” The LATIBEX is an electronic trading market created in 1999 by the Madrid Stock Exchange in order to facilitate the trading market of Latin American Securities in Euros.

Trading on the BM&FBovespa

The preferred shares and common shares are traded on the BM&FBovespa, the only Brazilian stock exchange that trades shares. Trading on the BM&FBovespa is limited to brokerage firms and a limited number of authorized entities. The CVM and BM&FBovespa have discretionary authority to suspend trading in shares of a particular issuer under certain circumstances.

If you were to trade in the preferred shares or common shares on the BM&FBovespa, your trade would settle in three business days after the trade date. Delivery of and payment for shares is made through the facilities of a separate clearinghouse, which maintains accounts for brokerage firms. The seller is ordinarily required to deliver the shares to the exchange on the second business day following the trade date. The clearinghouse for the BM&FBovespa is Companhia Brasileira de Liquidação e Custódia (CBLC).

In order to better control volatility, the BM&FBovespa has adopted a “circuit breaker” system pursuant to which trading sessions may be suspended (i) for a period of 30 minutes whenever the index of this stock exchange falls more than 10% from the index registered for the previous day; (ii) for one hour if the index of this stock exchange falls 15% or more from the index registered for the previous day, after the reopening of trading; and (iii) for a certain period of time to be defined by the BM&FBovespa, if the index of this stock exchange falls 20% or more from the index registered for the previous day, after the reopening of trading.

The BM&FBovespa is less liquid than the NYSE and other major exchanges in the world. As of December 31, 2012, the aggregate market capitalization of the 364 companies listed on the BM&FBovespa was equivalent to approximately R$2.52 trillion and the 10 largest companies listed on the BM&FBovespa represented approximately 50% of the total market capitalization of all listed companies. Although any of the outstanding shares of a listed company may be traded on a Brazilian stock exchange, in most cases fewer than half of the listed shares are actually available for trading by the public. The remainder of these shares is held by small groups of controlling persons, governmental entities or one principal shareholder.

Our preferred shares and common shares have daily liquidity on the BM&FBovespa and have had no suspension of trading in the past five years other than due to BM&FBovespa utilizing circuit breakers on a few occasions in 2008 with respect to the trading of all shares on the BM&FBovespa.

We have been a member of Special Corporate Governance Level 1 of the BM&FBovespa since October 2001. The rules regarding such corporate governance segment are comprised by the Special Corporate Governance Level 1 Regulations (“Regulamento do Nível 1 de Governança Corporativa”), which were amended on March 21, 2011 by BM&FBovespa and approved by the CVM. Such revised set of rules became effective on May 10, 2011. Among the obligations that are contemplated by such regulations, we are required to:

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· present our consolidated statements of financial position, Standardized Financial Statements- DFP, consolidated income statement, quarterly financial statements – ITR, and the Reference Form (Formulário de Referência);

· include, in the notes to our quaterly financial statements, a note regarding related party transactions, containing the disclosure provided in the applicable accounting rules to annual financial statements;

· disclose in the Reference Form, any direct or indirect ownership interest per type and class exceeding 5% of each type and class of the Company’s capital stock, to the level of individual shareholders, once the Company has been provided with such information;

· disclose the amount of free float shares and their respective percentage in relation to total shares outstanding, which shall be of at least 25% of shares representing our capital stock;

· disclose, by December 10th of each year, an annual timetable of corporate events, containing, at a minimum, the date of (a) acts and corporate events, (b) public meetings with analysts and other applicable parties, and (c) disclosure of financial information scheduled for the next fiscal year. Any changes in scheduled events must be informed to the BM&FBovespa and to the public at least 5 days in advance;

· hold at least one annual meeting with market analysts and any other applicable parties

· prepare, disclose and submit to the BM&FBovespa, a securities trading policy and a code of conduct establishing the values and principles that guide the Company;

· establish that the term of office of our board of directors shall not exceed two years, with reelection being permitted;

· have different persons occupying the positions of chairman of the board of directors and chief executive officer or main executive officer of our company; and

· adopt mechanisms that provide for capital dispersion in any public share offerings.

· include in our by-laws the mandatory provisions required by the BM&FBovespa by May 10, 2014 (which we have already complied with);

Disclosure of Trading by Insiders

Brazilian securities regulations require our controlling shareholders, management, members of our Fiscal Council and any other technical or advisory body to disclose to us, the CVM and the BM&FBovespa the number and types of securities issued by us, our subsidiaries and our controlling companies that are held by them or by persons closely related to them and any changes in their respective ownership positions during the preceding 12 months. The information regarding the trading of such securities (amount, price and date of acquisition) must be provided to the CVM and the BM&FBovespa by the Company within 10 days of the end of the month in which they have occurred or of the month in which the managers of the Company were empowered.

Disclosure of Material Developments

Under Brazilian securities regulations, we must disclose any material development related to our business to the CVM and the BM&FBovespa. We are also required to publish a notice of those material developments. A development is deemed material if it has a material impact on: the price of our securities, the decision of investors to trade in our securities or the decision of investors to exercise any rights as holders of any of our securities. Under special circumstances, we may submit to the CVM a request for confidential treatment for certain material developments.

Trading on Brazilian stock exchanges by non-residents of Brazil is subject to limitations under Brazilian foreign investment legislation. See “Item 10. Additional Information—Exchange Controls.”

Regulation of Brazilian Securities Markets

The Brazilian securities markets are principally governed by Law No. 6,385, dated December 7, 1976, and the Brazilian Corporate Law, each as amended and supplemented, and by regulations issued by the CVM, the CMN, and the Central Bank, which has, among other powers, licensing authority over brokerage firms, and which regulates foreign investments and foreign exchange transactions.

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Under the Brazilian Corporate Law, a corporation is either publicly owned, such as we are, or closely held (companhia fechada). All publicly owned companies, including us, are registered with the CVM and are subject to reporting requirements. Our shares are traded on the BM&FBovespa, but may be traded privately subject to certain limitations. The Brazilian OTC market consists of direct trades and trades between individuals in which a financial institution registered with the CVM serves as intermediary.

We have the option to ask that trading in our securities on the BM&FBovespa be suspended in anticipation of a material announcement. Trading may also be suspended on the initiative of the BM&FBovespa or the CVM based on or due to, among other reasons, a belief that a company has provided inadequate information regarding a material event or has provided inadequate responses to inquiries by the CVM or the stock exchange.

Brazilian law provides general restrictions on unfair trading practices and market manipulation, although in Brazil there may be fewer instances of enforcement actions and judicial precedent is less well defined than in certain other countries.

Trading on the BM&FBovespa by non-residents of Brazil is subject to limitations under Brazilian foreign investment and tax legislation. The Brazilian custodian for the preferred shares or the common shares must obtain registration from the Central Bank of Brazil to be eligible to remit for the remittance of funds U.S. dollars abroad for payments of dividends, any other cash disbursements, or upon the disposition of the shares and sales proceeds thereof. In the event that a holder of Preferred ADSs exchanges its Preferred ADSs for preferred shares or a holder of Common ADSs exchanges its Common ADSs for common shares, the holder will be entitled to continue to rely on the depositary bank’s certificate of registration for five business days after the exchange. Thereafter, the holder may not be able to obtain and remit U.S. dollars abroad upon the disposition of the preferred shares or common shares, or distributions relating to the preferred shares or common shares, unless the holder qualifies for and obtains a new certificate of registration. See “Item 10. Additional Information—Exchange Controls.”

Item 10. Additional Information

Memorandum and Articles of Association

By-laws

We are a state-controlled company registered under the laws of Brazil. The registration number given to us by the Board of Trade of Minas Gerais (Junta Comercial do Estado de Minas Gerais) is 31300040127. Set forth below is a brief summary of certain significant provisions of (i) our by-laws, as amended by our general and special shareholders’ meeting on April 27, 2012 and (ii) Brazilian Corporate Law. The description of our by-laws contained herein does not purport to be complete and is qualified by reference to our by-laws, which have been filed as an exhibit to this annual report.

Object and Purpose

As described in Article 1 of our by-laws, we have four main purposes: (i) to construct operate and explore electric power generation, transmission and distribution system and to trade electric power and related services; (ii) to develop commercial activities in the energy field; (iii) to render consulting services to companies in Brazil and abroad related to our industry; and (iv) to perform activities directly or indirectly relating to our corporate purposes, including the development of telecommunication and information systems.

Preferred Shares

Holders of preferred shares have the right to receive annual minimum dividends in an amount equal to the greater of 10% of the par value of each preferred share or 3% of the net worth value associated with each preferred share. Holders of our preferred shares also will have priority over any other class of shares if we decide to redeem shares. A preferred share does not entitle its owner to vote at the general shareholders’ meetings.

Share Subscription

Shares purchased by the State Government, which must constitute at all times the majority of our voting shares, are paid for in accordance with the Brazilian Corporate Law. Shares purchased by other shareholders (whether natural persons or companies) shall be paid for in accordance with the decision resulting from the general meeting of shareholders that addresses the matter.

Article 171 of the Brazilian Corporate Law provides that each shareholder has a general preemptive right to subscribe for new shares or convertible securities issued in any capital increase, in proportion to that shareholder’s shareholding, except in the event

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of the exercise of any option to acquire shares of our capital stock. Shareholders must exercise their preemptive rights within 30 days after the publication of the notice of capital increase.

In the event of a capital increase, holders of Preferred ADSs, which represent preferred shares, and holders of Common ADSs, which represent common shares, would have preemptive rights to subscribe only to newly issued preferred shares or common shares, as the case may be, in proportion to their shareholdings but may not be able to exercise these rights because of U.S. securities law limitations. See “Item 3. Risk Factors—Risks Relating to the Preferred Shares, Preferred ADSs, Common shares and Common ADSs—You may not be able to exercise preemptive rights with respect to our securities.”

Non-controlling Shareholders

Our by-laws provide that the preferred and minority common shareholders are entitled to elect one member and an alternate to the Board of Directors, respectively, in a separate voting, as more fully described in “—Rights of Shareholders—Rights of Minority Shareholders.”

Dividends

For a discussion of our dividend policy, see “Item 8. Financial Information—Dividend Policy and Payments.”

General Meetings

General meetings of shareholders are held for any legal purpose, as provided by the Brazilian Corporate Law. Ordinary general meetings of shareholders are held within the first four months of the fiscal year and are called upon 15 days prior notice. The Brazilian Corporate Law also provides that the following actions may only be taken at a shareholders’ meeting:

· amendment of our by-laws;

· increases or decreases to our issued capital stock or subscription of new shares;

· election of members to our Board of Directors and Fiscal Council;

· authorization of the issuance of convertible debentures or any other convertible securities;

· suspension of the rights of a shareholder who has violated Brazilian Corporation Law or our by-laws;

· approval of any merger (fusão) or consolidation (incorporação) with another company in which we are not the surviving company or a spin-off (cisão);

· acceptance or rejection of the valuation of in-kind contributions offered by a shareholder in consideration for the issuance of shares of our capital stock;

· approval of our transformation into a limited liability company (sociedade empresária limitada) or any other corporate form;

· approval of any dissolution or liquidation, the appointment and dismissal of the respective liquidator and review of the reports prepared by him or her;

· any action regarding an application for bankruptcy or compulsory rescheduling of our debts;

· approval of the financial statements on an annual basis; and

· cancellation of registration with the CVM as a publicly-held company or delisting of our common shares from the BM&FBovespa, except in the case of a privatization tender offer.

As a general rule, the affirmative vote of shareholders representing at least the majority of our issued and outstanding common shares present in person or represented by proxy at a shareholders’ meeting is required to approve or ratify any proposed action, and abstentions are not taken into account. However, the affirmative vote of shareholders representing one half of our issued and outstanding voting capital is required to:

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· create preferred shares or to increase disproportionately an existing class of preferred shares relative to the other classes of shares, unless such action is provided for or authorized by our by-laws;

· modify a preference, privilege or condition of redemption or amortization conferred on one or more classes of preferred shares, or to create a new class with greater privileges than the existing classes of preferred shares;

· reduce the percentage of mandatory dividends;

· change our corporate purpose;

· merge us with another company if we are not the surviving company or consolidate us with another company;

· spin off a portion of our assets or liabilities;

· approve our participation in a group of companies;

· apply for cancellation of liquidation status;

· approve our dissolution; and

· approve the compulsory transfer of all of our shares to another company in order to make us a wholly-owned subsidiary of that other company (incorporação de ações).

Shareholders may be represented at a shareholders’ meeting by an attorney-in-fact appointed no more than one year prior to the meeting date. To be eligible to represent a shareholder in a shareholders’ meeting, the attorney-in-fact must be a shareholder, one of our executive officers or directors or an attorney-at-law. In a publicly held corporation, such as ours, the attorney-in-fact may also be a financial institution.

Subject to the provisions of the Brazilian Corporate Law and our by-laws, our Board of Directors may ordinarily call our shareholders’ meetings. These meetings may also be called by:

· the Fiscal Council, if the Board of Directors fails to call a general shareholders’ meeting within one calendar month after the date it was required to do so under applicable laws or a special shareholders’ meeting in the case of serious and urgent matters affecting us; any shareholder, whenever the executive officers fail to call the meeting of shareholders within 60 days of being required to do so by the Brazilian Corporate Law or by our by-laws; and

· shareholders holding at least five percent of our capital stock, if our Board of Directors fails to call a meeting within eight days after receipt of a request from that shareholder to call the meeting that indicates the issues to be discussed or calls for the creation of the Fiscal Council.

Board of Directors

Our by-laws mandate that our Board of Directors shall be comprised of 14 directors and 14 alternates. One director is designated a chairman and another director is designated the vice-chairman.

Our Board of Directors is responsible for, among other things:

· establishing the general direction of our business;

· electing and dismissing executive officers;

· approving the sale or pledge of our fixed assets, or the granting of guarantees to third parties, with a value of at least R$14 million;

· approving, upon proposal by the Board of Executive Officers, the sale or the creation of any “in rem” guarantees with respect to our permanent assets and the granting by us of any personal guarantee to any third party in an amount exceeding R$14 million;

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· approving, upon a proposal by the Board of Executive Officers, loans, financings, agreements and any actions which would bind us in an amount exceeding R$14 million;

· calling the general meetings of shareholders;

· supervising the management of the Board of Executive Officers, reviewing our books and documents and requesting information regarding executed and soon-to-be executed contracts, as well as other items of interest;

· previously manifestation regarding the management report and the accountability of the Board of Directors, to be submitted for the Annual Shareholders’ Meeting approval;

· approving our annual and interim financial statements;

· appointing and dismissing independent auditors;

· approving, upon proposal by the Board of Executive Officers, the commencement or waiver of bidding proceedings for the purchase of goods or services with a value of at least R$14 million;

· authorizing, upon proposal by the Board of Executive Officers, legal and administrative action to be taken on our behalf and the settlement of judicial and extra judicial matters in which we are involved with a value of at least R$14 million;

· approving the issuance of securities (debentures, commercial papers, notas promissórias, among others) in the local and international capital markets;

· delegating to Board of Executive Officers the power to authorize signature contracts of commercialization of electric energy or rendering distribution and transmission services, in terms of legislation;

· approving CEMIG’s long-term strategic plan, the multi-year strategic implementation plan, and the annual budget, and any alterations or revisions thereto;

· annually, setting the directives and establish the limits, including financial limits, for spending on personnel, including concession of benefits and collective work agreements, subject to the competency of the shareholders meeting and in obedience to the annual budget approved;

· authorizing the exercise of the right of preference under Shareholders’ agreements or to vote in wholly-owned subsidiaries, jointly-controlled companies, affiliated companies and the consortia in which CEMIG participates, except in the case of Cemig Distribution and Cemig Generation and Transmission, for which the competency to decide on these matters shall be that of the shareholders meeting; and

· approving the declarations of vote in the shareholders meetings and the orientations for voting in the meetings of the boards of directors of the wholly-owned subsidiaries, jointly-controlled companies, affiliated companies and the consortia in which CEMIG participates, when participation in the capital of other companies or consortia is involved, and the decisions must, in any event and not only in matters relating to participation in the capital of other companies or consortia, obey the provisions of the by-laws, the long-term strategic plan and the multi-year strategic implementation plan.

Under the Brazilian Corporate Law, directors of a corporation generally have certain duties equivalent to those imposed under the laws of most states of the United States, including a duty of loyalty to the corporation, a duty to refrain from self dealing and a duty to use reasonable care in the management of the corporation’s affairs. Our directors and officers may be held liable for breaches of duty to us and our shareholders and may be subject to judicial actions in proceedings brought by government agencies or our shareholders.

There are no provisions in our by-laws with respect to (i) a director’s power to vote on proposals or contracts in which such director is materially interested, (ii) borrowing powers exercisable by the directors, (iii) age limits for retirement of board members, and (iv) number of shares required for director qualification.

The chairman and vice-chairman of our Board of Directors are chosen by our Board of Directors at its first meeting following the election of the board members. The vice chairman of our Board of Directors will act as a temporary replacement for our chairman when the chairman is absent or impeded from exercising his functions.

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Our shareholders have the responsibility of setting the remuneration of the board members at the General Meeting of Shareholders at which the board members are elected.

Rights of Shareholders

We extend to our shareholders all of the rights that are provided under Brazilian law. Our by-laws are in compliance with the Brazilian Corporate Law.

Essential Rights

Article 109 of the Brazilian Corporate Law provides that a corporation may not deny certain rights to its shareholders under any circumstances. These shareholders’ rights include:

· the right to have a share of the corporation’s earnings;

· the right to have a share of the corporation’s assets, in the event of liquidation thereof;

· the right to supervise our management according to the Brazilian Corporate Law;

· preemptive rights to subscribe new shares or securities convertible into shares, except for exceptions provided by the Brazilian Corporate Law and our by-laws; and

· the right to withdraw from the company under certain circumstances provided in the Brazilian Corporate Law.

Voting Rights

As a general rule, only our common shares are entitled to vote and each common share corresponds to one vote. Holders of preferred shares acquire voting rights if, during three consecutive fiscal years, we fail to pay a fixed or minimum dividend to which the preferred shares are entitled. If a holder of preferred shares acquires voting rights in this manner, such rights will be identical to the voting rights of a holder of common shares and will continue until the dividend is paid. No restrictions exist on the right of a holder of common shares or preferred shares to exercise voting rights with respect to such shares by virtue of such holder being a non-resident of Brazil or a citizen of a country other than Brazil. However, holders of Preferred ADSs may only vote the underlying preferred shares through the depositary according to the terms of the Second Amended and Restated Deposit Agreement, and holders of Common ADSs may only vote the underlying common shares through the depositary according to the terms of the Common ADS Deposit Agreement. In any circumstance in which holders of preferred shares are entitled to vote, each preferred share will entitle its holder to one vote.

Redemption Rights

Our common shares and preferred shares are not redeemable, except that a dissenting shareholder is entitled under Brazilian Corporate Law to obtain redemption upon a decision made at a shareholders’ meeting by shareholders representing at least 50% of the voting shares:

· to create a new class of preferred shares or to disproportionately increase an existing class of preferred shares relative to the other classes of shares (unless such actions are provided for or authorized by the by-laws);

· to modify a preference, privilege or condition of redemption or amortization conferred on one or more classes of preferred shares, or to create a new class with greater privileges than the existing classes of preferred shares;

· to reduce the mandatory distribution of dividends;

· to change our corporate purposes;

· to merge us with another company or consolidate us;

· to transfer all of our shares to another company in order to make us a wholly-owned subsidiary of such company;

· to approve the acquisition of control of another company at a price that exceeds certain limits set forth in Brazilian Corporate Law;

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· to approve our participation in a centralized group of companies as defined under Brazilian Corporate Law; or

· in the event that the entity resulting from (a) a merger, (b) a transfer of shares as described in clause (6) above or (c) a spin-off that we conduct fails to become a listed company within 120 days of the shareholders’ meeting at which such decision was taken.

Only holders of shares adversely affected by the changes mentioned in items (1) and (2) above may require us to redeem their shares. The right of redemption mentioned in items (5), (6) and (8) above may only be exercised if our shares do not satisfy certain tests of liquidity at the time of the shareholder resolution. The right of redemption lapses 30 days after publication of the minutes of the relevant shareholders’ meeting, unless, in the case of items (1) and (2) above, the resolution is subject to confirmation by the preferred shareholders (which must be made at a special meeting to be held within one year), in which case the 30-day term is counted from the publication of the minutes of the special meeting.

We would be entitled to reconsider any action giving rise to redemption rights within 10 days following the expiration of such rights if the redemption of shares of dissenting shareholders would jeopardize our financial stability. Law No. 9,457 dated May 5, 1997, which amended Brazilian Corporate Law, contains provisions which, among other provisions, restrict redemption rights in certain cases and allow companies to redeem their shares at their economic value, subject to certain requirements. Our by-laws currently do not provide that our capital stock will be redeemable at its economic value and, consequently, any redemption pursuant to Brazilian Corporate Law would be made at no less than the book value per share, determined on the basis of the last balance sheet approved by the shareholders; provided that if the general shareholders’ meeting giving rise to redemption rights occurred more than 60 days after the date of the last approved balance sheet, a shareholder would be entitled to demand that his or her shares be valued on the basis of a new balance sheet dated within 60 days of such general shareholders’ meeting.

Rights of Non-controlling Shareholders

The Brazilian Corporate Law provides that shareholders who own at least 5% of the capital stock of a corporation are afforded the following rights, among others:

· the right to require that the books of the corporation be made available for review, whenever these shareholders become suspicious that Brazilian law or the corporation’s by-laws have been violated, or that irregularities have been committed by the management of the corporation;

· the right to call a general meeting of shareholders, under certain circumstances, whenever the corporation’s directors or officers, as the case may be, fail to do so; and

· the right to file an action for indemnification by directors or officers, as the case may be, for damages caused to the assets of the corporation, whenever it is determined at the general meeting of shareholders that such a claim shall not be filed.

Non-controlling shareholders that own, individually or in the aggregate, our outstanding common shares (since at least 10% of our outstanding common shares are held by non-controlling shareholders), and also holders of our preferred shares, have the right to appoint one member of the Fiscal Council and an alternate. All shareholders have the right to attend general meetings of shareholders.

The Brazilian Corporate Law also provides that minority shareholders that hold either (i) preferred shares representing at least 10% of the total share capital of a company or (ii) common shares representing at least 15% of the voting capital of a company, have the right to appoint one member and an alternate to the Board of Directors. If no common or preferred shareholder meets these thresholds, shareholders holding preferred shares or common shares representing at least 10% of the total share capital of the company are entitled to combine their holdings to appoint one member and an alternate to the Board of Directors.

Changes in Rights of Shareholders

Any change with respect to the rights of holders of our common shares or preferred shares requires a shareholders’ meeting. Under the Brazilian Corporate Law, the proposed changes must be approved by a majority of the affected class. Certain changes with respect to the rights of non-voting shares, including preferred shares, such as a change in payment or voting rights, may give rise to the exercise of redemption rights by the holders of the affected shares.

Going Private Transactions and Delisting from the BM&FBovespa

Our delisting, as a public company, must be preceded by a tender offer by our controlling shareholders or ourselves for the acquisition of all our then outstanding shares, subject to the conditions below:

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· the price offered for the shares under the public offering must be the fair value of those shares, as established in Brazilian Corporate Law; and

· shareholders holding more than two thirds of our float shares shall have expressly agreed to our decision to become a private company or accepted the offer.

According to Brazilian Corporate Law, a fair price shall be at least be equal to our valuation, as determined by one or more of the following valuation methods: book value, net book value assessed by market price, discounted cash flow, multiples, price of our shares in the market or any other valuation method accepted by the CVM. This price of the offer may be revised if challenged within 15 days of its publication by holders of at least 10% of our outstanding shares, by means of a request sent to our management that a special shareholders` meeting be called to decide on whether to request a new valuations under the same or different valuation method. Our shareholders that request a new valuation and those who approve such request shall reimburse us for incurred costs if the new valuation is lower than the challenged valuation. However, if the second valuation is higher, the offeror will have the option to continue the offer with the new price or quit the offer.

Arbitration

Pursuant to the Brazilian Corporate Law and related regulations, if provided for in a company’s by-laws, disputes among shareholders will be subject to arbitration. Our by-laws currently do not provide for arbitration.

Material Contracts

For information concerning our material contracts, see “Item 4. Information on the Company” and “Item 5. Operating and Financial Review and Prospects.”

Exchange Controls

There are no restrictions on the ownership of preferred shares or common shares of non-financial institutions by legal entities domiciled outside Brazil. However, your right to convert dividend payments and proceeds from the sale of preferred shares or common shares into foreign currency and to remit such amounts outside Brazil is subject to restrictions under foreign investment legislation which generally requires, among other things, that you register the relevant investment with the Central Bank and the CVM.

Investments in the preferred shares through the holding of Preferred ADSs, or in the common shares through the holding of Common ADSs, must be made pursuant to Annex V to CMN Resolution No. 1,289, as amended by CMN Resolution No. 1,927 also known as the Annex V Regulations. Direct investments in the preferred shares upon the cancellation of the Preferred ADSs, or in the common shares upon the cancellation of the Common ADSs, may be held by foreign investors under Law No. 4,131 of September 3, 1962 or CMN Resolution No. 2,689 of January 26, 2000, both of which effectively allow registered foreign investors to invest substantially in any capital market instrument in Brazil and extend a favorable tax treatment to all foreign investors registered and qualified under CMN Resolution No. 2,689, who are not resident in a tax haven, as defined by Brazilian tax laws.

Under CMN Resolution No. 2,689, foreign investors may invest in almost all financial assets and engage in almost all transactions available in the Brazilian financial and capital markets, provided that certain requirements are fulfilled. In accordance with CMN Resolution No. 2,689, the definition of foreign investor includes individuals, legal entities, mutual funds and other collective investment entities that are domiciled or headquartered abroad.

Securities and other financial assets held by CMN Resolution No. 2,689 investors must be registered or maintained in deposit accounts or in the custody of an entity duly licensed by the Central Bank or the CVM. In addition, any transfer of a security that is held pursuant to CMN Resolution No. 2,689 must be made through the stock exchanges or organized OTC markets licensed by the CVM, except for a transfer resulting from a corporate reorganization outside of Brazil or occurring upon the death of a foreign investor by operation of law or will.

Holders of Preferred ADSs or Common ADSs who have not registered their investment with the Central Bank could be adversely affected by delays in, or refusals to grant, any required government approval for conversions of payments made in reais and remittances abroad of these converted amounts.

The Annex V Regulations provide for the issuance of depositary receipts in foreign markets in respect of shares of Brazilian issuers. The Preferred ADSs have been approved under the Annex V Regulations by the Central Bank and the CVM, and the Common ADSs have been approved by the CVM (since authorization from the Central Bank is no longer necessary).

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Electronic certificates of registration have been issued in the name of Citibank, N.A., the depositary bank, with respect to the Preferred ADSs and the Common ADSs, and are maintained by Citibank Distribuidora de Títulos e Valores Mobiliários S.A., the Brazilian custodian for the preferred shares and the common shares, on behalf of the depositary bank. These electronic certificates of registration are registered through the Central Bank Information System. Pursuant to the certificates of registration, the custodian and the depositary bank are able to convert dividends and other distributions or sales proceeds with respect to the preferred shares represented by Preferred ADSs and the common shares represented by the Common ADSs into foreign currency and remit the proceeds outside Brazil.

In the event that a holder of Preferred ADSs exchanges such Preferred ADSs for preferred shares, or a holder of Common ADSs exchanges such Common ADSs for common shares, such holder will be entitled to continue to rely on the depositary bank’s certificate of registration for five business days after the exchange. Thereafter, the holder may not be able to convert into foreign currency and remit outside Brazil the proceeds from the disposition of, or distributions with respect to, the preferred shares or the common shares, unless the holder is a duly qualified investor under Resolution No. 2,689 by registering with the CVM and the Central Bank and appointing a representative in Brazil. If not so registered, the holder will be subject to less favorable Brazilian tax treatment than a holder of Preferred ADSs or Common ADSs. Regardless of qualification under Resolution No. 2,689, residents in tax havens are subject to less favorable tax treatment than other foreign investors. See “—Taxation—Brazilian Tax Considerations.”

Under current Brazilian legislation, the Federal Government may impose temporary restrictions of foreign capital abroad in the event of a serious imbalance or an anticipated serious imbalance of Brazil’s balance of payments. For approximately nine months in 1989 and early 1990, the Federal Government froze all dividend and capital repatriations held by the Central Bank that were owed to foreign equity investors, in order to conserve Brazil’s foreign currency reserves. These amounts were subsequently released in accordance with Federal Government directives. We cannot assure you that the Federal Government will not impose similar restrictions on foreign reparations in the future.

Taxation

The following summary contains a description of certain Brazilian and U.S. federal income tax consequences of the purchase, ownership and disposition of preferred shares, common shares, Preferred ADSs or Common ADSs by a United States person, as defined in section 7701(a)(30) of the Internal Revenue Code of 1986, or the Code, or a holder that otherwise will be subject to U.S. federal income tax on a net income basis in respect of preferred shares, common shares, Preferred ADSs or Common ADSs, which we refer to as a U.S. holder, but it does not purport to be a comprehensive description of all of the tax considerations that may be relevant to a decision to purchase preferred shares, common shares, Preferred ADSs or Common ADSs. In particular this summary deals only with U.S. holders that will hold preferred shares, common shares, Preferred ADSs or Common ADSs as capital assets and does not address the tax treatment of U.S. holders that own or are treated as owning 10% or more of the voting shares of the Company or that may be subject to special tax rules, such as banks or other financial institutions, insurance companies, regulated investment companies, dealers in securities or currencies, traders in securities that elect to mark to market, “pass-through entities” such as partnerships or persons that will hold preferred shares, common shares, Preferred ADSs or Common ADSs as part of a hedging transaction, constructive sale transaction, position in a “straddle” or a “conversion transaction” for tax purposes, and persons that have a “functional currency” other than the U.S. dollar. Moreover, this summary does not describe any implications under U.S. state or local law or the federal estate tax or gift tax. U.S. shareholders should consult their own tax advisors regarding such matters.

The summary is based upon tax laws of Brazil and the United States as in effect on the date hereof which are subject to change, possibly with retroactive effect, and to different interpretations. Prospective purchasers of Preferred ADSs or Common ADSs are encouraged to consult their own tax advisors as to the Brazilian, U.S. or other tax consequences of the purchase, ownership and disposition of preferred shares, common shares, Preferred ADSs or Common ADSs, including, in particular, the effect of any foreign, state or local tax laws.

Although there is currently no income tax treaty in force between Brazil and the United States, the tax authorities of both countries have had discussions that may culminate in such a treaty. No assurance can be given, however, as to whether or when a treaty will enter into force or how it will affect the U.S. holders of preferred shares, common shares, Preferred ADSs or Common ADSs.

Brazilian Tax Considerations

General — The following discussion summarizes the main Brazilian material tax consequences of the acquisition, ownership and disposal of preferred shares, common shares, Preferred ADSs or Common ADSs, as the case may be, by a holder that is not domiciled in Brazil, which we refer to as a non-Brazilian holder for purposes of Brazilian taxation. In the case of a holder of preferred shares or common shares, we assume the investment is registered with the Central Bank. The following discussion does not address all of the Brazilian tax considerations applicable to any particular non-Brazilian holder. Therefore, each non-Brazilian holder should

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consult his or her own tax adviser concerning the Brazilian tax consequences of an investment in our preferred shares, common shares, Preferred ADSs or Common ADSs.

Taxation of Dividends — Dividends paid by us, including stock dividends and other dividends paid in property to the depositary in respect of the preferred shares or common shares, or to a non-Brazilian holder in respect of the preferred shares or common shares, are currently exempted from withholding tax in Brazil to the extent that the dividends are paid out of profits generated as of January 1, 1996. Dividends relating to profits generated prior to January 1, 1996 may be subject to Brazilian withholding tax at varying rates, depending on the year the profits were generated.

Payments of Interest on Capital — Law No. 9,249, dated as of December 26, 1995, as amended, permits Brazilian corporations to make distributions to shareholders of interest on capital, or interest attributed to shareholders’ equity. These distributions may be paid in cash. Such payments represent a deductible expense from the payor’s income tax and social contribution tax basis. This interest is limited to the lowest value comparison between the daily pro rata variation of the Federal Government’s long-term interest rate, as determined by the Central Bank from time to time, that is applied to the Company’s net equity and the greater of:

· 50% of net income (after the social contribution on net profits and before the provision for corporate income tax, and the amounts attributable to shareholders as interest on net equity) for the period in respect of which the payment is made; or

· 50% of the sum of retained earnings and earnings reserves as of the date of the beginning of the period in respect of which the payment is made.

Any payment of interest on capital to shareholders (including holders of Preferred ADSs in respect of preferred shares and Common ADSs in respect of common shares) is subject to a withholding tax at a rate of 15%, or 25% if the non-Brazilian holder is domiciled in a jurisdiction that does not impose income tax or where the maximum income tax rate is lower than 20% or where the local legislation imposes restrictions on disclosing the shareholding composition or the ownership of the investment, or a Tax Haven Holder. These payments may be included, at their net value, as part of any mandatory dividend.

On June 24, 2008, Law No. 11,727 was enacted, which established the concept of “privileged tax regime”, in connection with transactions subject to transfer pricing and thin capitalization rules, which is more comprehensive than the tax haven concept. Under this new law, a “privileged tax regime” is a considered to apply to a jurisdiction that meets any of the following requirements: (1) does not tax income or taxes income at a maximum rate lower than 20%; (2) grants tax advantages to a non-resident entity or individual (a) without requiring substantial economic activity in the jurisdiction of such non-resident entity or individual or (b) to the extent such non-resident entity or individual does not conduct substantial economic activity in the jurisdiction of such non-resident entity or individual; (3) does not tax income generated abroad, or imposes tax on income generated abroad at a maximum rate lower than 20%, or (4) restricts the ownership disclosure of assets and ownership rights or restricts disclosure about the execution of economic transactions.

Although the interpretation of the current Brazilian tax legislation could lead to the conclusion that the concept of “privileged tax regime” should apply only for the purposes of Brazilian transfer pricing rules, it is unclear whether such concept would also apply to other types of transactions, such as investments carried out in the Brazilian financial and capital markets for purposes of this law. There is no judicial guidance as to the application of Law No. 11,727 of June 24, 2008 and, accordingly, we are unable to predict whether the Brazilian Internal Revenue Service or the Brazilian courts would decide that the “privileged tax regime” concept shall be applicable to deem a Non-Resident Holder as a Tax Haven Resident when carrying out investments in the Brazilian financial and capital markets. However, in the event that the “privileged tax regime” concept is interpreted to be applicable to transactions carried out in the Brazilian financial and capital markets, this tax law would accordingly result in the imposition of taxation to a Non-Resident Holder that meets the privileged tax regime requirements in the same way applicable to a Tax Haven Resident. Current and prospective investors should consult with their own tax advisors regarding the consequences of the implementation of Law 11,727 and of any related Brazilian tax law or regulation concerning “tax haven” or “privileged tax regimes”.

To the extent that payments of interest on capital are included as part of a mandatory dividend, we are required to distribute an additional amount to ensure that the net amount received by shareholders, after payment of the applicable withholding tax is at least equal to the mandatory dividend.

Distributions of interest on net equity to foreign holders may be converted into U.S. dollars and remitted outside Brazil, subject to applicable exchange controls, to the extent that the investment is registered with the Brazilian Central Bank.

We cannot assure you that our Board of Directors will not determine that future distributions should be made by means of dividends or interest on net equity.

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Taxation of Gains — According to Law No. 10,833/03, the gains recognized on a disposal of assets located in Brazil, such as our shares, by a non-Brazilian holder, are subject to withholding income tax in Brazil. This rule is applicable regardless of whether the disposal is conducted in Brazil or abroad and/or if the disposal is made or not to an individual or entity resident or domiciled in Brazil.

As a general rule, capital gains realized as a result of a disposal transaction are the positive difference between the amount realized on the disposal of the asset and the respective acquisition cost.

Capital gains realized by non-Brazilian holders on the disposal of shares sold on the Brazilian stock exchange (which includes the transactions carried out on the organized over-the-counter market):

· are subject to the withholding income tax at a zero percent rate, when realized by a non-Brazilian holder that (i) has registered its investment in Brazil before the Central Bank under the rules of the Brazilian Monetary Counsel, or a Registered Holder, and (ii) is not a Tax Haven Holder; and

· are subject to income tax at a rate of 15% with respect to gains realized by a non-Brazilian holder that is not a Registered Holder and is not a Tax Haven Holders (including a non-Brazilian holder who qualifies under Law No. 4,131/62) and gains earned by Tax Haven Holders that are Registered Holders. In this case, a withholding income tax of 0.005% shall be applicable and can be offset against any income tax due on the capital gain.

Any other gains realized on the disposal of shares that are sold on the Brazilian stock exchange:

· are subject to income tax at a rate of 15% when realized by any non-Brazilian holder that is not a Tax Haven Holder, no matter if a Registered Holder or not; and

· are subject to income tax at a rate of 25% when realized by a Tax Haven Holder, no matter if a Registered Holder or not.

In the cases above, if the gains are related to transactions conducted on the Brazilian non-organized over-the-counter market with intermediation, the withholding income tax of 0.005% shall also be applicable and can be offset against any income tax due on the capital gain.

Any exercise of preemptive rights relating to shares will not be subject to Brazilian income tax. Gains realized by a non-Brazilian holder on the disposal of preemptive rights will be subject to Brazilian income tax according to the same rules applicable to disposal of shares.

There can be no assurance that the current favorable tax treatment of Registered Holders will continue in the future.

Sale of Preferred ADSs and Common ADSs by U.S. Holders to Other Non-Residents in Brazil — Pursuant to Section 26 of Law No. 10,833, published on December 29, 2003, the sale of property located in Brazil involving non-resident investors is subject to Brazilian income tax as of February 1, 2004. Our understanding is that ADSs do not qualify as property located in Brazil and, thus, should not be subject to the Brazilian withholding tax. Insofar as the regulatory norm referred to is generic and has not been tested through the administrative or judicial courts, we are unable to assure the final outcome of such discussion.

If such argument does not prevail, it is important to mention that with respect to the cost of acquisition to be adopted for calculating such gains, Brazilian law has conflicting provisions regarding the currency in which such amount must be determined. CEMIG’s Brazilian counsel’s view is that the capital gains should be based on the positive difference between the cost of acquisition of the preferred shares or common shares registered with the Brazilian Central Bank in foreign currency and the value of disposal of those preferred shares or common shares in the same foreign currency. This view has been supported by a precedent issued by the Brazilian administrative court. However, considering that tax authorities are not bound by such precedent, assessments have been issued adopting the cost of acquisition in Brazilian currency.

Gains on the Exchange of Preferred ADSs for Preferred Shares or the Exchange of Common ADSs for Common Shares — Although there is no clear regulatory guidance, the exchange of ADSs for shares should not be subject to Brazilian tax. Non-Brazilian holders may exchange Preferred ADSs for the underlying preferred shares or Common ADSs for the underlying common shares, sell the preferred shares or common shares on a Brazilian stock exchange and remit abroad the proceeds of the sale within five business days from the date of exchange (in reliance on the depositary’s electronic registration), with no tax consequences. Although there is no clear regulatory guidance, the exchange of ADSs for shares should not be subject to Brazilian withholding income tax.

Upon receipt of the underlying preferred shares in exchange for Preferred ADSs or the underlying common shares in exchange for Common ADSs, non-Brazilian holders may also elect to register with the Central Bank the U.S. dollar value of such

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preferred shares or common shares as a foreign portfolio investment under Resolution No. 2689/00, which will entitle them to the tax treatment referred above in connection with “U.S. market investors.”

Alternatively, the non-Brazilian holder is also entitled to register with the Central Bank the U.S. dollar value of such preferred shares or common shares as a foreign direct investment under Law 4,131/62, in which case the respective sale would be subject to the tax treatment referred in the section “Taxation of Gains.”

Gains on the Exchange of Preferred Shares for Preferred ADSs or Common Shares for Common ADSs — The deposit of preferred shares in exchange for the Preferred ADSs or common shares in exchange for the Common ADSs may be subject to Brazilian income tax on capital gains if the amount previously registered with the Central Bank as a foreign investment in preferred shares or common shares or, in the case of other market investors under Resolution No. 2,689, the acquisition cost of the preferred shares or common shares, as the case may be, is lower than:

· the average price per preferred share or common share on the Brazilian stock exchange on which the greatest number of such preferred shares or common shares were sold on the day of deposit; or

· if no preferred shares or common shares were sold on that day, the average price on the Brazilian stock exchange on which the greatest number of preferred shares or common shares were sold during the 15 preceding trading sessions.

The difference between the amount previously registered, or the acquisition cost, as the case may be, and the average price of the preferred shares or common shares, calculated as set forth above, is considered a capital gain subject to income tax at a rate of 15% or 25% for Tax Haven Holders. Although there is no clear regulatory guidance, such taxation should not apply in case of Non-Resident Holders registered under Resolution No. 2,689/00, other than Tax Haven Residents.

Taxation of Foreign Exchange Transactions — Brazilian law imposes Taxation on Foreign Exchange Transactions (conversion of reais into foreign currency or vice-versa), through the IOF tax (Imposto sobre Operações Financeiras – Tax on Financial Transactions). The current applicable rate for almost all foreign currency exchange transactions is 0.38%. Under Decree 7853/2012, the rate of IOF tax on all settlements of foreign exchange transactions, including simultaneous transactions, for foreign loans entering Brazil contracted on or after December 05, 2012, that require registry with the Brazilian Central Bank, contracted directly or through the issuance of securities in the international market with average minimum maturity of up to 360 days, is 6%. Settlement of foreign exchange transactions related to foreign loans with average minimum maturity superior to 360 days are subject to IOF tax at a rate of 0%. Settlements of foreign exchange transactions for investments made by a Non-Resident Holder in the Brazilian financial and capital markets is subject to IOF tax at a rate of 6%. However, as of December 1, 2011, settlement of foreign exchange transactions executed by Non-Resident Holders and related to investments in Brazil in variable income traded on the stock exchange or the commodities and futures exchange are subject to IOF tax at the rate of 0%. The 0% rate also applies to settlement of simultaneous foreign exchange transactions related to the cancellation of depositary receipts to transfer the investment into shares traded on the stock exchange. Remittances of funds abroad related to the return of the investments in the Brazilian financial and capital markets made by non-resident investors, the return of foreign loans and the remittance of dividends and Interest on Equity, are subject to IOF foreign exchange tax, at the rate of 0%. Although there is no clear regulatory instruction, conversion of reais to dollars for payment of dividends to holders of ADSs is also expected to benefit from IOF foreign exchange tax at the rate of 0%.

Tax on Transactions Involving Bonds and Securities — Brazilian law imposes a Tax on Transactions Involving Bonds and Securities, or IOF/Bonds Tax, including those carried out on a Brazilian stock exchange. The rate of IOF applicable to transactions involving stocks (such as our preferred shares, Preferred ADSs, common shares and Common ADSs) is currently zero, although the assignment of shares traded on Brazilian stock exchanges to issue depositary receipts traded abroad is subject to IOF at the rate of 1.5%. The Minister of Finance is permitted to increase such rate at any time up to 1.5% per day, but only in respect to future transactions.

Other Brazilian Taxes — Some Brazilian states impose gift and inheritance tax on gifts or bequests made by individuals or entities not domiciled or residing in Brazil to individuals or entities domiciled or residing within such states. There are no Brazilian stamps, issues, registrations, or similar taxes or duties payable by holders of preferred shares, common shares, Preferred ADSs or Common ADSs.

U.S. Tax Considerations

In general, for U.S. federal income tax purposes, holders of ADRs evidencing ADSs will be treated as the beneficial owners of the common shares or preferred shares represented by those ADSs.

Taxation of Distributions — Subject to the discussion below under “– Passive Foreign Investment Company Rules,” distributions with respect to the shares or the ADSs (other than distributions in redemption of the shares subject to Section 302(b) of

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the Code or in a liquidation of the Company) will, to the extent made from current or accumulated earnings and profits of the Company as determined under U.S. federal income tax principles, constitute dividends. A distribution also includes the amount of any Brazilian taxes withheld on any such distribution, if any. Whether such current or accumulated earnings and profits will be sufficient for all such distributions on the shares or ADSs to qualify as dividends depends on the future profitability of the Company and other factors, many of which are beyond the control of the Company. To the extent that such a distribution exceeds the amount of the Company’s earnings and profits, it will be treated as a non-taxable return of capital to the extent of the U.S. holder’s basis in the shares or ADSs, and thereafter as capital gain. As used below, the term “dividend” means a distribution that constitutes a dividend for U.S. federal income tax purposes. The Company does not currently intend to maintain calculation of its earnings and profits under U.S. federal income tax principles. Accordingly, U.S. holders should expect that all distributions made with respect to the shares or ADSs will generally be treated as dividends. Cash dividends (including amounts withheld in respect of Brazilian taxes) paid with respect to (i) the shares generally will be includible in the gross income of a U.S. holder as ordinary income on the day on which the dividends are received by the U.S. holder or (ii) the shares represented by ADSs generally will be includible in the gross income of a U.S. holder as ordinary income on the day on which the dividends are received by the depositary bank and, in either case, will not be eligible for the dividends received deduction allowed to corporations. Dividends paid in reais will be includible in the income of a U.S. holder in a U.S. dollar amount calculated by reference to the exchange rate in effect on the day they are received by the U.S. holder, in the case of shares, or the depositary bank, in the case of shares represented by ADSs.

If dividends paid in reais are converted into U.S. dollars on the day they are received by the U.S. holder or the depositary bank, as the case may be, U.S. holders generally should not be required to recognize foreign currency gain or loss in respect of the dividend income. U.S. holders should consult their own tax advisors regarding the treatment of any foreign currency gain or loss if any reais received by the U.S. holder or the depositary bank are not converted into U.S. dollars on the date of receipt, as well as the tax consequences of the receipt of any additional reais from the custodian on account of Brazilian inflation.

Dividends generally will constitute foreign source income and generally will constitute “passive category income” or, in the case of certain U.S. holders, “general category income,” for foreign tax credit purposes. In the event Brazilian withholding taxes are imposed on such dividends, such taxes may be treated as a foreign income tax eligible, subject to generally applicable limitations and conditions under U.S. federal income tax law, for credit against a U.S. holder’s U.S. federal income tax liability (or at a U.S. holder’s election, may be deducted in computing taxable income). The calculation and availability of foreign tax credits and, in the case of a U.S. holder that elects to deduct foreign taxes, the availability of deductions, involves the application of rules that depend on a U.S. holder’s particular circumstances. In the event Brazilian withholding taxes are imposed, U.S. holders should consult their own tax advisors regarding the availability of foreign tax credits with respect to Brazilian withholding taxes.

Distributions to U.S. holders of additional shares of “common stock” or preemptive rights relating to such “common stock” with respect to their common shares or Common ADSs that are made as part of a pro rata distribution to all shareholders of the Company generally will not be treated as dividend income for U.S. federal income tax purposes, but could result in additional U.S.-source taxable gain upon the sale of such additional shares or preemptive rights. Non-pro rata distributions of such shares or rights generally would be includible in the U.S. holder’s gross income to the same extent and in the same manner as distributions payable in cash. In that event, the amount of such distribution (and the basis of the new shares or preemptive rights so received) generally will equal the fair market value of the shares or preemptive rights on the date of distribution. It is not entirely clear whether the preferred shares will be treated as “preferred stock” or “common stock” for this purpose. If the preferred shares are treated as “common stock” for this purposes the treatment above would apply to distributions of shares or preemptive rights with respect to preferred shares or Preferred ADSs, On the other hand, if the preferred shares are treated as “preferred stock” a distribution of additional shares or preemptive rights would be includible in gross income to the same extent as a cash distribution whether or not such distribution is considered a pro rata distribution.

Qualified Dividend Income — Notwithstanding the foregoing, certain dividends received by individual U.S. holders that constitute “qualified dividend income” currently may be subject to a reduced maximum marginal U.S. federal income tax rate. Qualified dividend income generally includes, among other dividends, dividends received during the taxable year from “qualified foreign corporations.” In general, a foreign corporation is treated as a qualified foreign corporation with respect to any dividend paid by the corporation with respect to stock of the corporation that is readily tradable on an established securities market in the United States. For this purpose, a share is treated as readily tradable on an established securities market in the United States if an ADR backed by such share is so traded.

Notwithstanding this previous rule, dividends received from a foreign corporation that is a passive foreign investment company (as defined in section 1297 of the Code), or in either the taxable year of the corporation in which the dividend was paid or the preceding taxable year will not constitute qualified dividend income. In addition, the term “qualified dividend income” will not include, among other dividends, any (i) dividends on any share or ADS which is held by a taxpayer for 60 days or less during the 120-day period beginning on the date which is 60 days before the date on which such share or the shares backing the ADS become ex-dividend with respect to such dividends (as measured under section 246(c) of the Code) or (ii) dividends to the extent that the taxpayer is under an obligation (whether pursuant to a short sale or otherwise) to make related payments with respects to positions in

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substantially similar or related property. Moreover, special rules apply in determining a taxpayer’s foreign tax credit limitation under section 904 of the Code in the case of qualified dividend income.

Individual U.S. holders should consult their own tax advisors to determine whether or not amounts received as dividends from us will constitute qualified dividend income subject to a reduced maximum marginal U.S. federal income tax rate and, in such case, the effect, if any, on the individual U.S. holder’s foreign tax credit.

Taxation of Capital Gains — Deposits and withdrawals of shares by U.S. holders in exchange for ADSs will not result in the realization of gain or loss for U.S. federal income tax purposes.

Subject to the discussion below under “– Passive Foreign Investment Company Rules,” gain or loss realized by a U.S. holder on the sale, redemption or other taxable disposition of shares or ADSs will be subject to U.S. federal income taxation as capital gain or loss in an amount equal to the difference between such U.S. holder’s basis in the shares or the ADSs and the amount realized on the disposition. Gain or loss recognized by a U.S. holder on such sale, redemption or other taxable disposition generally will be long-term capital gain or loss if, at the time of the sale or other taxable disposition, the shares or ADSs, as applicable, have been held for more than one year. Certain non-corporate U.S. holders (including individuals) may be eligible for preferential rates of U.S. federal income tax in respect of long-term capital gains. The deduction of a capital loss is subject to limitations for U.S. federal income tax purposes. Gain realized by a U.S. holder on a sale, redemption or other taxable disposition of shares or ADSs, including gain that arises because the U.S. holder’s basis in the shares or ADSs has been reduced because a distribution is treated as a return of capital rather than as a dividend, generally will be treated as U.S. source income for U.S. foreign tax credit purposes.

If a Brazilian withholding tax or income tax is imposed on the sale, redemption or other taxable disposition of shares or ADSs as described in “—Taxation—Brazilian Tax Considerations,” the amount realized by a U.S. holder will include the gross amount of the proceeds of such sale, redemption or other taxable disposition before deduction of the Brazilian withholding tax or income tax if applicable. The availability of U.S. foreign tax credits for these Brazilian taxes is subject to certain limitations and involves the application of rules that depend on a U.S. holder’s particular circumstances. U.S. holders should consult their own tax advisors regarding the application of the foreign tax credit rules to their investment in, and disposition of, shares or ADSs.

Passive Foreign Investment Company Rules - Certain adverse U.S. federal income tax rules generally apply to a U.S. person that owns or disposes of stock in a non-U.S. corporation that is classified as a passive foreign investment company (a “PFIC”). In general, a non-U.S. corporation will be classified as a PFIC for any taxable year during which, after applying relevant look-through rules with respect to the income and assets of subsidiaries, either (i) 75.0% or more of the non-U.S. corporation’s gross income is “passive income” or (ii) 50.0% or more of the gross value (determined on a quarterly basis) of the non-U.S. corporation’s assets produce passive income or are held for the production of passive income. For these purposes, passive income generally includes, among other things, dividends, interest, rents, royalties, gains from the disposition of passive assets and gains from commodities and securities transactions (other than certain active business gains from the sale of commodities). In determining whether a non-U.S. corporation is a PFIC, a pro rata portion of the income and assets of each corporation in which it owns, directly or indirectly, at least 25.0% interest (by value) is taken into account.

The Company does not believe that it was a PFIC, for United States federal income tax purposes, for its preceding taxable year and does not expect to be a PFIC in its current taxable year or in the foreseeable future. However, because PFIC status depends upon the composition of a company’s income and assets, the market value of assets from time to time, and the application of rules that are not always clear, there can be no assurance that the Company will not be classified as a PFIC for any taxable year.

If the Company was to be classified a PFIC, a U.S. holder could be subject to material adverse tax consequences including being subject to greater amounts of tax on gains and certain distributions on the shares or ADSs as well as increased reporting obligations. U.S. holders should consult their tax advisors about the possibility that the Company might be classified as a PFIC and the consequences if the Company was classified as a PFIC.

Medicare Tax on Net Investment Income – A U.S. holder that is an individual, an estate or a trust (other than a trust that falls into a special class of trusts that is exempt from such tax) will be subject to a 3.8% tax on the lesser of (1) the U.S. holder’s “net investment income” (in the case of individuals) or “undistributed net investment income” (in the case of estates and trusts) for the relevant taxable year and (2) the excess of the U.S. holder’s “modified adjusted gross income” (in the case of individuals) or “adjusted gross income” in the case of estates and trusts) for the taxable year over a certain threshold (which in the case of individuals will be between $125,000 and $250,000 depending upon the individual’s circumstances). A U.S. holder’s net investment income generally will include its dividend income on the shares or ADSs, and its net gains from the disposition of the shares or ADSs. U.S. holders that are individuals, estates or trusts should consult their own tax advisors regarding the applicability of the Medicare tax to their income and gains in respect of the shares or ADSs.

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Information Reporting and Backup Withholding — Information reporting requirements will generally apply to U.S. holders of ADSs and U.S. holders will be required to comply with applicable certification procedures to establish that they are not subject to back up withholding. Investors who are individuals and fail to report required information could be subject to substantial penalties. Investors should consult their own tax advisors regarding these requirements.

In addition, U.S. holders should be aware that recently enacted legislation imposes new reporting requirements with respect to the holding of certain foreign financial assets, including stock of foreign issuers which is not held in an account maintained by a financial institution, if the aggregate value of all such assets exceeds US$50,000. U.S. holders that hold the ADSs through a U.S. brokerage account should not be subject to this new reporting requirement with respect to their investment in the ADSs. U.S. holders should consult their own tax advisors regarding the application of the information reporting rules to the ADSs or shares and the application of the recently enacted legislation to their particular situations.Dividends and Paying Agents

We pay dividends on preferred shares and common shares in the amounts and in the manner set forth under “Item 8. Financial Information—Dividend Policy and Payments.” We will pay dividends in respect of preferred shares represented by Preferred ADSs or common shares represented by Common ADSs to the custodian for the depositary bank, as record owner of the preferred shares represented by Preferred ADSs or the common shares represented by Common ADSs. As promptly as practicable after receipt of the dividends we pay through Citibank N.A. to the custodian, it will convert these payments into U.S. dollars and remit such amounts to the depositary bank for payment to the holders of Preferred ADSs or Common ADSs in proportion to individual ownership.

Documents on Display

We are subject to the informational requirements of the Securities Exchange Act of 1934, as amended, or the Exchange Act. In accordance with these requirements, we file reports and other information with the SEC. These materials, including this annual report and the accompanying exhibits, may be inspected and copied at the SEC’s Public Reference Room at 100 F Street, N.E., Room 1580, Washington, D.C. 20549. Copies of the materials may be obtained from the SEC’s Public Reference Room at prescribed rates. The public may obtain information on the operation of the SEC’s Public Reference Room by calling the SEC in the United States at 1-800-SEC-0330. In addition, copies of the exhibits that accompany this annual report may be inspected at our principal executive offices located at Avenida Barbacena, 1200, 30190—131 Belo Horizonte, Minas Gerais, Brazil.

Insurance

We have insurance policies to cover damages to our headquarters building and to the turbines, generators and transformers of our major power plants and substations caused by fire and risks such as equipment failures. We also have insurance policies to cover damages to and by our aircrafts used in connection to our operations. We do not have general third party liability insurance covering accidents and have not solicited bids related to this type of insurance. However, we may contract for this type of insurance in the future. In addition, we have not solicited bids for, nor do we carry, insurance coverage for major catastrophes affecting our facilities such as earthquakes and floods or for operating system failures. We do not have insurance coverage for business interruption risk, which means damages we suffer and consequential damages suffered by our consumers resulting from an interruption in power distribution are generally not covered by our insurance and we may be subject to significant related losses. See “Item 3. Key Information—Risk Factors—Risks Relating to CEMIG—We operate without general third party liability and catastrophe insurance policies.”

We believe that, since we have contracted for fire and operational risk insurance, our insurance coverage will be at a level that is customary in Brazil for the type of businesses in which we are engaged.

Difficulties of Enforcing Civil Liabilities Against Non-U.S. Persons

We are a state-controlled mixed capital company established under the laws of Brazil. All of our executive officers and directors presently reside in Brazil. In addition, substantially all of our assets are located in Brazil. As a result, it will be necessary for holders of Preferred ADSs or Common ADSs to comply with Brazilian law in order to obtain an enforceable judgment against our executive officers or directors or our assets. It may not be possible for holders of Preferred ADSs or Common ADSs to effect service of process within the United States upon our executive officers and directors, or to realize in the United States upon judgments against these persons obtained in U.S. courts based upon civil liabilities of these persons, including any judgments based upon U.S. federal securities laws, to the extent these judgments exceed these persons’ U.S. assets. We have been advised by Brazilian counsel, Souza, Cescon, Barrieu & Flesch Advogados, that judgments of U.S. courts for civil liabilities based upon the federal securities laws of the United States may be, subject to the requirements described below, enforced in Brazil to the extent Brazilian courts may have jurisdiction. A judgment against us, or the persons described above obtained outside Brazil without reconsideration of the merits, is subject to confirmation by the Brazilian Superior Court of Justice. That confirmation will occur if the foreign judgment:

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· fulfills all formalities required for its enforceability under the laws of the country where the foreign judgment is granted;

· is issued by a competent court after proper service of process is made in accordance with Brazilian law, or after sufficient evidence of the parties absence has been given, as established pursuant to applicable Law;

· is not subject to appeal;

· is for the payment of a sum certain;

· is authenticated by a Brazilian consular officer in the country where the foreign judgment is issued and is accompanied by a sworn translation into Portuguese; and

· is not contrary to Brazilian national sovereignty, public policy or public morality.

We cannot assure you the confirmation process described above will be conducted in a timely manner or that Brazilian courts would enforce a monetary judgment for violation of the United States securities laws with respect to the Preferred ADSs and the preferred shares represented by the Preferred ADSs or the Common ADSs and the common shares represented by the Common ADSs.

We were further advised by respective Brazilian counsel that:

· original actions based on the federal securities laws of the United States may be brought in Brazilian courts and that, subject to Brazilian public policy and national sovereignty, Brazilian courts will enforce liabilities in such actions against us and our officers; and

· the ability of a judgment creditor or the other persons named above to satisfy a judgment by attaching our assets or those of the selling shareholders is limited by provisions of Brazilian law.

A plaintiff (whether Brazilian or non-Brazilian) residing outside Brazil during the course of litigation in Brazil must provide a bond to guarantee court costs and legal fees if the plaintiff owns no real property in Brazil that could secure such payment. The bond must have a value sufficient to satisfy the payment of court fees and defendant’s attorney fees, as determined by a judge in Brazil. This requirement does not apply to a proceeding to enforce a foreign judgment which has been confirmed by the Brazilian Superior Court of Justice.

Item 11. Quantitative and Qualitative Disclosures about Market Risk

We are exposed to market risk from changes in foreign currency exchange rates and interest rates.

We are exposed to foreign exchange risk because certain of our loans and financings are denominated in currencies (primarily the U.S. dollar) other than the currency in which we earn revenues (the real). See “Item 5. Operating and Financial Review and Prospects—Critical Accounting Estimates.”

Exchange Rate Risk

At December 31, 2012, approximately 3.27% of our outstanding indebtedness, or R$528 million, was denominated in foreign currencies, of which approximately 92.61%, or R$489 million, was denominated in U.S. dollars. We do not have substantial revenues denominated in any foreign currencies and, due to regulations that require us to keep excess cash on deposit in real-denominated accounts at Brazilian banks, we do not have monetary assets denominated in foreign currencies.

In 2012, we used financial instruments such as interest rate swaps to manage risk and hedge our foreign exchange rate exposure. The purpose of the swaps was to reduce our exposure on the original interest rate of certain financing from an interest rate calculated based on the U.S. dollar/real exchange rate to an interest rate calculated based on the CDI rate. See Notes 2.6 (b), 19, 26, 27 and 28 to our consolidated financial statements.

In 2013, the potential loss we would experience in the event of a hypothetical 25% and 50% depreciation of the real against the U.S. dollar and other foreign currencies would be approximately R$614 million and R$737 million, respectively related primarily due to an increase in our real-denominated interest expense. In 2013, a hypothetical 25% and 50% depreciation of the real against the U.S. dollar would result in an additional annual rate expense, of approximately R$124 million and R$247 million, respectively, reflecting the increased cost in reais of foreign currency-denominated indebtedness from loans, financings and debentures with

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maturity dates in 2012. compared to probable scenario This sensitivity analysis assumes a simultaneous unfavorable 25% and 50% fluctuation in each of the exchange rates affecting the foreign currencies in which our indebtedness is denominated.

The tables below provide summary information regarding our exposure to exchange rate risk as of December 31, 2012:

U.S. Dollar |  | R$ (Million)
Financing |  | 489
Supplier (Itaipu) |  | 219
Less Contracted derivative instruments |  | (19)
|  | 689
Other Currencies |  |
Financing |  | 39
Other |  | 4
Net liabilities exposed to exchange rate risk |  | 43

Interest Rate Risk

At December 31, 2012, we had R$16,170 million in loans and financing outstanding, of which approximately R$14,812 million bore interest at floating rates which, R$11.938 million bear interest at rates tied to inflation indexes and the SELIC rate and R$217 million is subject principally to LIBOR.

At December 31, 2012, we had liabilities, net of other assets that bore interest at floating rates in the amount of R$10,650 million. These assets consisted mainly of cash and cash equivalents and our account receivable from the State Government, bearing interest at rates tied to IGP-DI and SELIC, respectively, as summarized in the tables below. A hypothetical, instantaneous and unfavorable change of 100 basis points in interest rates applicable to floating rate financial assets and liabilities held at December 31, 2012 would result in a potential loss of R$106.5 million to be recorded as a financial expense in our consolidated financial statements.

Total Debt Portfolio

|  | R$ (Million)
Floating rate debt: |  |
Real-denominated |  | 14,595
Foreign currency-denominated |  | 217
|  | 14,812
Fixed rate debt: |  |
Real-denominated |  | 1,047
Foreign currency-denominated |  | 311
Total |  | 16.170

|  | Total Portfolio
|  | Floating Rate (R$ million)
Assets: |  |
Cash and cash equivalents |  | 2,329
Securities |  | 1,720
Escrow Depósits |  | -132
Total |  | 4,181
Liabilities: |  |
Financings (Floating Rate) |  | (14,181)
Derivative instruments (1) |  | (19)
Total liabilities |  | (14,831)
Total |  | (10,650)

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(1) Swaps to reduce our exposure on the original interest rate of certain financing from an interest rate calculated based on the U.S. dollar/real exchange rate to an interest rate calculated based on the CDI rate.

Item 12. Description of Securities Other than Equity Securities

American Depositary Shares

Citibank, N.A. serves as the depositary (the “Depositary”) for both our Common ADSs and Preferred ADSs. Holders of ADSs, any person or entity having a beneficial interest deriving from the ownership of the ADSs, and persons depositing shares or surrendering ADSs for cancellation and withdrawal of Deposited Securities (as defined in the Deposit Agreements) are required to pay to the Depositary certain fees and related charges as identified below.

The fees associated with our Common ADSs are as follows :

Service |  |  | Rate |  |  | By Whom Paid
(1) Issuance of Common ADSs upon deposit of common shares (excluding issuances as a result of distributions described in paragraph (4) below). |  |  | Up to $5.00 per 100 Common ADSs (or fraction thereof) issued. |  |  | Person depositing common shares or person receiving Common ADSs.
(2) Delivery of Deposited Securities, property and cash against surrender of Common ADSs. |  |  | Up to $5.00 per 100 Common ADSs (or fraction thereof) surrendered. |  |  | Person surrendering Common ADSs for purpose of withdrawal of Deposited Securities or person to whom Deposited Securities are delivered.
(3) Distribution of cash dividend or other cash distributions (i.e. sale of rights and other entitlements). |  |  | Up to $2.00 per 100 Common ADSs (or fraction thereof) held. |  |  | Person to whom distribution is made.
(4) Distribution of Common ADSs pursuant to (i) stock dividends or other free stock distributions, or (ii) exercise of rights to purchase additional Common ADSs. |  |  | Up to $5.00 per 100 Common ADSs (or fraction thereof) issued. |  |  | Person to whom distribution is made.
(5) Distribution of securities other than Common ADSs or rights to purchase additional Common ADSs (i.e. spin off shares). |  |  | Up to $5.00 per 100 Common ADSs (or fraction thereof) issued. |  |  | Person to whom distribution is made.
(6) Transfer of ADRs. |  |  | $1.50 per certificate presented for transfer. |  |  | Person presenting certificate for transfer.

The fees associated with our Preferred ADSs are as follows:

Service |  |  | Rate |  |  | By Whom Paid
(1) Issuance of Preferred ADSs upon deposit of preferred shares (excluding issuances contemplated by paragraphs (3)(b) and (5) below). |  |  | Up to $5.00 per 100 Preferred ADSs (or fraction thereof) issued. |  |  | Person for whom deposits are made or person receiving Preferred ADSs.
(2) Delivery of Deposited Securities, property and cash against surrender of Preferred ADSs. |  |  | Up to $5.00 per 100 Preferred ADSs (or fraction thereof) surrendered. |  |  | Person surrendering Preferred ADSs or making withdrawal.
(3) Distribution of (a) cash dividend or (b) Preferred ADSs pursuant to stock dividends (or other free distribution of stock). |  |  | No fee, so long as prohibited by the exchange upon which the Preferred ADSs are listed. If the charging of such fee is not prohibited, the fees specified in (1) above shall be payable in respect of a distribution of Preferred ADSs pursuant to stock dividends (or other free |  |  | Person to whom distribution is made.

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|  |  | distribution of stock) and the fees specified in (4) below shall be payable in respect of distributions of cash. |  |  |
(4) Distribution of cash proceeds (i.e., upon sale of rights and other entitlements). |  |  | Up to $2.00 per 100 Preferred ADSs (or fraction thereof) held. |  |  | Person to whom distribution is made.
(5) Distribution of Preferred ADSs pursuant to exercise of rights. |  |  | Up to $5.00 per 100 Preferred ADSs (or fraction thereof) issued. |  |  | Person to whom distribution is made.

Direct and indirect depositary payments

We have an agreement with the Depositary to reimburse us, up to a limited amount, for certain expenses in connection with our ADR programs, including listing fees, legal and accounting expenses, proxy distribution costs and investor relation related expenses. These reimbursements for the year ended December 31, 2012 totaled a net amount of approximately US$3.6 million, after deduction of applicable US taxes, in the amount of US$1.6 million.

PART II

Item 13. Defaults, Dividend Arrearages and Delinquencies

Certain of CEMIG’s loans and financing agreements contain covenants that require us to maintain financial ratios, calculated in accordance with Brazilian Corporate Law. As of December 31, 2012, we were in non-compliance with some ratios contained in a credit instrument among Cemig Distribution and Santander (originally ABN Amro Bank). Such ratios were the following:

Cemig D

· Debt/EBITDA was 3.68x, when it was required to be equal or less than 2.5x

Cemig (as guarantor)

· EBTIDA/Interests was 2.8 x, when it was required to be equal or above 3.0x

· Debt/EBITDA was 2.7x, when it was required to be equal or less than 2.5x

Cemig D and Cemig obtained a waiver from Santander Bank on December 18, 2012.

As of December 31, 2012, we were in non-compliance with some ratios contained in a credit instrument among Cemig Distribution and Banco ItaúBBA. Such ratios were the following:

Cemig D

· Debt/EBTIDA was 4.58x, when it was required to be equal or less than 3.36x

· Debt/(Shareholder’s equity + Debt) was 65.2%, when it was required to be equal or less than 62%

· Short term Debt/EBITDA was 266.1%, when it was required to be equal or less than 200%

· Capex/EBITDA was 120.2%, when it was required to be equal or less than 96%

The company had obtained the waiver from Banco ItaúBBA on December 18, 2012, considering preliminary figures and some actual figures ended up being not compatible with the obtained waiver. As another waiver was not obtained prior to December 31, 2012, not only the loan, but pthers with cross-default conditions had to be recognized as a current liability as contracts whose terms have not been met are recognized in current liabilities. The amount transferred to current liabilities as a result of non-compliance with the covenant was R$ 1,206 million. The waiver is expected to be obtained in May/2013.

Item 14. Material Modifications to the Rights of Security Holders and Use of Proceeds

Not applicable.

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Item 15. Controls and Procedures

(a) Evaluation of Disclosure Controls and Procedures

Our Executive Board, including our Chief Executive Officer, or CEO, and Chief Financial and Investor Relations Officer, or CFO, evaluated the effectiveness of our disclosure controls and procedures, and concluded that on December 31, 2012, these disclosure controls and procedures were effective to provide reasonable assurance that information required to be disclosed in our filings and submissions under the Exchange Act is (i) recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and (ii) accumulated and communicated to our management, including our CEO and CFO, as appropriate to allow timely decisions regarding required disclosure.

(b) Management’s Annual Report on Internal Control related to Financial Reporting

Our Executive Board, including our CEO and CFO, is responsible for establishing and maintaining effective internal controls over financial reporting.

Our internal controls over financial reporting include policies and procedures that were implemented to provide reasonable assurance as to (i) the reliability of the recording accounting and financial information; (ii) the preparation of accounting records in accordance with IFRS; (iii) the processing of payments and receipts in accordance with management authorization; and (iv) the timely detection of inappropriate acquisitions, and the disposal or allocation of material assets. We emphasize that due to their inherent limitations, the possibility exists that these actions may not prevent or detect misstatements. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or non compliant with the policies or procedures.

Our management evaluated the effectiveness of our internal controls over financial reporting at December 31, 2012, based on the criteria established in the Integrated Internal Control Framework specified by the Committee of Sponsoring Organizations of the Treadway Commission, or COSO, and concluded that, for the year ended December 31, 2012, our system of internal controls over financial reporting is effective.

The Company’s independent registered public accounting firm which audited our consolidated financial statements for the year ended December 31, 2012, Deloitte Touche Tohmatsu Auditores Independentes, has audited the effectiveness of the Company’s internal control over financial reporting as of December 31, 2012 and issued an attestation report, which is included below.

The Ethics Committee

Our Ethics Committee was established on August 12, 2004, and is made up of three permanent members and three alternate members. It is responsible for the management, dissemination and updating of the Statement of Ethical Principles and Code of Professional Conduct.

The Committee receives and investigates all reports of violation of the ethical principles and standards of conduct Specifically with regard to ethical principles, these should be presented with the identification of the interested party. Complaints or doubts should be addressed to: CEMIG, Av. Barbacena 1200, S.A. - 19th Floor/A1. The Committee may also be contacted by e-mail comissaodeetica@cemig.com.br.

In December 2006 we implemented the Anonymous Reporting Channel, available on our intranet. The purpose of this portal is to receive, anonymously, complaints or denunciations of irregular practices, such as financial fraud, misappropriation of assets, receipt of unfair advantages, and the engagement of illegal contracts. This channel aims to improve transparency, correction of unethical or illegal behavior, corporate governance, as well as being an instrument that meets the requirements of the Sarbanes-Oxley Act.

(c) Attestation Report of the Registered Public Accounting Firm

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of
Companhia Energética de Minas Gerais - CEMIG
Belo Horizonte, MG, Brazil

We have audited the internal control over financial reporting of Companhia Energética de Minas Gerais – CEMIG and subsidiaries (the “Company”) as of December 31, 2012, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Annual Report on Form 20-F. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

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A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with International Financial Reporting Standards (IFRS), as issued by the International Accounting Standards Board (IASB). A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with International Financial Reporting Standards (IFRS), as issued by the International Accounting Standards Board (IASB) and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2012, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements of the Company as of and for the year ended December 31, 2012 and our report dated April 26, 2013 expressed an unqualified opinion on those financial statements and included explanatory paragraphs regarding: (i) the fact that the depreciation rates relating to property plant and equipment of generation activities under the regulation for independent producers and realization of certain concession financial assets related to distribution of gas are estimated considering facts and circumstances mentioned on notes 2.6 (h) and 13. As new information becomes available or decisions are taken by the granting authorities, the depreciation rates relating to property plant and equipment or realization of certain concession financial assets related to distribution of gas may change; and (ii) the fact that the Madeira Energia S.A. joint venture has presented recurring losses and negative working capital, and, as of the date of the report, Madeira Energia S.A. depends on either its shareholders’ financial support or on issuance of additional debt securities to continue to operate.

/s/ Deloitte Touche Tohmatsu Auditores Independentes

Belo Horizonte, MG, Brazil

April 26, 2013

(d) Changes in Internal Control over Financial Reporting

There has been no change in our system of internal control over financial reporting during the year ended December 31, 2012 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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Item 16.

Item 16A. Audit Committee Financial Expert

Our Fiscal Council acts as our audit committee for purposes of the Sarbanes-Oxley Act of 2002. Under Section 10A-3 of the SEC rules on Audit Committees of listed companies, non-U.S. issuers are permitted not to have a separate Audit Committee made up of independent members if there is a Fiscal Council established and chosen in accordance with the legal rules of its origin country, expressly requiring or allowing that such council follow certain obligations. Also in accordance with this exemption, a Fiscal Council may exercise the obligations and responsibilities of an Audit Committee of the United States up to the limit permitted by Brazilian law. The financial experts of our Fiscal Council are Mr. Helton da Silva Soares and Mr. Ari Barcelos da Silva.

Item 16B. Code of Ethics

We have adopted a code of ethics, as defined in Item 16B of Form 20-F under the Exchange Act. Our code of ethics applies to our Chief Executive Officer, Chief Financial and Investor Relations Officer and persons performing similar functions as well as to our directors and other officers and employees. Our code of ethics was filed with the SEC as Exhibit 11 to our Annual Report on Form 20-F for the fiscal year ended December 31, 2003, and is also available on our website at www.cemig.com.br. If we amend the provisions of our code of ethics that apply to our Chief Executive Officer, Chief Financial Officer and persons performing similar functions, or if we grant any waiver of such provisions, we will disclose such amendment or waiver within five business days following the date of the amendment or waiver on our web site at www.cemig.com.br.

Item 16C. Principal Accountant Fees and Services

Audit and Non-Audit Fees

The following table summarizes the aggregate fees billed to us by Deloitte Touche Tohmatsu Auditores Independentes during the fiscal year ended December 31, 2012 and by KPMG Auditores Independentes during the fiscal years ended December 31, 2012 and 2011:

|  |  | Year ended December 31,
| 2012(DTT) |  | 2012(KPMG) |  | 2011
|  |  | (thousands of reais)
Audit fees | 686 |  | 123 |  | 624
Additional services: |  |  |  |  |
Diagnosis and assesment of internal controls –SOX | 56 |  | 150 |  | 255
Tax Fees | 23 |  | 6 |  | 121
Audit-Related Fees | - |  | 7 |  | 302
R&D Projects | - |  | - |  | 25
Translation of reports | 2 |  | - |  | 9
Training related to tax regulation | - |  | - |  | 6
Technical Report related to Financial Project | - |  | - |  | 16
Total fees | 767 |  | 286 |  | 1,358

Audit fees — Audit fees in the above table are the aggregate fees billed by Deloitte Touche Tohmatsu Auditores Independentes in 2012 and KPMG Auditores Independentes in 2012 and 2011 in connection with the audit of our annual financial statements prepared in accordance with the accounting practices adopted in Brazil and the review of our quarterly statutory financial statements.

Tax Fees — Tax fees are fees for professional services in relation to tax return reviews (tax compliance).

Audit-Related Fees — Audit-related fees are fees for services in connection with regulatory demands.

Audit Committee Pre-Approval Policies and Procedures

Our Fiscal Council currently serves as our audit committee for purposes of the Sarbanes-Oxley Act of 2002. However, as required by Brazilian legislation, we have adopted pre-approval policies and procedures by which all audit and non-audit services provided by external auditors must be approved by the Board of Directors. Any service proposals submitted by external auditors need to be discussed and approved by the Board of Directors during its meetings. Once the proposed service is approved, we formalize the

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engagement of services. The approval of any audit and non-audit services to be provided by our external auditors is specified in the minutes of our Board of Directors.

Item 16D. Exemptions from the Listing Standards for Audit Committees

We are relying on the general exemption from the listing standards relating to audit committees contained in Rule 10A-3(c)(3) under the Exchange Act. We have a Fiscal Council that carries out the functions of an audit committee of the United States to the extent permitted under Brazilian law. Brazilian law requires our Fiscal Council to be separate from our board of directors, and members of our Fiscal Council are not elected by our management. Brazilian law provides standards for the independence of our Fiscal Council from our management.

We do not believe that our reliance on this general exemption will materially affect the ability of our Fiscal Council to act independently and to satisfy the other requirements of the listing standards relating to audit committees contained in Rule 10A-3 under the Exchange Act.

Item 16E. Purchases of Equity Securities by the Issuer and Affiliated Purchasers

Not applicable.

Item 16F. Change in Registrant’s Certifying Accountant

KPMG Auditores Independentes was appointed to act as our independent public accounting firm for a five-year period to audit our consolidated financial statements for the fiscal years ended December 31, 2007, 2008, 2009, 2010 and 2011. Pursuant to CVM regulations, Brazilian public companies are required to rotate their independent public accounting firm every five years.

Due to the limitations set forth in these regulations, we did not seek to renew KPMG’s contract when it expired and KPMG could not attempt to stand for reelection. On December 9, 2011, our Board of Directors approved the bidding process for the selection of the new auditor, which resulted in the appointment of Deloitte Touche Tohmatsu Auditores Independents. Deloitte Touche Tohmatsu Auditores Independentes began to act as our independent public accounting firm with respect to the review of our quarterly information for the second quarter of 2012.

KPMG Auditores Independentes’s reports on our financial statements for the each of the five fiscal years ended on December 31, 2007, 2008, 2009, 2010 and 2011 did not contain an adverse opinion or disclaimer of opinion, nor was it qualified or modified as to uncertainty, audit scope or accounting principles. During such five fiscal years, there were no disagreements with KPMG Auditores Independentes, whether or not resolved, on any matter of accounting principles or practices, financial statement disclosure, or scope of audit procedures, which disagreement, if not resolved to the satisfaction of KPMG Auditores Independentes, would have caused KPMG Auditores Independentes to make a reference to the subject matter of the disagreement in connection with its audit reports for such fiscal years.

We have requested KPMG Auditores Independentes to furnish us with a letter addressed to the SEC stating whether or not it agrees with the above statements. A copy of this letter is filed as Exhibit 4.34 to this Form 20-F.

We did not consult Deloitte Touche Tohmatsu Auditores Independentes during our two most recent fiscal years or any subsequent interim period as to the application of accounting principles to a specified transaction, either completed or proposed, the type of audit opinion that might be rendered on our financial statements or any matter that was either the subject of a disagreement (as defined in Item 16F(a)(1)(iv) of Form 20-F) or a reportable event (as described in Item 16F(a)(1)(v) of Form 20-F).

Item 16G. Corporate Governance

Corporate Governance Differences from NYSE Practices

On November 4, 2003, the New York Stock Exchange, or NYSE, established new corporate governance rules. Under the rules, foreign private issuers are subject to a more limited set of corporate governance requirements than U.S. domestic issuers. Under these rules, we are required to set forth in our annual report to shareholders a description of the significant differences between CEMIG’s corporate governance practices and those that would apply to a U.S. domestic issuer under the NYSE corporate governance rules. The following table summarizes these differences.

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Section |  | NYSE Corporate Governance Rule for U.S. Domestic Issuers |  | Our Approach
303A.01 |  | A listed company must have a majority of independent directors. “Controlled companies” are not required to comply with this requirement. |  | Under Section 303A of the rules of the New York Stock Exchange, “controlled company” is taken to include a company in which more than 50% of the voting power is held by one individual, a group or another company. Since 50.97% of the voting stock of CEMIG is held by the State of Minas Gerais, it is considered to be a controlled company. Therefore, this requirement currently does not apply to CEMIG.
303A.03 |  | The non-management directors of a listed company must meet at regularly scheduled executive sessions without management. |  | The non-management directors of CEMIG do not meet at regularly scheduled executive sessions without management.
303A.04 |  | A listed company must have a nominating/corporate governance committee composed entirely of independent directors, with a written charter that covers certain minimum specified duties. “Controlled companies” are not required to comply with this requirement. |  | As a controlled company, CEMIG is not required to have a nominating/governance committee. Nonetheless, CEMIG has a Corporate Governance Committee, composed of dependent and independent directors, and its responsibilities are clearly defined in the internal regulations of the Board of Directors.
303A.05 |  | A listed company must have a compensation committee composed entirely of independent directors, with a written charter that covers certain minimum specified duties. “Controlled companies” are not required to comply with this requirement. |  | As a controlled company, CEMIG would not be required to comply with the compensation committee requirements as if it were a U.S. domestic issuer. CEMIG does not have a compensation committee.
303A.06 and 303A.07 |  | A listed company must have an audit committee with a minimum of three independent directors that satisfy the independence requirements of Rule 10A-3 under the Securities Exchange Act of 1934, as amended, with a written charter that covers certain minimum specified duties. |  | CEMIG exercised its prerogative under SEC Rule 10A-3 and the Sarbanes Oxley Act of 2002, which allow non U.S. issuers not to have an Audit Committee. Our Fiscal Council carries out the functions of an Audit Committee of the United States up to the limit permitted by Brazilian law.
|  |  |  | CEMIG’s Fiscal Council is a permanent body, responsible, principally, for inspection and supervision of the activities of the management and for verifying the managers’ compliance with their duties under the law and under the by-laws.
303A.08 |  | Shareholders must be given the opportunity to vote on all equity-compensation plans and material revisions thereto, with limited exemptions set forth in the NYSE rules. |  | Under Brazilian Corporate Law, shareholder preapproval is required for the adoption of equity compensation plans.
303A.09 |  | A listed company must adopt and disclose corporate governance guidelines that cover certain minimum specified subjects. |  | CEMIG’s listing on BM&FBovespa is at Corporate Governance Level 1, and CEMIG is thus obliged to comply with the rules contained in those related regulations. In addition, CEMIG’s Manual for Disclosure and Use of Information, its Securities Trading Policy, the Internal Regulations of its Board of Directors, and its Code of Ethics outline important rules of corporate governance which orient its management.
303A.12 |  | Each listed company Chief Executive Officer must certify to the NYSE each year that he or she is not aware of any violation by the company of NYSE corporate governance listing standards. |  | CEMIG’s Chief Executive Officer will promptly notify the NYSE in writing after any executive officer of CEMIG becomes aware of any material non-compliance with any applicable provisions of the NYSE corporate governance rules.

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PART III

Item 17. Financial Statements

Not applicable.

Item 18. Financial Statements

Reference is made to pages F-1 through F-129 hereof.

The following financial statements are filed as part of this annual report on Form 20-F:

· Report of Deloitte Touche Tohmatsu Auditores Independentes for the year ended December 31, 2012;

· Report of KPMG Auditores Independentes for the years ended December 31, 2011 and December 31, 2010;

· Audited Consolidated Statement of Financial Position as of December 31, 2012 and December 31, 2011;

· Audited Consolidated Income Statement and Statements of Comprehensive Income for the years ended December 31, 2012, 2011 and 2010;

· Audited Consolidated Statements of Changes in Shareholders’ Equity for the years ended December 31, 2012, 2011 and 2010;

· Audited Consolidated Statements of Cash Flows for the years ended December 31, 2012, 2011 and 2010; and

· Notes to the Consolidated Financial Statements

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Item 19. Exhibits

The following documents are included as exhibits to this annual report:

Exhibit Number |  | Document
1 |  | Corporate by-laws of CEMIG, as amended and in effect since April 27, 2012.
2.1 |  | Second Amended and Restated Deposit Agreement, dated as of August 10, 2001, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of ADSs evidenced by ADRs issued thereunder (incorporated by reference to the Registration Statement on Form F-6 relating to the ADSs filed on August 20, 2001 (File No. 333-13826)).
2.2 |  | Shareholders’ Agreement, dated June 18, 1997, between the State Government and Southern, relating to the rights and obligations of owners of our shares (incorporated by reference to Exhibit 2.1 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
2.3 |  | Amendment No. 1 to the Second Amended and Restated Deposit Agreement, dated as of August 10, 2001, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of ADSs evidenced by ADRs issued thereunder (incorporated by reference to the Registration Statement on Form F-6 relating to the ADSs filed on June 11, 2007 (File No. 333-143636)).
2.4 |  | Deposit Agreement, dated as of June 12, 2007, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of ADSs evidenced by ADRs issued thereunder (incorporated by reference to the Registration Statement on Form F-6 relating to the common share ADSs filed on May 7, 2007 (File No. 333-142654)).
4.1 |  | Contract of Concession for Generating Electric Energy, dated July 10, 1997, between the Federal Government and us, relating to the provision of electric energy generation services to the public (incorporated by reference to Exhibit 4.1 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
4.2 |  | Contract of Concession of Electric Energy Transmission Services, dated July 10, 1997, between the Federal Government and us, relating to the transmission of electric energy to the public (incorporated by reference to Exhibit 4.2 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
4.3 |  | Second Amendment to the Electricity Transmission Concession Contract, dated September 16, 2005 (incorporated by reference to Exhibit 4.3 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.4 |  | Third Amendment to the Electricity Transmission Concession Contract, for the Northern, Southern, Eastern, and Western geographic areas, dated April 13, 2010 (incorporated by reference to Exhibit 4.4 to our Registration Statement on Form 20-F filed on June 30, 2010 (File No. 1-15224)).
4.5 |  | Contracts of Concession of Public Service for Distribution of Electric Energy, dated July 10, 1997, between the Federal Government and us, relating to the provision of electric energy distribution services to the public (incorporated by reference to Exhibit 4.3 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
4.6 |  | First Amendment to the Electricity Distribution Concession Contract, dated March 31, 2005 (incorporated by reference to Exhibit 4.5 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.7 |  | Second Amendment to the Electricity Distribution Concession Contract, dated September 16, 2005 (incorporated by reference to Exhibit 4.6 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.8 |  | Contract for the Assignment of CRC Account, dated May 31, 1995, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.4 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
4.9 |  | First Amendment to the Contract for the Assignment of CRC Account, dated February 24, 2001, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.5 to our Annual Report on Form 20-F filed on March 26, 2003 (File No. 1-15224)).

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Exhibit Number |  | Document
4.10 |  | Second Amendment to the Contract for the Assignment of CRC Account, dated October 14, 2002, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.6 to our Annual Report on Form 20-F filed on March 26, 2003 (File No. 1-15224)).
4.11 |  | Third Amendment to the Contract for the Assignment of CRC Account, dated October 24, 2002, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.7 to our Annual Report on Form 20-F filed on March 26, 2003 (File No. 1-15224)).
4.12 |  | Fourth Amendment to the Contract for the Assignment of CRC Account, dated January 23, 2006, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.14 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.13 |  | Announcement of Start of Public Distribution of Senior Units under CRC Account Securitization Fund, dated as of January 26, 2006 (incorporated by reference to Exhibit 4.15 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.14 |  | Summary of Indenture Covering Public Distribution of Non-Convertible Unsecured Debentures, dated August 24, 2006, between Cemig Distribution and Unibanco—União dos Bancos Brasileiros S.A. (incorporated by reference to Exhibit 4.18 to our Registration Statement on Form 20-F filed on July 23, 2007 (File No. 1-15224)).
4.15 |  | Summary of Indenture Covering Public Distribution of Non-Convertible Unsecured Debentures, dated April 17, 2007, between Cemig Generation and Transmission and Unibanco—União dos Bancos Brasileiros S.A. (incorporated by reference to Exhibit 4.19 to our Registration Statement on Form 20-F filed on July 23, 2007 (File No. 1-15224)).
4.16 |  | Summary of Indenture Covering the Second Issuance of Debentures, dated December 19, 2007, between Cemig Distribution and BB Banco de Investimento S.A. (incorporated by reference to Exhibit 4.20 to our Annual Report on Form 20-F filed on June 30, 2008 (File No. 1-15224)).
4.17 |  | Share Purchase Agreement, dated April 23, 2009, between Cemig Generation and Transmission, Terna—Rete Elettrica Nazionale S.p.A., and CEMIG (incorporated by reference to Exhibit 4.22 to our Registration Statement on Form 20-F filed on June 19, 2009 (File No. 1-15224)).
4.18 |  | English Summary of Share Purchase Agreement between Companhia Energética de Minas Gerais – CEMIG and Andrade Gutierrez Concessões S.A., dated December 30, 2009 (incorporated by reference to Exhibit 4.18 to our Registration Statement on Form 20-F filed on June 30, 2010 (File No. 1-15224)).
4.19 |  | English Summary of Share Purchase Agreement between Companhia Energética de Minas Gerais – CEMIG and Fundo de Investimento em Participações PCP, dated December 31, 2009 (incorporated by reference to Exhibit 4.19 to our Registration Statement on Form 20-F filed on June 30, 2010 (File No. 1-15224)).
4.20 |  | English Summary of Put Option Agreement between Companhia Energética de Minas Gerais – CEMIG and Enlighted Partners Venture Capital LLC, dated March 24, 2010 (incorporated by reference to Exhibit 4.20 to our Registration Statement on Form 20-F filed on June 30, 2010 (File No. 1-15224)).
4.21 |  | English Summary of Share Purchase Agreement among Transmissora Aliança de Energia Elétrica S.A., Abengoa Concessões Brasil Holding S.A. and Abengoa Participações Holding S.A., dated June 2, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.22 |  | English Summary of Share Purchase Agreement among Transmissora Aliança de Energia Elétrica S.A., Abengoa Concessões Brasil Holding S.A., Abengoa Construção Brasil Ltda., NTE - Nordeste Transmissora de Energia S.A. and Abengoa Participações Holding S.A., dated June 2, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.23 |  | Summary of Indenture Covering Public Distribution of Non-Convertible Unsecured Debentures, dated March 3, 2010, between Cemig Generation and Transmission and BB – Banco de Investimento S.A. (incorporated by reference to Exhibit 4.23 to our Annual Report on Form 20-F filed on June 30, 2011 (File No. 1-15224)).

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Exhibit Number |  | Document
4.24 |  | English Summary of Share Purchase Agreement between Transmissora Aliança de Energia Elétrica S.A. and Abengoa Concessões Brasil Holding S.A. dated March 16, 2012 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.25 |  | English Summary of Investment Agreement among RR Participações S.A., Light S.A. and Renova Energia S.A. dated July 8, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.26 |  | English Summary of Put Option Agreement between Parati S.A and Fundação de Seguridade Social Braslight dated July 15, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.27 |  | English Summary of Share Purchase and Sale Agreement entered into between Amazônia Energia Participações S.A. and Construtora Queiroz Galvão S.A., Construtora OAS Ltda., Contern Construções e Comércio Ltda, Cetenco Engenharia S.A., Galvão Engenharia S.A. and J. Malucelli Construtora de Obras S.A., for shares in Norte Energia S.A. dated October 25, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.28 |  | English Summary of Share Acquisition Agreement between CEMIG and the State of Minas Gerais dated December 27, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.29 |  | Summary of Indenture Covering the Public Distribution of Non-Convertible Unsecured Debentures, dated March 13, 2012, between Cemig Geração e Transmissão S.A., HSBC Corretora de Títutlos e Valores Mobiliários S.A., Banco BTG Pactual S.A. and Banco do Nordeste do Brasil S.A. (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.30 |  | Initial Announcement of Public Distribution, under the Regime of Firm Guarantee of Placement, of Unsecured Debentures Not Convertible into Shares, with Additional Guarantee, in Three Series, of the Third Issue by Cemig Distribuição S.A., dated March 19, 2012.
4.31 |  | Initial Announcement of Public Distribution, under the Regime of Best Efforts for Placement, of Unsecured Debentures Not Convertible into Shares, with Additional Guarantee, in up to Three Series, of the Third Issue by Cemig Geração e Transmissão S.A., dated March 12, 2012.
4.32 |  | Summary of Private Contract for Investment in Transmission Assets, among Companhia Energética de Minas Gerais –Cemig, Cemig Geração e Transmissão S.A. e Trasmissora Aliança de Energia Elétrica S.A. dated May 17, 2012.
4.33 |  | Summary of the Share Purchase Agreement between Cemig Capim Branco Energia S.A., Suzano Papel e Celulose S.A., and Suzano Holding S.A., internening by Comercial Agrícola Paineiras LTDA (“Paineiras”) e Epícares Empreendimentos e Participações LTDA (“Epícares”), dated March 12, 2013.
4.34 |  | Letter of KPMG Auditores Independentes furnished to the SEC addressing the auditors rotation as per Item 16F(a)(1)(v) of Form 20-F, dated April 29, 2013.
4.35 |  | Summary of the Commitment Undertaking for Settlement, signed between the State of Minas Gerais and Companhia Energética de Minas Gerais – CEMIG, dated November 22, 2012.
8 |  | List of Subsidiaries (incorporated by reference to Exhibit 8 to our Annual Report on Form 20-F filed on May 25, 2005 (File No. 1-15224)).
11 |  | Code of Ethics (incorporated by reference to Exhibit 11 to our Annual Report on Form 20-F filed on July 1, 2004 (File No. 1-15224)).
12.1 |  | Chief Executive Officer Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated April 29, 2013.
12.2 |  | Chief Officer for Finance and Investor Relations Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated April 29, 2013.
13.1 |  | Chief Executive Officer Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated April 29, 2013.
13.2 |  | Chief Officer for Finance and Investor Relations Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated April 29, 2013.

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SIGNATURES

The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused and authorized the undersigned to sign this annual report on its behalf.

| COMPANHIA ENERGÉTICA DE MINAS GERAIS–CEMIG
| By: | /s/ Djalma Bastos de Morais
| Name: Djalma Bastos de Morais
| Title: Chief Executive Officer

Date: April 29, 2013

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Exhibit Index

Exhibit Number |  | Document
1 |  | Corporate by-laws of CEMIG, as amended and in effect since April 27, 2012.
2.1 |  | Second Amended and Restated Deposit Agreement, dated as of August 10, 2001, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of ADSs evidenced by ADRs issued thereunder (incorporated by reference to the Registration Statement on Form F-6 relating to the ADSs filed on August 20, 2001 (File No. 333-13826)).
2.2 |  | Shareholders’ Agreement, dated June 18, 1997, between the State Government and Southern, relating to the rights and obligations of owners of our shares (incorporated by reference to Exhibit 2.1 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
2.3 |  | Amendment No. 1 to the Second Amended and Restated Deposit Agreement, dated as of August 10, 2001, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of ADSs evidenced by ADRs issued thereunder (incorporated by reference to the Registration Statement on Form F-6 relating to the ADSs filed on June 11, 2007 (File No. 333-143636)).
2.4 |  | Deposit Agreement, dated as of June 12, 2007, by and among us, Citibank, N.A., as depositary, and the holders and beneficial owners of ADSs evidenced by ADRs issued thereunder (incorporated by reference to the Registration Statement on Form F-6 relating to the common share ADSs filed on May 7, 2007 (File No. 333-142654)).
4.1 |  | Contract of Concession for Generating Electric Energy, dated July 10, 1997, between the Federal Government and us, relating to the provision of electric energy generation services to the public (incorporated by reference to Exhibit 4.1 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
4.2 |  | Contract of Concession of Electric Energy Transmission Services, dated July 10, 1997, between the Federal Government and us, relating to the transmission of electric energy to the public (incorporated by reference to Exhibit 4.2 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
4.3 |  | Second Amendment to the Electricity Transmission Concession Contract, dated September 16, 2005 (incorporated by reference to Exhibit 4.3 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.4 |  | Third Amendment to the Electricity Transmission Concession Contract, for the Northern, Southern, Eastern, and Western geographic areas, dated April 13, 2010 (incorporated by reference to Exhibit 4.4 to our Registration Statement on Form 20-F filed on June 30, 2010 (File No. 1-15224)).
4.5 |  | Contracts of Concession of Public Service for Distribution of Electric Energy, dated July 10, 1997, between the Federal Government and us, relating to the provision of electric energy distribution services to the public (incorporated by reference to Exhibit 4.3 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
4.6 |  | First Amendment to the Electricity Distribution Concession Contract, dated March 31, 2005 (incorporated by reference to Exhibit 4.5 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.7 |  | Second Amendment to the Electricity Distribution Concession Contract, dated September 16, 2005 (incorporated by reference to Exhibit 4.6 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.8 |  | Contract for the Assignment of CRC Account, dated May 31, 1995, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.4 to our Registration Statement on Form 20-F filed on August 13, 2001 (File No. 1-15224)).
4.9 |  | First Amendment to the Contract for the Assignment of CRC Account, dated February 24, 2001, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.5 to our Annual Report on Form 20-F filed on March 26, 2003 (File No. 1-15224)).
4.10 |  | Second Amendment to the Contract for the Assignment of CRC Account, dated October 14, 2002, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.6

Table of Contents

Exhibit Number |  | Document
|  | to our Annual Report on Form 20-F filed on March 26, 2003 (File No. 1-15224)).
4.11 |  | Third Amendment to the Contract for the Assignment of CRC Account, dated October 24, 2002, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.7 to our Annual Report on Form 20-F filed on March 26, 2003 (File No. 1-15224)).
4.12 |  | Fourth Amendment to the Contract for the Assignment of CRC Account, dated January 23, 2006, between the State Government and us, relating to amounts due to us from the State Government (incorporated by reference to Exhibit 4.14 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.13 |  | Announcement of Start of Public Distribution of Senior Units under CRC Account Securitization Fund, dated as of January 26, 2006 (incorporated by reference to Exhibit 4.15 to our Registration Statement on Form 20-F filed on June 30, 2006 (File No. 1-15224)).
4.14 |  | Summary of Indenture Covering Public Distribution of Non-Convertible Unsecured Debentures, dated August 24, 2006, between Cemig Distribution and Unibanco—União dos Bancos Brasileiros S.A. (incorporated by reference to Exhibit 4.18 to our Registration Statement on Form 20-F filed on July 23, 2007 (File No. 1-15224)).
4.15 |  | Summary of Indenture Covering Public Distribution of Non-Convertible Unsecured Debentures, dated April 17, 2007, between Cemig Generation and Transmission and Unibanco—União dos Bancos Brasileiros S.A. (incorporated by reference to Exhibit 4.19 to our Registration Statement on Form 20-F filed on July 23, 2007 (File No. 1-15224)).
4.16 |  | Summary of Indenture Covering the Second Issuance of Debentures, dated December 19, 2007, between Cemig Distribution and BB Banco de Investimento S.A. (incorporated by reference to Exhibit 4.20 to our Annual Report on Form 20-F filed on June 30, 2008 (File No. 1-15224)).
4.17 |  | Share Purchase Agreement, dated April 23, 2009, between Cemig Generation and Transmission, Terna—Rete Elettrica Nazionale S.p.A., and CEMIG (incorporated by reference to Exhibit 4.22 to our Registration Statement on Form 20-F filed on June 19, 2009 (File No. 1-15224)).
4.18 |  | English Summary of Share Purchase Agreement between Companhia Energética de Minas Gerais – CEMIG and Andrade Gutierrez Concessões S.A., dated December 30, 2009 (incorporated by reference to Exhibit 4.18 to our Registration Statement on Form 20-F filed on June 30, 2010 (File No. 1-15224)).
4.19 |  | English Summary of Share Purchase Agreement between Companhia Energética de Minas Gerais – CEMIG and Fundo de Investimento em Participações PCP, dated December 31, 2009 (incorporated by reference to Exhibit 4.19 to our Registration Statement on Form 20-F filed on June 30, 2010 (File No. 1-15224)).
4.20 |  | English Summary of Put Option Agreement between Companhia Energética de Minas Gerais – CEMIG and Enlighted Partners Venture Capital LLC, dated March 24, 2010 (incorporated by reference to Exhibit 4.20 to our Registration Statement on Form 20-F filed on June 30, 2010 (File No. 1-15224)).
4.21 |  | English Summary of Share Purchase Agreement among Transmissora Aliança de Energia Elétrica S.A., Abengoa Concessões Brasil Holding S.A. and Abengoa Participações Holding S.A., dated June 2, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.22 |  | English Summary of Share Purchase Agreement among Transmissora Aliança de Energia Elétrica S.A., Abengoa Concessões Brasil Holding S.A., Abengoa Construção Brasil Ltda., NTE - Nordeste Transmissora de Energia S.A. and Abengoa Participações Holding S.A., dated June 2, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.23 |  | Summary of Indenture Covering Public Distribution of Non-Convertible Unsecured Debentures, dated March 3, 2010, between Cemig Generation and Transmission and BB – Banco de Investimento S.A. (incorporated by reference to Exhibit 4.23 to our Annual Report on Form 20-F filed on June 30, 2011 (File No. 1-15224)).
4.24 |  | English Summary of Share Purchase Agreement between Transmissora Aliança de Energia Elétrica S.A. and Abengoa Concessões Brasil Holding S.A. dated March 16, 2012 (incorporated by reference to the Form 20-F filed on April 27,

Table of Contents

Exhibit Number |  | Document
|  | 2012 (File No. 1-15224)).
4.25 |  | English Summary of Investment Agreement among RR Participações S.A., Light S.A. and Renova Energia S.A. dated July 8, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.26 |  | English Summary of Put Option Agreement between Parati S.A and Fundação de Seguridade Social Braslight dated July 15, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.27 |  | English Summary of Share Purchase and Sale Agreement entered into between Amazônia Energia Participações S.A. and Construtora Queiroz Galvão S.A., Construtora OAS Ltda., Contern Construções e Comércio Ltda, Cetenco Engenharia S.A., Galvão Engenharia S.A. and J. Malucelli Construtora de Obras S.A., for shares in Norte Energia S.A. dated October 25, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.28 |  | English Summary of Share Acquisition Agreement between CEMIG and the State of Minas Gerais dated December 27, 2011 (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.29 |  | Summary of Indenture Covering the Public Distribution of Non-Convertible Unsecured Debentures, dated March 13, 2012, between Cemig Geração e Transmissão S.A., HSBC Corretora de Títutlos e Valores Mobiliários S.A., Banco BTG Pactual S.A. and Banco do Nordeste do Brasil S.A. (incorporated by reference to the Form 20-F filed on April 27, 2012 (File No. 1-15224)).
4.30 |  | Initial Announcement of Public Distribution, under the Regime of Firm Guarantee of Placement, of Unsecured Debentures Not Convertible into Shares, with Additional Guarantee, in Three Series, of the Third Issue by Cemig Distribuição S.A., dated March 19, 2012.
4.31 |  | Initial Announcement of Public Distribution, under the Regime of Best Efforts for Placement, of Unsecured Debentures Not Convertible into Shares, with Additional Guarantee, in up to Three Series, of the Third Issue by Cemig Geração e Transmissão S.A., dated March 12, 2012.
4.32 |  | Summary of Private Contract for Investment in Transmission Assets, among Companhia Energética de Minas Gerais –Cemig, Cemig Geração e Transmissão S.A. e Trasmissora Aliança de Energia Elétrica S.A. dated May 17, 2012.
4.33 |  | Summary of the Share Purchase Agreement between Cemig Capim Branco Energia S.A., Suzano Papel e Celulose S.A., and Suzano Holding S.A., internening by Comercial Agrícola Paineiras LTDA (“Paineiras”) e Epícares Empreendimentos e Participações LTDA (“Epícares”), dated March 12, 2013.
4.34 |  | Letter of KPMG Auditores Independentes furnished to the SEC addressing the auditors rotation as per Item 16F(a)(1)(v) of Form 20-F, dated April 29, 2013.
4.35 |  | Summary of the Commitment Undertaking for Settlement, signed between the State of Minas Gerais and Companhia Energética de Minas Gerais – CEMIG, dated November 22, 2012.
8 |  | List of Subsidiaries (incorporated by reference to Exhibit 8 to our Annual Report on Form 20-F filed on May 25, 2005 (File No. 1-15224)).
11 |  | Code of Ethics (incorporated by reference to Exhibit 11 to our Annual Report on Form 20-F filed on July 1, 2004 (File No. 1-15224)).
12.1 |  | Chief Executive Officer Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated April 29, 2013.
12.2 |  | Chief Officer for Finance and Investor Relations Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated April 29, 2013.
13.1 |  | Chief Executive Officer Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated April 29, 2013.
13.2 |  | Chief Officer for Finance and Investor Relations Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated April 29, 2013.

Table of Contents

| Companhia Energética de Minas Gerais – CEMIG
| Financial Statements as of December 31, 2012, December 2011 and January 1, 2011 and for the Years Ended December 31, 2012, 2011 and 2010 and Report of Independent Registered Public Accounting Firms

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CONSOLIDATED STATEMENT OF FINANCIAL POSITION

AS OF DECEMBER 31, 2012 AND 2011 AND JANUARY 1, 2011

ASSETS

(MILLIONS OF R$)

|  | Notes |  | 2012 |  | 2011 Reclassified |  | 01/01/2011 Reclassified |
CURRENT |  |  |  |  |  |  |  |  |
Cash and cash equivalents |  | 6 |  | 2,486 |  | 2,862 |  | 2,980 |
Securities |  | 7 |  | 1,558 |  | 359 |  | 322 |
Consumers and traders |  | 8 |  | 2,347 |  | 2,550 |  | 2,263 |
Concession holders – transport of energy |  |  |  | 505 |  | 427 |  | 401 |
Financial assets of the concession |  | 13 |  | 1,041 |  | 1,120 |  | 625 |
Recoverable taxes |  | 9 |  | 360 |  | 354 |  | 374 |
Recoverable income and social contribuion taxes |  | 10a |  | 263 |  | 221 |  | 490 |
Traders – free energy transactions |  |  |  | 21 |  | 22 |  | 30 |
Restricted cash |  |  |  | 132 |  | 3 |  | 14 |
Inventories |  |  |  | 68 |  | 54 |  | 41 |
Provision for gain on financial instruments |  |  |  | 32 |  | - |  | - |
Account receivable from the State of Minas Gerais Government |  |  |  | 2,422 |  | - |  | - |
Other credits |  |  |  | 755 |  | 560 |  | 546 |
TOTAL, CURRENT |  |  |  | 11,990 |  | 8,532 |  | 8,086 |
NON-CURRENT |  |  |  |  |  |  |  |  |
Securities |  | 7 |  | 162 |  | - |  | - |
Account receivable from the State of Minas Gerais Government |  | 12 |  | - |  | 1,830 |  | 1,837 |
Deferred income and social contribution taxes |  | 10b |  | 1,452 |  | 1,236 |  | 1,218 |
Recoverable taxes |  | 9 |  | 445 |  | 328 |  | 140 |
Recoverable income and social contribution taxes |  | 10a |  | 34 |  | 23 |  | 83 |
Escrow deposits |  | 11 |  | 1,420 |  | 1,388 |  | 1,027 |
Consumers and traders |  | 8 |  | 315 |  | 159 |  | 96 |
Traders – free energy transactions |  |  |  | 10 |  | 12 |  | - |
Other credits |  |  |  | 269 |  | 172 |  | 138 |
Financial assets of the concession |  | 13 |  | 11,166 |  | 9,086 |  | 7,672 |
Investments |  | 14 |  | 226 |  | 177 |  | - |
Property, plant and equipment |  | 15 |  | 8,811 |  | 8,662 |  | 8,229 |
Intangible assets |  | 16 |  | 4,473 |  | 5,404 |  | 4,948 |
TOTAL, NON-CURRENT |  |  |  | 28,783 |  | 28,477 |  | 25,388 |
TOTAL ASSETS |  |  |  | 40,773 |  | 37,009 |  | 33,474 |

The notes are an integral part of these consolidated financial statements.

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CONSOLIDATED STATEMENT OF FINANCIAL POSITION

AS AT DECEMBER 31, 2012 AND 2011 AND JANUARY 1, 2011

LIABILITIES AND EQUITY

(MILLIONS OF R$)

|  | NOTE |  | 2012 |  | 2011 Reclassified (note 2, 5) |  | 01/01/2011 Reclassified (note 2, 5) |
CURRENT |  |  |  |  |  |  |  |  |
Suppliers |  | 17 |  | 1,735 |  | 1,190 |  | 1,121 |
Regulatory charges |  | 20 |  | 413 |  | 368 |  | 384 |
Employee profit sharing |  |  |  | 86 |  | 90 |  | 116 |
Taxes payable |  | 18a |  | 569 |  | 517 |  | 404 |
Income and social contribution taxes payable |  | 18b |  | 127 |  | 129 |  | 137 |
Interest on capital and dividends payable |  |  |  | 3,479 |  | 1,243 |  | 1,154 |
Loans and financings |  | 19 |  | 5,159 |  | 4,355 |  | 1,546 |
Debentures |  | 19 |  | 1,947 |  | 3,467 |  | 656 |
Payroll and related charges |  |  |  | 260 |  | 272 |  | 243 |
Employee post-retirement benefits |  | 21 |  | 89 |  | 101 |  | 99 |
Provision for losses on financial instruments |  |  |  | - |  | 24 |  | 69 |
Concessions payable |  |  |  | 18 |  | 8 |  | - |
Other obligations |  |  |  | 425 |  | 405 |  | 474 |
TOTAL CURRENT LIABILITIES |  |  |  | 14,307 |  | 12,169 |  | 6,403 |
NON-CURRENT |  |  |  |  |  |  |  |  |
Regulatory charges |  | 20 |  | 170 |  | 262 |  | 142 |
Loans and financings |  | 19 |  | 4,126 |  | 5,255 |  | 6,114 |
Debentures |  | 19 |  | 4,938 |  | 2,703 |  | 4,910 |
Taxes payable |  | 18a |  | 1,003 |  | 897 |  | 693 |
Deferred Income and social contribution taxes |  | 18b |  | 948 |  | 885 |  | 984 |
Provisions |  | 22 |  | 468 |  | 549 |  | 371 |
Concessions payable |  |  |  | 192 |  | 130 |  | 118 |
Employee post-retirement benefits |  | 21 |  | 2,229 |  | 2,187 |  | 2,062 |
Provision for losses on financial instruments |  |  |  | 1 |  | - |  | - |
Other obligations |  |  |  | 347 |  | 227 |  | 201 |
TOTAL NON-CURRENT LIABILITIES |  |  |  | 14,422 |  | 13,095 |  | 15,595 |
TOTAL LIABILITIES |  |  |  | 28,729 |  | 25,264 |  | 21,998 |
EQUITY |  | 23 |  |  |  |  |  |  |
Share capital |  |  |  | 4,265 |  | 3,412 |  | 3,412 |
Capital reserves |  |  |  | 3,954 |  | 3,954 |  | 3,954 |
Profit reserves |  |  |  | 2,856 |  | 3,293 |  | 2,873 |
Equity Valuation Reserve |  |  |  |  |  |  |  |  |
Deemed cost of property, plant and equipment |  |  |  | 965 |  | 1,081 |  | 1,209 |
Other Comprehensive Income |  |  |  | 4 |  | 5 |  | 1 |
Funds allocated for capital increase |  |  |  | - |  | - |  | 27 |
TOTAL EQUITY |  |  |  | 12,044 |  | 11,745 |  | 11,476 |
TOTAL LIABILITIES AND EQUITY |  |  |  | 40,773 |  | 37,009 |  | 33,474 |

The notes are an integral part of these consolidated financial statements.

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CONSOLIDATED INCOME STATEMENT

FOR THE YEARS ENDED DECEMBER 31, 2012, 2011 AND 2010

(MILLIONS OF R$, EXCEPT EARNINGS PER SHARE)

|  | NOTE |  | 2012 |  | 2011 Reclassified (note 2, 5) |  | 2010 Reclassified (note 2, 5) |
REVENUES |  | 24 |  | 18,460 |  | 15,749 |  | 13,790 |
OPERATING COSTS |  | 25 |  |  |  |  |  |  |
COST OF ELECTRICITY AND GAS |  |  |  |  |  |  |  |  |
Electricity purchased for resale |  |  |  | (5,951) |  | (4,278) |  | (3,722) |
Charges for the use of the basic transmission grid |  |  |  | (1,011) |  | (830) |  | (729) |
Gas purchased for resale |  |  |  | (495) |  | (329) |  | (225) |
|  |  |  | (7,457) |  | (5,437) |  | (4,676) |
COST |  |  |  |  |  |  |  |  |
Personnel and management |  |  |  | (1,026) |  | (934) |  | (967) |
Materials |  |  |  | (68) |  | (73) |  | (126) |
Outsourced services |  |  |  | (832) |  | (740) |  | (805) |
Depreciation and amortization |  |  |  | (949) |  | (911) |  | (898) |
Operating provisions |  |  |  | (36) |  | (71) |  | (14) |
Royalties for usage of water resources |  |  |  | (186) |  | (154) |  | (140) |
Cost of Construction |  |  |  | (1,630) |  | (1,529) |  | (1,328) |
Other |  |  |  | (199) |  | (152) |  | (46) |
|  |  |  | (4,926) |  | (4,564) |  | (4,324) |
TOTAL COST |  |  |  | (12,383) |  | (10,001) |  | (9,000) |
GROSS PROFIT |  |  |  | 6,077 |  | 5,748 |  | 4,790 |
OPERATING EXPENSES |  | 25 |  |  |  |  |  |  |
Selling expenses |  |  |  | (348) |  | (190) |  | (283) |
General and administrative expenses |  |  |  | (1,280) |  | (841) |  | (367) |
Other operating expenses |  |  |  | (627) |  | (413) |  | (581) |
|  |  |  | (2,255) |  | (1,444) |  | (1,231) |
Equity in subsidiaries |  |  |  | (3) |  | (1) |  | - |
Gain on issuance of shares of jointly controlled entities |  |  |  | 264 |  | - |  | - |
Operational profit before Financial revenue (expenses) and Taxes |  |  |  | 4,083 |  | 4,303 |  | 3,559 |
Financial revenues |  | 26 |  | 3,210 |  | 995 |  | 841 |
Financial expenses |  | 26 |  | (1,958) |  | (1,965) |  | (1,594) |
Profit before taxes |  |  |  | 5,335 |  | 3,333 |  | 2,806 |
Income and social contribution taxes |  | 10c |  | (1,504) |  | (1,111) |  | (872) |
Deferred income and social contribution taxes |  | 10c |  | 441 |  | 193 |  | 324 |
PROFIT FOR THE YEAR |  |  |  | 4,272 |  | 2,415 |  | 2,258 |
Basic earnings per preferred and common share |  | 23 |  | 5.01 |  | 2.83 |  | 2.65 |
Diluted earnings per preferred and common share |  | 23 |  | 5.01 |  | 2.83 |  | 2.65 |

The notes are an integral part of these consolidated financial statements.

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CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

FOR THE YEARS ENDED DECEMBER 31, 2012, 2011 AND 2010

(MILLIONS OF R$)

|  | 2012 |  | 2011 |  | 2010 |
PROFIT FOR THE YEAR |  | 4,272 |  | 2,415 |  | 2,258 |
OTHER COMPREHENSIVE INCOME |  |  |  |  |  |  |
Foreign currency transation adjustments |  | 5 |  | 6 |  | (1) |
Cash flow hedge instruments (net of income and social contribution taxes) |  | (1) |  | (1) |  | 2 |
|  | 4 |  | 5 |  | 1 |
COMPREHENSIVE INCOME FOR THE YEAR |  | 4,276 |  | 2,420 |  | 2,259 |

The notes are an integral part of these consolidated financial statements.

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY

FOR THE YEARS ENDED DECEMBER 31, 2012, 2011 AND 01/01/2011

(MILLIONS OF R$, EXCEPT DIVIDENDS PER SHARE)

|  | Share capital |  | Capital reserves |  | Profit reserves |  | Equity Valuation Adjustments |  | Retained earnings |  | Funds allocated for capital increase |  | Total equity |
BALANCE AT JANUARY 01, 2010 |  | 3,102 |  | 3,969 |  | 3,177 |  | 1,343 |  | (453) |  | 27 |  | 11,165 |
Profit for the year |  | - |  | - |  | - |  | - |  | 2,258 |  | - |  | 2,258 |
Other comprehensive income: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Foreign currency transation differences |  | - |  | - |  | - |  | (1 | ) | - |  | - |  | (1 | )
Cash flow hedge instruments |  | - |  | - |  | - |  | 2 |  | - |  | - |  | 2 |
Total comprehensive income for the year |  | - |  | - |  | - |  | 1 |  | 2,258 |  | - |  | 2,259 |
Transactions with shareholders recorded directly in shareholders’ equity |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Ordinary Dividends (R$1.65 per share) |  | - |  | - |  | - |  | - |  | (1,129 | ) | - |  | (1,129) |
Extraordinary Dividends (R$1.32 per share) |  | - |  | - |  | (900 | ) | - |  | - |  | - |  | (900) |
Proposed additional dividends in 2010 (R$ 0.10 per share) |  | - |  | - |  | 67 |  | - |  | (67 | ) | - |  | - |
Other changes in shareholders’ equity |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Increase in share capital |  | 310 |  | (15 | ) | (295 | ) | - |  | - |  | - |  | - |
Acquisition of jointly-controlled subsidiaries – effect of first-time adoption of IFRS |  | - |  | - |  | - |  | - |  | 82 |  | - |  | 82 |
Constitution of reserves |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Legal reserve |  | - |  | - |  | 113 |  | - |  | (113) |  | - |  | - |
Retained earnings |  | - |  | - |  | 712 |  | - |  | (712) |  | - |  | - |
Realization of reserves |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Deemed cost of property, plant and equipment |  | - |  | - |  | - |  | (134) |  | 134 |  | - |  | - |
BALANCE AT DECEMBER 31, 2010 |  | 3,412 |  | 3,954 |  | 2,874 |  | 1,210 |  | - |  | 27 |  | 11,477 |

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|  | Share capital |  | Capital reserves |  | Profit reserves |  | Equity Valuation Adjustments |  | Retained earnings |  | Funds allocated for capital increase |  | Total equity |
BALANCE AT JANUARY 01, 2011 |  | 3,412 |  | 3,954 |  | 2,874 |  | 1,210 |  | - |  | 27 |  | 11,477 |
Profit for the year |  | - |  | - |  | - |  | - |  | 2,415 |  | - |  | 2,415 |
Other comprehensive income: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Foreign currency transation adjustments |  | - |  | - |  | - |  | 6 |  | - |  | - |  | 6 |
Cash flow hedge instruments (net of income and social contribution taxes) |  | - |  | - |  | - |  | (1) |  | - |  | - |  | (1) |
Total comprehensive income for the year |  | - |  | - |  | - |  | 5 |  | 2,415 |  | - |  | 2,420 |
Transactions with shareholders recorded directly in equity |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Ordinary Dividends (R$1.77 per share) |  | - |  | - |  | - |  | - |  | (1,208) |  | - |  | (1,208) |
Extraordinary Dividends (R$1.25 per share) |  | - |  | - |  | (850 | ) | - |  | - |  | - |  | (850) |
Additional dividends proposed in 2010 (R$$ 0.10 per share) |  | - |  | - |  | (67) |  | - |  | - |  | - |  | (67) |
Additional dividends proposed in 2011 (R$$ 0.13 per share) |  | - |  | - |  | 86 |  | - |  | (86) |  |  |  | - |
Other changes in Equity |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Return of funds allocated for capital increase |  | - |  | - |  | - |  | - |  | - |  | (27) |  | (27) |
Constitution of reserves |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Legal reserve |  | - |  | - |  | 109 |  | - |  | (109) |  | - |  | - |
Retained earnings |  | - |  | - |  | 1,141 |  | - |  | (1,141) |  | - |  | - |
Realization of reserves |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Deemed cost of property, plant and equipment |  | - |  | - |  | - |  | (129) |  | 129 |  | - |  | - |
BALANCE AT DECEMBER 31, 2011 |  | 3,412 |  | 3,954 |  | 3,293 |  | 1,086 |  | - |  | - |  | 11,745 |

The notes are an integral part of these consolidated financial statements.

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|  | Share capital |  | Capital reserves |  | Profit reserves |  | Equity Valuation Adjustments |  | Retained earnings |  | Total equity |
BALANCE AT DECEMBER 31, 2011 |  | 3,412 |  | 3,954 |  | 3,293 |  | 1,086 |  | - |  | 11,745 |
Profit for the year |  | - |  | - |  | - |  | - |  | 4,272 |  | 4,272 |
Other comprehensive income: |  |  |  |  |  |  |  |  |  |  |  |  |
Foreign currency transation adjustments |  | - |  | - |  | - |  | 5 |  | - |  | 5 |
Cash flow hedge instruments (net of income and social contribution taxes) |  | - |  | - |  | - |  | (1) |  | - |  | (1) |
Total comprehensive income for the year |  | - |  | - |  | - |  | 4 |  | 4,272 |  | 4,276 |
Transactions with shareholders recorded directly in equity |  |  |  |  |  |  |  |  |  |  |  |  |
Increase in share capital (Note 23) |  | 853 |  | - |  | (853 | ) | - |  | - |  | - |
Ordinary Dividends |  |  |  |  |  |  |  |  |  |  |  |  |
Ordinary Dividends (R$0.62 per share) |  | - |  | - |  | - |  | - |  | (591) |  | (591) |
Interest on Capital (R$1.99 per share) |  | - |  | - |  | - |  | - |  | (1,700) |  | (1,700) |
Extraordinary Dividends (R$1.88 per share) |  | - |  | - |  | (1,600 | ) | - |  | - |  | (1,600) |
Additional dividends proposed in 2011 (R$$ 0.11 per share) |  | - |  | - |  | (86 | ) | - |  | - |  | (86) |
Additional dividends proposed in 2012 (R$$ 0.74 per share) |  | - |  | - |  | 628 |  | - |  | (628) |  | - |
Other changes in Equity |  |  |  |  |  |  |  |  |  |  |  |  |
Constitution of reserves |  |  |  |  |  |  |  |  |  |  |  |  |
Legal reserve |  | - |  | - |  | 171 |  | - |  | (171) |  | - |
Retained earnings |  | - |  | - |  | 1,303 |  | - |  | (1,303) |  | - |
Realization of reserves |  |  |  |  |  |  |  |  |  |  |  |  |
Deemed cost of property, plant and equipment |  | - |  | - |  | - |  | (121) |  | 121 |  | - |
BALANCE AT DECEMBER 31, 2012 |  | 4,265 |  | 3,954 |  | 2,856 |  | 969 |  | - |  | 12,044 |

The notes are an integral part of these consolidated financial statements.

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CONSOLIDATED STATEMENT OF CASH FLOWS

FOR THE YEARS ENDED DECEMBER 31, 2012, 2011 AND 01/01/2011

(MILLIONS OF R$)

|  | 2012 |  | 2011 Reclassified (note 2, 5) |  | 2010 Reclassified (note 2, 5) |
CASH FLOWS FROM OPERATING ACTIVITIES |  |  |  |  |  |  |
PROFIT FOR THE YEAR |  | 4,272 |  | 2,415 |  | 2,258 |
Expenses (revenues) not affecting cash and cash equivalents |  |  |  |  |  |  |
Income and social contribution taxes |  | 1,063 |  | 918 |  | 548 |
Depreciation and amortization |  | 1,001 |  | 983 |  | 896 |
Loss on disposal of property, plant and equipment and intangible assets |  | 128 |  | 21 |  | - |
Equity in subsidiaries |  | 3 |  | 1 |  | - |
Interest and monetary variation |  | (2,075) |  | 546 |  | 573 |
Gain on issuance of shares of jointly controlled entities |  | (264) |  | - |  | - |
Operating provisions |  | 639 |  | 342 |  | (78) |
Employee post-retirement benefits |  | 264 |  | 287 |  | 208 |
Other |  | - |  | 85 |  | 72 |
|  | 5,031 |  | 5,598 |  | 4,477 |
(Increase) / decrease in assets |  |  |  |  |  |  |
Consumers and traders |  | (355) |  | (541) |  | (66) |
Recoverable taxes |  | (132) |  | (168) |  | 107 |
Recoverable Income and social contribution taxes |  | 134 |  | 101 |  | (75) |
Escrow deposits |  | (34) |  | (226) |  | (400) |
Financial assets of the concession |  | 812 |  | 660 |  | 501 |
Other |  | (446) |  | 121 |  | 7 |
|  | (20) |  | (53) |  | 60 |
Increase (decrease) in liabilities |  |  |  |  |  |  |
Suppliers |  | 549 |  | 69 |  | 269 |
Taxes payable |  | 196 |  | 402 |  | (352) |
Payroll and related charges |  | (13) |  | 29 |  | (110) |
Regulatory charges |  | (42) |  | 104 |  | 60 |
Employee post-retirement benefits |  | (233) |  | (160) |  | (56) |
Other |  | 225 |  | (123) |  | 333 |
|  | 682 |  | 321 |  | 144 |
Cash from operating activities |  | 5,692 |  | 5,866 |  | 4,681 |
Interest on loans, financings and debentures paid |  | (1,209) |  | (1,083) |  | (803) |
Income and social contribution taxes paid |  | (1,368) |  | (885) |  | (502) |
NET CASH FROM OPERATING ACTIVITIES |  | 3,115 |  | 3,898 |  | 3,376 |

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|  | 2012 |  | 2011 Reclassified (note 2, 5) |  | 2010 Reclassified (note 2, 5) |
CASH FLOWS FROM INVESTING ACTIVITIES |  |  |  |  |  |  |
In short-term investments |  | (1,361) |  | (37) |  | (322) |
In financial assets of the concession |  | (160) |  | (1,026) |  | (1,477) |
Redemption of the Account receivable from the State of Minas Gerais Government |  | 1,498 |  | - |  | - |
Net cash received on dilution in jointly-controlled subsidiary |  | 668 |  | - |  | - |
Acquisition of jointly-controlled subsidiary, net of cash acquired |  | (361) |  | - |  | - |
In investments |  | (116) |  | (178) |  | - |
In property, plant and equipment |  | (598) |  | (924) |  | (347) |
In intangible assets |  | (1,670) |  | (1,852) |  | (2,298) |
NET CASH USED IN INVESTING ACTIVITIES |  | (2,100) |  | (4,017) |  | (4,444) |
CASH FLOWS OF FINANCING ACTIVITIES |  |  |  |  |  |  |
Loans, financings and debentures obtained |  | 7,195 |  | 4,255 |  | 6,227 |
Repayment of loans, financings and debentures |  | (6,838) |  | (2,219) |  | (4,775) |
Interest on capital and dividends paid |  | (1,748) |  | (2,035) |  | (1,829) |
NET CASH FROM (USED IN) FINANCING ACTIVITIES |  | (1,391) |  | 1 |  | (377) |
NET CHANGE IN CASH AND CASH EQUIVALENTS |  | (376) |  | (118) |  | (1,445) |
STATEMENT OF CHANGES IN CASH AND CASH EQUIVALENTS |  |  |  |  |  |  |
Beginning of the year |  | 2,862 |  | 2,980 |  | 4,425 |
End of the year |  | 2,486 |  | 2,862 |  | 2,980 |
|  | (376) |  | (118) |  | (1,445) |

The notes are an integral part of these consolidated financial statements.

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NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

AS AT DECEMBER 31, 2012 AND 2011

(FIGURES IN MILLIONS OF R$, EXCEPT WHERE OTHERWISE INDICATED)

1. OPERATIONS

a) The Company

Companhia Energética de Minas Gerais (“Cemig” or “the Company”) is a listed corporation registered in the Brazilian Registry of Corporate Taxpayers (CNPJ) under number 17.155.730/0001-64, with shares traded at Corporate Governance Level 1 on the BM&F Bovespa (“Bovespa”), on the New York Stock Exchange (“NYSE”), and on the stock exchange of Madrid (“Latibex”). It is domiciled in Brazil, with head office at Avenida Barbacena 1200, Belo Horizonte, in the State of Minas Gerais, and operates exclusively as a Parent Company, with interest in companies controlled individually or jointly, the main objects of which are construction and commercial operation of systems for generation, transformation, transmission, distribution and sale of electricity, and activities in the various fields of energy.

On December 31, 2012, Cemig’s current liabilities exceeded its current assets by R$ 2,317. This excess was primarily due to the transfers of loans and financings to Current liabilities, due to non-compliance with restrictive covenants in the contracts of Cemig D (Distribution) and as a result of the flow of payments on the existing contracts, added to the funding raised due to the increase in the average price of electricity brought for resale caused by the higher dispatching of thermal plants. In relation to the restrictive covenants it should be pointed out that the Company is in the process of obtaining the waivers from the creditors so that immediate or early payment is not demanded of the amounts payable at December 31, 2012, and has the expectation of obtaining these consents in 2013, at which moment the subsidiary will reclassify those balances to Non-current liabilities.

Management monitors the Company’s cash flow, and is assessing measures to adjust its present situation to the levels considered appropriate to meet its needs, including renegotiations of financings or new transactions to raise funds in the market. As an example, we draw attention to the Third Issue of Non-convertible debentures by Cemig D, on February 15, 2013, in the amount of R$ 2.160 billion, which funds were allocated to redemption in full of the commercial promissory notes of Cemig D’s fifth and sixth issues.

CEMIG has equity interests in the following subsidiaries and jointly controlled entities that were in operation at December 31, 2012:

■ | Cemig Geração e Transmissão S.A. (Cemig GT) (subsidiary) – Electric power generation and transmission, through 53 power plants (47 hydroelectric power plants, 4 wind power plants and 2 thermoelectric power plants) and transmission lines, mostly belonging to the Brazilian national generation and transmission grid system.
| Cemig GT has equity interests in the following subsidiaries and jointly controlled entities:

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|  | - Hidrelétrica Cachoeirão S.A. (Cachoeirão) (jointly controlled): Production and sale of electric power as an independent power producer, through the Cachoeirão hydroelectric power plant located at Pocrane, in the State of Minas Gerais. The plant began operating in 2009;
|  | - Baguari Energia S.A. (Baguari Energia) (jointly controlled): Construction, operation, maintenance and commercial operation of the Baguari Hydroelectric Plant, through participation in the UHE Baguari Consortium (Baguari Energia 49.00% and Neoenergia 51.00%), located on the Doce river in Governador Valadares, the State of Minas Gerais. The plant began operation of its units during the period from September 2009 to May 2010;
|  | - Transmissora Aliança de Energia Elétrica S.A (TAESA) (jointly controlled): Construction, operation and maintenance of electric power transmission facilities in 11 states of Brazil. TAESA has the following subsidiaries: Empresa de Transmissão do Alto Uruguai S.A. (ETAU), Brasnorte Transmissora de Energia S.A. (Brasnorte), Abengoa Participações S.A, União de Transmissoras de Energia Elétrica (UNISA), Nordeste Transmissora de Energia S.A (NTE) and Abengoa Participações Holding S.A. (Abengoa);
|  | - Central Eólica Praias de Parajuru S.A. (Parajuru) (jointly controlled): Production and sale of electric power through the Parajuru wind farm, in the city of Beberibe, in the State of Ceará. The plant began operating in August 2009;
|  | - Central Eólica Praia do Morgado S.A. (Morgado) (jointly controlled): Production and sale of electric power at the Morgado wind farm in the city of Acaraú in the State of Ceará, Northern Brazil. The plant began operating in May 2010;
|  | - Central Eólica Volta do Rio S.A. (Volta do Rio) (jointly controlled): Production and sale of electric power at the Volta do Rio Wind Farm in the city of Acaraú in the State of Ceará, Northern Brazil. The plant began operating in September 2010;
|  | - Hidrelétrica Pipoca S.A. (Pipoca) (jointly controlled): Independent production of electric power, through construction and commercial operation of the Pipoca PCH (Small Hydro Plant), located on the Manhuaçu River, in the cities of Caratinga and Ipanema, in the State of Minas Gerais. The plant began operating in October 2010;
|  | - Empresa Brasileira de Transmissão de Energia S.A. (EBTE) (jointly-controlled): Holder of a public electric power transmission service concession, through the transmission lines in the State of Mato Grosso. The transmission facility began operating in June 2011;
|  | - Madeira Energia S.A. (Madeira) (jointly controlled): Implementation, construction, operation and commercial operation through its subsidiary Santo Antônio Energia S.A., of the Santo Antônio hydroelectric power plant located in the Madeira river basin in the State of Rondônia. The plant began its commercial operations in March, 2012. See more information in note 14.
|  | Madeira has presented capital expenditures related to the construction and development project for the construction of the plant, which according to financial projections, should be absorbed by future revenue from operations. Madeira´s property, plant and equipment balance at December 31, 2012 was approximately R$14,527 (R$1,453 of which rolls up into the financial information of Cemig GT). During

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|  | this phase of the project, Madeira incurred certain losses in recent years as it has been in a pre-operating stage, and at December 31, 2012, Madeira had a negative net working capital (current liabilities in excess of current assets) in the amount of R$1,166, R$117 thousand of which rolls up into the financial information of Cemig GT based on its equity interest. Management of Madeira Energia S.A. has plans to resolve the situation of negative net working capital. As of this date, Madeira depends on the financial support of its stockholders and/or on obtaining loans from third parties to continue operating.
|  | - Lightger S.A. (“Lightger”) (jointly controlled): Independent electric power production through construction and commercial operation of the hydroelectric powerstation referred to as the Paracambi Small Hydroelectric Power Plant, on the Ribeirão das Lages river in the city of Paracambi, in the State of Rio de Janeiro. The start up of operations occurred in May, 2012;
|  | Subsidiaries and jointly-controlled subsidiaries of Cemig GT at development stage:
|  | - Guanhães Energia S.A. (Guanhães Energia) (jointly controlled): Production and trade of electric power through construction and commercial operation of the following Small Hydroelectric Plants (PCHs) in the State of Minas Gerais: Dores de Guanhães, Senhora do Porto and Jacaré, in the city of Dores de Guanhães; and Fortuna II, in the city of Virginópolis. It is scheduled to start operating the first turbine in October 2013;
|  | - Cemig Baguari Energia S.A. (Cemig Baguari) (subsidiary): Production and trade of electric power as an independent power producer, in future projects;
|  | - Amazônia Energia Participações S.A (“Amazônia Energia”) (jointly controlled) – Special Purpose Company (SPC) established by Cemig GT and Light, for the purpose of acquisition of a 9.77% interest of Norte Energia SA (“NESA”), a holding company of the concession of the Belo Monte hydroelectric power plant (“Belo Monte Hydroelectric Plant”). Cemig GT holds a 74.5% interest in Amazônia Energia and Light holds 25.5%. The start up of operations is scheduled for February 2015;
■ | Cemig Distribuição S.A. (Cemig D”) (subsidiary) – Distribution of electric power through distribution grids and lines in practically all of the State of Minas Gerais;
■ | Light S.A. (“Light”) (jointly controlled): Holding company that holds direct and indirect interests in other companies for operating electric power services, including generation, transmission, trading or distribution, and other related services. Light has the following subsidiaries and jointly-controlled subsidiaries:
|  | - Light Serviços de Eletricidade S.A. (“Light SESA”) (subsidiary) – listed company in Bovespa: Operating mainly in electric power distribution, in various municipalities of the State of Rio de Janeiro;
|  | - Light Energia S.A. (“Light Energia”) (private subsidiary): Its main activities are studying, planning, building and commercially operating systems for generation, transmission, trading of electric power and related services. Light Energia has equity interests in Central Eólica São Judas Tadeu Ltda., Central Eólica Fontainha Ltda. and Renova Energia S.A.;

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|  | - Light Esco Prestação de Serviços Ltda. (“Light Esco”) (subsidiary): Its main activity is purchasing, selling, importing and exporting of electric power, and providing of consulting services in the energy sector;
|  | - Itaocara Energia Ltda. (“Itaocara Energia”) (subsidiary): A company in the development stage – its main activities are the planning, construction, installation and commercial operation of electric power plants;
|  | - Lightger Ltda. (“Lightger”) (jointly controlled): A company in the development stage, set up to participate in auctions of concessions, authorizations and permissions in new power plants. On December 24, 2008, Lightger obtained its installation license, authorizing the start of construction of its Paracambi Small Hydroelectric Plant. It is a jointly-controlled subsidiary of Light S.A. (with 51%) and Cemig GT (with 49%). The start up of operations is scheduled for beginning of 2012;
|  | - Light Soluções em Eletricidade Ltda. (“Light Soluções”) (formerly Lighthidro Ltda.) (subsidiary): A company in the development stage, set up to participate in auctions of concessions, authorizations and permissions in new power plants;
|  | - Instituto Light para o Desenvolvimento Urbano e Social (Instituto Light): Its purpose is to participate in social and cultural projects, with a focus on the economic and social development of cities;
|  | - Lightcom Comercializadora de Energia S.A. (Lightcom) (subsidiary): Involved in purchasing, selling, importing and exporting electric power and general consulting services in the free and regulated markets for electric power;
|  | - Axxiom Soluções Tecnológicas S.A. (Axxiom) (jointly controlled): It provides technological solutions and systems for operational management of public service concessions, including electric power, gas, water and waste companies and other utilities. Jointly controlled by Light S.A (51%) and CEMIG (49%);
|  | - CR Zongshen E-Power Fabricadora de Veículos S.A. (“E-Power”): (jointly-controlled): An unlisted corporation, at pre-operational stage, with the principal object of manufacturing two-wheeled electric vehicles under the Kasinski brand name. Light S.A. and CR Zongshen Fabricadora de Veículos S.A., under the name “Kasinski”, are the Company’s sole stockholders, respectively owning 20% and 80% of E-Power’s nominal common shares.
|  | - Amazônia Energia Participações S.A. (“Amazônia Energia”) (jointly-controlled): An unlisted corporation whose objects are to be a stockholder in Norte Energia S.A. (NESA), which holds the concession to operate the Belo Monte Hydroelectric Plant, on the Xingu River, in the State of Pará and to manage this interest. It is jointly-controlled by Light S.A. (with 25.5%) and Cemig GT (with 74.5%). Amazônia Energia holds 9.8% of the share capital of NESA, having significant influence in management, but without joint control.
■ | Sá Carvalho S.A. (Sá Carvalho) (subsidiary): Production and sale of electric power, as an electric power public service concession holder, through the Sá Carvalho hydroelectric power plant;

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■ | Usina Térmica Ipatinga S.A. (Ipatinga) (subsidiary): Production and sale, as an independent power producer, of thermoelectric power, through the Ipatinga thermoelectric power plant, located on the facilities of Usinas Siderúrgicas de Minas Gerais S.A. – USIMINAS;
■ | Companhia de Gás de Minas Gerais – GASMIG (GASMIG) (jointly controlled): Acquisition, transport and distribution of natural gas and related products, through a concession for distribution of gas in the State of Minas Gerais.;
■ | Cemig Telecomunicações S.A. (Cemig Telecom) (subsidiary): Providing telecommunications services and developing activities related to them, through an integrated system consisting of optical fiber cables, coaxial cables, and electronic and associated equipment (multi-service network). It holds 49% of Ativas Data Center (Ativas) (jointly controlled), the principal activity of which is providing services to supply IT and communications infrastructure, comprising hosting and related services for medium and large-sized corporations;
■ | Efficientia S.A. (Efficientia) (subsidiary): Providing energy efficiency and optimization services and energy solutions through studies and execution of projects, as well as providing operation and maintenance services in energy supply facilities;
■ | Horizontes Energia S.A. (Horizontes) (subsidiary): Production and sale of electric power, as an independent power producer, through the Machado Mineiro and Salto do Paraopeba hydroelectric power plants in the the State of Minas Gerais, and the Salto do Voltão and Salto do Passo Velho power plants in the State of Santa Catarina;
■ | Central Termelétrica de Cogeração S.A. (Cogeração) (subsidiary): Production and sale of thermoelectric power produced as an independent producer in future projects;
■ | Rosal Energia S.A. (Rosal) (subsidiary): Production and sale of electric power, as an electric power public service concession holder, through the Rosal hydroelectric power plant located on the border between the States of Rio de Janeiro and Espírito Santo, Brazil;
■ | Empresa de Serviços e Comercialização de Energia Elétrica S.A. (formerly Central Hidrelétrica Pai Joaquim S.A. (subsidiary): Production and sale of electric power as an independent power producer in future projects;
■ | Cemig PCH S.A. (PCH) (subsidiary): Production and sale of electric power as an independent power producer, through the Pai Joaquim hydroelectric power plant;
■ | Cemig Capim Branco Energia S.A. (Capim Branco) (subsidiary): Production and sale of electric power as an independent power producer, through the Amador Aguiar I and II hydroelectric power plants, built through a consortium with private sector partners;

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■ | Usina Termelétrica Barreiro S.A. (Barreiro) (subsidiary): Production and sale of electric power, as an independent thermoelectric power producer, through the construction and operation of the UTE Barreiro thermoelectric power plant, located in the facilities of V&M do Brasil S.A., in the State of Minas Gerais;
■ | Cemig Trading S.A. (Cemig Trading) (subsidiary): Sale and brokerage of electric power;
■ | Companhia Transleste de Transmissão (Transleste) (jointly controlled): Operation of the transmission line connecting the substation located in Montes Claros and the substation of the Irapé hydroelectric power plant;
■ | Companhia Transudeste de Transmissão (Transudeste) (jointly controlled): Construction, operation and maintenance of the Itutinga–Juiz de Fora transmission line;
■ | Companhia Transirapé de Transmissão (Transirapé) (jointly controlled): Construction, operation and maintenance of the Irapé–Araçuaí transmission line;
■ | Empresa Paraense de Transmissão de Energia S.A. (ETEP) (jointly controlled): Holder of an electric power public service concession for a transmission line in the State of Pará. ETEP has set up the subsidiary Empresa Santos Dumont de Energia S.A. (ESDE);
■ | Empresa Norte de Transmissão de Energia S.A. (ENTE) (jointly controlled): Holder of an electric power public service concession for transmission through two transmission lines in the States of Pará and Maranhão;
■ | Empresa Regional de Transmissão de Energia S.A. (ERTE) (jointly controlled): Holder of an electric power public service concession for a transmission line in the State of Pará;
■ | Empresa Amazonense de Transmissão de Energia S.A. (EATE) (jointly controlled): Holder of an electric power public service concession for the transmission lines between the substations of Tucuruí, Marabá, Imperatriz, Presidente Dutra and Açailândia. EATE has interests in the following transmission companies: Empresa Brasileira de Transmissão de Energia S.A. (EBTE) (jointly controlled); Sistema de Transmissão Catarinense S.A. (STC) (subsidiary) and Lumitrans Companhia Transmissora de Energia Elétrica S.A. (Lumitrans) (subsidiary);
■ | Empresa Catarinense de Transmissão de Energia S.A. (ECTE) (jointly controlled): Holder of an electric power public service concession for transmission lines in the State of Santa Catarina;
■ | Axxiom Soluções Tecnológicas S.A. (Axxiom) (jointly controlled): Providing technological solutions and systems for operational management of public service concessions, including electric power, gas, water and waste companies and other utilities. Jointly controlled by Light S.A (51%) and Cemig (49%);

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■ | Transchile Charrúa Transmisión S.A. – (Transchile) (jointly controlled): Implementation, operation and maintenance of the Charrúa–Nueva Temuco transmission line and two transmission line sections in the Charrúa and Nueva Temuco substations, in the central region of Chile. The head office of Transchile is in Santiago, Chile. The transmission line began operating in January 2010;
■ | Companhia de Transmissão Centroeste de Minas (Centroeste) (jointly controlled): Construction, operation and maintenance of the Furnas–Pimenta transmission line. The transmission line began operating in April 2010;
■ | Parati S.A Participações em Ativos de Energia Elétrica (Parati) (jointly controlled): holding company that holds interests in other Brazilian or foreign companies that operate in any activity. Through Parati, CEMIG holds an additional 6.42% interest in Light;
■ | Cemig Serviços (subsidiary): It provides services related to planning, construction, operation and maintenance of electric power generation, transmission and distribution systems, and provides administrative, commercial and engineering services in the different energy fields.
The joint control investments were made by CEMIG and its subsidiaries through shareholders’ agreements with the other shareholders of the investee companies.

2 BASIS OF PREPARATION

2.1 Statement of compliance

The consolidated financial statements have been prepared in accordance with International Financial Reporting Standards (IFRS), as issued by the International Accounting Standards Board (IASB).

On April 25, 2013, the Company’s Fiscal Counsel authorized the issuing of the Financial Statements for the year ended December 31, 2012.

2.2 Basis of measurement

The consolidated financial statements have been prepared on the historical cost basis except for the following material items in the statement of financial position:

| ■ | Financial instruments and derivative financial instruments measured at fair value.
| ■ | Non-derivative financial assets measured at fair value through profit or loss.
| ■ | Financial assets held for trading measured at fair value.
| ■ | Financial assets of the Concession measured by the New Replacement Value (VNR), equivalent to fair value.

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2.3. Functional and presentation currency

These consolidated financial statements are presented in Reais, which is the Company’s functional currency. All financial information is presented in millions of Reais, except where otherwise indicated.

2.4. Use of estimates and judgment

The preparation of the consolidated financial statements in conformity with IFRS requires management to make judgments, estimates and assumptions that affect the application of policies and reported amounts of assets, liabilities, income and expenses. Actual results may differ from these estimates.

Estimates and underlying assumptions are reviewed on an ongoing basis. Revisions to accounting estimates are recognized in the period in which the estimates are reviewed and in any future periods affected.

The Company believes that the following accounting policies reflect management’s most critical judgments, estimates and assumptions that are important to its business operations and the understanding of its results:

■ Note 8 – Allowance for doubtful accounts;

■ Note 10 – Deferred income tax and social contribution;

■ Nota 13 – Financial Assets of the concession;

■ Note 16 – Intangible;

■ Note 15 –Depreciation;

■ Note 16 – Amortization;

■ Note 21 – Employee post-retirement benefits;

■ Note 22 – Provisions;

■ Note 24 – Unbilled electric power supplied;

■ Note 29 – Fair value measurements and derivative financial instruments.

2.5 Reclassifications of account balances, as of December 31, 2011 and 2010 and 01/01/2011

Certain balances in the financial statements for the year ended December 31, 2011, originally issued on March 26, 2012, although not material in scale, are being reclassified for the purposes of comparison with the financial statements for the year ended December 31, 2012. In this case the Company made errors that were not material and were not intentional. Although the adjustments are not material in scale, individually or jointly, the Company decided to adjust the comparative balances of 2011 and 2010 for the presentation of the financial statements for 2012, with the objective of maintaining the comparison of the balances. Neither net profits, nor net assets were adjusted as a result of the reclassification.

Below we give a summary of the financial statements which had non-material reclassifications, to provide better understanding of the effects:

2010 |
Income Statement |  | Note |  | Published |  | Reclassification |  | Reclassified |
Revenues |  | c |  | 13,847 |  | (57 | ) | 13,790 |
Depreciation and amortization |  | c |  | (867 | ) | (32 | ) | (899 | )
Total Cost |  |  |  | (8,968 | ) | (32 | ) | (9,000 | )
Gross Profit |  |  |  | 4,879 |  | (89 | ) | 4,790 |
Financial Expenses |  | c |  | (1,667 | ) | (73 | ) | (1,594 | )
Profit before income tax |  |  |  | 2,822 |  | (16 | ) | 2,806 |
Deferred income and social contribution taxes |  | c |  | 308 |  | 16 |  | 324 |
Profit for the Year |  |  |  | 2,415 |  | — |  | 2,415 |

Cash Flow |  | Note |  | Published |  | Reclassification |  | Reclassified |
CASH FLOWS FROM OPERATING ACTIVITIES |  |  |  |  |  |  |  |  |
Expenses (revenues) not affecting cash and cash equivalents |  |  |  |  |  |  |  |  |
Income and social contribution taxes |  | e |  | (307 | ) | 855 |  | 548 |
Interest and monetary variation |  | e |  | (516 | ) | 1,089 |  | 573 |
Increase (decrease) in liabilities |  |  |  |  |  |  |  |  |
Taxes payable |  | e |  | 1 |  | (353 | ) | (352 | )
Loans, financings and debentures |  | e |  | 286 |  | (286 | ) | — |
Cash Flows of operating activities |  |  |  |  |  |  |  |  |
Interest on loans, financings and debentures paid |  | e |  | — |  | (803 | ) | (803 | )
Income and social contribution taxes paid |  | e |  | — |  | (502 | ) | (502 | )
Net cash from operating activities |  |  |  | 3,376 |  | — |  | 3,376 |

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01.01.2011 |
Statement of Financial Position |  | Note |  | Published |  | Reclassification |  | Reclassified |
Assets |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |
Restricted Cash |  | g |  | - |  | 14 |  | 14 |
Other credits |  | g |  | 560 |  | (14) |  | 546 |
Total Current Assets |  |  |  | 8,086 |  | - |  | 8,086 |
Non-Current |  |  |  |  |  |  |  |  |
Deferred income tax and social contribution |  | a |  | 1,801 |  | (582) |  | 1,218 |
Financial assets of the concession |  | b |  | 7,316 |  | 356 |  | 7,672 |
Intangible assets |  | b |  | 4,804 |  | 144 |  | 4,948 |
Total Non-Current Assets |  |  |  | 25,470 |  | (82) |  | 25,388 |
Total Assets |  |  |  | 33,556 |  | (82) |  | 33,474 |
Liabilities |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |
Loans and financings |  | g |  | 1,574 |  | (28) |  | 1,546 |
Debentures |  | g |  | 629 |  | 28 |  | 656 |
Total Current Liabilities |  |  |  | 6,403 |  | - |  | 6,403 |
Non-Current |  |  |  |  |  |  |  |  |
Loans and financings |  | g |  | 6,244 |  | (131) |  | 6,114 |
Debentures |  | g |  | 4,779 |  | 131 |  | 4,910 |
Taxes payable and deferred income tax and social contribution |  | a, b |  | 1,065 |  | (82) |  | 984 |
Total Non-Current Liabilities |  |  |  | 15,676 |  | (82) |  | 15,594 |
Total Liabilities |  |  |  | 22,080 |  | (82) |  | 21,998 |
Total Liabilities and Equity |  |  |  | 33,556 |  | (82) |  | 33,474 |

2011 |
Statement of Financial Position |  | Note |  | Published |  | Reclassification |  | Reclassified |
Assets |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |
Linked funds |  | g |  | - |  | 3 |  | 3 |
Other credits |  | g |  | 562 |  | (3) |  | 559 |
Total Current Assets |  |  |  | 8,532 |  | - |  | 8,532 |
Non-Current |  |  |  |  |  |  |  |  |
Deferred income tax and social contribution |  | a |  | 2,036 |  | (800) |  | 1,236 |
Financial assets of the concession |  | b |  | 8,778 |  | 308 |  | 9,086 |
Intangible assets |  | b |  | 5,261 |  | 143 |  | 5,404 |
Concession holders – transport of energy |  | g |  | - |  | 12 |  | 12 |
Other credits |  | g |  | 184 |  | (12) |  | 172 |
Total Non-Current Assets |  |  |  | 28,826 |  | (349) |  | 28,477 |
Total Assets |  |  |  | 37,358 |  | (349) |  | 37,009 |
Liabilities |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |
Loans and financings |  | g |  | 4,382 |  | (28) |  | 4,355 |
Debentures |  | g |  | 3,439 |  | 28 |  | 3,467 |
Provision for losses on financial instruments |  | g |  | 25 |  | (2) |  | 23 |
Concessions payable |  | g |  | - |  | 8 |  | 8 |
Other obligations |  | g |  | 414 |  | (6) |  | 408 |
Total Current Liabilities |  |  |  | 12,169 |  | - |  | 12,169 |
Liabilities |  |  |  |  |  |  |  |  |
Non-Current |  |  |  |  |  |  |  |  |
Loans and financings |  | g |  | 5,358 |  | (104) |  | 5,255 |
Debentures |  | g |  | 2,600 |  | 104 |  | 2,704 |
Taxes payable and deferred income tax and social contribution payable |  | a, b |  | 1,234 |  | (349) |  | 885 |
Total Non-Current Liabilities |  |  |  | 13,443 |  | (349) |  | 13,095 |
Total Liabilities |  |  |  | 25,613 |  | (349) |  | 25,264 |
Total Liabilities and Shareholders´Equity |  |  |  | 37,358 |  | (349) |  | 37,009 |

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Income Statement |  | Note |  | Published |  | Reclassification |  | Reclassified |
Revenues |  | c |  | 15,814 |  | (66) |  | 15,749 |
Depreciation and amortization |  | c |  | (867) |  | (44) |  | (911) |
Total Cost |  |  |  | (9,957) |  | 44 |  | (10,001) |
Gross Profit |  |  |  | 5,857 |  | (109) |  | 5,748 |
Financial Expenses |  | c |  | (2,051) |  | 86 |  | (1,965) |
Profit before income tax |  |  |  | 3,356 |  | (23) |  | 3,333 |
Deferred income and social contribution taxes |  | c |  | 170 |  | 23 |  | 193 |
Profit for the Year |  |  |  | 2,415 |  | - |  | 2,415 |
Cash Flow |  | Note |  | Published |  | Reclassification |  | Reclassified |
CASH FLOWS FROM OPERATING ACTIVITIES |  |  |  |  |  |  |  |  |
Expenses (revenues) not affecting cash and cash equivalents |  |  |  |  |  |  |  |  |
Income and social contribution taxes |  | e |  | (171) |  | 1,088 |  | 918 |
Depreciation and amortization |  | e |  | 939 |  | 43 |  | 983 |
Interest and monetary variation |  | e |  | (783) |  | 1,328 |  | 546 |
(Increase) / decrease in assets |  |  |  |  |  |  |  |  |
Recoverable Income and social contribution taxes |  | e |  | 433 |  | (331) |  | 101 |
Increase (decrease) in liabilities |  |  |  |  |  |  |  |  |
Taxes payable |  | e |  | 317 |  | 85 |  | 402 |
Loans, financings and debentures |  | e |  | 246 |  | (246) |  | - |
Cash Flows of operating activities |  |  |  |  |  |  |  |  |
Interest on loans, financings and debentures paid |  | e |  | - |  | (1,083) |  | (1,083) |
Income and social contribution taxes paid |  | e |  | - |  | (885) |  | (885) |
Net cash from operating activities |  |  |  | 3,898 |  | - |  | 3,898 |

The reclassifications above are presented to provide more material information in relation to the following items:

a) Deferred income tax and Social Contribution tax: The deferred liability balances of income tax and Social Contribution tax were offset with the corresponding balances in assets, in each one of the entities that comprised the economic group.

b) The Company reclassified deferred income tax liability relating to the difference between the book value and fair value found on the acquisitions after January 1, 2009, in the consolidated information, previously presented net within the assets acquired.

c) Reclassification of the realization of acquired assets of the concessions from Financial expenses to Depreciation and amortization for distribution and generation acquisitions and to the transmission revenue line, for electricity transmission assets.

d) Allocation of Interest and monetary adjustment in the adjustments to net profit do not affect cash and cash equivalents, in the Cash flow Statement.

e) Allocations of current income tax and Social Contribution tax in the adjustments to net profit do not affect cash and cash equivalents, in the Cash flow Statement.

f) Electricity bought for resale, and Charges for use of national transmission grid: In 2011 these were presented net of the credits for the PIS, Pasep and Cofins taxes applying to acquisition and transport of inputs. They have been reclassified to Taxes – Federal;

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The other items were separated for the purpose of better presentation of their effects in the financial statements.

2.6. Significant accounting policies

The accounting policies described below have been applied consistently to all periods presented in this consolidated financial statements.

The accounting policies have been applied consistently by the entities of the group.

a) Financial instruments

Non-derivative financial assets – The Company initially recognizes loans and receivables and deposits on the date that they are originated. All the other financial assets (including assets designated at fair value through profit and loss) are recognized initially on the date of trading, which is the date that the Company becomes one of the parties to the contractual provisions of the instrument.

The Company derecognizes a non-derivative financial asset when the contractual rights to the cash flows from the asset expire, or it transfers the rights to receive the contractual cash flows on the financial asset in a transaction where substantially all the risks and rewards of ownership of the financial asset are transferred. Any interest in transferred financial assets that is created or retained by the Company is recognized as a separate asset or liability.

Financial assets and liabilities are offset and the net amount is presented in the statement of financial position when, and only when, the Company has a legal right to offset the amounts and intends either to settle them on a net basis or to realize the asset and settle the liability simultaneously.

The Company has the following non-derivative financial assets: Cash, Cash equivalents and Short-term investments measured at fair value through profit or loss, Consumers and traders, Concession holders – transport of energy, Account receivable from the State of Minas Gerais Government, restricted cash, judicial deposits and Financial assets of the concession, recognized at their nominal value and similar to their fair values.

Non-derivative financial liabilities– The Company initially recognizes debt securities issued and subordinated liabilities on the date that they are originated. All other financial liabilities (including liabilities designated at fair value through profit or loss) are recognized initially on the trade date on which is the date the Company becomes a party to the contractual provisions of the instrument. The company derecognizes a financial liability when its contractual obligations are discharged, cancelled or expire.

The Company has the following non-derivative financial liabilities: loans and financing, debentures, suppliers and other obligations. Such financial liabilities are recognized initially at fair value plus any directly attributable transaction costs. Subsequent to initial recognition these financial liabilities are measured at amortized cost using the effective interest method.

Share Capital – Common shares are classified as equity. Preferred shares are classified as equity if they are not redeemable, or redeemable only at the Company’s option. Owners of preferred shares do not

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have the right to vote but do have preference in the liquidation of the share capital. The rights to mandatory minimum dividends as established for the preferred shares are described in Note 23.

The mandatory minimum dividends as defined in the by-laws are recognized as a liability in the statement of financial position.

Financial instruments at fair value through profit or loss – A financial asset is classified as a financial instrument at fair value through the profit or loss if it is classified as held for trading or is designated as such upon initial recognition. Financial assets are designated at fair value through profit or loss if the Company manages such investments and makes purchase and sale decisions based on their fair value in accordance with the Company’s documented risk management or investment strategy. Attributable transaction costs are recognized in the income statement when incurred. Financial assets at fair value through profit or loss are measured at fair value, and changes in the fair value are recognized in the income statement for the period. Securities were classified in this category.

Financial instruments available for sale: A financial instrument is classified as available for sale when the purpose for which it was acquired is not investment of funds to obtain short-term gains, and there is no intention of keeping the investments up to maturity or, further, when they do not fit in the other categories. As from December 31, 2012, assets in this category include the financial assets of the transmission and distribution concessions that were covered by Provisional Measure 579, subsequently approved by Congress, becoming Law 12783 of January 11, 2013. They are measured at the New Replacement Value (VNR), equivalent to fair value on the date of these financial statements. The Company recognizes a financial asset resulting from a concession contract when it has an unconditional contractual right to receive cash or another financial asset from, or under the direction of, the concession-granting power for the services of construction or improvement provided.

Loans and receivables – Loans and receivables are financial assets with fixed or calculable payments that are not quoted on an active market. These assets are recognized initially at fair value plus any directly attributable transaction costs. Subsequent to initial recognition loans and receivables are measured at the amortized cost using the effective interest method, less any impairment losses.

The Company holds the following types of loans and receivables: cash, cash equivalents, consumers and traders, concession holders – transport of energy, accounts receivable from the Government of the State of Minas Gerais, , financial assets of the concession not embraced by Provisional Measure 579 (PM 579), converted into Law 12,783, judicial deposits and traders – free energy transactions.

Cash and cash equivalents comprise cash balances, financial deposits and short-term investments with original maturity of three months or less from the date of its contract and are subject to an insignificant risk of change in value, classified as loans and receivables. Cash equivalents are held for the purpose of meeting short-term cash commitments rather than for investment or other purposes.

The Company recognizes a financial asset resulting from a service concession agreement when it has an unconditional contractual right to receive cash or another financial asset from or at the direction of the grantor for the construction or upgrading of services provided. These financial assets are measured at fair value upon initial recognition. Subsequent to initial recognition the financial assets are measured at amortized cost and classified as loans and receivables.

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Derivative financial instruments and hedging activities - The jointly controlled subsidiary Madeira held financial hedge derivative instruments to hedge cash flow and regulate the main financial risk exposures, and the subsidiary Cemig D holds financial hedge derivative instruments to manage their exposures to risks of changes in foreign currency. Derivatives are initially recognized at fair value and attributable transaction costs are recognized in the income statement when incurred. After initial recognition, derivatives are measured at fair value and changes in fair value are recorded in the income statement, except in the circumstances described below for hedge accounting.

The method of accounting for gains and losses of derivatives is subject to the possible classification of the derivative instrument as a cash flow hedge. The effective portion of the changes in fair value of derivatives designated and described as cash flow hedge is recognized in other comprehensive income. The gain or loss related to the ineffective portion is recognized immediately in financial income. The amounts accumulated in equity are realized in the Income Statement in the periods when the hedged item affects the result. For derivatives that are not classified as cash flow hedge, changes in fair value are recognized as gains or losses in the financial results.

For the use of hedge accounting, Madeira applies its policy classifying the applicable derivatives as cash flow hedge, emphasizing that its management considers the instruments that offset between 80% and 125% of the change in price of the item for which the hedge was taken out as highly effective.

b) Foreign currency

Transactions in foreign currencies are translated into the Company’s respective functional currency at the exchange rates at the dates of the transactions. Monetary assets and liabilities denominated in foreign currencies on the reporting date are retranslated into the functional currency at the exchange rate on that date. The exchange gain or loss on monetary items is the difference between the amortized cost in the functional currency at the beginning of the period, adjusted for effective interest and payments made during the period, and the amortized cost in foreign currency translated at the exchange rate at the end of the reporting period. Non-monetary assets and liabilities denominated in foreign currencies that are measured at fair value are retranslated into the functional currency at the exchange rate on the date that the fair value was determined. Foreign currency differences arising on retranslation are recognized in the income statement. Non-monetary items that are measured in terms of historical cost in a foreign currency are translated using the exchange rate on the date of the transaction. See more information on note 3.

Gains and losses arising from changes in foreign currencies related to the jointly-controlled subsidiary Transchile are recognized directly in shareholders’ equity as an accumulated foreign currency translation adjustment, and are recognized in the income statement when these investments are sold, in whole or in part. The financial statements of subsidiaries outside Brazil are adjusted to Brazilian and international accounting practices and are subsequently translated into the Company’s functional currency at the exchange rate on the reporting date.

c) Consumers and Traders

Accounts receivable from consumers, traders and concessionaires are recorded initially at fair value, whether already invoiced or not, and, subsequently, measured by amortized cost. The receivable balance includes the respective direct taxes that are the Company’s tax responsibility, less any applicable tax credits that were withheld at the source.

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The allowance for doubtful accounts is recorded at an amount estimated by management as sufficient to cover probable losses as follows: (i) for consumers with material debts, an individual analysis of the balance is made, taking into account the history of default, negotiations in progress and the existence of real guarantees; (ii) for other consumers, the debts that are more than 90 days past due for residential consumers, or more than 180 days past due for commercial consumers, or more than 360 days past due for the other consumer types, are provisioned at 100%. These criteria are the same as those established by ANEEL.

For large consumers an analysis of individual debtors and the actions underway to receive credits is made.

d) Inventories

Inventories are measured at the lower of cost and net realizable value. The cost of inventories is based on the principle of average cost of acquisition and includes expenditures incurred in acquiring the inventories, and other costs incurred in bringing them to their existing location and condition. The materials purchased for inventory purposes are classified in current assets and are not depreciated or amortized; the materials destined for construction of property, plant and equipment or intangible assets are classified in property, plant and equipment or intangible assets.

Net realizable value is the estimated selling price in the normal course of business, less the estimated costs of completion and selling expenses.

e) Operating leases

Payments made under operating lease agreements are recognized as expenses in the income statement on a straight-line basis over the period of the leasing agreement.

f) Assets linked to the concession

Distribution activity

The portion of the assets of the concession that will be fully amortized during the concession period are recorded as intangible assets and are fully amortized during the concession agreement period.

Amortization reflects the estimated useful life of the assets and is calculated on a straight-line basis over the useful lives of the distribution assets, using the distribution amortization rates established by ANEEL.

The Company assesses the residual value of the distributions assets, which represents the amount that will not be fully amortized by the end of the concession period. The residual value is reported in the consolidated financial statements as a financial asset because it represents an unconditional right to receive cash or another financial asset directly from the grantor at the end of the concession agreement period.

New distribution assets are recorded initially in intangible assets, stated at the cost of acquisition, including the capitalized borrowing costs. When these assets are placed in service, the Company assesses whether there will be any residual value at the end of the concession agreement period and then reclassifies the residual value amount to financial assets, in accordance with the criteria

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mentioned in the previous paragraphs.

When an asset is replaced, the net book value of the asset is written off as an expense to the income statement.

Transmission activity

For new transmission concessions, granted after the year 2000, the costs related to the construction of the infrastructure are expensed when incurred. The Company recognizes construction revenue by reference to the stage of completion of a contract, which includes the taxes applicable to the revenue and any profit margin. Costs of the infrastructure are recorded in the income statement, when incurred. A construction revenue is also recorded in the income statement as a counterpart of a financial asset, because there is an unconditional right to receive cash or other financial assets directly from the grantor during and at the end of the concession agreement period.

For transmission concessions granted before the year 2000, the Company has not adopted the IFRIC 12 retrospectively due to the volume and age of the assets. Instead, the net book values of these assets were used and classified as financial assets for purposes of the first-time adoption of IFRS.

As the Company earns transmission revenue through making its transmission network available to users, and there have been no historical issues with respect to the demand for transmission activity, the Company considers there is no significant risk of a shortage of demand for transmission activity. Accordingly, the transmission assets have been classified as financial assets in the consolidated financial statements.

Of the total amounts billed, the portion related to the operation and maintenance of the assets is recorded as revenue, and the portion related to the construction revenue, originally recorded at the time of formation of the assets, is used to recover the financial assets.

Additions for expansion and reinforcement generate additional cash flow from the grantor and, therefore, this new cash flow is incorporated into the balance of the financial asset.

Due to acceptance of the terms of renewal of certain transmission concessions, as described in more detail in Note 4, the the transmission assets of such concessions will be the subject of indemnity by the Concession-granting Power. As such, as of December 31, 2012, the Company recognized an accounts corresponding to the estimated indemnity to be received.

Gas Activity

The portion of the assets of the concession that will be fully used during the concession period are recorded as intangible assets and are fully amortized during the concession agreement period.

The amortization for the gas related assets is calculated on a straight-line basis over the useful lives of the gas related assets, using the amortization rates based on the useful life estimates made by Management.

The Company has measured the value of the assets which will not be fully amortized by the end of the concession agreement period and reports this amount as a financial asset because it is an

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unconditional right to receive cash or other financial asset directly from the grantor.

New gas related assets are recorded initially in intangible assets, valued at the cost of acquisition, including capitalized borrowing costs. When these assets are placed in service, the Company assesses whether there will be any residual value at the end of the concession agreement period and then reclassifies the residual value to financial assets, in accordance with the criteria described in the previous paragraphs.

When an asset is replaced, the net book value of the assets is written off as an expense to the income statement.

Wind Power Generation Activity

The costs related to construction of the infrastructure are recorded in the income statement when calculating and recording construction revenue based on the stage of completion of the work performed, including taxes on income and any profit margin.

The balances of assets, used during the concession period, are recognized as Intangible Assets.

g) Intangible assets

Intangible assets are assets related to service concession agreements and software.

The Company recognizes intangible assets either through acquisition from third parties or internally generated. For an intangible asset acquired from third parties, the Company values the asset in the financial statements at its total cost of acquisition, net of accumulated amortization. For an internally-generated intangible asset, the Company recognizes the intangible asset during its development phase only if use of the asset is technically feasible and if the asset is likely to produce future economic benefits. The Company values its internally-generated intangible assets at cost, net of accumulated amortization and accumulated impairment losses.

For intangible assets linked to the concession, the accounting practices as described in the item “assets linked to the concession” above are applied.

h) Property, plant and equipment

Items of property, plant and equipment are measured at acquisition or formation cost, including deemed cost and borrowing costs, less accumulated depreciation. Cost includes expenditures that are directly attributable to the acquisition of the asset. The cost of assets built by the Company includes the cost of materials and direct labor, and any other costs directly attributable to bringing the assets to their present location and in working conditions for their intended use.

The subsequent costs are capitalized to the extent that is probable that future benefits associated with the expenses will flow to the Company.

The carrying amount of the replaced asset is written-off, and the repairs and maintenaince costs are fully recorded in the the income statement.

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Depreciation and amortization are calculated on the balance of property, plant and equipment in service and on the underlying asset balances of investments in consortia, on a straight-line basis, using the rates determined by ANEEL for the assets related to electricity activities, and reflect the estimated useful life of the assets.

The principal depreciation rates applied to the Company’s property, plant and equipment assets are shown in Note 15.

Interest and other financing charges incurred on financings linked to the construction in progress during the construction period are capitalized as constructions in progress and consortias.

For borrowings raised for construction purposes of a specific asset of plant, property and equipment, the Company capitalizes all the financial costs related to the borrowings directly to the respective asset constructed. For other borrowings raised that are not linked directly to a specific asset of property, plant and equipment, a weighted average rate is used to capitalize and allocate the borrowing costs of these loans.

i) Impairment

Financial assets

A financial asset not carried at fair value through profit or loss is assessed at each reporting date to determine whether there is objective evidence that it is impaired. A financial asset is impaired if objective evidence indicates that a loss event has occurred after the initial recognition of the asset, and that the loss event had a negative effect on the estimated future cash flows of that asset that can be estimated reliably.

Objective evidence that financial assets are impaired can include default or delinquency by a debtor, restructuring of an amount due to the Company on terms that the Company would not consider otherwise, indications that a debtor or issuer will enter into bankruptcy or the disappearance of an active market for a security. In addition, for an investment in an equity security, a significant or prolonged decline in its fair value below its cost is objective evidence of impairment.

The Company considers evidence of impairment for receivables at both a specific asset and collective level. All individually significant receivables are assessed for specific impairment. All individually significant receivables found not to be specifically impaired are then collectively assessed for any impairment that has been incurred but not yet identified. Receivables that are not individually significant are collectively assessed for impairment by grouping together receivables with similar risk characteristics.

When assessing collective impairment, the Company uses past trends of the probability of default, timing of recoveries and the amount of loss incurred, adjusted to reflect management’s judgment as to whether current economic and credit conditions are such that the actual losses are likely to be greater or less than suggested by historical trends.

An impairment loss in respect of a financial asset measured at amortized cost is calculated as the

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difference between its carrying amount and the present value of the estimated future cash flows discounted at the asset’s original effective interest rate. Losses are recognized in profit or loss and reflected in an allowance account against receivables. Interest on the impaired asset continues to be recognized through the unwinding of the discount. When a subsequent event causes the amount of impairment loss to decrease, the decrease in impairment loss is reversed through profit or loss.

Non-financial Assets

The carrying amounts of the Company’s non-financial assets, other than inventories and deferred income tax and social contribution, are reviewed at each reporting date to determine whether there is any indication of impairment. If any such indication exists, then the recoverable amount of the asset is estimated. The carrying amount of property, plant and equipment and intangible assets is tested if there is evidence that an asset may be impaired.

j) Employee benefits

Defined contribution plans

A defined contribution plan is a post-employment benefit plan under which an entity pays fixed contributions into a separate entity (pension fund) and will have no legal or constructive obligation to pay further amounts. Obligations for contributions to defined contribution pension plans are recognized as an employee benefit expense in the income statement in the periods during which services are rendered by employees. Prepaid contributions are recognized as an asset to the extent that a cash refund or a reduction in future payments is available. Contributions to a defined contribution plan that are due more than 12 months after the end of the period in which the employees render the service are discounted to their present value.

Defined benefit plans

A defined benefit plan is a post-employment benefit plan other than a defined contribution plan. The Company’s net obligation in respect of defined benefit pension plans is calculated separately for each plan by estimating the amount of future benefit that employees have earned in return for their services rendered in the current and prior periods; that benefit is discounted to determine its present value. Any unrecognized past service costs and the fair value of any plan assets are deducted. The discount rate is the yield at the reporting date on well rated bonds that have maturity dates approximating the terms of the Company’s obligations and that are denominated in the same currency in which the benefits are expected to be paid. The calculation is performed annually by a qualified actuary using the projected unit credit method. When the calculation results in a benefit to the Company, the asset to be recognized is limited to the total of any unrecognized past service costs and net actuarial losses and the present value of the economic benefits available in the form of future reimbursements available in the form of any future refunds from the plan or reductions in future contributions to the plan. In order to calculate the present value of the economic benefits, consideration is given to any minimum funding requirements that apply to any plan in the Company. An economic benefit is available to the Company if it is realizable during the life of the plan, or on settlement of the plan’s liabilities.

When the benefits of a plan are improved, the portion of the increased benefit related to the past service of the employees is recognized in the income statement on a straight-line basis over the average period until the benefits become vested. To the extent that the benefits vest immediately, the

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expense is recognized immediately in the income statement.

The Company recognizes all actuarial gains and losses in excess of 10% of the plan assets or 10% of the plan’s liabilities in the income statement over the average time of future service of the present active participants.

For the Company’s defined benefit pension plan obligations, the liability recorded in the statement of financial position is the greater of: a) the debt agreed-upon with the foundation for amortization of the actuarial obligations, and b) the present value of the actuarial obligation after deduction of the fair value of plan assets, as calculated by a qualified actuary and provided in the actuarial opinion. In the years presented, the debt agreed-upon with the foundation is greater than the amounts of the actuarial report. In this case, the annual amount recorded in the income statement corresponds to the charges and monetary variation on that debt, which is recognized as a financial expense of the Company.

Other long-term employee benefits

The Company’s net obligation in respect of long-term employee benefits other than pension plans is the amount of the future benefit that employees have earned in return for their service in current and prior periods; that benefit is discounted to determine its present value, and the fair value of any related assets is deducted. The discount rate is the yield at the reporting date on well rated bonds that have maturity dates approximating the terms of the Company’s obligations. The calculation is performed annually by a qualified actuary using the projected unit credit method. Any actuarial gains and losses are recognized in the income statement in the period in which they arise.

The procedures mentioned above are used for the actuarial obligations related to the Company’s employee health plan, life insurance plan, and dental plan.

Termination benefits

Termination benefits are recognized as an expense when the Company is committed demonstrably, without realistic possibility of withdrawal, to a formal detailed plan to either terminate the employment before the normal retirement date, or to provide termination benefits as a result of an offer made to encourage voluntary redundancy. Termination benefits for voluntary redundancies are recognized as an expense if the Company has made an offer of voluntary redundancy, it is probable that the offer will be accepted, and the number of acceptances can be reliably estimated.

Short-term employee benefits

Short-term employee benefit obligations are measured on an undiscounted basis and are expensed as the related service is provided.

A liability is recognized for the amount expected to be paid under short-term cash bonus or profit-sharing plans if the Company has a present legal or constructive obligation to pay this amount as a result of past services provided by the employee, and the obligation can be estimated reliably. Employee profit sharing specified in the Company’s by-laws is accrued in accordance with the requirements established in the collective agreements with the employee unions and recorded in employee and manager profit sharing.

k) Provisions

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A provision is recognized if, as a result of a past event, the Company has a present legal or constructive obligation that can be estimated reliably, and it is probable that an outflow of economic benefits will be required to settle the obligation.

Onerous Contracts – A provision for onerous concessions is recognized when the expected benefits to be derived from the contract are lower than the unavoidable cost of meeting the obligations of the concession. The provision is measured at present value at the lower of the expected cost of terminating the concession contract and the expected net cost of continuing with it.

l) Income tax and social contribution

Current and deferred income tax and the social contribution are calculated based on the rates of 15%, plus a surcharge of 10% on taxable income exceeding R$240 thousand, for income tax, and 9% on taxable income for the social contribution, and take into account offsetting of tax loss carry forwards and negative balances for calculation of social contribution, limited to 30% of the taxable income.

The income tax and social contribution expense comprises current and deferred taxes. The current tax and the deferred tax are recognized in the income statement unless they are related to a business combination, or items directly recognized in equity or other comprehensive income.

Current tax is the expected tax payable or receivable on the taxable income or loss for the year, using tax rates enacted or substantially enacted at the reporting date, and any adjustment to the tax payable in respect of previous years.

Deferred tax is recognized in respect of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for taxation purposes. Deferred tax is measured at the rates that are expected to be applied to temporary differences when they are reversed, based on the laws that have been enacted or substantially enacted by the reporting date.

Deferred tax assets and liabilities are offset if there is a legally enforceable right to offset current tax liabilities and assets, and they are related to income taxes levied by the same tax authority on the same taxable entity.

A deferred tax asset is recognized for unused tax losses, tax credits and deductible temporary differences, to the extent that it is probable that future taxable profits will be available against which they can be used.

Deferred tax assets are reviewed at each reporting date and are reduced to the extent that it is no longer probable that the related tax benefit will be realized.

m) Revenue

In general, for the Company’s business in electric power, gas, telecommunications and other sectors, revenues are recognized when persuasive evidence exists, usually in the form of an executed sales agreement, that the significant risks and rewards of ownership have been transferred to the customer

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on services rendered and goods sold. It is associated costs and possible return fom sales can be estimated reliably, and the amount of revenue can be measured reliably.

Revenue from electric power sales are recorded based on the energy delivered and the tariffs specified in the contractual terms or in effect in the market. Revenues for energy supplied of electric power to end consumers are recorded when the energy is supplied to customers. The invoicing is performed on a monthly basis. Unbilled energy supplied, from the period between the last billing and the end of each month, is estimated based on the billing from the previous month and is accrued at the end of the month. The differences between the amounts accrued and the actual revenues realized, which have not historically been significant, are recorded in the following month.

Revenue from the supply of electric power to the Brazilian grid system is recorded when the supply has taken place and is invoiced to consumers on a monthly basis, in accordance with the payment schedules specified in the concession agreement.

For newer transmission concessions, the portion of the invoicing related to operation and maintenance of the transmission lines is recorded on a monthly basis as revenues in the income statement. The revenue related to construction services under the contract for service concessions is recognized on a percentage of completion basis.

For the older transmission concessions, the fair value of the operation and maintenance of the transmission lines and the remuneration of the financial asset are recorded as revenue in the income statement each month.

The services provided include charges for connection and other related services and revenues are recorded when the services are provided.

n) Financial income and financial costs

Financial income includes interest income on funds invested, fee income for consumer payments made late, interest income on financial assets of the concession, interest income on other financial assets. Interest income is recognized in the income statement using the effective interest method.

Financial costs include interest expense on borrowings and foreign exchange and monetary variation on borrowings. Interest expense on the Company’s borrowings is recognized using the effective interest method.

o) Earnings per share

Basic earnings per share (EPS) is calculated by dividing the profit or loss attributable to the controlling shareholders of the Company by the weighted average number of common and preferred shares outstanding during the period. Diluted EPS is determined by adjusting the profit or loss attributable to shareholders and the weighted average number of common and preferred shares outstanding, adjusted for own shares held, for the effects of all dilutive potential shares, with the diluted effect in the periods presented.

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p) Segment reporting

An operating segment is a component of the Company that engages in business activities from which it may earn revenues and incur expenses, including revenues and expenses related to transactions with any of the Company’s other components. All operating results of operating segments are reviewed regularly by the Company’s CEO to make decisions on resources to be allocated to the segment and to assess its performance, and for which individual financial information is available. Company’s operates in four segments: electric power, gas, telecommunication and other, as further detailed in Note 5.

Segment results that are reported to the CEO include items directly attributable to a segment as well as those that can be allocated on a reasonable basis. Unallocated items comprise mainly corporate assets, head office expenses and income tax and social contribution assets and liabilities.

Segment capital expenditure is the total cost incurred during the year to acquire property, plant and equipment, and intangible assets other than goodwill.

q) New accounting pronouncements not yet adopted

The Company has not adopted the new and revised IFRS below, which had been issued and not yet adopted. It will present those that it believes to be applicable to its operations in more detail:

■ | IFRS 9 – Financial Instruments (4)
■ | IFRS 10 – Consolidated Financial Statements (2)
■ | IFRS 11 – Joint Arrangements (2)
■ | IFRS 12 – Disclosure of Interests in Other Entities (2)
■ | IFRS 13 – Fair Value Measurement (2)
■ | Changes to IAS 1: Presentation of items of Other Comprehensive Income (1)
■ | Changes to IFRS 7: Disclosure – Offsetting Financial Assets and Financial Liabilities (2)
■ | Changes to IFRS 9 and IFRS 7: IFRS 9: Mandatory effective date of IFRS 9 and Transition Disclosures (4)
■ | Consolidated Financial Statements, Joint Arrangements and Disclosure of Interests in Other Entities: Transition Guidance (Amendments to IFRS 10, IFRS 11 and IFRS 12) (2)
■ | IAS 19 (revised in 2011) – Employee Benefits (2)
■ | IAS 27 (revised in 2011) – Consolidated and separate financial statements (2)
■ | IAS 28 (revised in 2011) – Investments in Associates and Joint Ventures (2)
■ | Offsetting Financial Assets and Financial Liabilities (Amendments to IAS 32) (3)
■ | Changes to Annual Improvements 2009–2011 Cycle
■ | IFRIC 20 – Stripping Costs in the Production Phase of a Surface Mine (2)
(Key:) | (1) | In effect for annual periods starting on or after July 1, 2012.
| (2) | In effect for annual periods starting on or after January 1, 2013.
| (3) | In effect for annual periods starting on or after January 1, 2014.

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| (4) | In effect for annual periods starting on or after January 1, 2015.

IFRS 9 – Financial Instruments:

IFRS 9 – Financial instruments, issued in November 2009 and altered in October 2010, introduces new requirements for the classification, measurement and write-off of financial assets and liabilities.

IFRS 9 establishes that all the financial assets recognized that are within the scope of IAS 39 – Financial instruments: Recognition and measurement (equivalent to CPC 38) must be subsequently measured at amortized cost or fair value.

The most significant effect of IFRS 9 related to the classification and measurements of financial statements refers to the accounting of the changes in fair value of a financial liability (designated at fair value through profit or loss) attributable to changes in the credit risk of that liability. Specifically, under IFRS 9, in relation to the financial liabilities recognized at fair value through profit or loss, the amount of the change in the fair value of the financial liability attributable to changes in the credit risk of that liability is recognized in “Other comprehensive income”, unless the recognition of the effects of the change in the credit risk of the liability in “Other components of comprehensive income” results in or increases the accounting mismatch in the profit and loss account. Variations in fair value attributable to the credit risk of a financial liability are not reclassified in the profit and loss account. Previously, under IAS 39 and CPC 38, the total amount of the variation in the fair value of the financial asset recognized at fair value through profit or loss was recognized in the profit and loss account.

The Company’s Management expects that the IFRS 9 to be adopted in the financial statements will have a significant effect on the balances reported in relation to its financial assets and liabilities (for example, the financial assets of the concession currently classified as investments available for sale will be measured at fair value at the end of the subsequent reporting periods, and the alterations in fair value will be recognized in profit or loss). However, it is not possible to supply a reasonable estimate of this effect until a detailed review is carried out.

Consolidation, participation agreements, affiliates and related disclosures

In May 2011 a package of five standards on consolidation, participation agreements, affiliates and disclosures was issued, including IFRS 10, IFRS 11, IFRS 12, IAS 27 (revised in 2011) and IAS 28 (revised in 2011).

The main requirements of these five rules are as follows:

IFRS 10 replaced parts of IAS 27 – Consolidated and separate financial statements – that deal with consolidated financial statements. SIC–12 Consolidation: Special Purpose Entities – will be withdrawn, when IFRS 10 is applied. Under IFRS 10, there is only one basis for consolidation, namely, control. Additionally, IFRS 10 will include a new definition of control which contains three elements: (a) power over an investee; (b) exposure, or rights, to variable returns from the holding in the investee; and (c) capacity to use its power over the investee to effect the value of the returns to the investor. Wide-ranging orientations have been included in IFRS 10 to deal with complex scenarios.

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IFRS 11 replaces IAS 31 – Interests in joint ventures. IFRS 11 deals with how a participation agreement in which two or more parties have joint control should be classified. SIC-13 – Jointly Controlled Entities – Non-Monetary Contributions by Venturers – will be withdrawn with the application of IFRS 11. Under IFRS 11, participation agreements are classified as joint operations or joint ventures, depending on the rights and obligations of the parties to the agreements. Additionally, under IFRS 11, joint ventures must be accounted by the equity method, while jointly-controlled subsidiaries, under the previous criterion of IAS 31, allowed accounting by the equity method or by the proportional accounting method.

IFRS 12 is a disclosure standard applicable to entities that have holdings in subsidiaries, participation agreements, affiliates and/or structured entities that are not consolidated. In general, the requirements for disclosure under IFRS 12 are more wide-ranging than the present rules.

These five rules, together with the respective changes related to the rules for transition, are applicable to annual periods starting on or after January 1, 2013.

Management believes that the application of these five rules will cause a significant effect on the amounts reported in the Company’s consolidated financial statements. All the entities that are jointly-controlled by the Company listed in Note 3 (c), are proportionately consolidated in these financial statements, and qualify as joint ventures under the requirements of IFRS 11. Thus, they will in future be presented by the equity method starting in 2013.

As a result the adoption, Management expects the following approximate impacts on Company’s 2012 figures: A reduction of total assets and total liabilities in the amount of R$ 7,630 million; a reduction in Operational profit before Financial revenue (expenses) and taxes of R$ 1,213 million; and a reduction in net revenue in the amount of R$ 3,850 million. The profit for the year, and total equity, would not be affected by adoption of the new practices.

IFRS 13 - Measurement at fair value

IFRS 13 presents a single source of orientation for measurements of fair value and disclosures on measurements of fair value. The rule defines fair value, presents a structure of measurement of fair value and requires disclosures of the measurements of fair value. The scope of IFRS 13 is wide-ranging, applying to items of financial and non-financial instruments, for which other IFRS call for or allow measurements of fair value and disclosures of measurements of fair value, except in certain cases. For example, quantitative and qualitative disclosures, based on the three-level hierarchy of fair value currently required for financial instruments only in accordance with IFRS 7 – Financial Instruments – Disclosures, will be complemented by IFRS 13 so as to include all assets and liabilities in their scope.

IFRS 13 is applicable for annual periods starting on or after January 1, 2013.

Management expects that the adoption of this new rule could affect certain amounts reported in the financial statements and result in more wide-ranging disclosures in its financial statements.

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Changes to IAS 1

The changes to IAS 1 allow presentation of the Profit and loss account and the Statement of comprehensive income in a single statement or in two separate and consecutive statements. However, the changes to IAS 1 call for additional disclosures in the section of Other comprehensive income, in such a way that the items of Other comprehensive income are grouped in two categories: (a) items which will not be subsequently reclassified in the profit and loss account; and (b) items which will be subsequently reclassified in the profit and loss account in accordance with certain conditions. The income tax on the items of Other comprehensive income will be allocated in the same way.

The changes to IAS 1 are applicable for annual periods starting on or after July 1, 2012. The presentation of the items of Other comprehensive income will be appropriately modified as and when the changes are adopted in future accounting periods.

Changes to IFRS 7 and IAS 32 – Offsetting Financial Assets and Financial Liabilities, and related disclosures

The changes to IAS 32 clarify questions of adoption existing in relation to the requirements for offsetting of financial assets and liabilities. Specifically, these alterations clarify the meaning of “at present has the legal right to offset” and “simultaneous realization and settlement”.

The alterations to IFRS 7 require that entities disclose the information on the rights of offsetting and related agreements (such as requirements for guarantees) for the financial instruments that are subject to offsetting or similar contracts.

The changes to IFRS 7 are applicable for annual periods beginning on or after January 1, 2013 and periods intermediate to these annual periods. The disclosures should be made retroactively for all the periods compared. However, the changes to IAS 32 are not applicable to annual periods starting before January 1, 2014, with backdated adoption required.

Management believes that the adoption of these changes to IAS 32 and IFRS 7 could result in additional disclosures in relation to offsetting of financial assets and liabilities in the future.

IAS 19 – Employee benefits

The changes to IAS 19 change the accounting of defined-benefit plan and severance benefit. The most significant change relates to accounting of the changes in the defined-benefit obligations and assets of the plan in the year itself, with the elimination of the “corridor approach” permitted in the previous version of IAS 19 and early recognition of the cost of past services. The changes require that all actuarial gains and losses be recognized immediately through Other comprehensive income so that the net assets or liabilities of the pension plan are recognized in the consolidated Statement of financial position to reflect the full value of the plan’s deficit or surplus. Further, the expenses on interest and the expected return on the plan’s assets used in the previous version of IAS 19 had been replaced by a value of “net interest”, calculated on the basis of the discount rate on the assets or liabilities of the net defined benefit.

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The effect arising from the adoption of the new accounting practices for recording of actuarial obligations with post-employment benefits will represent a reduction in equity on January 1, 2013 in the amount of R$ 496,956 (to R$ 105,637 on January 1, 2013). The impact on the profit and loss account for 2013 arising from the review of the Pronouncement will represent a reduction of R$ 18 million in the expense on post-employment benefits in comparison with the expense which would be registered in accordance with the former accounting practice.

This net effect represents various adjustments, including the effect of income tax: a) full recognition of the actuarial gains through Other comprehensive income and reduction of the net deficit of the pension fund; b) immediate reduction of the cost of past services in the profit and loss account and increase of the net deficit of the pension fund; and c) reversal of the difference between the gain resulting from the expected rate of return on the pension plan’s assets and the discount rate, through Comprehensive income.

Annual Improvements 2009–2011 Cycle (May 2012)

The annual improvements to the 2009–2011 cycle of IFRS include various alterations to numerous IFRS. The changes to IFRS are applicable for annual periods starting on or after January 1, 2013, and include:

■ Changes to IAS 16 – Property, plant and equipment;

■ Alterations to IAS 32 – Financial instruments: presentation.

Alterations to IAS 16

The changes to IAS 16 set out that replacement parts, equipment and service equipment should be classified as property, plant and equipment to the extent that they are in accordance with the definition of PP&E of IAS 16 and, otherwise, as inventories. Management has not determined whether the changes to IAS 16 will have a significant effect on the Company’s accounting statements.

Changes to IAS 32

The changes to IAS 32 state that the income tax related to distributions to holders of equity instruments and to costs of equity transactions must be accounted in accordance with IAS 12 – Income taxes. Management believes that the changes to IAS 32 will not have a significant effect on the Company’s accounting statements.

Pronouncement not applicable to the Company

■ IFRIC 20 – Stripping Costs in the Production Phase of a Surface Mine.

r) Determination of adjustment to present value

The Company applied the adjustment to present value on certain onerous concession contracts (see note 4) and also on the balance of the debentures issued (see note 19) by the Company. The discount rates used were consistent with the cost of raising funds in transactions with the same term on the date of the transactions, which represents, in the Company’s estimation, a percentage of 12.50%,

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including inflation expectations.

3.PRINCIPLES OF CONSOLIDATION

The financial statements of the subsidiaries and jointly-controlled subsidiaries described in Note 1 have been consolidated for purposes of the consolidated financial statements.

(a) Subsidiaries and jointly-controlled subsidiaries

The financial statements of subsidiaries and jointly-controlled subsidiaries are included in the consolidated financial statements from the date on which the control, or shared control, begins until the date on which the control or shared control ceases. The assets, liabilities and results of the jointly-controlled subsidiaries have been consolidated into the consolidated financial statements using proportional consolidation. The accounting policies of subsidiaries and jointly-controlled subsidiaries are aligned with the policies adopted by the Company.

The joint control of the Company is established through a shareholders’ agreement signed previously, whose strategic, financial and operating decisions are taken with unanimous consent between the parties.

In some jointly controlled companies, Cemig has more than 50% of the voting rights, however, there are shareholders´ agreements that give the minority shareholders relevant rights that represent the sharing of control.

(b) Consortia

The quota-part of the assets, liabilities and revenues and expenses of consortium operations is registered in the subsidiary that owns the corresponding equity interest.

(c) Transactions eliminated on consolidation

Intra-group balances and transactions, and any unrealized income and expenses arising from intra-group transactions, are eliminated when preparing the consolidated financial statements. Unrealized gains arising from transactions with invested companies recorded under the equity method are eliminated against the investment in proportion to the Company’s interest. Unrealized losses are eliminated in the same way as unrealized gains, but only to the extent that there is no evidence of a loss through impairment.

The references made in these financial statements of subsidiaries and jointly controlled companies are performed in proportion to the Company’s interest.

Transchile’s financial statements, for consolidation purposes, are translated from U.S. dollars (Transchile’s functional currency) to Reais based on the exchange rate at the reporting date, since CEMIG’s functional currency is the Real. Foreign currency differences are recognized in other comprehensive income and are presented in shareholders’ equity. Since January 1, 2009, CEMIG’s date of transition to IFRS, the Company has applied IAS 21 – The Effects of Changes in Foreign Exchange Rates and these differences have been recognized in the Equity Valuation Adjustments account.

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The reporting dates of the remaining subsidiaries and jointly-controlled subsidiaries used for consolidation purposes coincide with those of the holding company.

The consolidated financial statements include the balances and transactions of the exclusive investment funds, which the only unit holder is the Company and its subsidiaries. The funds comprise public and private debt securities and debentures of companies with a minimum Brazilian long-term risk rating of A+(bra), thus ensuring high liquidity of the securities.

The exclusive funds, of which financial statements are regularly reviewed and audited, are subject to obligations restricted to payment for services rendered for administration of the assets, attributed to the operation of investments, such as custody fees, audit fees and other expenses. There are no significant financial obligations or assets of the unit holders to guarantee these obligations.

As shown in the table below, the Company uses full and proportional consolidation criteria when preparing its consolidated financial statements. The interest in the Company’s subsidiaries and jointly-controlled subsidiaries presented in the table below based on the subsidiary’s share capital held by CEMIG.

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Subsidiaries and jointly controlled companies |  | Form of consolidation |  | 2012 |  | 2011 |  | 01/01/2011 |
| Direct stake (%) |  | Indirect stake (%) |  | Direct stake (%) |  | Indirect stake (%) |  | Direct stake (%) |  | Indirect stake (%) |
Subsidiaries and jointly controlled companies |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Cemig Geração e Transmissão |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Cemig Baguari Energia |  | Full |  | - |  | 100 |  | - |  | 100 |  | - |  | 100 |
Hidrelétrica Cachoeirão |  | Proportional |  | - |  | 49 |  | - |  | 49 |  | - |  | 49 |
Guanhães Energia |  | Proportional |  | - |  | 49 |  | - |  | 49 |  | - |  | 49 |
Madeira Energia |  | Proportional |  | - |  | 10 |  | - |  | 10 |  | - |  | 10 |
Hidrelétrica Pipoca |  | Proportional |  | - |  | 49 |  | - |  | 49 |  | - |  | 49 |
Baguari Energia |  | Proportional |  | - |  | 69.39 |  | - |  | 69.39 |  | - |  | 69.39 |
Empresa Brasileira de Transmissão de Energia – EBTE |  | Proportional |  | - |  | 49 |  | - |  | 49 |  | - |  | 49 |
Central Eólica Praias de Parajuru |  | Proportional |  |  |  | 49 |  |  |  | 49 |  |  |  | 49 |
Central Eólica Volta do Rio |  | Proportional |  | - |  | 49 |  | - |  | 49 |  | - |  | 49 |
Central Eólica Praias de Morgado |  | Proportional |  | - |  | 49 |  | - |  | 49 |  | - |  | 49 |
Taesa |  | Proportional |  | - |  | 43.36 |  | - |  | 56.69 |  | - |  | 56.69 |
Light Ger |  | Proportional |  | - |  | 49 |  | - |  | 49 |  | - |  | 49 |
Amazônia Energia |  | Proportional |  | - |  | 74.50 |  | - |  | 74.50 |  | - |  | - |
Cemig Distribuição |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Cemig Telecom |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Ativas Data Center |  | Proportional |  | - |  | 49 |  | - |  | 49 |  | - |  | 49 |
Rosal Energia |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Sá Carvalho |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Horizontes Energia |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Usina Térmica Ipatinga |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Cemig PCH |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Cemig Capim Branco Energia |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Cemig Trading |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Efficientia |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Central Termelétrica de Cogeração |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
UTE Barreiro |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Empresa de Serviços e Comercialização de Energia Elétrica |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Cemig Serviços |  | Full |  | 100 |  | - |  | 100 |  | - |  | 100 |  | - |
Gasmig |  | Proportional |  | 59.57 |  | - |  | 55.19 |  | - |  | 55.19 |  | - |
Companhia Transleste de Transmissão |  | Proportional |  | 25 |  | - |  | 25 |  | - |  | 25 |  | - |
Companhia Transudeste de Transmissão |  | Proportional |  | 24 |  | - |  | 24 |  | - |  | 24 |  | - |
Companhia Transirapé de Transmissão |  | Proportional |  | 24.5 |  | - |  | 24.5 |  | - |  | 24.5 |  | - |
Light |  | Proportional |  | 26.06 |  | - |  | 26.06 |  | - |  | 26.06 |  | - |
Light SESA |  | Full |  | - |  | 26.06 |  | - |  | 26.06 |  | - |  | 26.06 |
Light Energia |  | Full |  | - |  | 26.06 |  | - |  | 26.06 |  | - |  | 26.06 |
Light Esco |  | Full |  | - |  | 26.06 |  | - |  | 26.06 |  | - |  | 26.06 |
Light Ger |  | Full |  | - |  | 13.29 |  | - |  | 13.29 |  | - |  | 13.29 |
Light Soluções em Eletricidade |  | Full |  | - |  | 26.06 |  | - |  | 26.06 |  | - |  | 26.06 |
Instituto Light |  | Full |  | - |  | 26.06 |  | - |  | 26.06 |  | - |  | 26.06 |
Itaocara Energia |  | Full |  | - |  | 26.06 |  | - |  | 26.06 |  | - |  | 26.06 |
Lightcom |  | Full |  | - |  | 26.06 |  | - |  | 26.06 |  | - |  | 26.06 |
Amazônia Energia Participações |  | Proportional |  | - |  | 6.65 |  | - |  | 6.65 |  | - |  | 6.65 |
CR Zongshen E-Power Fabricadora de Veículos |  | Proportional |  | - |  | 5.21 |  | - |  | 5.21 |  | - |  | 5.21 |
Axxiom |  | Proportional |  | - |  | 13.29 |  | - |  | 13.29 |  | - |  | 13.29 |
Transchile |  | Proportional |  | 49 |  | - |  | 49 |  | - |  | 49 |  | - |
Companhia de Transmissão Centroeste de Minas |  | Proportional |  | 51 |  | - |  | 51 |  | - |  | 51 |  | - |
Empresa Amazonense de Transmissão de Energia – EATE |  | Proportional |  | 49.98 |  | - |  | 49.98 |  | - |  | 49.98 |  | - |
Sistema de Transmissão Catarinense – STC |  | Full |  | - |  | 39.99 |  | - |  | 39.99 |  | - |  | 30.82 |
Lumitrans Cia. Transmissora de Energia Elétrica |  | Full |  | - |  | 39.99 |  | - |  | 39.99 |  | - |  | 30.82 |
Empresa Brasileira de Transmissão de Energia – EBTE |  | Proportional |  | - |  | 25.49 |  | - |  | 25.49 |  | - |  | 19.65 |
Empresa Paraense de Transmissão de Energia – ETEP |  | Proportional |  | 49.98 |  | - |  | 49.98 |  | - |  | 49.98 |  | - |
Empresa Santos Dumont Energia – ESDE |  | Full |  | - |  | 49.98 |  | - |  | 49.98 |  | - |  | 49.98 |
Empresa Norte de Transmissão de Energia – ENTE |  | Proportional |  | 49.99 |  | - |  | 49.99 |  | - |  | 49.99 |  | - |
Empresa Regional de Transmissão de Energia – ERTE |  | Proportional |  | 49.99 |  | - |  | 49.99 |  | - |  | 49.99 |  | - |
Empresa Catarinense de Transmissão de Energia – ECTE |  | Proportional |  | 19.09 |  | - |  | 19.09 |  | - |  | 19.09 |  | - |
Empresa de Transmissão Serrana - ETSE |  | Full |  | - |  | 19.09 |  | - |  | 19.09 |  | - |  | - |
Axxiom |  | Proportional |  | 49 |  | - |  | 49 |  | - |  | 49 |  | - |
Parati |  | Proportional |  | 25 |  | - |  | 25 |  | - |  | - |  | - |
Light |  | Proportional |  | - |  | 6.43 |  | - |  | 6.43 |  | - |  | - |

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4. CONCESSIONS HELD BY THE CEMIG GROUP; AND THE EFFECTS OF PROVISIONAL MEASURE 579 OF SEPTEMBER 11, 2012 (CONVERTED TO LAW 12783 OF JANUARY 11, 2013)

CEMIG and its subsidiaries and jointly-controlled subsidiaries hold the following concessions from ANEEL:

|  | Location |  | Date of Concession or Authorization |  | Date of Expiration
GENERATION |  | Location: (RIVER) |  |  |  |
Hydroelectric power plants |  |  |  |  |  |
UHE Santo Antônio |  | River Madeira |  | 06/2008 |  | 06/2043
São Simão |  | River Paranaíba |  | 01/1965 |  | 01/2015
Emborcação |  | River Paranaíba |  | 07/1975 |  | 07/2025
Nova Ponte |  | River Araguari |  | 07/1975 |  | 07/2025
Jaguara |  | River Grande |  | 08/1963 |  | 08/2013
Miranda |  | River Araguari |  | 12/1986 |  | 12/2016
Três Marias |  | River São Francisco |  | 04/1958 |  | 07/2015
Volta Grande |  | River Grande |  | 02/1967 |  | 02/2017
Irapé |  | River Jequitinhonha |  | 01/1999 |  | 02/2035
Aimorés |  | River Doce |  | 07/2000 |  | 12/2035
Salto Grande |  | River Santo Antônio |  | 10/1963 |  | 07/2015
Funil |  | River Grande |  | 10/1964 |  | 12/2035
Queimado |  | River Preto |  | 11/1997 |  | 01/2033
Itutinga |  | River Grande |  | 01/1953 |  | 07/2015
Capim Branco I |  | River Araguari |  | 08/2001 |  | 08/2036
Capim Branco II |  | River Araguari |  | 08/2001 |  | 08/2036
Camargos |  | River Grande |  | 08/1958 |  | 07/2015
Porto Estrela |  | River Santo Antônio |  | 05/1997 |  | 07/2032
Igarapava |  | River Grande |  | 05/1995 |  | 12/2028
Piau |  | River Piau / Pinho |  | 10/1964 |  | 07/2015
Gafanhoto |  | River Pará |  | 09/1953 |  | 07/2015
Sá Carvalho |  | River Piracicaba |  | 12/1994 |  | 12/2024
Rosal |  | Itabapoana – RJ |  | 05/1997 |  | 05/2032
Pai Joaquim |  | River Araguari |  | 04/2002 |  | 04/2032
Salto Paraopeba |  | River Paraopeba |  | 10/2000 |  | 10/2030
Machado Mineiro |  | River Pardo |  | 07/1995 |  | 07/2025
Salto do Passo Velho |  | River Capecozinho |  | 10/2000 |  | 10/2030
Salto do Voltão |  | River Capecozinho |  | 10/2000 |  | 10/2030
PCH Cachoeirão |  | River Manhuaçu |  | 07/2000 |  | 07/2030
UHE Baguari |  | River Doce |  | 08/2006 |  | 08/2041
PCH Pipoca |  | River Manhuaçu |  | 09/2001 |  | 09/2031
Light – UHE Fontes Nova |  | River dos Lajes |  | 07/1996 |  | 06/2026
Light – UHE Nilo Peçanha |  | River dos Lajes |  | 07/1996 |  | 06/2026
Light – UHE Pereira Passos |  | River dos Lajes |  | 07/1996 |  | 06/2026
Light – UHE Ilha dos Pombos |  | River Paraíba do Sul |  | 07/1996 |  | 06/2026
Light – UHE Santa Branca |  | River Paraíba do Sul |  | 07/1996 |  | 06/2026
Wind power plants (1) |  | (CITY/STATE) |  |  |  |
Morro do Camelinho |  | Gouveia – MG |  | 03/2000 |  | 01/2017
Praias do Parajuru |  | Berberibe – CE |  | 09/2002 |  | 08/2029
Volta do Rio |  | Aracajú – CE |  | 12/2001 |  | 08/2034
Praia de Morgado |  | Aracajú - CE |  | 12/2001 |  | 08/2034
Grupo Eólico Renova (14) |  | Sudoeste da Bahia |  | 08/2011 |  | 08/2045
Thermoelectric power plants (1) |  | CITY/STATE) |  |  |  |
Igarapé |  | Juatuba – MG |  | 01/2005 |  | 08/2024
Ipatinga |  | Ipatinga – MG |  | 11/2000 |  | 12/2014
Barreiro |  | Belo Horizonte – MG |  | 02/2002 |  | 04/2023
Projects in progress – Hydroelectric power plants (1) |  | (RIVER) |  |  |  |
PCH Dores dos Guanhães |  | River Guanhães |  | 11/2002 |  | 11/2032
PCH Fortuna II |  | River Guanhães |  | 12/2001 |  | 12/2031
PCH Senhora do Porto |  | River Guanhães |  | 10/2002 |  | 10/2032
PCH Jacaré |  | River Guanhães |  | 10/2002 |  | 10/2032

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TRANSMISSION |  | Location: (STATE) |  |  |  |
National Grid |  | Minas Gerais |  | 07/1997 |  | 07/2015
Substation Itajubá – 3 |  | Minas Gerais |  | 10/2000 |  | 10/2030
Transmission Lines |  |  |  |  |  |
Transleste – Irapé – Montes Claros |  | Minas Gerais |  | 02/2004 |  | 02/2034
Transudeste –Itutinga – Juiz de Fora |  | Minas Gerais |  | 03/2005 |  | 03/2035
Transirapé – Irapé – Araçuaí |  | Minas Gerais |  | 03/2005 |  | 03/2035
EBTE – Juína-Brasnorte |  | Mato Grosso |  | 10/2008 |  | 10/2038
ETEP – Tucuruí – Vila do Conde |  | Pará |  | 06/2001 |  | 06/2031
ENTE – Tucuruí – Marabá – Açailândia |  | Pará/Maranhão |  | 12/2002 |  | 12/2032
ERTE – Vila do Conde – Santa Maria |  | Pará |  | 12/2002 |  | 12/2032
EATE – Tucuruí – Presidente Dutra |  | Pará |  | 06/2001 |  | 06/2031
ECTE – Campos Novos – Blumenau |  | Santa Catarina |  | 11/2000 |  | 11/2030
STC – Barra Grande |  | Santa Catarina |  | 06/2006 |  | 06/2036
Lumitrans – Machadinho |  | Santa Catarina |  | 07/2004 |  | 07/2034
Taesa - TSN (1) |  | Goiás/ Bahia |  | 12/2000 |  | 12/2030
Taesa – Munirah (2) |  | Bahia |  | 02/2004 |  | 02/2034
Taesa – Gtesa (3) |  | Pernambuco/ Paraíba |  | 01/2002 |  | 01/2032
Taesa – Patesa (4) |  | Rio Grande do Norte |  | 12/2002 |  | 12/2032
Taesa – NVT (5) |  | Maranhão/Distrito Federal |  | 12/2000 |  | 12/2030
Taesa – ETAU (6) |  | Santa Catarina/Rio G. do Sul |  | 12/2002 |  | 12/2032
Taesa – ETEO (7) |  | São Paulo |  | 05/2000 |  | 05/2030
Taesa – Brasnorte (8) |  | Mato Grosso |  | 03/2008 |  | 03/2038
Taesa – STE (9) |  | Rio Grande do Sul |  | 12/2002 |  | 12/2032
Taesa – ATE (10) |  | Paraná/São Paulo |  | 02/2004 |  | 02/2034
Taesa – ATE II (11) |  | Tocantins/Piauí/Bahia |  | 03/2005 |  | 03/2035
Taesa – ATE III (12) |  | Tocantins/Pará |  | 03/2006 |  | 03/2036
Transchile – LT Charrua – Nueva Temuco |  | Chile |  | 05/2005 |  | 05/2028
Centroeste de Minas – LT Furnas – Pimenta |  | Minas Gerais |  | 03/2005 |  | 03/2035
Projects in progress – Transmission |  |  |  |  |  |
ESDE –Barbacena2-Juiz de Fora 1 |  | Minas Gerais |  | 11/2009 |  | 11/2039
Taesa – São Gotardo (13) |  | Minas Gerais |  | 08/2012 |  | 08/2042
DISTRIBUTION |  |  |  |  |  |
Cemig Distribuição |  |  |  |  |  |
North |  | Minas Gerais |  | 04/1997 |  | 02/2016
South |  | Minas Gerais |  | 04/1997 |  | 02/2016
East |  | Minas Gerais |  | 04/1997 |  | 02/2016
West |  | Minas Gerais |  | 04/1997 |  | 02/2016
Light SESA and Light Energia |  |  |  |  |  |
Metropolitan Region |  | Rio de Janeiro |  | 07/1996 |  | 06/2026
Grande Rio |  | Rio de Janeiro |  | 07/1996 |  | 06/2026
Vale do Paraíba |  | Rio de Janeiro |  | 07/1996 |  | 06/2026

(1) TSN – Transmissora Sudeste Nordeste S.A.

(2) Munirah Transmissora de Energia S.A.

(3) Gtesa - Goiânia Transmissora de Energia S.A.

(4) Paraíso Açu Transmissora de Energia S.A.

(5) NVT - Novatrans Energia S.A.

(6) ETAU - Empresa de Transmissão Alto Uruguai S.A.

(7) ETEO - Empresa de Transmissão de Energia do Oeste S.A.

(8) Brasnorte Transmissora de Energia S.A.

(9) STE – Sul Transmissora de Energia S.A.

(10) ATE – Transmissora de Energia S.A.

(11) ATE II – Transmissora de Energia S.A.

(12) ATE III – Transmissora de Energia S.A.

(13) São Gotardo Transmissora de Energia S.A.

(14) Renova Energia S.A.

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The following tables list the authorizations held by Renova Energia S.A:

Small Hydro Plants |  | Contract |  | ANEEL´s Resolution |  | Date of Resolution |  | Installed capacity
Cachoeira da Lixa |  | PROINFA |  | 697 |  | 12/24/2003 |  | 14.8 MW
Colino 2 |  | PROINFA |  | 695 |  | 12/25/2003 |  | 16.0 MW
Colino 1 |  | PROINFA |  | 703 |  | 12/26/2003 |  | 11.0 MW

Wind Power Plants |  | Contract |  | Mining and Energy Ministry Order |  | Date of Order |  | Installed capacity
Centrais Eólicas Alvorada S.A. |  | LER 03/2009 |  | 695 |  | 08/05/2010 |  | 8.0 MW
Centrais Eólicas Candiba S.A. |  | LER 03/2009 |  | 691 |  | 08/05/2010 |  | 9.6 MW
Centrais Eólicas Guanambi S.A. |  | LER 03/2009 |  | 700 |  | 08/06/2010 |  | 20.8 MW
Centrais Eólicas Guirapá S.A. |  | LER 03/2009 |  | 743 |  | 08/19/2010 |  | 28.8 MW
Centrais Eólicas Igaporã S.A. |  | LER 03/2009 |  | 696 |  | 08/05/2010 |  | 30.4 MW
Centrais Eólicas Ilhéus S.A. |  | LER 03/2009 |  | 690 |  | 08/05/2010 |  | 11.2 MW
Centrais Eólicas Lucílio de Almeida S.A. |  | LER 03/2009 |  | 692 |  | 08/05/2010 |  | 24.0 MW
Centrais Eólicas Nossa Senhora Conceição S.A. |  | LER 03/2009 |  | 693 |  | 08/05/2010 |  | 28.8 MW
Centrais Eólicas Pajeú do Vento S.A. |  | LER 03/2009 |  | 694 |  | 08/05/2010 |  | 25.6 MW
Centrais Eólicas Pindaí S.A. |  | LER 03/2009 |  | 699 |  | 08/05/2010 |  | 24.0 MW
Centrais Eólicas Planaltina S.A. |  | LER 03/2009 |  | 697 |  | 08/05/2010 |  | 27.2 MW
Centrais Eólicas Porto Seguro S.A. |  | LER 03/2009 |  | 698 |  | 08/05/2010 |  | 6.4 MW
Centrais Eólicas Rio Verde S.A. |  | LER 03/2009 |  | 742 |  | 08/19/2010 |  | 30.4 MW
Centrais Eólicas Serra do Salto S.A |  | LER 03/2009 |  | 689 |  | 08/05/2010 |  | 19.2 MW
Centrais Eólicas Morrão S.A |  | LER 05/2010 |  | 268 |  | 04/20/2011 |  | 28.8 MW
Centrais Eólicas Seraíma S.A |  | LER 05/2010 |  | 332 |  | 05/27/2011 |  | 28.8 MW
Centrais Eólicas Tanque S.A |  | LER 05/2010 |  | 330 |  | 05/26/2011 |  | 28.8 MW
Centrais Eólicas da Prata S.A |  | LER 05/2010 |  | 117 |  | 03/25/2011 |  | 20.8 MW
Centrais Eólicas dos Araças S.A |  | LER 05/2010 |  | 241 |  | 04/07/2011 |  | 30.4 MW
Centrais Eólicas Ventos dos Nordeste S.A |  | LER 05/2010 |  | 161 |  | 03/18/2011 |  | 22.4 MW
Centrais Eólicas Borgo S.A |  | LEN 02/2011 |  | 222 |  | 04/13/2012 |  | 19.2 MW
Centrais Eólicas Dourados S.A |  | LEN 02/2011 |  | 130 |  | 03/13/2012 |  | 28.8 MW
Centrais Eólicas Maron S.A |  | LEN 02/2011 |  | 107 |  | 03/08/2012 |  | 28.8 MW
Centrais Eólicas Serra do Espinhaço S.A |  | LEN 02/2011 |  | 171 |  | 03/22/2012 |  | 17.6 MW
Centrais Eólicas Ametista S.A |  | LEN 02/2011 |  | 135 |  | 03/14/2012 |  | 28.8 MW
Centrais Eólicas Caetité S.A |  | LEN 02/2011 |  | 167 |  | 03/21/2012 |  | 28.8 MW
Centrais Eólicas Espigão S.A |  | LEN 02/2011 |  | 172 |  | 03/22/2012 |  | 9.6 MW
Centrais Eólicas Pelourinho S.A |  | LEN 02/2011 |  | 168 |  | 03/21/2012 |  | 22.4 MW
Centrais Eólicas Pilões S.A |  | LEN 02/2011 |  | 128 |  | 03/13/2012 |  | 28.8 MW
Renova Energia S.A. (São Salvador) * |  | LEN 06/2012 |  | - |  | - |  | -

* Awaiting publication of Ordinance

Distribution concessions

The concession contracts and the Brazilian legislation establish a mechanism of maximum prices that allows for 3 types of adjustment of tariffs charged: (1) the annual Adjustment; (2) the period Review; and (3) Extraordinary Review.

The company has the right, each year, to receive an annual tariff Adjustment, the purpose of which is to compensate the effects of inflation on tariffs, and make it possible to pass through to consumers certain changes in costs that are outside the Company’s control, such as the cost of electricity, electricity bought for resale, and the sector charges, including charges resulting from the use of the transmission and distribution facilities.

Further to this, Aneel carries out a periodic review of tariff levels – every five years for Cemig D, and every four years for Light – which aims to identify changes in the Company’s costs, and to establish a factor based on

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scale gains, which will be applied in the annual tariff adjustment, to share such gains with the Company’s consumers.

The company also has the right to request an extraordinary review of tariffs, if unpredictable events significantly change the economic/financial equilibrium of the concession. The periodic review and the extraordinary review are subject, to a certain extent, to the discretion of Aneel, although there are specific rules are pre-established for each review cycle. Although it is laid down in the concession contracts that the Company must continue to have economic/financial equilibrium, it cannot be guaranteed that Aneel will set tariffs that will adequately compensate the Company and that revenues and operational profits will not be adversely affected by such tariffs. When the Company requests a tariff adjustment it is necessary to prove the financial impact resulting from these events on its operations.

Under these contracts the Company is authorized to charge its consumers a rate for retail supply of energy that consists of two components:

(1) |  | a portion relating to the costs of generation, transmission and distribution that are non-controllable (“Portion A Costs”); and
(2) |  | a portion of operational costs (“Portion B Costs”).

Both portions are set as part of the original concession for given initial periods. Subsequently to the initial periods, and at regular intervals, Aneel has the authority to review the Company’s costs, to determine inflation adjustments (or other similar adjustment factors), if any, applicable to the Portion B Costs (the “Scalar Adjustment”) for the subsequent period. This review may result in a positive, null or negative scalar adjustment.

Generation concessions

In Generation, the company, as well as selling electricity through auctions to the distributors in the captive market, also sells electricity to Free Consumers in the Free Market (Ambiente de Contratação Livre, or ACL). In the Free Market, electricity is traded by generation concession holders, Small Hydro Plants (PCHs), self-generators, traders, and importers of electricity.

Free consumers are those that have demand exceeding 3 MW at a voltage of 69kV or higher, or at any voltage if their supply began after July 1995.

A consumer that has opted for the Free Market may return to the regulated system only if it gives its distributor five years’ prior notice. The purpose of this period of notice is to ensure that if necessary the distributor will be able to buy additional electricity to supply the re-entry of Free Consumers into the regulated market. The state-controlled generators can sell electricity to Free Consumers, but unlike the private generators they are obliged to do so through an auction process.

Transmission concessions

Under its transmission concession contracts, Cemig is authorized to charge the Tariff for Use of the Transmission System (Tarifa de Uso do Sistema de Transmissão, or TUST). These tariffs are adjusted annually on the same date as the adjustments of the Permitted Annual Revenue (Receitas Anuais Permitidas, or RAP) of

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the transmission concession holders. This tariff period starts on July 1 of the year of publication of the tariffs and runs until June 30 of the subsequent year.

The service of transport of large quantities of electricity for long distances, in Brazil, is provided by a network of transmission lines and substations operating at a voltage of 230 kV or higher, referred to technically as the Basic Grid (Rede Básica), or National Grid.

Any agent of the electricity sector that produces or consumes electricity has the right to use the Basic Grid, as does the consumer, provided certain technical and legal requirements are met. This is referred to as Open Access, and in Brazil is guaranteed by law and by the regulator, Aneel.

The payment for use of transmission service also applies to generation provided by Itaipu Binacional, the company operating the Itaipu plant on the borders of Brazil and Paraguay. However, due to the legal characteristics of that plant, the corresponding charges are assumed by the distribution concessions that hold the respective quotas of its output.

For the newer transmission concessions – granted after the year 2000, the portion of the assets that will not be used during the concession is recorded as a financial asset, because there is an unconditional right to receive cash or other financial assets directly from the grantor at the end of the concession agreement period.

Starting from 2013, for the Company’s older transmission concessions, granted before the year 2000, remuneration will be according to the terms of Provisional Measure 579 (converted into Law 12,783), under which the assets are the property of the Grantor Power, and the Company is remunerated for the operation and maintenance of these assets.

Gas concessions

The concessions for natural gas distribution are given at the State level, and in the state of Minas Gerais the tariffs for natural gas are fixed by the regulatory body – the Minas Gerais State Economic Development Department, in accordance with the market segment. The tariffs comprise a portion for the cost of gas and a portion relative to the operation of the concession. The tariffs are adjusted each quarter to pass through the cost of gas, and once a year, to update the portion that aims to cover the costs relating to the provision of distribution service – remuneration on capital invested – and to cover all the operational, commercial and administrative expenses incurred by the Concession holder.

As well as these adjustments, a Tariff Review is scheduled for July 2015. These reviews should occur each five years, to evaluate variations in the company’s costs and to adapt the tariffs. In the concession contract there is also a possibility of an Extraordinary Review if events take place that put the economic / financial equilibrium of the concession at risk.

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PROVISIONAL MEASURE 579 (FEDERAL LAW 12783)

On September 11, 2012 the Brazilian federal government issued Provisional Measure 579 (“PM 579”), subsequently approved by Congress and sanctioned on January 11, 2013, which makes provisions governing: electricity generation, transmission and distribution concessions; reduction of the sector charges and moderation of tariffs.

With PM 579, the government aimed to close the debate on whether those electricity concessions that are referred to by Articles 17, §5º, 19 and 22 of Law 9074 (of July 7, 1995) and have expiry dates as from 2015, will be renewed, under the terms set out in that Law and in the respective Concession Contracts; or whether they would be put out to tender.

PM 579, when dealing with the extensions of concessions for electricity distribution, transmission and generation covered by the articles listed above, imposed new conditions on the concession holders for extension, allowing extension for a period of 30 years, provided that (i) the expiry dates of those concessions were brought forward, and (ii) concession holders would sign Amendments to their Concession Contracts with the Concession-granting Power, establishing the new conditions.

The extension referred to also depends on express acceptance by the concession holder of the criteria for remuneration, allocation of energy, and quality standards contained in PM 579; and PM 579 also specifies that indemnity for assets not yet amortized or depreciated will be based on the New Replacement Value (Valor Novo de Reposição, or VNR).

Also, concessions not extended under PM 579 will remain with their present holders, and will be tendered (by auction or competition), for 30 years, at the end of each concession contract.

In keeping with the timetable set by PM 579, Mining and Energy Ministry (MME) Ministerial Orders 578 and 579, of October 31, 2012, set out the initial tariffs for the hydroelectric plants covered by PM 579, and also the initial electricity transmission revenues governed by its Article 6, applying to cases where the extension of the concession is brought forward.

On November 1, 2012, Joint Order 580 of the Mining and Energy and Finance Ministries laid down the values of indemnities to be paid to holders of generation and transmission contracts that opt to accept early extension of their concessions. It needs to be pointed out that the amounts of indemnity that have been published for transmission are partial, and do not include the assets dating from before June 2000. There are plans for defining the value of the indemnity for these assets in 2013.

In response to the circumstances created by PM 579, the Company’s Board of Directors made the following decisions in relation to renewal of concessions:

Electricity distribution

Application was made for renewal of the following public electricity distribution service concession contracts:

CEMIG North, N º 002/97;

CEMIG South, N º 003/97;

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CEMIG East, N º 004/97; and

CEMIG West, N º 005/97

– all dated July 10, 1997, and given under DNAEE Ministerial Order 130 of April 17, 1997, published in the federal Official Gazette of April 22, 1997, and extended by Ministerial Order 125 of April 17, 1997 issued by the Mining and Energy Ministry, published in the federal Official Gazette on April 22, 1997.

The expiry dates of the distribution concessions of Cemig D that will be extended for 30 years are in February 2016.

Since the concessions of Light have expiry dates only after 2026, the rules introduced by PM 579 do not affect Light at this moment, and no significant impact to be recognized has been identified.

Electricity transmission

The Company applied for renewal of concession contract 006/97 – Cemig, which governs the transmission facilities under its responsibility classified as being part of the National Grid within the state of Minas Gerais, under Law 9074/95 and the relevant regulations.

The book value of the financial assets relating to contract 006/97 is R$ 635. The indemnity specified in Interministerial Order 580 for the Company’s post-June-2000 transmission assets is R$ 285. As mentioned above, no value for indemnity for the transmission assets prior to June 2000 has yet been disclosed.

Since the company, under the criteria specified in PM 579, has the right to indemnity for the total of its assets that have not yet been depreciated and the actual value of the indemnity has not yet been disclosed by Aneel, the company has estimated indemnity values, using as a reference Aneel Technical Note 387/2012, in which studies are presented for definition of the VNR of the transmission facilities, the total indemnity of Cemig being estimated at R$ 828.

The difference between the book value and the estimated value of the indemnity has been posted by the company as a gain in the Profit and loss account for 2012, in the amount of R$ 192.

The announced indemnity of R$ 285 for the transmission assets subsequent to June 2000 was received in January 2013. It has been specified that the indemnity for the remaining portion, in the estimated amount of R$ 542, will be received over a period of 30 years, in accordance with criteria yet to be decided by the Concession-granting power.

PM 579 does not apply to the transmission concessions of Taesa and TBE, so there are no impacts relating to the VNR to be recognized in their financial statements.

Electricity generation

The Company opted not to renew the electricity generation concessions for the plants listed below, which are included in Concession Contract 007/97 – Cemig Geração:

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Power plant |  | Concession expiry date |  | Installed capacity (MW) |  | Net balance of the assets based on historic cost, at December 31, 2012 |  | Net balance of the assets based on deemed cost, at December 31, 2012 |
Hydroelectric plants |  |  |  |  |  |  |  |  |
Três Marias |  | 07/2015 |  | 396.00 |  |  | 53 |  |  | 429 |  |
Volta Grande |  | 02/2017 |  | 380.00 |  |  | 30 |  |  | 83 |  |
Salto Grande |  | 07/2015 |  | 102.00 |  |  | 14 |  |  | 44 |  |
Itutinga |  | 07/2015 |  | 52.00 |  |  | 3 |  |  | 11 |  |
Camargos |  | 07/2015 |  | 46.00 |  |  | 5 |  |  | 22 |  |
Small Hydro Plants |  |  |  |  |  |  |  |  |  |  |  |
Piau |  | 07/2015 |  | 18.01 |  |  | 1 |  |  | 11 |  |
Gafanhoto |  | 07/2015 |  | 14.00 |  |  | 2 |  |  | 16 |  |
Peti |  | 07/2015 |  | 9.40 |  |  | 2 |  |  | 10 |  |
Tronqueiras |  | 07/2015 |  | 8.50 |  |  | 2 |  |  | 14 |  |
Joasal |  | 07/2015 |  | 8.40 |  |  | 2 |  |  | 10 |  |
Martins |  | 07/2015 |  | 7.70 |  |  | - |  |  | 3 |  |
Cajuru |  | 07/2015 |  | 7.20 |  |  | 4 |  |  | 5 |  |
Paciência |  | 07/2015 |  | 4.08 |  |  | 1 |  |  | 6 |  |
Marmelos |  | 07/2015 |  | 4.00 |  |  | 1 |  |  | 6 |  |
Dona Rita |  | 07/2015 |  | 2.41 |  |  | 1 |  |  | 3 |  |
Sumidouro |  | 07/2015 |  | 2.12 |  |  | 2 |  |  | 2 |  |
Anil |  | 07/2015 |  | 2.08 |  |  | 1 |  |  | - |  |
Poquim |  | 07/2015 |  | 1.41 |  |  | 2 |  |  | 5 |  |
|  |  |  | 1,065.31 |  |  | 126 |  |  | 680 |  |

Note: The amounts for the deemed cost were recorded at the time of adoption of IFRS, on January 1, 2009. The difference between the amount of the deemed cost and the historic cost is posted directly in a specific line of the Company’s equity, without this initial reporting having an effect on the Company’s reported profit.

For the concessions for the Jaguara, São Simão and Miranda plants, which have expiry dates in August 2013, January 2015 and December 2016, respectively, the Company believes that it has the right to extend the concessions on the conditions prior to PM 579, under clauses existing in those contracts and under Article 19 of Law 9074/1995.

The historic balances of the assets of these plants on December 31, 2012 totaled R$ 1,032; and on the basis of deemed cost, used in the adoption of the new accounting standards, was R$ 1,305.The concession contract states that Cemig GT will have the right to indemnity of the assets that have not been depreciated at the end of the concessions, which in the company’s interpretation will take place after the extension mentioned in the previous paragraph.

The other generation concessions of the Cemig group are not governed by PM 579, and thus they produce no impact to be recognized in the financial statements.

Concessions payable

When obtaining the concessions for construction of certain generation projects, the Company agreed to make payments to ANEEL during the concession agreement period as compensation for commecial exploration. The information on the Company’s concessions and the amounts to be paid, refer to the table below:

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Ventures |  | Nominal amount in 2012 |  | Present value in 2012 |  | Amortization period |  | Index
Porto Estrela (Consortium) |  | 390 |  | 138 |  | 08/2001 to 07/2032 |  | IGPM
Irapé |  | 33 |  | 12 |  | 03/2006 to 02/2035 |  | IGPM
Queimado (Consortium) |  | 8 |  | 3 |  | 01/2004 to 12/2032 |  | IGPM
Baguari (Consortium) |  | 5 |  | 2 |  | 09/2009 to 09/2042 |  | IPCA
Itaocara (Consortium) |  | 71 |  | 33 |  | to 09/2036 |  | IGPM

The Company makes its payments to the grantor on a monthly basis in accordance with the payment schedule agreed upon by both the Company and ANEEL. While the agreed-upon payment schedules may stipulate varying monthly amounts of payment, for accounting purposes the Company used the updated carrying amount and recognized the expenses incurred on a straight-line basis over the concession contract period.

The payments paid to the grantor for the Porto Estrela, Irapé, Queimado and Baguari plants in 2012 were approximately R$6.1, R$1.3, R$0.4 and R$0.2 , respectively.

The present value of the payments to be paid in the 12-month period are: R$13.9, R$1.3, R$0.4 and R$0.3 , respectively.

The rate used by CEMIG to discount the face value of its onerous concession liabilities to present value was 12.50%, which represents the average borrowing rate under normal conditions on the date of transition to IFRS.

5. OPERATING SEGMENTS

The Company has three primary operating segments: Generation, Transmission and Distribution. These primary operating segments are configured separately to reflect the regulatory framework of the Brazilian electric power sector, which has different legislations for each segment.

The segments mentioned above reflect the Company’s management and its organizational and monitoring structure. Due to the structure of the regulatory framework, the operating segments were not set up per geographical area.

The Company also operates in the gas, telecommunications and other businesses markets that have a smaller impact on the results of its operations.

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The table below presents disclosures per operating segment for 2012, 2011 and 2010:

FINANCIAL STATEMENTS BY ACTIVITY DECEMBER 31, 2012 |
DESCRIPTION |  | ELECTRIC POWER |  |  |  |  |  |  |  |  |  |  |
| Generation |  | Transmission |  | Distribution |  | Gas |  | Telecom |  | Other |  | Elimination |  | Total |
ASSETS |  | 12,913 |  | 9,929 |  | 14,156 |  | 937 |  | 422 |  | 2,739 |  | (323 | ) | 40,773 |
INVESTMENTS |  | 804 |  | (178) |  | 1,446 |  | 155 |  | 32 |  | 1 |  | - |  | 2,260 |
REVENUE |  | 4,556 |  | 1,680 |  | 11,722 |  | 625 |  | 136 |  | 294 |  | (553) |  | 18,460 |
COST |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
COST OF ELECTRICITY AND GAS |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Electricity bought for resale |  | (767) |  | - |  | (5,275) |  | - |  | - |  | (181) |  | 272 |  | (5,951) |
Charges for the use of the basic transmission grid |  | (287) |  | - |  | (973) |  | - |  | - |  | - |  | 249 |  | (1,011) |
Gas bought for resale |  | - |  | - |  | - |  | (495) |  | - |  | - |  | - |  | (495) |
Total - Cost of electricity and gas |  | (1,054) |  | - |  | (6,248) |  | (495) |  | - |  | (181) |  | 521 |  | (7,457) |
OPERATING COSTS AND EXPENSES |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Personnel and management |  | (194) |  | (143) |  | (911) |  | (21) |  | (39) |  | (53) |  | - |  | (1,361) |
Employee and manager profit sharing |  | (40) |  | (24) |  | (164) |  | - |  | (2) |  | (14) |  | - |  | (244) |
Post-employment obligations |  | (20) |  | (10) |  | (94) |  | - |  | - |  | (10) |  | - |  | (134) |
Materials |  | (10) |  | (10) |  | (58) |  | (1) |  | - |  | (3) |  | - |  | (83) |
Outsourced services |  | (170) |  | (97) |  | (807) |  | (8) |  | (22) |  | (51) |  | 28 |  | (1,127) |
Depreciation and amortization |  | (389) |  | (5) |  | (494) |  | (20) |  | (36) |  | (57) |  | - |  | (1,001) |
Operating provisions |  | 1 |  | 4 |  | (386) |  | - |  | - |  | (401) |  | - |  | (782) |
Royalties for use of water resources |  | (186) |  | - |  | - |  | - |  | - |  | - |  | - |  | (186) |
Construction Cost |  | - |  | (159) |  | (1,446) |  | (25) |  | - |  | - |  | - |  | (1,630) |
Other |  | (114) |  | (40) |  | (371) |  | (3) |  | (19) |  | (91) |  | 5 |  | (634) |
Total - Operational Cost |  | (1,122) |  | (484) |  | (4,731) |  | (78) |  | (118) |  | (680) |  | 33 |  | (7,182) |
TOTAL COST |  | (2,176) |  | (484) |  | (10,979) |  | (573) |  | (118) |  | (861) |  | 553 |  | (14,638) |
GROSS PROFIT |  | 2,380 |  | 1,196 |  | 743 |  | 52 |  | 18 |  | (567) |  | - |  | 3,822 |
Gain on issuance of shares of jointly controlled entities |  | - |  | 259 |  | 5 |  | - |  | - |  | - |  | - |  | 264 |
Equity in subsidiaries |  | (3) |  | - |  | - |  | - |  | - |  | - |  | - |  | (3) |
Financial Revenues |  | 131 |  | 156 |  | 327 |  | 32 |  | 11 |  | 2,553 |  | - |  | 3,210 |
Financial Expenses |  | (429) |  | (564) |  | (727) |  | (13) |  | (13) |  | (212) |  | - |  | (1,958) |
Profit before taxes |  | 2,079 |  | 1,047 |  | 348 |  | 71 |  | 16 |  | 1,774 |  | - |  | 5,335 |
Income tax and social contribution tax |  | (612) |  | (107) |  | (429) |  | (14) |  | (4) |  | (338) |  | - |  | (1,504) |
Deferred income tax and social contribution tax |  | 56 |  | (124) |  | 374 |  | - |  | (2) |  | 137 |  | - |  | 441 |
PROFIT FOR THE YEAR |  | 1,523 |  | 816 |  | 293 |  | 57 |  | 10 |  | 1,573 |  | - |  | 4,272 |

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FINANCIAL STATEMENTS BY ACTIVITY AT DECEMBER 31, 2011 RECLASSIFIED |
DESCRIPTION |  | ELECTRIC POWER |  |  |  |  |  |  |  |  |  |  |
| Generation |  |  | Transmission |  |  | Distribution |  |  | Gas |  |  | Telecom |  |  | Other |  |  | Elimination |  |  |  | Total |  |
ASSETS |  | 12,104 |  |  | 8,711 |  |  | 13,128 |  |  | 854 |  |  | 420 |  |  | 14,702 |  |  | (12,910 | ) |  |  | 37,009 |  |
INVESTMENTS |  | 972 |  |  | 1,030 |  |  | 1,857 |  |  | 84 |  |  | 36 |  |  | - |  |  | - |  |  |  | 3,979 |  |
REVENUE |  | 3,783 |  |  | 1,290 |  |  | 10,548 |  |  | 458 |  |  | 125 |  |  | 50 |  |  | (505 | ) |  |  | 15,749 |  |
COST |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
COST OF ELECTRICITY AND GAS |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Electricity bought for resale |  | (587 | ) |  | - |  |  | (3,921 | ) |  | - |  |  | - |  |  | - |  |  | 230 |  |  |  | (4,278 | ) |
Charges for the use of the basic transmission grid |  | (268 | ) |  | - |  |  | (812 | ) |  | - |  |  | - |  |  | - |  |  | 250 |  |  |  | (830 | ) |
Gas bought for resale |  | - |  |  | - |  |  | - |  |  | (329 | ) |  | - |  |  | - |  |  | - |  |  |  | (329 | ) |
Total - Cost of electricity and gas |  | (855 | ) |  | - |  |  | (4,733 | ) |  | (329 | ) |  | - |  |  | - |  |  | 480 |  |  |  | (5,437 | ) |
OPERATING COSTS AND EXPENSES |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Personnel and managers |  | (176 | ) |  | (137 | ) |  | (839 | ) |  | (19 | ) |  | (28 | ) |  | (50 | ) |  | - |  |  |  | (1,249 | ) |
Employee and manager profit sharing |  | (35 | ) |  | (20 | ) |  | (148 | ) |  | - |  |  | (2 | ) |  | (16 | ) |  | - |  |  |  | (221 | ) |
Post-employment obligations |  | (19 | ) |  | (9 | ) |  | (87 | ) |  | - |  |  | (1 | ) |  | (8 | ) |  | - |  |  |  | (124 | ) |
Materials |  | (11 | ) |  | (12 | ) |  | (72 | ) |  | (1 | ) |  | - |  |  | (2 | ) |  | - |  |  |  | (98 | ) |
Outsourced services |  | (131 | ) |  | (72 | ) |  | (802 | ) |  | (7 | ) |  | (21 | ) |  | (18 | ) |  | 20 |  |  |  | (1,031 | ) |
Depreciation and amortization |  | (409 | ) |  | (6 | ) |  | (505 | ) |  | (22 | ) |  | (35 | ) |  | (6 | ) |  | - |  |  |  | (983 | ) |
Operating provisions |  | (6 | ) |  | (3 | ) |  | (249 | ) |  | - |  |  | (1 | ) |  | 2 |  |  | - |  |  |  | (257 | ) |
Royalties for use of water resources |  | (154 | ) |  | - |  |  | - |  |  | - |  |  | - |  |  | - |  |  | - |  |  |  | (154 | ) |
Construction Cost |  | - |  |  | (117 | ) |  | (1,412 | ) |  | - |  |  | - |  |  | - |  |  | - |  |  |  | (1,529 | ) |
Other |  | (60 | ) |  | (36 | ) |  | (236 | ) |  | (5 | ) |  | (16 | ) |  | (14 | ) |  | 5 |  |  |  | (362 | ) |
Total - Operational Cost |  | (1,001 | ) |  | (412 | ) |  | (4,350 | ) |  | (54 | ) |  | (104 | ) |  | (112 | ) |  | 25 |  |  |  | (6,008 | ) |
TOTAL COST |  | (1,856 | ) |  | (412 | ) |  | (9,083 | ) |  | (383 | ) |  | (104 | ) |  | (112 | ) |  | 505 |  |  |  | (11,445 | ) |
GROSS PROFIT |  | 1,927 |  |  | 878 |  |  | 1,465 |  |  | 75 |  |  | 21 |  |  | (62 | ) |  | - |  |  |  | 4,304 |  |
Equity in subsidiaries |  | (1 | ) |  | - |  |  | - |  |  | - |  |  | - |  |  | - |  |  | - |  |  |  | (1 | ) |
Financial Revenues |  | 178 |  |  | 130 |  |  | 362 |  |  | 26 |  |  | 11 |  |  | 288 |  |  | - |  |  |  | 995 |  |
Financial Expenses |  | (462 | ) |  | (500 | ) |  | (713 | ) |  | (12 | ) |  | (13 | ) |  | (265 | ) |  | - |  |  |  | (1,965 | ) |
Profit before taxes |  | 1,642 |  |  | 508 |  |  | 1,114 |  |  | 89 |  |  | 19 |  |  | (39 | ) |  | - |  |  |  | 3,333 |  |
Income tax and social contribution tax |  | (460 | ) |  | (83 | ) |  | (383 | ) |  | (20 | ) |  | (6 | ) |  | (159 | ) |  | - |  |  |  | (1,111 | ) |
Deferred income tax and social contribution tax |  | 57 |  |  | (62 | ) |  | 69 |  |  | - |  |  | 5 |  |  | 124 |  |  | - |  |  |  | 193 |  |
PROFIT (LOSS) FOR THE YEAR |  | 1,239 |  |  | 363 |  |  | 800 |  |  | 69 |  |  | 18 |  |  | (74 | ) |  | - |  |  |  | 2,415 |  |

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FINANCIAL STATEMENTS BY ACTIVITY DECEMBER 31, 2010 RECLASSIFIED |
DESCRIPTION |  | ELECTRIC POWER |  |  |  |  |  |  |  |  |  |  |
| Generation |  |  |  | Transmission |  |  |  | Distribution |  |  |  | Gas |  |  |  | Telecom |  |  |  | Other |  |  |  | Elimination |  |  |  | Total |  |
ASSETS |  | 11,549 |  |  |  | 7,906 |  |  |  | 11,115 |  |  |  | 842 |  |  |  | 390 |  |  |  | 13,641 |  |  |  | (11,969 | ) |  |  | 33,474 |  |
INVESTMENTS |  | 359 |  |  |  | 1,581 |  |  |  | 2,051 |  |  |  | 52 |  |  |  | 78 |  |  |  | 1 |  |  |  | - |  |  |  | 4,122 |  |
REVENUE |  | 3,311 |  |  |  | 1,072 |  |  |  | 9,184 |  |  |  | 502 |  |  |  | 105 |  |  |  | 131 |  |  |  | (515 | ) |  |  | 13,790 |  |
COST |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
COST OF ELECTRICITY AND GAS |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Electricity bought for resale |  | (382 | ) |  |  | - |  |  |  | (3,570 | ) |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 230 |  |  |  | (3,722 | ) |
Charges for the use of the basic transmission grid |  | (271 | ) |  |  | - |  |  |  | (712 | ) |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 254 |  |  |  | (729 | ) |
Gas bought for resale |  | - |  |  |  | - |  |  |  | - |  |  |  | (225 | ) |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (225 | ) |
Total - Cost of electricity and gas |  | (653 | ) |  |  | - |  |  |  | (4,282 | ) |  |  | (225 | ) |  |  | - |  |  |  | - |  |  |  | 484 |  |  |  | (4,676 | ) |
OPERATING COSTS AND EXPENSES |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Personnel and managers |  | (184 | ) |  |  | (132 | ) |  |  | (822 | ) |  |  | (18 | ) |  |  | (11 | ) |  |  | (45 | ) |  |  | - |  |  |  | (1,212 | ) |
Employee and manager profit sharing |  | (49 | ) |  |  | (26 | ) |  |  | (236 | ) |  |  | - |  |  |  | (1 | ) |  |  | (13 | ) |  |  | - |  |  |  | (325 | ) |
Post-employment obligations |  | (24 | ) |  |  | - |  |  |  | (73 | ) |  |  | - |  |  |  | - |  |  |  | (10 | ) |  |  | - |  |  |  | (107 | ) |
Materials |  | (14 | ) |  |  | (12 | ) |  |  | (106 | ) |  |  | (1 | ) |  |  | (1 | ) |  |  | - |  |  |  | - |  |  |  | (134 | ) |
Outsourced services |  | (132 | ) |  |  | (56 | ) |  |  | (724 | ) |  |  | (5 | ) |  |  | (16 | ) |  |  | (17 | ) |  |  | 27 |  |  |  | (923 | ) |
Depreciation and amortization |  | (402 | ) |  |  | 6 |  |  |  | (489 | ) |  |  | (8 | ) |  |  | (33 | ) |  |  | (1 | ) |  |  | - |  |  |  | (927 | ) |
Operating provisions |  | 4 |  |  |  | (3 | ) |  |  | (252 | ) |  |  | - |  |  |  | 1 |  |  |  | 112 |  |  |  | - |  |  |  | (138 | ) |
Royalties for use of water resources |  | (140 | ) |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (140 | ) |
Construction Cost |  | 2 |  |  |  | (212 | ) |  |  | (932 | ) |  |  | (186 | ) |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (1,328 | ) |
Other |  | (58 | ) |  |  | (35 | ) |  |  | (206 | ) |  |  | 1 |  |  |  | (12 | ) |  |  | (15 | ) |  |  | 4 |  |  |  | (321 | ) |
Total - Operational Cost |  | (997 | ) |  |  | (470 | ) |  |  | (3,840 | ) |  |  | (217 | ) |  |  | (73 | ) |  |  | 11 |  |  |  | 31 |  |  |  | (5,555 | ) |
TOTAL COST |  | (1,650 | ) |  |  | (470 | ) |  |  | (8,122 | ) |  |  | (442 | ) |  |  | (73 | ) |  |  | 11 |  |  |  | 515 |  |  |  | (10,231 | ) |
GROSS PROFIT |  | 1,661 |  |  |  | 602 |  |  |  | 1,062 |  |  |  | 60 |  |  |  | 32 |  |  |  | 142 |  |  |  | - |  |  |  | 3,559 |  |
Equity in subsidiaries |  | 201 |  |  |  | 117 |  |  |  | 332 |  |  |  | 25 |  |  |  | 7 |  |  |  | 69 |  |  |  | 90 |  |  |  | 841 |  |
Financial Revenues |  | (454 | ) |  |  | (364 | ) |  |  | (606 | ) |  |  | (9 | ) |  |  | (5 | ) |  |  | (66 | ) |  |  | (90 | ) |  |  | (1,594 | ) |
Profit before taxes |  | 1,408 |  |  |  | 355 |  |  |  | 788 |  |  |  | 76 |  |  |  | 34 |  |  |  | 145 |  |  |  | - |  |  |  | 2,806 |  |
Income tax and social contribution tax |  | (436 | ) |  |  | (80 | ) |  |  | (209 | ) |  |  | (16 | ) |  |  | (5 | ) |  |  | (126 | ) |  |  | - |  |  |  | (872 | ) |
Deferred income tax and social contribution tax |  | 63 |  |  |  | 14 |  |  |  | (6 | ) |  |  | - |  |  |  | (1 | ) |  |  | 254 |  |  |  | - |  |  |  | 324 |  |
PROFIT FOR THE YEAR |  | 1,035 |  |  |  | 289 |  |  |  | 573 |  |  |  | 60 |  |  |  | 28 |  |  |  | 273 |  |  |  | - |  |  |  | 2,258 |  |

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6. CASH AND CASH EQUIVALENTS

|  | 2012 |  | 2011 |  | 2010 |
Bank accounts |  | 157 |  | 157 |  | 95 |
Financial investments |  |  |  |  |  |  |
Bank certificates of deposit |  | 2,250 |  | 2,346 |  | 2,516 |
National Treasury Bonds (LTNs) |  | - |  | 26 |  | - |
Financial Bonds - Banks |  | - |  | 177 |  | - |
Others |  | 79 |  | 156 |  | 369 |
|  | 2,329 |  | 2,705 |  | 2,885 |
|  | 2,486 |  | 2,862 |  | 2,980 |

These financial investments are transactions contracted with Brazilian institutions and international financial institutions with branches in Brazil for securities at normal market prices and under normal market conditions. All of these investments are readily convertible into known amounts of cash and are subject to an insignificant risk of change in value and there is no restriction on its use. The Company holds Time Deposits with Special Guarantees (DPGEs), which receive a percentage of return based on the CDI rate (which varies from 100% to 110%) published by CETIP (the Clearing House for the Custody and Financial Settlement of Securities).

The Company’s exposure to interest rate risk and a sensitivity analysis of the Company’s financial assets and liabilities are shown in Note 28.

7. SECURITIES

Securities refers to financial investments in transactions contracted with Brazilian financial institutions, and international financial institutions that have branch offices in Brazil, at market prices and on market conditions.

|  | 2012 |  | 2011 |  | 01/01/2011 |
Cash investments |  |  |  |  |  |  |
Current |  |  |  |  |  |  |
Bank certificates of deposit |  | 991 |  | 359 |  | 322 |
Treasury Financial Notes (LFTs) |  | 21 |  | - |  | - |
Financial Notes – Banks |  | 361 |  | - |  | - |
National Treasury Notes (NTNs) |  | 80 |  | - |  | - |
Debentures |  | 67 |  | - |  | - |
Others |  | 38 |  | - |  | - |
|  | 1,558 |  | 359 |  | 322 |
Non-current |  |  |  |  |  |  |
Bank certificates of deposit |  | 26 |  | - |  | - |
Financial Notes – Banks |  | 79 |  | - |  | - |
Debentures |  | 2 |  | - |  | - |
Others |  | 55 |  | - |  | - |
|  | 162 |  | - |  | - |
|  | 1,720 |  | 359 |  | 322 |

These securities are classified in accordance with the accounting rules in Explanatory Note 28.

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8. CONSUMERS AND TRADERS

Consumer category |  | Balances not yet due |  | Up to 90 days past due |  | More than 90 days past due |  | Total |
|  | 2012 |  | 2012 |  | 2011 |  | 01/01/2011 |
Residential |  | 615 |  | 248 |  | 282 |  | 1,145 |  | 1,189 |  | 1,023 |
Industrial |  | 506 |  | 92 |  | 164 |  | 762 |  | 787 |  | 711 |
Commercial, services and others |  | 373 |  | 70 |  | 192 |  | 635 |  | 563 |  | 466 |
Rural |  | 71 |  | 24 |  | 29 |  | 124 |  | 115 |  | 102 |
Governmental entities |  | 117 |  | 17 |  | 61 |  | 195 |  | 156 |  | 139 |
Public illumination |  | 44 |  | 5 |  | 22 |  | 71 |  | 95 |  | 84 |
Public service |  | 60 |  | 12 |  | 48 |  | 120 |  | 184 |  | 194 |
Subtotal – Consumers |  | 1,786 |  | 468 |  | 798 |  | 3,052 |  | 3,089 |  | 2,719 |
Wholesale supply to other concession holders |  | 213 |  | 44 |  | 6 |  | 263 |  | 241 |  | 195 |
Spot supply transactions |  | 62 |  | - |  | 8 |  | 70 |  | - |  | - |
Allowance for doubtful accounts receivable |  | - |  | - |  | (723) |  | (723) |  | (621) |  | (555) |
Total – Consumers and traders |  | 2,061 |  | 512 |  | 89 |  | 2,662 |  | 2,709 |  | 2,359 |
Current assets |  |  |  |  |  |  |  | 2,347 |  | 2,550 |  | 2,263 |
Non-current assets |  |  |  |  |  |  |  | 315 |  | 159 |  | 96 |

The breakdown of the allowance for doubtful accounts, by consumer category, is as follows:

|  | 2012 |  | 2011 |  | 01/01/2011 |
Residential |  | 252 |  | 317 |  | 249 |
Industrial |  | 254 |  | 106 |  | 98 |
Commercial, services and others |  | 159 |  | 152 |  | 116 |
Rural |  | 16 |  | 16 |  | 17 |
Governmental entities |  | 22 |  | 6 |  | 26 |
Public illumination |  | 11 |  | 12 |  | 19 |
Public service |  | 9 |  | 12 |  | 30 |
|  | 723 |  | 621 |  | 555 |

The allowance for doubtful accounts is considered to be sufficient to cover any losses on the recoverability of these assets.

Changes in the allowance for doubtful accounts in 2012 and 2011 were as follows:

Balance at January 1, 2011 |  | 555 |
Formation of provision |  | 164 |
Write-offs of accounts receivable |  | (98) |
Balance at December 31, 2011 |  | 621 |
Provision accrued |  | 315 |
Write-offs of accounts receivable |  | (213) |
Balance at December 31, 2012 |  | 723 |

The Company’s exposure to credit risk related to accounts receivables from consumers and traders is presented in Note 28.

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9. RECOVERABLE TAXES

|  | 2012 |  | 2011 |  | 01/01/2011 |
Current |  |  |  |  |  |  |
Recoverable ICMS |  | 187 |  | 153 |  | 223 |
PIS and PASEP |  | 17 |  | 33 |  | 27 |
COFINS |  | 139 |  | 157 |  | 117 |
Other |  | 17 |  | 11 |  | 7 |
|  | 360 |  | 354 |  | 374 |
NON CURRENT |  |  |  |  |  |  |
Recoverable ICMS |  | 275 |  | 243 |  | 85 |
PIS, PASEP and COFINS |  | 30 |  | 15 |  | 55 |
|  | 140 |  | 70 |  | - |
|  | 445 |  | 328 |  | 140 |
|  | 805 |  | 682 |  | 514 |

PASEP and COFINS credits originate from acquisitions of property, plant and equipment and can be offset against state taxes payable over 48 months.

The recoverable ICMS (VAT) tax credits, recorded in non-current assets, originate from acquisitions of property, plant and equipment and can be used to offset state tax obligations over a 48 month period. The amount reclassified to current assets as of December 31, 2011 was made in accordance with management’s estimates of the amounts which will be used on or before December 31, 2012.

10. INCOME TAX AND SOCIAL CONTRIBUTION

a) Income Tax And Social Contribution Recoverable

The balances of income tax and social contribution refer to tax credits in the income tax returns from previous years and advance payments made in 2012, which will be offset against the amount of federal tax payable calculated for the year 2013, recorded under Taxes payable.

|  | 2012 |  | 2011 |  | 01/01/2011 |
Current |  |  |  |  |  |  |
Income tax |  | 194 |  | 171 |  | 353 |
Social contribution |  | 69 |  | 50 |  | 137 |
|  | 263 |  | 221 |  | 490 |
Non-current |  |  |  |  |  |  |
Income tax |  | 32 |  | 21 |  | 66 |
Social contribution |  | 2 |  | 2 |  | 17 |
|  | 34 |  | 23 |  | 83 |
|  | 297 |  | 244 |  | 573 |

b) Deferred Income Tax And Social Contribution

CEMIG and its subsidiaries and jointly-control subsidiaries have income taxes and social contribution calculated at the statutory annual rates of 25% and 9%, respectively. The Company’s tax credits for these taxes are comprised as follows:

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|  | 2012 |  |  |  | 2011 |  |  |  | 01/01/2011 |  |
Tax credits: |  |  |  |  |  |  |  |  |  |  |  |
Tax loss carryforwards |  | 366 |  |  |  | 409 |  |  |  | 569 |  |
Provisions |  | 146 |  |  |  | 142 |  |  |  | 128 |  |
Employee post-retirement benefits |  | 391 |  |  |  | 369 |  |  |  | 350 |  |
Allowance for doubtful accounts receivable |  | 249 |  |  |  | 212 |  |  |  | 192 |  |
Tax credits on absorption of subsidiary |  | 104 |  |  |  | 329 |  |  |  | 84 |  |
Taxes payable – suspended liability (1) |  | 179 |  |  |  | 181 |  |  |  | 143 |  |
Paid concessions |  | 66 |  |  |  | 62 |  |  |  | 58 |  |
Regulatory assets not recognized by IFRS |  | 230 |  |  |  | - |  |  |  | - |  |
Others |  | 50 |  |  |  | 145 |  |  |  | 119 |  |
Total |  | 1,781 |  |  |  | 1,849 |  |  |  | 1,643 |  |
Deferred obligations |  |  |  |  |  |  |  |  |  |  |  |
Cost of issuing securities |  | (6 | ) |  |  | (4 | ) |  |  | (3 | ) |
Foreign exchange variations |  | (21 | ) |  |  | (18 | ) |  |  | (17 | ) |
Deemed cost of property, plant and equipment |  | (385 | ) |  |  | (521 | ) |  |  | (566 | ) |
Adjustment to present value |  | (84 | ) |  |  | (81 | ) |  |  | (80 | ) |
Adjustments for application of IFRIC12 – Concession contracts |  | (236 | ) |  |  | (315 | ) |  |  | (178 | ) |
Borrowing costs, capitalized |  | (27 | ) |  |  | (21 | ) |  |  | (5 | ) |
Regulatory liabilities not recognized by IFRS |  | - |  |  |  | (82 | ) |  |  | (49 | ) |
Taxes on income not redeemed – Presumed Profit method |  | (7 | ) |  |  | (4 | ) |  |  | (4 | ) |
Transmission companies: Indemnity gain |  | (81 | ) |  |  | - |  |  |  | - |  |
Assets related to concession |  | (430 | ) |  |  | (451 | ) |  |  | (501 | ) |
Others |  | - |  |  |  | (1 | ) |  |  | (6 | ) |
Total |  | (1,277 | ) |  |  | (1,498 | ) |  |  | (1,409 | ) |
Total, net |  | 504 |  |  |  | 351 |  |  |  | 234 |  |
Total Asset in the Statement of Financial Position |  | 1,452 |  |  |  | 1,236 |  |  |  | 1,218 |  |
Total Liaility in the Statement of Financial Position |  | (948 | ) |  |  | (885 | ) |  |  | (984 | ) |

(1) Income Tax on PASEP/COFINS.

At a meeting on March 26, 2013, the Board of Directors approved the technical study prepared by CEMIG’s Financial and Investor Relations Committees on the forecast for future taxable profits, which shows its ability to use the deferred tax assets according with CVM Instruction nº 371.

The deductible temporary differences and tax loss carry forwards do not expire under current tax law. Deferred tax assets were recognized in relation to these items as it is probable that future taxable income will be available, enabling the Company to use these tax assets.

In accordance with the individual estimates of CEMIG, including its subsidiaries and jointly-controlled subsidiaries, future taxable income will allow the Company to make use of its the deferred tax assets existing at December 31, 2012, as follows:

|  | Estimated Taxable Income |
2013 |  | 395 |
2014 |  | 358 |
2015 |  | 184 |
2016 |  | 198 |
2017 to 2018 |  | 277 |
2019 to 2020 |  | 210 |
2021 and 2022 |  | 159 |
|  | 1,781 |

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c) Reconciliation of income tax and social contribution expenses

The following table presents the reconciliation of the nominal income tax (25% tax rate) and social contribution (9% tax rate) expenses with the actual expenses incurred, as shown in the income statement:

|  | 2012 |  | 2011 |  | 2010 |
Profit before income tax and social contribution |  | 5,335 |  | 3,333 |  | 2,822 |
Income tax and social contribution – nominal expense |  | (1,814) |  | (1,133) |  | (959) |
Tax effects applicable to: |  |  |  |  |  |  |
Equity gain (loss) in in investments |  | (1) |  | - |  | - |
Non-deductible contributions and donations |  | (9) |  | (8) |  | (9) |
Tax incentives |  | 33 |  | 28 |  | 22 |
Tax credits not recognized |  | 34 |  | (2) |  | 2 |
Gain on issuance of shares of jointly controlled entities |  | 90 |  | - |  | - |
Amortization of goodwill |  | - |  | - |  | (10) |
Adjustment in income tax and social contribution – prior year |  | 12 |  | (3) |  | 4 |
Recognition of credits on tax loss carryforwards |  | - |  | 120 |  | 289 |
Interest on Capital |  | 578 |  | - |  | - |
VAT/TUSD legal action settlement – Minas Gerais State |  | (3) |  | - |  | - |
Difference between Presumed Profit and Real Profit |  | 32 |  | 32 |  | - |
Others |  | (15) |  | 48 |  | 97 |
Income tax and social contribution – effective expense |  | (1,063) |  | (918) |  | (564) |
Effective rate |  | 19.93% |  | 27.53% |  | 19.99% |
Current income tax and social contribution |  | (1,504) |  | (1,111) |  | (872) |
Deferred income tax and social contribution |  | 441 |  | 193 |  | 308 |

Income tax incentives of Transmissora Aliança de Energia Elétrica S.A. – Taesa

The Ministry of National Integration, through the Federal Agency for Development of the Northeast (ADENE) and the Federal Agency for the Development of the Amazon Region (ADA), issued Constitutive Reports 169/2004 and 0260/2003 granting some of Taesa’s subsidiaries tax benefits of a 75% reduction to their income tax payable for the activity carried out in the region to which the benefits apply. This benefit is calculated on a monthly quota of operating profit of the Northeast-Southeast line of 84.48%, which is the effective percentage of the line in the state of Bahia, an area subsided by SUDENE (Superintendency for the Development of the Northeast).

11. ESCROW DEPOSITS

The escrow deposits refer mainly to tax and labor issues.

The principal payments into court in relation to tax obligations relate to: income tax withheld on Interest on Equity; and the Pasep and Cofins taxes – in relation to exclusion of VAT tax from the amount taxable by the PASEP and COFINS taxes.

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|  | 2012 |  | 2011 |  | 01/01/2011 |
Labor obligations |  | 264 |  | 207 |  | 212 |
Tax obligations |  |  |  |  |  |  |
Income tax on interest on shareholders´capital |  | 15 |  | 14 |  | 15 |
State inheritance and donation taxes (ITCD) |  | 121 |  | 116 |  | 49 |
Pasep and Cofins tax (a) |  | 725 |  | 720 |  | 554 |
Others |  | 107 |  | 59 |  | 14 |
|  | 968 |  | 909 |  | 632 |
Others |  |  |  |  |  |  |
Regulatory |  | 33 |  | 45 |  | 52 |
Third party claims |  | 7 |  | 6 |  | 6 |
Civil actions |  | 1 |  | 14 |  | 8 |
Consumer works valuation |  | 2 |  | 13 |  | 2 |
Injunctions |  | 110 |  | 92 |  | 55 |
Others (b) |  | 35 |  | 102 |  | 60 |
|  | 188 |  | 272 |  | 183 |
|  | 1,420 |  | 1,388 |  | 1,027 |

(a) The balances of escrow deposits paid into court in relation to the PASEP and COFINS taxes have a corresponding provision recorded in Taxes and contributions. For details please see Note 18.

(b) Most of these items are amounts blocked by the courts under various lawsuits.

12. ACCOUNTS RECEIVABLE FROM THE MINAS GERAIS STATE GOVERNMENT AND CRC ACCOUNT SECURITIZATION FUND

a) CRC Agreement

The credit balance remaining from the Recoverable Results Account (CRC) was passed on to the Government of the State of Minas Gerais in 1995, through an agreement for assignment of the Recoverable Results Account (the “CRC Agreement”) pursuant to Law 8724/93 for monthly amortization over seventeen years, as from June 1, 1998, with interest of 6% per year, restated monthly by the Fiscal Reference Unit (UFIR).

On January 24, 2011, The CRC Agreement was modified to address issues relating to remuneration of the receivable, which replaced the monetary updating unit in the agreement from UFIR to IGP-DI inflation index, backdated to November 2000, due to the abolition of the UFIR in October 2000, and certain guarantees relating to dividend retention by the State Government.

The Second and Third Amendments to the CRC Agreement were signed in October 2002, setting new conditions for amortization of the credits receivable from the Minas Gerais State Government.

As a result of default in receipt of the credits specified in the Second and Third Amendments, the Fourth Amendment was signed, with the aim of making possible full receipt of the CRC balance through retention of dividends becoming payable to State Government. This agreement was approved by the Extraordinary General Meeting of Stockholders completed on January 12, 2006.

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According with the Fourth Amendment to the CRC Agreement, the Minas Gerais State Government would amortize this payable to the Company via 61 consecutive semi-annual installments, which are due on June 30 and December 31 of each year, over the period from June 2005 to June 2035.

b) Creation of CEMIG CRC Account Securitization Fund

On January 27, 2006, Cemig transferred the accounts receivable from the CRC Account Agreement to a credit securitzation investment fund (FDIC). The value of the FIDC was established by the Fund administrator, based on CEMIG’s long term financial predictions, estimating the dividends that would be withheld for amortization of the debit balance of the CRC agreement. Based on these projections, the FIDC, on that date, was valued at the total amount of R$1,659, of which R$900 are senior quotas and R$759 are subordinated quotas.

The senior quotas were acquired by financial institutions and are being amortized in 20 semi-annual installments, starting in June 2006, with interest accruing at the rate of CDI plus 1.7% per year, and are guaranteed by CEMIG.

The subordinated quotas were subscripted by Cemig and corresponded to the difference between the total value of the FIDC and the senior quotas.

The subordinated quotas were updated for monetary valuation purposes in the amount of the difference between the valuation of the FIDC using a rate of 10% per year and the increase in value of the senior quotas, as calculated based on CDI plus 1.7% per year.

To permit the early settlement of the CRC Contract, as described in details in item “c” below, on December 5, 2012 the Company bought back the senior quotas and on December 17, 2012 settled the FIDC, by transacting the receivables at the price posted in the FIDC of R$ 1,785 (R$ 695 for senior units and R$ 1,090 for subordinated units), as authorized by the Board of Directors.

c) Negotiation for the advanced settlement of account receivable from the Minas Gerais State Government - CRC

On November 20, 2012, the Minas Gerais State Government and the Company entered into a Commitment Undertaking, the aim of which was to create the practical conditions for early settlement, in full, of the obligations arising from the CRC Contract. A discount of approximately 35% was applied to the updated amount of the debtor balance, for payment at sight by the State of Minas Gerais to the bank account of the Company.

In the Undertaking, the State of Minas Gerais recognized and declared a liability payable by it under the CRC Contract, with face value of R$ 6,282, as of October 31, 2012, which after application of a discount of 35%, resulted in the amount of R$ 4,084. This amount was updated, and increased by the interest specified in the CRC Contract, up to the date of the actual payment, within the limit period of up to 30 business days from the date of entry of the funds, for each credit transaction carried out by the Statement of Minas Gerais to make the transaction possible. On December 31, 2012, the amount of R$ 4,084, increased by interest and monetary adjustment, comprised a total of R$ 4,168, which after deduction of the carrying amount of the accounts receivable of R$ 1,785, generated a financial gain of R$ 2,383. This amount was posted in the profit and loss in 2012.

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Within the process of negotiation of the early settlement of the CRC, to satisfy a condition for approval of the transaction by the Federal Government, the Company agreed a Term of Settlement to terminate the legal action between Cemig and the Federal Government related to the now-extinct CRC Account. As part of this arrangement, the State retained part of the amounts which would otherwise have been paid through to the Company, and passed through to the federal government the amount of R$ 403, under the settlement referred to. This is set out in more detail in Explanatory Note 23 – Provisions.

The movement of amounts on the CRC account was as follows:

Carrying amount |  | 1,785 |
Monetary updating of the contract as per conditions agreed with Minas Gerais State |  | 2,383 |
Net amounts settled by Minas Gerais State |  | (1,746) |
Balance at December 31, 2012 |  | 2,422 |

The outstanding balance as of December 31, 2012 was settled by the Government of the State on February 27 and 28, 2013.

13. FINANCIAL ASSETS OF THE CONCESSION

As described in Note 2, Item 2.6 (f), the Company’s distribution, transmission, gas and wind generation concession contracts are within the criteria for application of IFRIC 12 Service Concession Arrangements). At the end of the concession period, the grantor will provide indemnity to the Company for the unamortized value of the concession assets according concession agreement between CEMIG and ANEEL and effective legislation and regulatory rules.

As described in more detail in Note 4, the Company accepted renewal of the transmission concession of the subsidiary and the assets were reverted to the Granting Power, with indemnity being established for those assets.

The balances of the financial assets are as follows:

|  | 2012 |  | 2011 |  | 01/01/2011 |
Distribution concessions |  | 5,269 |  | 3,331 |  | 2,509 |
Gas concessions |  | 355 |  | 305 |  | 287 |
Newer transmission concessions |  | 6,405 |  | 5,812 |  | 4,756 |
Older transmission concessions |  | 178 |  | 758 |  | 745 |
|  | 12,207 |  | 10,206 |  | 8,297 |
Current assets |  | 1,041 |  | 1,120 |  | 625 |
Non-current assets |  | 11,166 |  | 9,086 |  | 7,672 |

For newer transmission concessions, the internal rate of return of financial assets ranged between 7.8% and 14.48%, in accordance with the specified characteristics of each concession and their investment dates.

Changes in the financial assets were as follows:

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Balance on December 31, 2011 |  | 10,206 |
Additions |  | 160 |
Acquisition of subsidiaries |  | 556 |
Monetary updating |  | 896 |
Dilution of equity interest in Taesa |  | (839 | )
Amounts received |  | (812 | )
Transfers |  | 1,848 |
Net gain on indemnity of assets |  | 192 |
Balance on December 31, 2012 |  | 12,207 |

On September 11, 2012 the Brazilian government issued Provisional Measure 579, governing renewals of concessions. See details in Note 4.

The Company understands that the financial assets of the gas concession will be indemnified by the Granting Power, that is to say: At the end of the concession the government of the State of Minas Gerais will indemnify the amount of the investments made in the last five years of the concession. For the balances of the financial assets determined by the other goods linked to the concession, the Company believes, and is supported in this opinion by a Legal Note issued by the office of the General Attorney of the State of Minas Gerais, that they will be subject to indemnity at the time of the termination of the concession, by one of the following routes: (i) by the new concession holder, in the event of the concession not being renewed; (ii) by the extension of the concession contact, for a period that is reasonable and necessary for amortization of the assets underlying financial assets, to maintain the balance of the contract; or (iii) through a contractual amendment that changes the indemnity clause to guarantee indemnity of the goods that have not been amortized, at the end of the concession. These options are still in the process of being decided upon by the Grantor Power.

14. INVESTMENTS

The table below gives summary financial information on investments in subsidiaries throw cost method. The figures are adjusted for the percentage stake or interest held by the Company.

|  | 2012 |  | 2011 |  | 01/01/2011 |
Gasmig (investment in progress) |  | - |  | 67 |  | - |
Norte Energia |  | 226 |  | 110 |  | - |
|  | 226 |  | 177 |  | - |

a) Additional acquisition of equity interest in Gasmig

On December 27, 2011 the Board of Directors authorized the acquisition of nominal preferred shares representing 4.38% of the total capital of Gasmig belonging to the government of the State of Minas Gerais, corresponding to a price per share of approximately R$3.75, adjusted by the amount indicated in an independent valuation opinion to be prepared by a specialized institution to be chosen and contracted by Cemig.

Completion of the Opinion resulted in a valuation of the holding acquired at R$65, representing a payment made in excess in the amount of R$2 million, to be restituted by the Minas Gerais State Government, recorded in “Other credits”. On July 9, 2012 the representative of Minas Gerais State signed Gasmig’s Share Transfer Book and as from that date the Company owns 59.57% of Gasmig.

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The fair values recognized in the acquisition are as follows:

Assets |  |  |
Cash and cash equivalents |  | 2 |
Consumers and traders |  | 12 |
Other credits |  | 9 |
Financial assets of the concession |  | 25 |
Intangible |  | 48 |
Liabilities |  |  |
Loans and financings |  | (9 | )
Other obligations |  | (22 | )
Net assets acquired |  | 65 |
Cash disbursed |  | 65 |

b) Stockholding Restructuring Operation in Taesa

The Transmission Assets Investment Contract

On May 17, 2012, Cemig GT entered into a contract (the “Transmission Assets Investment Contract”) with its jointly-controlled subsidiary Taesa, under which all the shareholdings owned by Cemig GT in EBTE (49% of EBTE) will be transferred to Taesa. With the transfer, Taesa will own 74.49% of EBTE, based on the holding of 49% transferred by Cemig GT, plus an indirect holding through EATE of 51% (Taesa owns 49.98% of the shares in EATE) (jointly referred to as “the TBE Group”).

Under the same agreement, Cemig undertakes to transfer to Taesa the totality of the shares held by Cemig in the electricity transmission companies of the TBE Group: ETEP (49.98%); ENTE (49.99%); ERTE (49.99%); EATE (49.98%) and ECTE (19.09%).

The conclusion of this stockholding restructuring transaction, and final transfer of the assets referred to above, was approved on April 9, 2013. See more information in note 34.

Under the Transmission Assets Investment Contract, Taesa is not allowed to dispose of, assign or transfer its holdings in the companies of the TBE Group before expiry of 120 months from the date of actual transfer of the said stockholdings, unless previously authorized by Cemig – but during that period Taesa may make total or partial disposal, assignment or transfer of any stockholding that it holds in the companies of the TBE Group provided that it transfers to Cemig the positive difference obtained on such disposal, assignment or transfer, the comparison being between the value of the consideration for the disposal, assignment or transfer and the amount for which the holdings in the TBE Group were transferred to Taesa, duly updated by the variation of the Selic rate published by the Brazilian Central Bank up to the date of the actual disposal, assignment or transfer.

Contract to assume obligations – change in shareholders’ agreement

On June 29, 2012 the indirect jointly-held subsidiary Taesa, together with Alupar Investimento S.A. (holder, with Cemig and Cemig GT, of control of the companies of the TBE Group) signed a private contract to assume

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obligations, agreeing the following: On January 2, 2013 (or on the date of transfer of the holdings in the companies of the TBE Group to Taesa, whichever is later), amended versions of the Shareholder’s Agreements of the companies in the TBE Group come into effect, and the changes to the respective by-laws must have been voted by Alupar Investimento S.A. and Taesa.

Based on the above, it is Taesa’s understanding that it will cease to hold actual shared control of the companies of the TBE Group when the amended shareholder’s agreements referred to come into force, and that it will from then on have significant influence in those companies.

c) Acquisition of the TBE companies – approvals to date

On July 25, 2012 the request for consent to the transfer of a percentage interest in the concessions (subject of the stockholding restructuring) was filed with Aneel. On October 4, 2012 the Company updated the documents submitted to Aneel, to continue with the process. The matter is currently being considered by Aneel’s Economic and Financial Inspection Department (Superintendência de Fiscalização Econômica e Financeira, or SFF/Aneel), which is expected to state its position on the transaction by December of this year.

d)Acquisition by Taesa of the remaining 50% of Unisa

On November 30, 2011, Taesa acquired from Abengoa, for R$ 800, 50% of the share capital of Unisa (formerly Abengoa Participações S.A.), the corporate objects of which are to hold interests in the equity capital of companies that provide public and private electricity transmission services. Unisa, on that date, held 100% of the shares in the transmission companies STE, ATE, ATE II and ATE III.

On March 16, 2012, Taesa signed a contract with Abengoa for acquisition of the remaining 50% of the share capital of Unisa. Conclusion of the transaction and actual transfer of the shares was at that time subject to certain conditions precedent. On July 3, 2012 Taesa concluded acquisition of the remaining 50% of the shares in Unisa held by Abengoa. This transaction was approved by Cade, the Brazilian monopolies authority, on July 4, 2012.

Based on the above, from November 30, 2011 to July 3, 2012, Unisa was jointly-controlled by Taesa and Abengoa, and as from July 4, 2012 (the acquisition date), became a wholly-owned subsidiary of Taesa. The total value of the consideration paid for the acquisition of the holding was R$ 876, comprising R$ 902 paid in cash, net of constitution of dividends receivable in the amount of R$ 28 and accounts payable in the amount of R$ 2, on the date of calculation of the transaction, under the terms of the agreement signed by the parties.

The assets acquired, and liabilities recognized, on the date of acquisition of the control of Unisa by Taesa (July 3, 2012) were recognized through the acquisition method applicable in the case of business combinations by stages, as shown below:

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July 3, 2012 |  | Fair values recognized on acquisition of Unisa |  | Amount proportional to Cemig GT’s holding |
Assets |  |  |  |  |
Cash and cash equivalents |  | 435 |  | 188 |
Clients |  | 52 |  | 22 |
Financial assets |  | 2,448 |  | 1,062 |
Other assets |  | 177 |  | 77 |
Liabilities |  |  |  |  |
Accounts payable to suppliers and others |  | (95 | ) | (41 | )
Loans and financings |  | (1,008 | ) | (437 | )
Deferred tax payable |  | (257 | ) | (111 | )
Total of the identifiable assets, net |  | 1,752 |  | 760 |
Holding, % |  | 100 | % | 43.36% |
Proportionate amount represented by the percentage holding |  | 1,752 |  | 760 |
Investment previously held |  | (831 | ) | (360 | )
Gain on the re-measurement on acquisition of the control of Unisa (a) |  | (45 | ) |  | (20 | ) |
Consideration transferred for the acquisition of 50% of Unisa on July 3, 2012 |  | 876 |  | 380 |
Amount paid in cash |  | 902 |  | 391 |
Dividends receivable |  | (28 | ) | (12 | )
Accounts payable |  | 2 |  | 1 |
Consideration transferred for the acquisition of 50% of Unisa on July 3, 2012 |  | 876 |  | 380 |

(a) As required by CPC 15(R1) and IFRS 3(R), in a business combination carried out in stages, the acquiring party must re-measure its interest held previously for the fair value on the date of obtaining of control (acquisition date) and must recognize the resulting gain or loss, if any, in the resulting profit and loss account for the period.

The considerations paid by Taesa for the combinations of businesses, through the acquisition of the initial 50% and then the remaining 50% of Unisa, were paid in cash with funds from the Company’s fourth and fifth issues of promissory notes, respectively.

e) New issue of shares by Taesa

On July 19, 2012 the indirectly jointly-controlled subsidiary Taesa issued 24 million Units in a public share offering, at R$ 65 per Unit. The Units in this transaction comprise one common share and two preferred shares, all nominal, of the book-entry type and without par value. On August 20, 2012, the supplementary lot of the public share offering, of three million Units, was exercised in its entirety, resulting in a total of 27 million Units under the public share offering.

The share capital of Taesa was increased, within the limit of its authorized capital ceiling of R$ 1.755 billion, by issuance of 81 million new shares: 27 million common and 54 million preferred. Following the increase the share capital of Taesa is R$ 3,068 which, after deduction of the issue costs of R$ 39, totaled R$ 3,029, comprising 344,498,907 nominal, book-entry shares without par value: 230,517,711 common and 113,981,196 preferred. Pursuant to Article 172, I, of the Brazilian Corporate Law and Article 9 of the Company’s by-laws, there was no first refusal right for existing stockholders of the Company in the subscription.

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With this issuance of shares Cemig GT reduces its percentage equity interest in Taesa, from 56.69% to 43.36% of the total capital, comprising 97,690,743 common shares and 51,683,548 preferred shares, as follows:

|  | COMMON SHARES |  | PREFERRED SHARES |  | TOTAL |
STOCKHOLDERS |  | Number of shares |  | % |  | Number of shares |  | % |  | Number of shares |  | % |
Taesa: Total shares issued |  | 230,517,711 |  | 100.00% |  | 113,981,196 |  | 100.00% |  | 344,498,907 |  | 100.00% |
Cemig GT |  | 97,690,743 |  | 42.38% |  | 51,683,548 |  | 45.34% |  | 149,374,291 |  | 43.36% |

This table shows the Company’s stockholding on December 31, 2011:

|  | COMMON SHARES |  | PREFERRED SHARES |  | TOTAL |
STOCKHOLDERS |  | Number of shares |  | % |  | Number of shares |  | % |  | Number of shares |  | % |
Taesa: Total shares issued |  | 203,517,711 |  | 100.00% |  | 59,981,196 |  | 100.00% |  | 263,498,907 |  | 100.00% |
Cemig GT |  | 97,690,743 |  | 48.00% |  | 51,683,548 |  | 86.17% |  | 149,374,291 |  | 56.69% |

Effects of the Taesa public share offering on Cemig’s profit and loss

As mentioned, Taesa issued shares at the price of R$ 65, which was higher than the book value of the shares in Taesa prior to the issue. The difference between the book value and the par value gave rise to a gain in the amount of R$ 259, reported in the profit and loss account of Cemig for the third quarter of 2012.

The effects on the Company’s consolidated cash flow are as follows:

Assets |  |  |
Consumers and traders |  | (23 | )
Other credits |  | (123 | )
Financial assets of the concession |  | (839 | )
Intangible assets |  | (201 | )
Liabilities |  |  |
Loans and financings |  | 455 |
Other obligations |  | 332 |
Gain on the dilution |  | (259 | )
Effects on cash flow |  | (657 | )

f) Madeira Energia S.A.

The jointly-controlled subsidiary Madeira Energia S.A. – MESA (“Mesa”) is an unlisted corporation, constituted on August 27, 2007, the objects of which are construction and commercial operation of the Santo Antônio Hydroelectric Plant located on the Madeira River, and its Associated Transmission System, under the terms of Concession Contract for Use of a Public Asset Nº 001/2008-MME. Mesa is developing the construction project of Santo Antonio Power Plant, and thus requires financial support from its joint controlling stockholders. The injection of R$ 288 arises from paying-up of subscriptions of shares in 2012, duly approved in Minutes, in accordance with the investment plan approved in the Notice of Board Spending Decision CRCA 089/07 by Cemig’s Board of Directors.

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g) Acquisition of an interest in Guanhães Energia S.A. (jointly-controlled subsidiary)

On August 28, 2012 the subsidiary Light Energia S.A. finalized the transaction to acquire a holding in Guanhães Energia, in which it acquired 51% of the common shares, from Investminas Participações S.A. Guanhães was created to build four Small Hydroelectric Plants (PCHs) – Dores de Guanhães, Senhora do Porto, Jacaré and Fortuna II, all in the State of Minas Gerais, with aggregate installed generation capacity of 44.80 MW. The first of these PCHs is scheduled to start operating in October 2013, and the last in February 2014. Guanhães Energia S.A. is jointly controlled by Light Energia S.A. (51%) and by Cemig GT (49%).

The value of the net assets acquired was R$ 27. The fair values recognized in the acquisition are as follows:

Assets |  |  |
Cash and cash equivalents |  | 15 |
Other credits |  | 4 |
Property, plant and equipment |  | 3 |
Intangible assets |  | 8 |
Liabilities |  |  |
Other obligations |  | (3 | )
Net assets acquired |  | 27 |
Cash expended |  | 27 |

i) Dilution of equity interest in Renova Energia S.A., subsidiary of Light

On July 13, 2012 Renova Energia S.A. and BNDES Participações S.A. (“BNDESPAR”), a wholly-owned subsidiary of the Brazilian Development Bank (BNDES), entered into an agreement for BNDESPAR to become a shareholder in Renova Energia.

On September 26, 2012 the transaction was finalized with subscription payment by BNDESPar of 23,059,239 common shares and 4,875,036 preferred shares, arising from assignment, free of charge, to BNDESPAR of the right of first refusal by RR Participações S.A., Light Energia S.A. and InfraBrasil Fundo de Investimento em Participações, as part of the capital increase transaction, at the issue price of R$ 9.3334 per share, for a total amount of R$ 314.

After the transaction, the percentage interest owned by Cemig’s investee Light Energia S.A. in Renova Energia S.A. was reduced from 25.9% to 22.0%. The transaction generated a gain for the investee Light Energia of R$ 14.

The effects on the cash flows are as follows:

Assets |  |  |
Other credits |  | (1 | )
Property, plant and equipment |  | (20 | )
Intangible assets |  | (9 | )
Liabilities |  |  |
Loans and financings |  | 11 |
Other obligations |  | 2 |
Gain on the dilution |  | (5 | )
Effects on cash flows |  | (21 | )

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Put options

Cemig has granted to Fundo de Participações Coliseu, which is a stockholder of Taesa, an option to sell the totality of the shares which that fund holds in Taesa, exercisable on October 30, 2014. The price of the option is calculated using the sum of the value of the injections of capital by the fund into Taesa, plus the running expenses of the fund, less any Interest on Equity, and dividends, distributed by Taesa. The exercise price is subject to monetary updating by the IPCA (Expanded National Consumer Price) Index (published by the IBGE) plus financial remuneration at 7.0% per year.

Cemig has granted to Fundo de Participações Redentor, which is a stockholder of Parati, an option to sell the totality of the shares which that fund holds in Parati, exercisable in May 2016. The price of the option is calculated using the sum of the value of the injections of capital by the fund into Parati, plus the running expenses of the fund, less any Interest on Equity, and dividends, distributed by Parati. The exercise price is subject to monetary updating by the CDI (interbank CD) Rate plus financial remuneration at 0.9% per year.

The Equity funds own common and preferred shares in Taesa and light, and at present exercise joint control, with the Company, over the activities of these companies. This being so, these options have been considered to be derivative instruments which should be accounted at fair value through profit or loss.

For the purposes of the termination of the method to be used in measuring the fair value of the said options, the Company observed the daily trading volume of the shares of Light and of Taesa, and that such options, if exercised by the Funds, will require the sale to the Company, in a single transaction, of the shares in the companies referred to in a quantity higher than the daily averages of exchange trading. Thus, the Company has adopted the discounted cash flow method for measurement of the fair values of the options: the fair value of these options was calculated on the basis of the estimated exercise price on the day of exercise of the option, less the fair value of the shares that are the subject of the put options, also estimated for the date of exercise, brought to present value at the date of the financial statements.

Based on the studies carried out, Cemig did not record obligations in its financial statements arising from these options, since the estimate of fair value of the options is close to zero.

15. PROPERTY, PLANT, AND EQUIPMENT

|  | December 31, 2012 |  | December 31, 2011 |
|  | Cost |  | Accumulated depreciation |  | Net value |  | Cost |  | Accumulated depreciation |  | Net value |
In Service |  | 19,885 |  | (12,268) |  | 7,617 |  | 19,052 |  | (12,022 | ) | 7,030 |
Land |  | 424 |  | - |  | 424 |  | 425 |  | - |  | 425 |
Reservoirs, dams and water courses |  | 8,570 |  | (5,169) |  | 3,401 |  | 7,990 |  | (5,035 | ) | 2,955 |
Buildings, works and improvements |  | 2,476 |  | (1,592) |  | 884 |  | 2,319 |  | (1,560 | ) | 759 |
Machinery and equipment |  | 8,335 |  | (5,444) |  | 2,891 |  | 8,233 |  | (5,363 | ) | 2,870 |
Vehicles |  | 20 |  | (14) |  | 6 |  | 26 |  | (16 | ) | 10 |
Furniture and fixtures |  | 59 |  | (49) |  | 11 |  | 59 |  | (48 | ) | 11 |
In progress |  | 1,194 |  | - |  | 1,194 |  | 1,632 |  | - |  | 1,632 |
Assets under construction |  | 1,194 |  | - |  | 1,194 |  | 1,632 |  | - |  | 1,632 |
Total Property, Plant and Equipment |  | 21,079 |  | (12,268) |  | 8,811 |  | 20,684 |  | (12,022 | ) | 8,662 |

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|  | 01/01/2011 |
|  | Cost |  | Accumulated depreciation |  | Net value |
In Service |  | 18,042 |  | (11,044) |  | 6,998 |
Land |  | 411 |  | - |  | 411 |
Reservoirs, dams and water courses |  | 7,643 |  | (4,643) |  | 3,000 |
Buildings, works and improvements |  | 2,287 |  | (1,442) |  | 845 |
Machinery and equipment |  | 7,664 |  | (4,941) |  | 2,723 |
Vehicles |  | 18 |  | (7) |  | 11 |
Furniture and fixtures |  | 19 |  | (11) |  | 8 |
In progress |  | 1,231 |  | - |  | 1,231 |
Assets under construction |  | 1,231 |  | - |  | 1,231 |
Total Property, Plant and Equipment |  | 19,273 |  | (11,044) |  | 8,229 |

The changes in property, plant, and equipment from December 31, 2012 to December 31, 2011 are as as follows:

|  | Balance at 01/01/2011 |  | Balance at 12/31/2011 |  | Additions / transfers |  | Write-off |  | Depreciation |  | Balance at 12/31/2012 |
In Service |  | 6,667 |  | 7,030 |  | 1,019 |  | (44) |  | (388) |  | 7,617 |
Land |  | 411 |  | 425 |  | (1) |  | - |  | - |  | 424 |
Reservoirs, dams and water courses |  | 3,000 |  | 2,955 |  | 592 |  | (1) |  | (144) |  | 3,402 |
Buildings, works and improvements |  | 845 |  | 75 8 |  | 158 |  | - |  | (33) |  | 883 |
Machinery and equipment |  | 2,723 |  | 2,871 |  | 269 |  | (38) |  | (211) |  | 2,891 |
Vehicles |  | 11 |  | 10 |  | - |  | (5) |  | 1 |  | 6 |
Furniture and fixtures |  | 8 |  | 11 |  | 1 |  | - |  | (1) |  | 11 |
In progress |  | 1,231 |  | 1,632 |  | (437) |  | (1) |  | - |  | 1,194 |
Total Property, Plant, and Equipment |  | 8,229 |  | 8,66 2 |  | 582 |  | (45) |  | (388) |  | 8,811 |

On September 11, 2012 the Brazilian government issued Provisional Measure 579 (which became Law 12783), governing renewals of concessions. See details in Note 4.

The Company has not identified any indicatives of impairment with regards to its property, plant, and equipment. The concession contracts specify that, at the end of the concession contract period of each concession, the grantor will decide the amount to be indemnified to the Company. Management believes that the indemtification of assets will be higher than their historical cost depreciated by their useful lives. Therefore, carrying amount of property, plant and equipment at the end of the concession period will be reimbursed to the Company by the granting authority.

ANEEL, in conformity with the Brazilian regulatory framework, is responsible for establishing and periodically reviewing the estimates of useful economic life for generation and transmission assets in the electricity sector. The estimates of useful life established by the ANEEL are used in the processes for reviewing tariff rates and calculating the indemnification due to the concessionaires at the end of the concession period. These are recognized by the Company as reasonable and were used as the basis for depreciation of the Company’s property, plant and equipment.

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The average annual depreciation rate is 2.31%. The main rates applied to the subsidiaries for the year ended December 31, 2012 are as follows:

Generation |  |  |
Hydroelectric power plants |  | 2.54 | %
Thermoelectric power plants |  | 4.09 | %
Management and other |  | 9.53 | %
Telecommunications |  | 7.33 | %

Under Articles 63 and 64 of Decree 41019 of February 26, 1957, goods and facilities used in generation and transmission are entailed to these services and cannot be withdrawn, disposed of, assigned or given in mortgage guarantees without the express, prior authorization of the Regulator. ANEEL Resolution 20/99 provides regulations for disposition of assets of public electricity service concessions. These include granting prior authorization for disposition of assets that are not appropriate for serving the concession and are earmarked for disposal, but they require the proceeds to be deposited in a blocked bank account, to be invested in the concession.

Some of the Company’s land and buildings recorded as property, plant and equipment - administration, were pledged in guarantee for court proceedings involving tax, labor, civil and other contingencies in the amount, net of depreciation, of R$0.8 at December 31, 2012.

CONSORTIA

The Company is a part in certain consortia for electricity generation projects, for which companies with an independent legal existence were not constituted to manage the concession objects . In these cases, the controls are maintained in PP&E, Intangible assets and Assets not linked to the activity, in compliance with Aneel Dispatch 3467 of September 18, 2008. The Company’s portion in each of the assets allocated to the consortia is recorded and controlled individually in the respective types of PP&E presented above The amounts of the investment, accumulated, by product, for each project, are as follows:

|  | Share in the electricity generated |  | Average annual rate of depreciation % |  | 2012 |  | 2011 |  | 01/01/2011 |
In service: |  |  |  |  |  |  |  |  |  |  |
Porto Estrela Power Plant |  | 33.33% |  | 2.42 |  | 39 |  | 39 |  | 39 |
Igarapava Power Plant |  | 14.50% |  | 2.52 |  | 58 |  | 57 |  | 56 |
FuniI Power Plant |  | 49.00% |  | 2.49 |  | 183 |  | 183 |  | 182 |
Queimado Power Plant |  | 82.50% |  | 2.42 |  | 212 |  | 209 |  | 207 |
Aimorés Power Plant |  | 49.00% |  | 2.55 |  | 551 |  | 551 |  | 550 |
Baguari Power Plant |  | 34.00% |  | 2.56 |  | 183 |  | 181 |  | - |
Consórcio Capim Branco Energia S.A. |  | 21.05% |  | 2.60 |  | 56 |  | 56 |  | 56 |
Accumulated depreciation |  |  |  |  |  | (236) |  | (193) |  | (171) |
Total, in service |  |  |  |  |  | 1,046 |  | 1,083 |  | 919 |
In progress: |  |  |  |  |  |  |  |  |  |  |
Baguari Power Plant |  | 34.00% |  |  |  | - |  | - |  | 181 |
Queimado Power Plant |  | 82.50% |  |  |  | - |  | 3 |  | 2 |
FuniI Power Plant |  | 49.00% |  |  |  | - |  | - |  | 1 |
Aimorés Power Plant |  | 49.00% |  |  |  | 1 |  | 1 |  | 1 |

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Igarapava Power Plant |  | 14.50% |  |  |  | 1 |  | 1 |  | 1 |
Consórcio Capim Branco Energia S.A. |  |  |  |  |  | 2 |  | 1 |  | 1 |
Total in progress |  |  |  |  |  | 4 |  | 6 |  | 187 |
Total, consortia |  |  |  |  |  | 1,050 |  | 1,089 |  | 1,106 |

The depreciation of the assets in the property, plant and equipment of the consortia is calculated by the straight-line method, based on rates established by ANEEL.

The table below shows, by project, the interests of the other partners in the electric power generated by the consortia:

Consortium – Power Plants |  | Consortium participants, other than CEMIG |  | Interest (%) |
Porto Estrela Power Plant |  | Companhia de Tecidos Norte de Minas Gerais – Coteminas |  | 33.34 |
|  | Vale S.A. |  | 33.33 |
Igarapava Power Plant |  | Vale S.A. |  | 38.15 |
|  | Companhia Mineira de Metais – CMN |  | 23.93 |
|  | Companhia Siderúrgica Nacional – CSN |  | 17.92 |
|  | Mineração Morro Velho – MMV |  | 5.50 |
Funil Power Plant |  | Vale S.A. |  | 51.00 |
Queimado Power Plant |  | Companhia Energética de Brasília |  | 17.50 |
Aimorés Power Plant |  | Vale S.A. |  | 51.00 |
Baguari Power Plant |  | Furnas Centrais Elétricas S.A. |  | 15.00 |
|  | Baguari I Geração de Energia Elétrica S.A. |  | 51.00 |
Amador Aguiar I and II Power Plants |  | Vale S.A. |  | 48.43 |
|  | Comercial e Agrícola Paineiras Ltda |  | 17.89 |
|  | Companhia Mineira de Metais – CMM |  | 12.63 |

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Fully Depreciated Assets

As at December 31, 2012, Cemig GT held a gross carrying amount of R$4,363 related to fully depreciated assets that are still in operation.

Borrowing costs

The Company transferred costs of loans and financings linked to works to the account Intangible assets, in the amount of R$ 65, on December 31, 2012.

On September 11, 2012 the Brazilian government issued Provisional Measure 579, which deals with renewals of concessions. For more details on this please see Note 4.

16. INTANGIBLE ASSETS

|  | 2012 |  | 2011 |
|  | Historical cost |  | Accumulated amortization |  | Residual value |  | Historical cost |  | Accumulated amortization |  | Residual value |
In Service |  | 10,641 |  | (7,154) |  | 3,487 |  | 10,607 |  | (6,725) |  | 3,882 |
Defined useful life |  |  |  |  |  |  |  |  |  |  |  |  |
Easements |  | 41 |  | (2) |  | 39 |  | 34 |  | (1) |  | 33 |
Onerous Concessions (paid concession rights) |  | 52 |  | (10) |  | 42 |  | 32 |  | (9) |  | 23 |
Concession assets |  | 10,325 |  | (6,966) |  | 3,359 |  | 10,362 |  | (6,572) |  | 3,790 |
Others |  | 223 |  | (176) |  | 47 |  | 179 |  | (143) |  | 36 |
In progress |  | 986 |  | - |  | 986 |  | 1,522 |  | - |  | 1,522 |
Assets under construction |  | 986 |  | - |  | 986 |  | 1,522 |  | - |  | 1,522 |
Intangible assets, net |  | 11,627 |  | (7,154) |  | 4,473 |  | 12,129 |  | (6,725) |  | 5,404 |

|  | 01/01/2011 |
|  | Historical cost |  | Accumulated amortization |  | Residual value |
In Service |  | 3,369 |  | (144) |  | 3,255 |
Defined useful life |  |  |  |  |  |  |
Easements |  | 64 |  | (2) |  | 62 |
Onerous Concessions (paid concession rights) |  | 32 |  | (8) |  | 24 |
Concession assets |  | 3,110 |  | - |  | 3,110 |
Others |  | 163 |  | (134) |  | 29 |
In progress |  | 1,723 |  | - |  | 1,723 |
Assets under construction |  | 1,723 |  | - |  | 1,723 |
Intangible assets, net |  | 5,092 |  | (144) |  | 4,948 |

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The changes in consolidated intangible assets in 2012 are as follows:

|  | 01/01/2011 |  | 2011 |  | Additions |  | Write-off |  | Accumulated Amortization |  | Transfers |  | 2012 |
In Service |  | 3,255 |  | 3,882 |  | (94) |  | (81) |  | (612) |  | 392 |  | 3,487 |
Defined Useful life |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Easements |  | 62 |  | 33 |  | - |  | - |  | (1) |  | 7 |  | 39 |
Onerous Concessions |  | 24 |  | 23 |  | - |  | (1) |  | (1) |  | 21 |  | 42 |
Concession assets |  | 3,110 |  | 3,790 |  | (94) |  | (80) |  | (602) |  | 345 |  | 3,359 |
Others |  | 29 |  | 36 |  | - |  | - |  | (8) |  | 19 |  | 47 |
In progress |  | 1,723 |  | 1,522 |  | 1,706 |  | (3) |  | - |  | (2,239) |  | 986 |
Assets under construction |  | 1,723 |  | 1,522 |  | 1,706 |  | (3) |  | - |  | (2,239) |  | 986 |
Intangible assets, net |  | 4,948 |  | 5,404 |  | 1,612 |  | (84) |  | (612) |  | (1,847) |  | 4,473 |

On September 11, 2012 the Brazilian government issued Provisional Measure 579, which deals with renewals of concessions. For more details please see Note 4.

The process of Tariff Review of the subsidiary Cemig D takes place every five years, through a process of economic evaluation, in which the tariffs of the distribution concessions of the company in the state of Minas Gerais are decided. Within the process of tariff review, the Regulatory Remuneration Base (Base Regulatória de Remuneração, or “BRR”), related to the assets linked to the concession, is decided.

On March 11, 2013, the Economic and Financial Supervision Department (Superintendência de Fiscalização Econômico Financeira, or SSF) of Aneel, through Dispatch 689, published the preliminary BRR of Cemig D, in the amount of R$ 5,111,837. Soon after the publication of the preliminary BRR, the Company’s Management began discussions with Aneel with the intention of demonstrating technically to Aneel the need for the said amount to be revised. Considering that the amount preliminarily disclosed by Aneel is likely to be modified and that, in the opinion of Management, the published amount was significantly lower than the value at which the homologation ought to be made, Management does not have sufficient elements to determine whether there would be a need for adjustments to the financial statements of Cemig D dated December 31, 2012, which were originally filed on March 28, 2013.

On April 5, 2013, a meeting of the Council of Aneel homologated the revised BRR of Cemig D, in the amount of R$ 5,511,768, which is R$ 399,931 higher than the BRR that was preliminarily published. The company is now awaiting the judgment on the first appeal submitted to Aneel, in which it states its disagreement as to certain criteria and values adopted by Aneel in the decision on the preliminary BRR that was published. Aneel has not yet considered this appeal. Additionally, the Company will submit a further appeal to Aneel questioning certain criteria and values of the BRR that were decided on April 5, 2013, since the amounts taken into account in the revised BRR, principally related to the Company’s expenditure on the Light for Everyone (Luz Para Todos) Program are still substantially inferior to those in fact incurred in the execution of this program. Management continues to expect that, when these appeals have been considered by Aneel, criteria and values defined by Aneel for the BRR will be revised, which will result in a higher amount than the one recently presented.

In view of the matter in the previous paragraph, Management has recalculated the impacts of this new BRR on the composition of the financial and intangible assets of its concessions, and concluded, based on its best estimates, that adjustments to the balances of these accounts, presented in the Company’s financial statements at December 31, 2012, are not necessary.

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Concession Assets

The portion of the distribution infrastructure that will be used during the concession period, consisting of the distribution assets, net of consumer interests (special obligations), was recorded as Intangible Assets.

ANEEL, in conformity with the Brazilian regulatory framework, is responsible for establishing the economic useful life of distribution assets in the electricity sector, periodically establishing a review of the valuation assessment of these rates. The rates established by the Agency are used in the tariff review process and the calculation of compensation at the end of the concession and they are recognized as a reasonable estimate of the useful life of the concession’s asset. Accordingly, these rates were used as the basis for evaluation and amortization of the intangible assets.

The easement, onerous concession, concession assets and other intangible assets, are amortized on a straight-line basis and the rates used are those defined by ANEEL. The Company has not identified evidence of loss through impairment of its intangible assets, which have a definite useful life. The Company has no intangible assets with an indefinite useful life.

Useful life review

On February 7, 2012, Aneel, by Normative Resolution 474, set forth new depreciaton rates for assets in service under electricity concessions based on a review of their useful lives. The new rates were applied as effective January 1, 2012.

The Company has processed the changes in the rates, and recalculated the amount of the indemnity of the assets that are subject to reversion on the expiration date of its concessions (2016 for Cemig D and 2026 for Light) and the respective amount attributable to intangible assets. Mentioned procedure resulted in the reclassification of R$ 438 from intangible assets to financial assets in 2012.

Borrowing costs

The Company transferred costs of loans and financings linked to works to the account Intangible assets, in the amount of R$ 30 on December 31, 2012.

17.SUPPLIERS

|  | 2012 |  | 2011 |  | 01/01/2011 |
Spot market - CCEE |  | 78 |  | 28 |  | 28 |
Charges for use of grid |  | 118 |  | 106 |  | 89 |
Electricity bought for resale |  | 848 |  | 429 |  | 494 |
Generation from Itaipu |  | 219 |  | 198 |  | 156 |
Gas purchased for resale |  | 34 |  | 29 |  | 23 |
Materials and services |  | 438 |  | 400 |  | 331 |
|  | 1,735 |  | 1,190 |  | 1,121 |

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18. TAXES PAYABLES

a)Taxes payable

The non-current liabilities for PASEP and COFINS refer to the legal action challenging the constitutionality of the inclusion of ICMS in the calculation basis for these taxes, and, the offsetting of the amounts paid in the last 10 years has been requested. The Company and its subsidiaries Cemig D and Cemig GT have obtained a Court injunction enabling them not to make the payment and authorizing payment in Court from 2008 until August, 2011. Thereafter, the Company opted to pay the new taxes each month.

|  | 2012 |  | 2011 |  | 01/01/2011 |
Current |  |  |  |  |  |  |
ICMS (Value-added tax) |  | 371 |  | 330 |  | 277 |
COFINS (Tax on revenue) |  | 118 |  | 95 |  | 66 |
PASEP (Tax on revenue) |  | 26 |  | 21 |  | 11 |
INSS (Social security) |  | 24 |  | 24 |  | 23 |
Others |  | 30 |  | 47 |  | 27 |
|  | 569 |  | 517 |  | 404 |
Non-current |  |  |  |  |  |  |
COFINS |  | 680 |  | 683 |  | 531 |
PASEP |  | 148 |  | 148 |  | 115 |
Others |  | 175 |  | 66 |  | 47 |
|  | 1,003 |  | 897 |  | 693 |
|  | 1,572 |  | 1,414 |  | 1,097 |

b)Income tax and social contribution payable

|  | 2012 |  | 2011 |  | 01/01/2011 |
Current |  |  |  |  |  |  |
Income tax |  | 97 |  | 87 |  | 112 |
Social contribution |  | 30 |  | 42 |  | 25 |
|  | 127 |  | 129 |  | 137 |

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19. LOANS, FINANCING AND DEBENTURES

|  | Maturity of |  |  |  |  |  | 2012 |  | 2011 |  | 01/01/2011 |
Lenders |  | Principal |  | Annual Interest Rates (%) |  | Currency |  | Current |  | Non Current |  | Total |  | Total |  | Total |
IN FOREIGN CURRENCY |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
ABN AMRO Real S.A. (3) |  | 2013 |  | 6% |  | US$ |  | 26 |  | - |  | 26 |  | 47 |  | 62 |
Banco do Brasil S.A. – Bônus Diversos (1) |  | 2024 |  | Various |  | US$ |  | 6 |  | 21 |  | 27 |  | 35 |  | 51 |
BNP Paribas |  | 2012 |  | 5.89% |  | EURO |  | - |  | - |  | - |  | 1 |  | 4 |
KFW |  | 2016 |  | 4.50% |  | EURO |  | 2 |  | 5 |  | 7 |  | 8 |  | 9 |
Brazilian National Treasury (5) |  | 2024 |  | Various |  | US$ |  | 3 |  | 10 |  | 13 |  | 17 |  | 19 |
Banco Inter Americano del Desarrollo (7) |  | 2026 |  | 2.12% |  | US$ |  | 2 |  | 34 |  | 36 |  | 35 |  | 34 |
BNP 36 MM – Euros |  | 2014 |  | 3.98% |  | EURO |  | - |  | 31 |  | 31 |  | 28 |  | - |
Merril Lynch – US$ 50 MM |  | 2016 |  | 2.59% |  | US$ |  | - |  | 33 |  | 33 |  | 31 |  | - |
Citi Bank – US$ 100 MM |  | 2018 |  | 2.46% |  | US$ |  | - |  | 119 |  | 119 |  | - |  | - |
BID (16) |  | 2022 |  | Libor + Spread 1.7 a 2.2%pa |  | US$ |  | 7 |  | 77 |  | 84 |  | 53 |  | - |
BID (16) |  | 2023 |  | Libor + Spread 1.5 a 1.88%pa |  | US$ |  | 13 |  | 130 |  | 143 |  | 93 |  | - |
Outros |  | 2019 |  | Various |  | Various |  | 8 |  | 1 |  | 9 |  | 11 |  | 12 |
Total foreign currency financing |  |  |  |  |  |  |  | 67 |  | 461 |  | 528 |  | 359 |  | 191 |
LOCAL CURRENCY |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Banco do Brasil S.A. |  | 2017 |  | 108.33% of CDI |  | R$ |  | 206 |  | - |  | 206 |  | - |  | - |
Banco do Brasil S.A. |  | 2017 |  | 108% of CDI |  | R$ |  | 5 |  | 442 |  | 447 |  | 592 |  | 888 |
Banco do Brasil S.A. |  | 2013 |  | CDI + 1.70% |  | R$ |  | 28 |  | - |  | 28 |  | 56 |  | 85 |
Banco do Brasil S.A. |  | 2013 |  | 107.60% of CDI |  | R$ |  | 133 |  | - |  | 133 |  | 137 |  | 135 |
Banco do Brasil S.A. |  | 2014 |  | 104.10% of CDI |  | R$ |  | 814 |  | 300 |  | 1,114 |  | 1,225 |  | 1,224 |
Banco do Brasil S.A. |  | 2013 |  | 10.83% |  | R$ |  | 793 |  | - |  | 793 |  | 706 |  | 630 |
Banco do Brasil S.A. |  | 2014 |  | 98.5% of CDI |  | R$ |  | 102 |  | 374 |  | 476 |  | 436 |  | - |
Banco do Brasil S.A. |  | 2012 |  | 106.00 of CDI |  | R$ |  | - |  | - |  | - |  | 100 |  | - |
Banco do Brasil S.A |  | 2013 |  | 104.08 % of CDI |  | R$ |  | 664 |  | - |  | 664 |  | - |  | - |
Banco do Brasil S.A |  | 2013 |  | 105.00 % of CDI |  | R$ |  | 1,083 |  | - |  | 1,083 |  | - |  | - |
Banco Itaú – BBA S.A |  | 2013 |  | CDI + 1.70% |  | R$ |  | 79 |  | - |  | 79 |  | 159 |  | 235 |
Banco Itaú – BBA S.A |  | 2014 |  | CDI + 1.70% |  | R$ |  | 2 |  | - |  | 2 |  | 3 |  | 4 |
Banco Votorantim S.A. |  | 2013 |  | CDI + 1.70% |  | R$ |  | 26 |  | - |  | 26 |  | 53 |  | 77 |
BNDES |  | 2026 |  | TJLP+2.34% |  | R$ |  | 8 |  | 96 |  | 104 |  | 112 |  | 119 |
Bradesco S.A. |  | 2014 |  | CDI + 1.70% |  | R$ |  | 1 |  | - |  | 1 |  | 2 |  | 1 |
Bradesco S.A. |  | 2013 |  | CDI + 1.70% |  | R$ |  | 97 |  | - |  | 97 |  | 198 |  | 296 |
Bradesco S.A. |  | 2011 |  | 105.50% of CDI |  | R$ |  | - |  | - |  | - |  | - |  | 351 |
Bradesco S.A. |  | 2012 |  | 106.00% of CDI |  | R$ |  | - |  | - |  | - |  | 990 |  | - |
Bradesco S.A. |  | 2013 |  | 103.00% of CDI |  | R$ |  | 601 |  | - |  | 601 |  | - |  | - |
ELETROBRÁS |  | 2013 |  | FINEL + 7.50% up to 8.50% |  | R$ |  | 13 |  | - |  | 13 |  | 26 |  | 37 |
ELETROBRÁS |  | 2023 |  | UFIR. RGR + 6% up to 8% |  | R$ |  | 69 |  | 321 |  | 390 |  | 429 |  | 373 |
Santander do Brasil S.A. |  | 2013 |  | CDI + 1.70% |  | R$ |  | 20 |  | - |  | 20 |  | 40 |  | 61 |
UNIBANCO S.A |  | 2013 |  | CDI + 1.70% |  | R$ |  | 79 |  | - |  | 79 |  | 161 |  | 241 |
UNIBANCO S.A (2) |  | 2013 |  | CDI + 1.70% |  | R$ |  | 19 |  | - |  | 19 |  | 40 |  | 60 |
Itaú e Bradesco (4) |  | 2015 |  | CDI + 1.70% |  | R$ |  | - |  | - |  | - |  | 820 |  | 891 |
Banco do Brasil S.A. (8) |  | 2020 |  | TJLP + 2.55% |  | R$ |  | 3 |  | 17 |  | 20 |  | 23 |  | 26 |
UNIBANCO S.A (8) |  | 2020 |  | TJLP + 2.55% |  | R$ |  | 1 |  | 4 |  | 5 |  | 6 |  | 6 |
CCB Bradesco S.A (5) |  | 2017 |  | CDI + 0.85% |  | R$ |  | 26 |  | 98 |  | 124 |  | 150 |  | 120 |
ABN AMRO Real S.A. (5) |  | 2014 |  | CDI + 0.95% |  | R$ |  | - |  | 26 |  | 26 |  | 27 |  | 22 |
BNDES (5) |  | 2019 |  | TLJP |  | R$ |  | 82 |  | 324 |  | 406 |  | 372 |  | 190 |
BNDES - Repasse (11) |  | 2033 |  | TJLP |  | R$ |  | 2 |  | 388 |  | 390 |  | 350 |  | 262 |
AMAZONIA – FNO (11) |  | 2031 |  | 10% a.a |  | R$ |  | - |  | 58 |  | 58 |  | 355 |  | 316 |
BNDES (11) |  | 2033 |  | TJLP + 2.40% |  | R$ |  | 1 |  | 378 |  | 379 |  | 55 |  | - |
BNDES – Principal Subcrédito A/B/C/D (16) |  | 2015 |  | Various |  | R$ |  | 6 |  | 61 |  | 67 |  | 67 |  | 366 |
BNDES (12) |  | 2024 |  | TJLP +2.15% |  | R$ |  | 3 |  | 34 |  | 37 |  | 40 |  | 42 |
CEF S.A (13) |  | 2022 |  | TJLP + 3.50% |  | R$ |  | 8 |  | 54 |  | 62 |  | 65 |  | 67 |
CEF S.A (14) |  | 2021 |  | TJLP + 3.50% |  | R$ |  | 6 |  | 43 |  | 49 |  | 52 |  | 54 |
CEF S.A (15) |  | 2022 |  | TJLP + 3.50% |  | R$ |  | 10 |  | 81 |  | 91 |  | 95 |  | 97 |
BNDES (16) |  | 2019 |  | Various |  | R$ |  | 43 |  | 188 |  | 231 |  | 211 |  | 14 |
Sindicato de Bancos (16) |  | 2015 |  | CDI + 0.90% |  | R$ |  | 7 |  | - |  | 7 |  | 18 |  | 28 |
CEF S.A (16) |  | 2016 |  | 117.5 % of CDI |  | R$ |  | 2 |  | 5 |  | 7 |  | 11 |  | 13 |
PROMISSORY NOTES (ITAU) (16) |  | 2012 |  | 105.50 of CDI |  | R$ |  | - |  | - |  | - |  | 669 |  | - |
BNDES – CEMIG TELECOM (18) |  | 2017 |  | Various |  | R$ |  | 9 |  | 35 |  | 44 |  | 52 |  | 49 |
BNDES (22) |  | 2028 |  | URTJ+1.97% |  | R$ |  | 4 |  | 58 |  | 62 |  | 50 |  | - |
Others |  | 2025 |  | Various |  | R$ |  | 37 |  | 280 |  | 317 |  | 298 |  | 89 |
Total Brazilian currency financing |  |  |  |  |  |  |  | 5,092 |  | 3,665 |  | 8,757 |  | 9,251 |  | 7.469 |
TOTAL |  |  |  |  |  |  |  | 5,159 |  | 4,126 |  | 9,285 |  | 9,610 |  | 7,660 |

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|  | Maturity |  | Annual |  |  |  | 2012 |  | 2011 |  | 01/01/2011 |
Lenders |  | of Principal |  | Interest Rates (%) |  | Currency |  | Current |  | Non Current |  | Total |  | Total |  | Total |
Debêntures – Governo do Estado de M.G. (6) (9) |  | 2031 |  | IGP-M |  | R$ |  | - |  | 53 |  | 53 |  | 47 |  | 37 |
Debêntures (6) |  | 2014 |  | IGP-M + 10.50 |  | R$ |  | 401 |  | - |  | 401 |  | 373 |  | 355 |
Debêntures (6) |  | 2017 |  | IPCA + 7.96 |  | R$ |  | 530 |  | - |  | 530 |  | 503 |  | 472 |
Debêntures (6) |  | 2011 |  | 104% of CDI |  | R$ |  | - |  | - |  | - |  | - |  | 243 |
Debêntures (6) |  | 2012 |  | CDI+ 0.90% |  | R$ |  | - |  | - |  | - |  | 1,755 |  | 1,726 |
Debêntures (6) |  | 2015 |  | IPCA + 7.68% |  | R$ |  | 543 |  | 902 |  | 1,445 |  | 1,368 |  | 1,285 |
Debêntures (6) |  | 2017 |  | CDI + 0.90% |  | R$ |  | 38 |  | 480 |  | 518 |  | - |  | - |
Debêntures (6) |  | 2022 |  | IPCA + 6.20% |  | R$ |  | 41 |  | 698 |  | 739 |  | - |  | - |
Debêntures (6) |  | 2019 |  | IPCA + 6.00% |  | R$ |  | 12 |  | 208 |  | 220 |  | - |  | - |
Debêntures 1ª EMISSÃO (6) (23) |  | 2013 |  | 106% of CDI |  | R$ |  | 32 |  | - |  | 32 |  | - |  | - |
DEBÊNTURES PRIVADAS (BNDESPAR(6) (17) |  | 2016 |  | 8.62% |  | R$ |  | 30 |  | 83 |  | 113 |  | 131 |  | 158 |
Debêntures Públicas CVM 476/09 (6) (17) |  | 2015 |  | 7.87% |  | R$ |  | - |  | 60 |  | 60 |  | - |  |  |
DEBENTURES TAESA (6) (16) |  | 2015 |  | CDI + 1.30% |  | R$ |  | 56 |  | 100 |  | 156 |  | 207 |  | 205 |
DEBENTURES TAESA (6) (16) |  | 2015 |  | IPCA+7.91¨% |  | R$ |  | 47 |  | 85 |  | 132 |  | 163 |  | 152 |
DEBENTURES TAESA (6) (16) |  | 2017 |  | 106% of CDI |  | R$ |  | - |  | 353 |  | 353 |  | 463 |  | 462 |
DEBENTURES TAESA (6) (16) |  | 2017 |  | CDI + 0.78% |  | R$ |  | 5 |  | 288 |  | 293 |  | - |  | - |
DEBENTURES TAESA (6) (16) |  | 2020 |  | IPCA + 4.85% p.a. |  | R$ |  | 3 |  | 349 |  | 352 |  | - |  | - |
DEBENTURES TAESA (6) (16) |  | 2024 |  | IPCA + 5.10% p.a. |  | R$ |  | 3 |  | 309 |  | 312 |  | - |  | - |
DEBENTURES(10) (6) |  | 2016 |  | CDI+1.30% |  | R$ |  | 3 |  | 22 |  | 25 |  | 13 |  | - |
DEBENTURES (19) (6) |  | 2016 |  | CDI+1.30% |  | R$ |  | 21 |  | 47 |  | 68 |  | 88 |  | - |
DEBENTURES (20) (6) |  | 2016 |  | CDI+1.30% |  | R$ |  | 44 |  | 159 |  | 203 |  | 167 |  | - |
DEBENTURES(21) (6) |  | 2016 |  | 112.5% of CDI |  | R$ |  | 7 |  | 21 |  | 28 |  | 35 |  | - |
Debêntures (6) (11) |  | 2013 |  | IPCA |  | R$ |  | 81 |  | 79 |  | 160 |  | 207 |  | 182 |
Debêntures 3ª Emissão - Light Energia(5) (6) |  | 2026 |  | CDI+1.18% |  | R$ |  | - |  | 10 |  | 10 |  | - |  | - |
Debêntures Renova - Light Energia(5) (6) |  | 2022 |  | CDI + 1.51% |  | R$ |  | - |  | 21 |  | 21 |  | - |  | - |
Debêntures Guanhães - Light Energia(5) (6) |  | 2013 |  | CDI + 0.39% |  | R$ |  | 11 |  | - |  | 11 |  | - |  | - |
Debêntures V (5) (6) |  | 2014 |  | CDI + 1.50% |  | R$ |  | 30 |  | 37 |  | 67 |  | 242 |  | 210 |
Debêntures VI (5) (6) |  | 2011 |  | 115% of CDI |  | R$ |  | - |  | - |  | - |  | - |  | 79 |
Debêntures VI I (5) (6) |  | 2016 |  | CDI + 135% |  | R$ |  | 3 |  | 211 |  | 214 |  | 214 |  | - |
Debêntures VIII (5) (6) |  | 2026 |  | CDI+1.18% |  | R$ |  | 1 |  | 152 |  | 153 |  | - |  | - |
Debêntures LIGHT ENERGIA (5) (6) |  | 2016 |  | CDI + 1.45% |  | R$ |  | 1 |  | 56 |  | 57 |  | 57 |  | - |
Debêntures LIGHT ENERGIA II (5) (6) |  | 2019 |  | CDI+1.18% |  | R$ |  | 4 |  | 138 |  | 142 |  | 137 |  | - |
ITAÚ – BBA DEBÊNTURES (6) (24) |  | 2017 |  | CDI + 0.9875% p.a. |  | R$ |  | - |  | 11 |  | 11 |  | - |  | - |
ITAÚ – BBA DEBÊNTURES (6) (25) |  | 2017 |  | CDI + 0.9875% p.a |  | R$ |  | - |  | 6 |  | 6 |  | - |  | - |
Total de Debentures |  |  |  |  |  |  |  | 1,947 |  | 4,938 |  | 6,885 |  | 6,170 |  | 5,566 |
Total Geral Consolidado |  |  |  |  |  |  |  | 7,106 |  | 9,064 |  | 16,170 |  | 15,779 |  | 13,226 |

(1) | These interest rates, which are based on the six-month Libor rate plus a spread of 0.81 to 0.88% per year, vary from 2.00 to 8.00 % per year;
(2) | Loan from the parent company;
(3) | Exchange rate Swaps for were contracted. The following are the rates for the loans and financings taking the swaps into account: CDI + 1.50% per year;
(4) | Refers to the senior quotas of the FIDC. See Note 12.
(5) | Loans, financings and debentures of RME (Light) and Parati.
(6) | Registered, unsecured, debentures not convertible into shares, without preference.
(7) | Financing of Transchile.
(8) | Financing of Cachoeirão.
(9) | Contracts adjusted to present value, as per changes to the corporate law in accordance with Law 11638/07.
(10) | Consolidated loans and financings of the TBE group.
(11) | Loan contracted for the jointly-controlled subsidiary Madeira Energia.
(12) | Loan contracted for the jointly-controlled subsidiary Hidrelétrica Pipoca S.A.
(13) | Loan contracted for the jointly-controlled subsidiary Praia de Morgado S.A.

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(14) | Loan contracted for the jointly-controlled subsidiary Praia de Parajuru S.A.
(15) | Loan contracted for the jointly-controlled subsidiary VDR S.A.
(16) | Loan contracted for the jointly-controlled subsidiary TAESA.
(17) | Loan and financing of Gasmig.
(18) | Loan arranged by Cemig Telecom – Ativas.
(19) | Consolidated loans and financings of the TBE group.
(20) | Consolidated loans and financings of the TBE group.
(21) | Consolidated loans and financings of the TBE group.
(22) | Loan and financing of Light-Ger.
(23) | Loan and financing of Ganhães Energia.
(24) | Loan and financing of Transudeste.
(25) | Loan and financing of Transirapé.

GUARANTEES

The outstanding balance of loans and financing, as at December 31, 2012 is guaranteed by CEMIG as follows:

|  | Reais |
Promissory Notes and Sureties |  | 3,223 |
Receivables |  | 32 |
Unsecured |  | 4,915 |
Lien on shares |  | 1,423 |
Chattel mortgage |  | 361 |
Contractual, unsecured |  | 4,426 |
Real |  | 1,470 |
Floating charges |  | 320 |
TOTAL |  | 16,170 |

The consolidated breakdown of loans, per currency and indexer, with the respective amortization, not taking into consideration the transfer of values to short-term due to non-compliance with a contractual covenant, as described in item “a” is as follows:

|  | 2013 |  | 2014 |  | 2015 |  | 2016 |  | 2017 |  | 2018 |  | 2019 |  | 2020 and onwards |  | Total |
Currency |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
U.S. dollar |  | 64 |  | 46 |  | 35 |  | 105 |  | 68 |  | 31 |  | 29 |  | 111 |  | 489 |
Euro |  | 2 |  | 33 |  | 2 |  | 2 |  | - |  | - |  | - |  | - |  | 39 |
|  | 66 |  | 79 |  | 37 |  | 107 |  | 68 |  | 31 |  | 29 |  | 111 |  | 528 |
Indexers |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
IPCA (Amplified Consumer Price Index) |  | 733 |  | 488 |  | 679 |  | 177 |  | 176 |  | 220 |  | 221 |  | 1,202 |  | 3,896 |
UFIR (Fiscal Reference Unit) / RGR |  | 70 |  | 75 |  | 62 |  | 50 |  | 40 |  | 36 |  | 24 |  | 35 |  | 392 |
SELIC |  | 1 |  | 1 |  | - |  | - |  | - |  | - |  | - |  | - |  | 2 |
Interbank Certificate of Deposit (CDI) |  | 3,966 |  | 1,137 |  | 622 |  | 549 |  | 1,147 |  | 17 |  | 27 |  | 102 |  | 7,567 |
Eletrobrás Finel internal index |  | 13 |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | 13 |
URTJ/TJLP ( * ) |  | 177 |  | 189 |  | 175 |  | 207 |  | 200 |  | 187 |  | 152 |  | 800 |  | 2,087 |
General Price Index – Market (IGP-M) |  | 23 |  | 381 |  | 2 |  | 1 |  | 1 |  | 1 |  | 1 |  | 57 |  | 467 |
UMBndes ( ** ) |  | 32 |  | 32 |  | 32 |  | 31 |  | 17 |  | 9 |  | 7 |  | 3 |  | 163 |
Others (IGP-DI, INPC) ( *** ) |  | 3 |  | - |  | - |  | 1 |  | 1 |  | 1 |  | - |  | - |  | 6 |
TR |  | 2 |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | 2 |
No indexer |  | 827 |  | 33 |  | 95 |  | 31 |  | 6 |  | 6 |  | 6 |  | 44 |  | 1,047 |
|  | 5,847 |  | 2,336 |  | 1,667 |  | 1,047 |  | 1,588 |  | 477 |  | 438 |  | 2,242 |  | 15,642 |
|  | 5,913 |  | 2,415 |  | 1,704 |  | 1,154 |  | 1,656 |  | 508 |  | 467 |  | 2,353 |  | 16,170 |

( * ) | URTJ = Interest Rate Reference Unit. Adjusted by the Long-term Interest Rate (TJLP)
( ** ) | UMBNDES = BNDES Monetary Unit.
( *** ) | IGP-DI inflation index (General Price Index – Domestic Availability).
| INPC – National Consumer Price Index.

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The following table sets forth the relative variance for the year of 2012, 2011 and 2010 for the principal foreign currencies, interest rates and indices applied to Loans, financing and debentures:

Currency |  | Accumulated Variance in 2012 (%) |  | Accumulated Variance in 2011 (%) |  | Accumulated Variance in 2010 (%) |  | Index |  | Accumulated Variance in 2012 (%) |  | Accumulated Variance in 2011 (%) |  | Accumulated Variance in 2010 (%) |
United States Dollars |  | 8.94 |  | 12.58 |  | (4.31) |  | IGP-M |  | 7.82 |  | 5.10 |  | 11.32 |
Euro |  | 10.73 |  | 9.25 |  | (11.14) |  | CDI |  | 8.37 |  | 11.64 |  | 9.71 |
|  |  |  |  |  |  |  | SELIC |  | 8.49 |  | 11.67 |  | 9.81 |
|  |  |  |  |  |  |  | IPCA |  | 5.84 |  | 6.50 |  | 5.63 |

The changes in financing are as follows:

Balance at January 1, 2011 |  | 13,226 |
Balance at December 31, 2011 |  | 15,779 |
Acquisition of jointly-controlled subsidiaries – opening balance |  | 296 |
Reduction of equity interests in subsidiaries |  | (648) |
Loans and financings obtained |  | 7,195 |
Capitalization |  | 6 |
Monetary and FX variation |  | 290 |
Financial charges recorded as provisions |  | 1,299 |
Financial charges paid |  | (1,209) |
Amortization |  | (6,838) |
Balance at December 31, 2012 |  | 16,170 |

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The consolidated totals of funds raised in 2012 are as follows:

Lenders |  | maturity date |  | Annual financial cost, % |  | Amount raised |
Foreign currency |  |  |  |  |  |  |
Citibank (SESA) |  | 2018 |  | Libor+1.66 |  | 53 |
Citibank (ENERGIA) |  | 2018 |  | Libor+1.66 |  | 42 |
Citibank (SESA) |  | 2018 |  | Libor+1.66 |  | 13 |
Citibank (ENERGIA) |  | 2018 |  | Libor+1.66 |  | 10 |
Total funds raised in foreign currency |  |  |  |  |  | 118 |
Brazilian currency |  |  |  |  |  |  |
Banco do Brasil S/A (Promissory Note) |  | 2013 |  | 104.08 of CDI |  | 640 |
Banco do Brasil S/A |  | 2013 |  | 102.50 of CDI |  | 600 |
Banco do Brasil S/A |  | 2017 |  | 108.33 of CDI |  | 196 |
Eletrobras |  | 2023 |  | 6 |  | 15 |
Eletrobras |  | 2023 |  | 6 |  | 15 |
DEBENTURES (ITAÚ BBA) - 5ª EMISSÃO |  | 2013 |  | 104 of CDI |  | 513 |
1ª série – 3 rd Issue |  | 2017 |  | CDI + 0.78 |  | 289 |
2ª série - 3 rd Issue |  | 2020 |  | IPCA + 4.85 |  | 346 |
3ª série - 3 rd Issue |  | 2024 |  | IPCA + 5.10 |  | 307 |
Banco Bradesco S/A |  | 2013 |  | 106 of CDI |  | 32 |
Debentures SAE |  | 2037 |  | IPCA + 6.5 |  | 77 |
Bndes 125 600 MM |  | 2028 |  | TJLP+ 1.97 |  | 12 |
Banco Bradesco S/A * |  | 2012 |  | 103 OF CDI |  | 1,000 |
Banco Bradesco S/A |  | 2017 |  | CDI+0.90 |  | 484 |
Banco Bradesco S/A |  | 2022 |  | IPCA+6.20 |  | 677 |
Banco Bradesco S/A |  | 2019 |  | IPCA+6.0 |  | 202 |
Banco do Brasil |  | 2013 |  | 105 of CDI |  | 1,081 |
Debêntures - Pine |  | 2017 |  | 12.65 |  | 19 |
Debêntures - Votorantim |  | 2017 |  | 12.65 |  | 24 |
Debentures – 8 th Issue (Light Sesa) |  | 2026 |  | CDI + 1.18 |  | 122 |
SESA Bndes Capex - Subcred |  | 2019 |  | TJLP + 1.81 a 3.21 |  | 56 |
ENERGIA Renova - Loan |  | 2029 |  | TJLP and CDI |  | 24 |
ENERGIA Renova - Debentures |  | 2022 |  | 123.45 of CDI |  | 17 |
SESA Debentures 8 th Issue |  | 2026 |  | CDI + 1.18 |  | 30 |
SESA Bndes Capex - Subcred |  | 2019 |  | TJLP - 1.81 a 3.21 |  | 14 |
ITAÚ - BBA (DEBENTURES) |  | 2017 |  | CDI + 0.9875 |  | 11 |
ITAÚ - BBA (DEBÊNTURES) |  | 2017 |  | CDI + 0.9875 |  | 11 |
DEBENTURES PÚBLICAS (Instrução CVM 476/09) |  | 2015 |  | 7.87 |  | 60 |
DEBENTURES |  | 2016 |  | CDI + 1.30 |  | 15 |
DEBENTURES |  | 2016 |  | CDI + 1.30 |  | 75 |
BNDES |  | 2026 |  | TJLP + 1.97 |  | 14 |
Others |  | Diversos |  | Various |  | 99 |
Total funds raised in Brazilian currency |  |  |  |  |  | 7,077 |
Overall total – Consolidated |  |  |  |  |  | 7,195 |

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The Debentures issued by its subsidiaries and jointly-controlled subsidiaries as at December 31, 2012 have the following characteristics:

Subsidiary |  | Form and class |  | Guarantee |  | Interest |  | COVENANTS |  | Maturity |  | 2012 |  | 2011 |  | 01/01/2011 |
CEMIG GERAÇÃO E TRANSMISSÃO (1) (2) |  | non-convertible into shares |  | Unsecured |  | IGP-M |  | No |  | 2031 |  | 53 |  | 47 |  | 37 |
CEMIG GERAÇÃO E TRANSMISSÃO (1) (2) |  | non-convertible into shares |  | No |  | IPCA + 7.68% |  | No |  | 2015 |  | 1,445 |  | 1,368 |  | 1,285 |
CEMIG GERAÇÃO E TRANSMISSÃO (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI +0.90% |  | No |  | 2017 |  | 517 |  | - |  | - |
CEMIG GERAÇÃO E TRANSMISSÃO (1) (2) |  | non-convertible into shares |  | Unsecured |  | IPCA + 6.00% |  | No |  | 2019 |  | 220 |  | - |  | - |
CEMIG GERAÇÃO E TRANSMISSÃO (1) (2) |  | non-convertible into shares |  | Unsecured |  | IPCA + 6.20% |  | No |  | 2022 |  | 739 |  | - |  | - |
CEMIG D (1) (3) |  | non-convertible into shares |  | No |  | IPCA + 7.96% |  | No |  | 2017 |  | 530 |  | 503 |  | 472 |
CEMIG D (1) (3) |  | non-convertible into shares |  | Unsecured |  | IGP-M + 10.50% |  | No |  | 2014 |  | 401 |  | 373 |  | 355 |
GUANHÃES ENERGIA S.A. (1) (2) |  | non-convertible into shares |  | Unsecured |  | 106% of CDI |  | No |  | 2013 |  | 32 |  | - |  |  |
GASMIG (1) (2) |  | Nominal, book-entry |  | Unsecured |  | 8.62% |  | No |  | 2016 |  | 112 |  | 131 |  | 158 |
GASMIG (1) (2) |  | Nominal, book-entry |  | Unsecured |  | 7.87% |  | No |  | 2015 |  | 60 |  | - |  | - |
TAESA (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI+1.30% |  | No |  | 2015 |  | 155 |  | 206 |  | 205 |
TAESA (1) (2) |  | non-convertible into shares |  | Unsecured |  | IPCA +7.91% |  | No |  | 2015 |  | 132 |  | 163 |  | 152 |
TAESA (1) (2) |  | non-convertible into shares |  | Unsecured |  | 106% of CDI |  | YES |  | 2017 |  | 353 |  | 463 |  | 462 |
TAESA (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI +0.78% |  | No |  | 2017 |  | 293 |  | - |  | - |
TAESA (1) (2) |  | non-convertible into shares |  | Unsecured |  | IPCA + 4.85% p.a. |  | No |  | 2020 |  | 352 |  | - |  | - |
TAESA (1) (2) |  | non-convertible into shares |  | Unsecured |  | IPCA + 5.10% p.a. |  | No |  | 2024 |  | 312 |  | - |  | - |
ECTE (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI+1.30% |  | No |  | 2016 |  | 26 |  | 13 |  | - |
ENTE (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI+1.30% |  | No |  | 2016 |  | 67 |  | 88 |  | - |
EATE (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI+1.30% |  | No |  | 2016 |  | 203 |  | 167 |  | - |
ETEP (1) (2) |  | non-convertible into shares |  | Unsecured |  | 112.5% of CDI |  | No |  | 2016 |  | 28 |  | 35 |  | - |
Madeira Energia S.A. (1) (2) |  | non-convertible into shares |  | Real guarantee |  | IPCA |  | No |  | 2013 |  | 160 |  | 207 |  | 182 |
LIGHT ENERGIA – GUANHÃES (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI + 0.39% |  | No |  | 2013 |  | 11 |  | - |  | - |
LIGHT ENERGIA - 8º EMISSÃO (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI + 1.35% |  | No |  | 2016 |  | 213 |  | 214 |  | - |
LIGHT ENERGIA – RENOVA (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI + 1.51% |  | No |  | 2022 |  | 21 |  | - |  | - |
LIGHT ENERGIA - 5º EMISSÃO (1) (2) |  | non-convertible into shares |  | Unsecured |  | CDI + 1.50% |  | No |  | 2014 |  | 67 |  | 242 |  | 210 |
LIGHT ENERGIA - 2º EMISSÃO (2) |  | non-convertible into shares |  | Unsecured |  | CDI+1.18% |  | YES |  | 2019 |  | 142 |  | 137 |  | - |
LIGHT ENERGIA - 1º EMISSÃO (2) |  | non-convertible into shares |  | Unsecured (also with personal guarantee) |  | CDI + 1.45% |  | YES |  | 2016 |  | 57 |  | 57 |  | - |
LIGHT ENERGIA - 3º EMISSÃO (1) (2) |  | non-convertible into shares |  | Unsecured |  | Cdi+1.18% |  | No |  | 2026 |  | 10 |  | - |  | - |
LIGHT ENERGIA - 8º EMISSÃO (1) (2) |  | non-convertible into shares |  | Unsecured |  | Cdi+1.18% |  | No |  | 2026 |  | 153 |  | - |  | - |
TRANSUDESTE (1) (2) |  | Book-entry, non-convertible convertible |  | Unsecured |  | CDI + 0.9875% p.a. |  | No |  | 2017 |  | 12 |  | - |  | - |
TRANSPIRAPE (1) (2) |  | Book-entry, non-convertible convertible |  | Unsecured |  | CDI + 0.9875% p.a |  | No |  | 2017 |  | 11 |  | - |  | - |
CEMIG GERAÇÃO E TRANSMISSÃO (1) (2) |  | non-convertible into shares |  | Unsecured (Collateral of Holding) |  | CDI+0.90% |  | No |  | 2012 |  | - |  | 1,755 |  | 1,726 |
LIGHT ENERGIA (1) (2) |  | non-convertible into shares |  | No |  | 115% +CDI |  | No |  | 2011 |  | - |  | - |  | 79 |
CEMIG GERAÇÃO E TRANSMISSÃO (1) (2) |  | non-convertible into shares |  | No |  | 104.00% of CDI |  | No |  | 2011 |  | - |  | - |  | 243 |
TOTAL |  |  |  |  |  |  |  |  |  |  |  | 6,887 |  | 6,169 |  | 5,566 |

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(1) With no renegotiation clause and no debentures in cash.

(2) Complied fully with the covenants.

(3) Not Complied with the covenants.

a) Covenants

Cemig and its subsidiaries Cemig Distribuição and Cemig Geração e Transmissão have contracts for loans and financing which contain covenants, requiring compliance on a semi-annual basis at the end of June and December each year.

The following are the main covenants:

Description of the covenant |  | Index required
Cemig: |  |
EBITDA/Interest |  | Greater than or equal to 3.0
Debt/EBITDA |  | Less than or equal to 2.5
Cemig Distribuição |  |
Debt/EBITDA; |  | Less than or equal to 2.5
Debt/EBITDA; |  | Less than or equal to 3.36
Current Debt/EBITDA |  | Less than or equal to 200%
Dívida/Patrimônio Líquido + Dívida |  | Less than or equal to 62%
EBITDA/Financial Result |  | Greater than or equal to 2.3
EBITDA/Interest |  | Greater than or equal to 3.0
Investment/EBITDA |  | Less than or equal to 96%
Cemig Geração e Transmissão |  |
Net Debt /EBITDA |  | Less than or equal to 3.25
Current Debt/EBITDA |  | Less than or equal to 90%
Debt/Shareholders’ Equity + Debt |  | Less than or equal to 61%
EBITDA/Financial Result |  | Greater than or equal to 2.6
Investment/EBITDA |  | Less than or equal to 60%

Net debt = | Sum of short and long-term remunerated financial obligations (loans, financings and debentures), less the balance of cash and cash equivalents. It should be pointed out that Net debt is not a measurement recognized by IFRS, does not have a standard meaning and could be non-comparable to measures with similar titles supplied by other Companies.
Current debt = Sum of short-term remunerated financial obligations (loans, financings and debentures).
Ebitda: | Ebitda is a non-accounting measure prepared by the Company, extracted from its financial statements which comprises net income, adjusted for the effects of net financial revenue (expenses), depreciation and amortization and income tax and the Social Contribution tax. Ebitda is not a measure recognized by IFRS; it does not have a standard meaning; and it may be non-comparable with measures with similar titles provided by other companies. Ebitda should not be considered in isolation or as a substitution for net income or operational profit nor as an indicator of operational performance or cash flow nor to measure liquidity nor the capacity for payment of debt. Specific criteria for the calculation of Ebitda are made in some contracts, with some variations from this formula.

At December 31, 2012, some of Cemig’s covenants clauses was not complied with. The company is negotiating with creditors consents in oder to assure the creditors will not accelerate any amounts due up to December 31, 2012.

The company expects to obtain the consents, but since this will take place after December 31, 2012, the contracts which have covenants that were not complied with are recognized in Current liabilities. The amount reclassified to the current liabilities as a result of the covenants was R$1,206.

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b) Debentures

The debentures issued by the Company’s subsidiaries and jointly-controlled subsidiaries are simple, non-convertible.

c)Issue of promissory notes by Cemig D

On July 2, 2012, Cemig D made its 5th issue of Commercial Promissory Notes, for public distribution, under CVM Instruction 476 of January 16 2009, in the amount of R$ 640.

Sixty-four Promissory Notes were issued, each with nominal unit value of R$ 10 (“the Promissory Notes”), with maturity on June 27, 2013. The Notes are remunerated by interest at 104.8% of the DI Rate, and have the surety guarantee of Cemig D.

The issue of the Notes was approved by the meeting of the Board of Directors on June 5, 2012. The proceeds were used to finance investments made or to be made, for payment of debt(s) contracted and/or strengthening of the Issuer’s working capital.

20. REGULATORY CHARGES

|  | 2012 |  | 2011 |  | 01/01/2011 |
Global Reversion Reserve – RGR |  | 75 |  | 59 |  | 46 |
Fuel Consumption Account – CCC |  | 33 |  | 68 |  | 51 |
Energy Development Account – CDE |  | 52 |  | 45 |  | 35 |
Eletrobrás – Compulsory loan |  | 1 |  | 1 |  | 1 |
ANEEL inspection charge |  | 5 |  | 5 |  | 4 |
Energy Efficiency |  | 150 |  | 148 |  | 156 |
Research and Development |  | 174 |  | 217 |  | 197 |
Energy System Expansion Research |  | 5 |  | 4 |  | 4 |
National Scientific and Technological Development Fund |  | 8 |  | 8 |  | 8 |
Alternative Energy Program – Proinfa |  | 26 |  | 23 |  | 18 |
Emergency capacity charge |  | 49 |  | 49 |  | 3 |
0.30% additional payment – Law 12111/09 |  | 5 |  | 3 |  | 3 |
|  | 583 |  | 630 |  | 526 |
Current liabilities |  | 413 |  | 368 |  | 384 |
Non-current liabilities |  | 170 |  | 262 |  | 142 |

21. EMPLOYEE POST-RETIREMENT BENEFITS

The Forluz Pension Fund

The Company sponsors a pension plan, administered by Fundação Forluminas de Seguridade Social (“Forluz”) covering substantially all its employees. The purpose of the pension plan is to provide the plan’s members and participants, and their dependents, with additional financial income to complement their retirement.

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On December 31, 2004, the actuarial liabilities and the plan’s assets were separated and allocated between CEMIG, Cemig Generação and Transmisão and Cemig Distribuição, based on the proportion of employees in each of these Companies.

FORLUZ provides the following supplementary pension benefit plan for its participants:

Mixed Benefits Pension Plan (Plan B): This plan operates as a defined-contribution plan during the phase of accumulation of funds for retirement benefits for normal time. The plan operates as a defined-benefit plan, providing disability and life insurance benefits for active employees and receipt of benefits for time contributed. The sponsors match the basic monthly contributions of the participants. Plan B is the only plan open for enrollment by new participants.

Paid-off Benefits Pension Plan (Plan A): This plan includes all currently employed and assisted participants who elected to migrate from the Company’s previously sponsored defined benefit plan, and who are entitled to a proportional paid-off benefit. For active employees, this benefit has been deferred until the date of retirement.

CEMIG, Cemig GT and Cemig D also maintain, independently of the plans made available by FORLUZ, payments of part of the life insurance premium for the retirees, and contribute to a health plan and a dental plan for the active employees, retired employee and dependents, administered by Cemig Saúde.

Amortization of Deficit in Actuarial Reserves

In this Note the Company presents its actuarial obligations and expenses incurred for purposes of the Retirement Plan, Health Plan, Dental Plan and Life Insurance Plan in accordance with the standards set forth in IAS 19 (Employee Benefits) and an independent actuarial report prepared as of December 31, 2012.

The Company recognized a debt payable, in the amount of R$815 as at December 31, 2012 (R$846 as at December 31, 2011) related to the pension fund actuarial losses from prior years. This payable is being amortized in monthly installments, until June 2024, and are calculated under the fixed-installment system (“Price Table”). After the Third Amendment to the FORLUZ Agreement, the amounts began to be adjusted only by the Amplified National Consumer Price Index (IPCA) published by IBGE (Brazilian Institute of Geography and Statistics), plus 6% per year.

The post-employment obligation, as included in the Company’s consolidated statement of financial position, represents the amount of debt as agreed-upon with FORLUZ for amortization of the actuarial obligations, since the debt payable is higher than the net actuarial liability. Because the Company is required to pay this debt even if FORLUZ has a surplus, the Company recorded the debt in full against equity on the date of transition to IFRS and then recorded the impacts related to monetary updating and interest in its financial result.

The Braslight Pension Fund

Light is a sponsor of Fundação de Seguridade Social Braslight (“Braslight”), a non-profit private pension plan entity whose purpose is to guarantee retirement revenue for Light employees subscribed with the Foundation, and a pension to their dependents.

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Braslight was established in April 1974, and has four plans – A, B, C and D – implemented in 1975, 1984, 1998 and 2010, respectively. Around 96% of the active participants that were formerly in plans A and B have migrated to plan C.

Nowadays, Light has Plan A and Plan B that is defined-benefit plans, Plan C that is a mixed and Plan D that the benefits are the defined contributions before and after their concession.

On October 2, 2001, the Department of Supplementary Pensions approved a resolution with regards to the actuarial deficit and refinancing of the Braslight amortizable pension plan reserve, which were then fully recognized. Based on this resolution, the reserve is being amortized on a straight-line basis in 300 monthly installments, starting in July 2001. The installments are monetarily updated for variations in the IGP-DI plus 6% interest per year. As of December 31, 2012, the Braslight pension plan reserve totaled to R$1,071 (R$1,095 as of December 31, 2010). The effect in the Company is R$ 348 on December 31, 2012 (R$ 356 on December 31, 2011)

The liabilities and expenses recognized by Light in connection with the supplementary retirement plan are adjusted in accordance with the terms of IAS 19 (Employee Benefits) and in conformity with the information as provided in a report by independent actuaries. The 2012 independent actuarial valuation was performed as of December 31, 2012.

Independent Actuarial Information

The tables below present Cemig’s consolidated actuarial information for the years ended December 31, 2012, which includes the additional amount related to the proportional consolidation of Light, as mentioned above:

|  | Pension plans and retirement supplement plans |  |  |  |  |  | Life |
|  | FORLUZ |  | BRASLIGHT |  | Health Plan |  | Dental Plan |  | Insurance |
Present value of funded obligations |  | 9,191 |  | 872 |  | 820 |  | 22 |  | 736 |
Fair value of the plan’s assets |  | (8,142) |  | (427) |  | - |  | - |  | - |
Present value of unfunded obligations |  | 1,049 |  | 445 |  | 820 |  | 22 |  | 736 |
Unrecognized actuarial gains (losses) |  | (741) |  | (89) |  | (239) |  | 9 |  | (200) |
Net liabilities |  | 308 |  | 356 |  | 581 |  | 31 |  | 536 |
Addition amount related to the debt payable to Forluz |  | 507 |  | - |  | - |  | - |  | - |
Total net liabilities |  | 815 |  | 356 |  | 581 |  | 31 |  | 536 |

As previously mentioned, the Company records an additional obligation corresponding to the difference between the obligation to supplement the retirement pensions stated in the actuarial report and the debt agreed upon with FORLUZ.

Starting with the 2013 business year, due to the adoption of the changes in IAS19 (R) , the difference between the net liability recorded in the Statement of financial position and the present value of unfunded obligations will be recognized in full, with a counterpart in Equity. As a result there will be an impact on Equity in January 2013 as a result of the new accounting practice, in the amount of R$ 497 (net of tax effects).

The changes in the present value of the Company’s defined-benefit obligations from December 31, 2011 to December 31, 2012 were as follows:

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|  | Pension plans and retirement supplement plans |  |  |  |  |  |  |
|  | FORLUZ |  | BRASLIGHT |  | Health Plan |  | Dental Plan |  | Life Insurance |
Defined-benefit obligation as of 12/31/2011 |  | 7,254 |  | 733 |  | 626 |  | 18 |  | 540 |
Cost of current service |  | 8 |  | - |  | 11 |  | - |  | 6 |
Interest on the actuarial obligation |  | 703 |  | 74 |  | 61 |  | 2 |  | 54 |
Actuarial losses (gains) recognized |  | 1,780 |  | 135 |  | 181 |  | 3 |  | 148 |
Benefits paid |  | (554 | ) |  | (70 | ) |  | (59 | ) |  | (1 | ) |  | (12 | ) |
Defined-benefit obligation as of 12/31/2012 |  | 9,191 |  | 872 |  | 820 |  | 22 |  | 736 |

The changes in the fair value of the plan assets of the plans from December 31, 2011 to December 31, 2012 were as follows:

|  | Pension plans and retirement supplement plans |
|  | FORLUZ |  | BRASLIGHT |
Fair value of the plan assets of the plan as of 12/31/2011 |  | 6,893 |  | 355 |
Expected return |  | 1,678 |  | 105 |
Employer Contributions |  | 125 |  | 37 |
Benefits paid |  | (554 | ) |  | (70 | ) |
Fair value of the plan assets of the plans as of 12/31/2012 |  | 8,142 |  | 427 |

The amounts recognized in the income statement for the year ended December 31, 2012 were as follows:

|  | Pension plans and retirement supplement plans |  |  |  |  |  | Life |
|  | FORLUZ |  | BRASLIGHT |  | Health Plan |  | Dental Plan |  | Insurance |
Current service cost |  | 8 |  | - |  | 11 |  | - |  | 6 |
Interest on the actuarial obligation |  | 703 |  | 74 |  | 61 |  | 2 |  | 54 |
Expected return on plan assets |  | (735 | ) | (37 | ) | - |  | - |  | - |
Actuarial losses (gains) recognized |  | - |  | - |  | - |  | (1 | ) | 1 |
Expense in 2012 as per the actuarial report |  | (24 | ) | 37 |  | 72 |  | 1 |  | 61 |
Adjustment related to debt with FORLUZ |  | 117 |  | - |  | - |  | - |  | - |
Total expense recorded in 2012 |  | 93 |  | 37 |  | 72 |  | 1 |  | 61 |

The changes in net liabilities from December 31, 2011 to December 31, 2012 are as follows:

|  | Pension plans and retirement supplement plans |  | Health Plan |  | Dental Plan |  | Life Insurance |  | Total |
|  | FORLUZ |  | BRASLIGHT |  |  |  |  |  |  |  |  |
Net liabilities as at December 31, 2010 |  | 868 |  | 265 |  | 554 |  | 30 |  | 444 |  | 2,161 |
Expenses incurred |  | 106 |  | 57 |  | 69 |  | 1 |  | 53 |  | 286 |
Contributions paid |  | (127) |  | (31) |  | (56) |  | - |  | (10) |  | (224) |
Acquisition of equity interest in Light |  | - |  | 65 |  | - |  | - |  | - |  | 65 |
Net liabilities December 31, 2011 |  | 847 |  | 356 |  | 567 |  | 31 |  | 487 |  | 2,28 8 |
Expenses incurred |  | 93 |  | 37 |  | 72 |  | 1 |  | 61 |  | 264 |
Contributions paid |  | (125) |  | (37) |  | (58) |  | (1) |  | (13) |  | (234) |
Net liabilities December 31, 2012 |  | 815 |  | 356 |  | 581 |  | 31 |  | 535 |  | 2,318 |
Current liabilities |  |  |  |  |  |  |  |  |  |  |  | 89 |
Non current liabilities |  |  |  |  |  |  |  |  |  |  |  | 2,229 |

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The expenses with pension funds are recorded in financial result as they represent the interest and monetary adjustments related to the debt with Forluz, as mentioned previously in this Note. The expenses related to the health, dental, and life insurance plans are recorded as other operating expenses.

The independent actuary’s estimate for the expense to be recognized for 2013 is as follows:

|  | Pension plans and retirement supplement plans Forluz |  | Health Plan |  | Dental Plan |  | Life Insurance |
|  | FORLUZ |  | BRASLIGHT |  |  |  |  |  |
Current service cost |  | 11 |  | - |  | 17 |  | - |  | 8 |
Interest on the actuarial obligation |  | 806 |  | 69 |  | 72 |  | 2 |  | 68 |
Expected return on plan assets |  | (717) |  | (34) |  | - |  | - |  | - |
Estimated expense in 2013 |  | 100 |  | 35 |  | 89 |  | 2 |  | 76 |

The independent actuary’s estimate for the payment of benefits during 2013 is as follows:

|  | Pension plans and retirement supplement plans - Forluz |  | Health Plan |  | Dental Plan |  | Life Insurance |
Estimated payment of benefits |  | 567 |  | 51 |  | 1 |  | 17 |

The Company and its subsidiaries Cemig GT and Cemig D expect to make contributions totaling R$135 and 75 respectively to the pension fund and to the defined contribution plan during 2013.

Light expect to make contributions totaling R$115 (the portion relating to Cemig would be R$37) to the pension fund during 2013.

The main categories of the plan’s assets, as a percentage of the plan’s total assets, are as follows:

|  | Cemig, Cemig GT e Cemig D |  | BRASLIGHT |
|  | 2012 |  | 2011 |  | 2012 |  | 2011 |
Shares in Brazilian companies |  | 0.08% |  | 0.11% |  | 15.23% |  | 13.07% |
Fixed income securities |  | 85.63% |  | 83.69% |  | 73.32% |  | 74.86% |
Property |  | 3.77% |  | 3.78% |  | 11.23% |  | 4.98% |
Others |  | 10.52% |  | 12.42% |  | 0.22% |  | 7.09% |
|  | 100.00% |  | 100.00% |  | 100.00% |  | 100.00% |

The Company’s consolidated pension plan assets include the following assets, valued at fair value, held by both CEMIG and Light:

|  | 2012 |  | 2011 |
Non-convertible debentures issued by the sponsors |  | 464 |  | 367 |
Shares issued by the sponsors |  | 10 |  | 12 |
Real estate properties of FORLUZ, occupied by the sponsors |  | 201 |  | 192 |
|  | 675 |  | 571 |

The table below presents the key assumptions used by the Company for its defined benefit pension plans for the years ended December 31, 2011, and December 31, 2012:

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|  | Cemig, Cemig GT e Cemig D |  | BRASLIGHT
|  | 2012 |  | 2011 |  | 2012 |  | 2011
Annual discount rate |  | 9.05% a 10.07% |  | 10.07% |  | 8.26% |  | 10.56%
Annual expected return on the plan’s assets |  | 9.05% a |  | 10.98% |  | 12.38% |  | 10.96%
Annual long-term inflation rate |  | 5.20% |  | 4.30% |  | 4.50% |  | 4.50%
Annual salary increases |  | 7.31% |  | 6.39% |  | 7.01% |  | 6.59%
Average Mortality table |  | AT-2000 |  | AT-2000 |  | AT-83 |  | AT-83
Disability table |  | Light média |  | Light média |  | Light forte |  | Light forte
Mortality table for disabled persons |  | IAPB-57 |  | IAPB-57 |  | IAPB-57 |  | IAPB-57

22. PROVISIONS AND CONTINGENCIES

Cemig and its subsidiaries and jointly-controlled subsidiaries are party to certain legal proceedings in Brazil arising in the normal course of business, regarding tax, employment and environmental law, and civil and other issues.

Proceedings in which the Company is a debtor

The Company, its subsidiaries and its jointly-controlled subsidiaries have made provisions for risks in tax, employment-law, regulatory and environmental legal proceedings in which the chances of loss are assessed as “probable” (i.e. it is expected that there will be an outflow of funds to settle the obligation), as follows:

|  | Balance in 01/01/2011 |  | Balance in 2011 |  | Additions |  | Updates |  | Reversals |  | Write- off |  | Effect of change of % stake in subsidiary |  | Balance in 2012
Labor claims |  | 115 |  | 135 |  | 26 |  | - |  | (19) |  | (17) |  | - |  | 125
Civil lawsuits |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Consumer relations |  | 71 |  | 84 |  | 7 |  | - |  | (21) |  | (4) |  | - |  | 66
Other civil cases |  | 56 |  | 65 |  | 84 |  | 4 |  | (31) |  | (27) |  | - |  | 95
|  | 126 |  | 149 |  | 91 |  | 4 |  | (52) |  | (31) |  | - |  | 161
Tax |  | 88 |  | 118 |  | 8 |  | 4 |  | (4) |  | (3) |  | 1 |  | 124
Environmental |  | 4 |  | 57 |  | 1 |  | - |  | (41) |  | (12) |  | - |  | 5
Regulatory |  | 27 |  | 78 |  | 446 |  | - |  | (27) |  | (457) |  | - |  | 40
Other |  | 10 |  | 12 |  | 7 |  | 1 |  | (2) |  | (5) |  | - |  | 13
Total |  | 371 |  | 549 |  | 579 |  | 9 |  | (145) |  | (525) |  | 1 |  | 468

Company’s management, due to the long periods and manner of working of the judiciary, tax and regulatory systems, believes that it is not practical to supply information that would be useful to the users of these financial statements about the time when any cash outflows, or any possibility of reimbursements, might take place in fact. The Company’s management believes that any loss in excess of the amounts provided for in respect of such contingencies will not have a material adverse effect on the Company’s results of operations or financial position.

Below are the details of the principal provisions and contingent liabilities, including the best expectations for future disbursements for such contingencies:

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Provisions, for legal actions with chances of loss assessed as “probable” and contingent liabilities linked, on the procedures with possible losses

Employment-law cases

The Company and its subsidiaries and jointly-controlled subsidiaries are parties in numerous legal actions filed by our employees and by outsourced professionals. Most of these claims relate to overtime and additional amounts for dangerous work. Other actions relate to outsourcing of labor, supplementary additions to or re-calculation of retirement pension payments by Forluz, and salary adjustments. The value of the contingency is approximately R$ 537, of which R$ 125 has been provisioned, being this the amount of probable future expected cash outflows on these claims.

Consumer relations

The Company and its subsidiaries and jointly-controlled subsidiaries are parties to several civil actions relating to indemnity for pain and suffering or property damage arising, principally, from accidents involving the electricity distribution network, irregularities in measurement of consumption and claims of undue invoicing, in the normal course of business, totaling R$ 155, of which total R$ 65 has been provisioned, being this the amount of probable future expected cash outflows on these claims.

Other civil actions

The Company and its subsidiaries and jointly-controlled subsidiaries are parties in various civil actions applying for indemnity for pain and suffering or material damage, among others, arising from incidents taking place during the normal course of business, in the amount of R$ 172, of which R$ 95 has been provisioned, being this the amount of probable future expected cash outflows on these claims.

Tax

The Company and its jointly-controlled subsidiaries are parties in numerous administrative and court actions relating, among other subjects, to the Urban Property Tax (Imposto sobre a Propriedade Territorial Urbana, or IPTU), the Social Integration Program (Programa de Integração Social, or PIS), the Contribution to Finance Social Security (Contribuição para o Financiamento da Seguridade Social, or Cofins), Corporate Income Tax (Imposto de Renda Pessoa Jurídica, or IRPJ), the Social Contribution Tax (Contribuição Social sobre o Lucro Líquido, or CSLL) and applications to stays tax execution. The value of the contingency is approximately R$ 215, of which R$ 40 has been provisioned.

ICMS (local state value added tax)

Light is a party in proceedings relating to the ICMS tax, the principal items being:

I. An infringement notice charging ICMS, Contribution to the State Poverty Combat Fund (Fundo Estadual de Combate à Pobreza, or FECP), and fine (periods January 1999–December 2003 and January 2006–December 2010), alleging non-payment of these deferred taxes in transactions prior to those of electricity distribution, that is to say, in transactions between the generating company and the distributing company, by reason of the occurrence of commercial losses.

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II. An infringement notice demanding ICMS tax due to the use by the subsidiary Light SESA of accumulated ICMS tax credits of Rheem Embalagens Ltda. in the acquisition of inputs and raw materials within the State of Rio de Janeiro.

III. An infringement notice issued to charge ICMS tax on amounts of the subsidy directed to low-income consumers arising from the Global Reversion Reserve Fund (Fundo de Reserva Global de Reversão, or RGR).

IV. Applicability of State Law 3188/99, which restricted the manner of appropriation of ICMS tax credits applying to the acquisition of goods destined for Property, plant and equipment, demanding that the credit should be made in portions, while such restriction was not specified in Complementary Law 87/96.

The amount of the contingencies, corresponding to the Company’s equity interest in Light is approximately R$ 537, of which R$ 37 has been provisioned, being this the amount of probable future expected cash outflows on these claims.

Gasmig is a party in actions relating to credits of ICMS tax on acquisition of property, plant and equipment used in the network and the applicability of ICMS tax to the calculation of the amount taxable for PIS and Cofins. The amount of the contingency, corresponding to the Company’s equity interest in Gasmig, is approximately R$ 40, of which R$ 22 has been provisioned.

Additionally, the Company is defendant in various actions relating to ICMS tax in relation to which, if it eventually has to pay the tax applicable to these transactions, it will be able to require reimbursement from consumers to recover the amount of the tax plus any penalty payment. The principal cases are:

I. Non-payment of ICMS tax on the portions of TUSD demand contracted and not used, invoiced in the period from January 2005 to December 2010, since the value of the tax applicable was excluded from electricity invoices, in compliance with the Court Injunction granted;

II. Various administrative and court proceedings brought by the Minas Gerais State Tax Authority charging ICMS on the transfer of excess of electricity during the period of electricity rationing.

No provision has been made and the amount, estimated, of the contingency is R$ 390. Due to an agreement with the Minas Gerais State government, involving court actions on ICMS tax, the actions in which the company is being claimed against, or claiming payment, are in the process of being extinguished.

The Minas Gerais Consumer Defense Institute (Instituto Mineiro de Defesa do Consumidor, or Imidec) brought a class action against the Company, questioning the charging of ICMS tax on the total amount of the invoice and not only on the service provided. Based on the assessment made by our legal advisors, that the merit of the discussion has already been the subject of a statement by the Federal Supreme Court, the possibility of loss has been reassessed from “possible” to “remote”.

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Social Security contributions

The Brazilian Federal Revenue Service (Secretaria da Receita Federal) has filed administrative proceedings against Cemig in relation to social security contributions alleged to be owed on various categories of payment: employee profit shares (Participações no’s Ucros e Resulted, or PLR); the Workers’ Food Program (Programa de Alimentação do Trabalhador, or PAT), the education assistance (auxílio-educação) contribution, overtime payments, payment for exposure to risk in the workplace, Sest/Senat (transport workers’ support programs), and fines for non-compliance with accessory obligations. The Company has presented defenses and awaits judgment. The value of the contingency is approximately R$ 924, of which R$ 1 has been provisioned, being this the amount of probable future expected cash outflows on these claims.

Finsocial tax

The federal government filed a rescission action against Cemig, to rescind the Appeal Court judgment given in the action for rescission previously filed by Cemig, on the subject of the Finsocial tax, with the argument that Cemig filed its action after the expiry period of two years. The value of the contingency is approximately R$ 99, of which R$ 22 has been provisioned.

Environmental

The Company and its subsidiaries are involved in environmental actions, relating to protected areas, environmental licenses, recovery of environmental damage and other subjects, in the amount of R$ 1,689, of which the Company has provisioned R$ 5, being this the amount of probable future expected cash outflows on these claims. We highlight the following:

A certain environment association filed a class action for indemnity for supposed collective environmental damage due to the construction and operation of the Nova Ponte hydroelectric plant. The amount envisaged by the action is R$ 1,582. The Company believes that it has arguments of merit for legal defense, and as a result has not constituted a provision for this action.

The Public Attorney’s Office of the State of Minas Gerais has brought civil public actions requiring the Company to invest at least 0.5% of its annual gross operational revenue, since 1997, in environmental protection and preservation of the water tables of the municipalities where Cemig’s power plants are located, and proportional indemnity for environmental damage caused, which cannot be recovered, arising from omission to comply with Minas Gerais State Law 12503/97. The Company has filed appeals to the Higher Appeal Court (STJ) and the Federal Supreme Court (STF). No provision has been constituted. The estimated amount of the contingency is R$ 94.

Regulatory

The Company and its subsidiaries and jointly-controlled subsidiaries are parties in numerous administrative and court proceedings in which the main issues disputed are:

I. The tariff charges in invoices relating to the use of the distribution system by a self-producer;

II. Violation of targets for indicators for continuity and provision of electricity;

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III. The tariff increase made during the federal government’s economic stabilization plan referred to as the “Cruzado Plan”, in 1986.

The amount of the contingency is approximately R$ 133, of which R$ 41 has been provisioned.

The CRC (Earnings Compensation) Account

a) Claim in legal action

Prior to 1993, holders of electricity concessions were guaranteed a rate of return on the investments in the assets used to provide services linked to the concession. Tariffs charged were uniform throughout the country, and part of profits generated by more profitable concession holders were reallocated to the less profitable ones, in such a way that the rate of return of all the companies was equal to the national average. The deficits were accounted in the “CRC” Account (Conta de Resultados a Compensar, or Earnings Compensation Account) of each concession holder. When the CRC Account and the guaranteed-return concept were abolished, Cemig used its positive balances in the CRC Account to offset its liabilities to the federal government.

Aneel filed an administrative action against the Company, contesting a credit relating to those positive balances. On October 31, 2002 Aneel issued a final administrative decision. On January 9, 2004, the federal Treasury Department (Secretaria do Tesouro Nacional) issued a collection notice in the amount of R$ 516 million. The Company did not make the payment, because it believes that it has arguments of merit for defense in court, and filed for an order of mandamus to suspend its inclusion in the Listing of Unpaid Public Sector Debts (Cadastro Informativo de Créditos Não Quitados do Setor Público, or Cadin). The order of mandamus was denied by the lower court, but an appeal was made to the Federal Court of the First Region, which granted a temporary injunction suspending inclusion in the Cadin.

The amount of the contingency on December 31, 2011 was R$ 1,015, and no provision has been made.

b) Negotiation for early settlement of the CRC Account

On November 20, 2012 the government of the State of Minas Gerais and the Company entered into a Commitment Undertaking, the purpose of which was to make possible the early payment of the obligations arising under the CRC Contract. A discount of approximately 35% was applied to the updated amount of the debtor balance, for payment at sight by the State of Minas Gerais into the account of the Company. Please refer to Note 12 – Accounts receivable from the government of the State of Minas Gerais; the Receivables Fund for additional details.

Of the amount received by the Company, the State Government withheld and passed to the Federal Government the amount of R$ 403 , referring to the Settlement Agreement signed to terminate the legal action existing between Cemig and the Federal Government relating to the now-extinct CRC Account. Arising from this retention, the Company reported an expense of the same amount in December 2012.

Other claims in the normal course of business

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In addition to the above cases, the Company is a party in other cases of smaller scale related to its normal course of operations, with an estimated total amount of R$ 88, of which R$ 14 has been provisioned. Management believes that it has adequate arguments in these actions, and does not expect significant losses relating to these issues that might have an adverse effect on the Company’s financial position or the result of its operations.

Contingent liabilities: for actions in which chances of loss are assessed as “possible”, and the Company believes it has arguments of merit for defense

Tax and similar charges

The Company is a party in numerous administrative and court proceedings in relation to taxes. Below are details of the principal cases:

Indemnity for employees’ future benefit – the “Anuênio”

In 2006 the Company paid an indemnity to its employees, totaling R$ 178, in exchange for the rights to future payments for time of service (Anuênio) which would otherwise be incorporated, in the future, into salaries. The company did not pay income tax nor Social Security contributions in relation to these amounts because it considered that these obligations are not applicable to amounts paid as an indemnity. However, to avoid the risk of a future fine arising from a differing interpretation by the federal tax authority (Secretaria da Receita Federal) or the National Social Security Institution (Instituto Nacional de Seguridade Social, or INSS), the Company applied for an order of mandamus to allow it to make an escrow payment into court of R$ 122. This is recorded in Escrow deposits. The amount of the contingency, updated, is R$ 204.

Profit sharing (“PLR”)

The National Social Security Institute (Instituto Nacional de Segurança Social, or INSS) opened an administrative proceeding against the Company, in 2006, due to non-payment of social security contributions on the amounts paid to employees as profit sharing in the period 2000 to 2004, due to the inspectors believing that the Company had not met the requirements of Law 10101 of 2000. In 2007, an order of mandamus was applied for, seeking to obtain a declaration that such payments of profit-sharing were not subject to the Social Security contribution. The Company received a partially favorable decision in 2008, which it has appealed and on which it awaits the 2nd instance decision. On December 31, 2011 the amount of the contingency was approximately R$ 141. On December 31, 2012, the amount was re-assessed by our legal advisers to R$ 0.5, due to it having been considered that the best possible estimate of the updated value of the payments made into court, which represents the social security contributions on the portions of Profit Shares paid.

Non-homologation of offsetting of tax credit

In several administrative tax proceedings dealing with offsetting of federal taxes, the Federal Tax Authority (Secretaria da Receita Federal) did not homologate tax returns offsetting credits arising from undue or excess payment by the Company. The amount of the contingency is R$ 397.

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Corporate tax return – restitution and offsetting

The Company is a party in an administrative case involving requests for restitution and compensation of credits arising from carryforwards indicated in the tax returns (DIPJs) for the calendar years 1977 to 2000, and also for excess payments identified by the corresponding tax payment receipts (DARFs and DCTFs). Due to completion of all procedures in the administrative sphere, an ordinary legal action has been filed, in the approximate total amount of R$ 337.

PIS and Cofins taxes

An infringement notice was served on Cemig for alleged underpayment of the PIS and Cofins taxes due to undue exclusions of financial expenses from the basis of calculation of those taxes. In spite of the Company having paid PIS and Cofins on financial revenues, the Federal Revenue Department (Secretaria da Receita Federal) believes that these amounts were underpaid. The amount of the contingency was R$ 81 on December 31, 2011. On December 31, 2012, the chances of loss in this action were re-assessed as “remote”, since the Federal Supreme Court (Supremo Tribunal Federal, or STF) gave an opinion in favor of obeying the principle of prior right in cases where change in the law results in a charge upon the taxpayer.

The Company is defendant in various legal proceedings, in which the plaintiffs demand suspension of charging of PIS and Cofins, on the argument that it is illegal to charge these taxes on electricity bills. The amount of the contingency is R$ 41. On December 31, 2012 the chances of loss were re-assessed as “remote”, due to a judgment that recognized the legitimacy of the passthrough of these contributions in electricity bills.

Tax contingencies of Light Sesa

Light Sesa has the following tax contingencies in which the chances of loss are assessed as “possible”:

I. | Income tax withheld source on amounts paid by Light SESA as dividends, on the argument that they arose from non-existence profit;
II. | Demand for corporate income tax and the Social Contribution tax on the profits earned by LIR Energy Limited (LIR) and Light Overseas Investment Limited (LOI) since 1996;
III. | Fine for alleged non-compliance with an accessory obligation relating to delivery of the electronic files for the calendar years 2003 to 2005.
IV. | Charge for Inspection of Occupation of Public Places (TFOP), made by the municipal prefecture of Barra Mansa.
V. | Omission of the offsetting for settlement for debits of Cofins tax (this case has now finally been closed, in favor of the Company).

The total of these cases, corresponding to Cemig’s proportional share in the capital of Light is R$ 503.

Regulatory matters

Contribution for Public Illumination (CIP)

Cemig is defendant in several public civil actions, claiming nullity of the clause in the Electricity Supply Contracts for public illumination, signed between the Company and the various municipalities of its concession area, and restitution by the Company of the difference representing the amounts charged in the last 20 years,

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in the event that the courts recognize that these amounts were unduly charged. The actions are grounded on an alleged mistake by Cemig in the estimate of time used for the calculation of the consumption of electricity by public illumination paid for by the Public Illumination Contribution (CIP). The Company believes that it has arguments of merit for legal defense, and as a result has not constituted a provision for this action, the amount of which is estimated at R$ 1,163.

Accounting of electricity sale transactions in the Electricity Trading Chamber (CCEE)

In an action dating from August 2002, AES Sul Distribuidora has challenged in the courts the criteria for accounting of electricity sale transactions in the wholesale electricity market during the period of rationing. It obtained an interim judgment in its favor in February 2006, which orders Aneel, working with the CCEE, to comply with the claim by AES Sul and recalculate the settlement of the transactions during the rationing period, leaving out of account Aneel’s Dispatch 288 of 2002. This was to be put into effect in the CCEE starting in November 2008, and would have resulted in an additional disbursement for Cemig, for the expense on purchase of energy in the short-term market, in the CCEE, in the amount of approximately R$ 135. On November 9, 2008 the Company obtained an injunction in the Regional Federal Appeal Court suspending the obligatory nature of the requirement to pay into court the amount owed arising from the Special Financial Settlement carried out by the CCEE. The Company has classified the chances of loss as “possible”, since this is a unique action, with no similar action having previously been judged, and because it deals with the General Agreement for the Electricity Sector, in which the Company has all the full documentation to support its allegations.

Tariff increases

Exclusion of consumers inscribed as Low-income

The Federal Public Attorneys’ Office filed a class action against the Company and Aneel, to avoid exclusion of consumers from classification in the Low-income Residential Tariff sub-category, requesting an order for the Company to pay 200% of the amount allegedly paid in excess by the consumers. The court ruled in favor of the plaintiff; the Company and Aneel have filed an interlocutory appeal, and await judgment. The amount of the contingency is, approximately, R$ 133. The Company has classified the chances of loss as “possible” due to other favorable judgments on this theme.

Period Tariff Adjustment – Neutrality of “Portion A”

The Municipal Association for Protection of the Consumer and the Environment (Associação Municipal de Proteção ao Consumidor e ao Meio Ambiente, or Amprocom) filed a public action against the Company and against Aneel, for identification of all the consumers that were allegedly injured in the processes of periodic Review and annual Adjustment of electricity rates, from 2002 through 2009, and restitution, through credit on electricity bills, of the amounts allegedly unduly charged, due to the non-inclusion of the effect of future variations in consumer electricity demand as a component of the distributor’s non-manageable costs (“Portion A”), and their allegedly undue inclusion in manageable costs (“Portion B”), resulting in economic/financial imbalance of the contract. The estimated amount of the contingency is R$ 158.

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Action in which the Company is creditor and in which economic benefits are probable

Pasep and Cofins taxes – Widening of the calculation base

CEMIG has alleged a legal claim challenging the fairness of the expansion of the taxable base for PIS and Cofins tax calculation purposes on financial revenue and on other non-operational revenues during the period from 1999 to January 2004, by Law 9718, of November 27, 1998. In the event of a judgment in the Company’s favor in the final instance (where no further appeal is possible), and noting that the Supreme Court has judged similar cases in favor of the taxpayer, , it will record a gain in the profit and loss account of R$ 202, net of income tax and Social Contribution tax.

23. EQUITY

(a) Share Capital

The fully paid-in shares , each with a par value of R$5.00, are distributed as follows:

Acionistas |  | Quantidade de Ações em 31 de dezembro de 2012 |
|  | Ordinárias |  | % |  | Preferenciais |  | % |  | Total |  | % |
Estado de Minas Gerais |  | 189.991.615 |  | 51 |  | - |  | - |  | 189.991.615 |  | 22 |
Outras Entidades do Estado |  | 50.246 |  | - |  | 8.821.839 |  | 2 |  | 8.872.085 |  | 1 |
AGC Energia S.A. |  | 122.901.990 |  | 33 |  | - |  | - |  | 122.901.990 |  | 14 |
Outros |  |  |  |  |  |  |  |  |  |  |  |  |
No País |  | 49.999.792 |  | 13 |  | 159644811 |  | 33 |  | 209644603 |  | 25 |
No Exterior |  | 9.893.442 |  | 3 |  | 311.714.493 |  | 65 |  | 321.607.935 |  | 38 |
Total |  | 372.837.085 |  | 100 |  | 480.181.143 |  | 100 |  | 853.018.228 |  | 100 |

Shareholders |  | Number of shares as of December 31, 2011 |
|  | Common |  | % |  | Preferred |  | % |  | Total |  | % |
The State of Minas Gerais |  | 151,993,292 |  | 51 |  | - |  | - |  | 151,993,292 |  | 22 |
Other entities of The State of Minas Gerais |  | 40,197 |  | - |  | 7,057,472 |  | 2 |  | 7,097,669 |  | 1 |
AGC Energia S.A. |  | 98,321,592 |  | 33 |  | - |  | - |  | 98,321,592 |  | 14 |
Other: |  |  |  |  |  |  |  |  |  |  |  |  |
In Brazil |  | 35,420,497 |  | 12 |  | 73,185,353 |  | 19 |  | 108,605,850 |  | 16 |
Abroad |  | 12,494,090 |  | 4 |  | 303,902,089 |  | 79 |  | 316,396,179 |  | 47 |
Total |  | 298,269,668 |  | 100 |  | 384,144,914 |  | 100 |  | 682,414,582 |  | 100 |

Shareholders |  | Number of shares as of January 1, 2011 |
|  | Common |  | % |  | Preferred |  | % |  | Total |  | % |
The State of Minas Gerais |  | 151,993,292 |  | 51 |  | - |  | - |  | 151,993,292 |  | 22 |
Other entities of The State of Minas Gerais |  | 40,197 |  | - |  | 7,057,472 |  | 2 |  | 7,097,669 |  | 1 |
AGC Energia S.A. |  | 98,321,592 |  | 33 |  | - |  | - |  | 98,321,592 |  | 14 |
Other: |  |  |  |  |  |  |  |  |  |  |  |  |
In Brazil |  | 35,084,145 |  | 12 |  | 88,391,812 |  | 23 |  | 123,475,957 |  | 18 |
Abroad |  | 12,830,442 |  | 4 |  | 288,695,630 |  | 75 |  | 301,526,072 |  | 45 |
Total |  | 298,269,668 |  | 100 |  | 384,144,914 |  | 100 |  | 682,414,582 |  | 100 |

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Earnings Per Share

Considering the capital increase through the issue of 170,603,646 new shares without a corresponding change in Share Capital of the Company, as described below, earnings per share is presented retrospectively under the new number of shares of the Company. Thus, considering that each class of shares participates equally in the income presented, the earnings per share, basic and diluted, in 2012, 2011 and 2010, are R$ 5.01, R$2.83 and R$2.65, respectively.

The number of shares used to calculate earnings per share, basic and diluted, is as follows:

Quantity of shares |  | 2012 |  | 2011
Common shares |  | 372,837,085 |  | 372,837,085
Preferred shares |  | 480,181,143 |  | 480,181,143
|  | 853,018,228 |  | 853,018,228
Treasury shares |  | (363,650) |  | (363,650)
Total |  | 852,654,578 |  | 852,654,578

Shareholders’ Agreement

On August 1, 2011, the Government of the State of Minas Gerais signed a Shareholders’ Agreement with AGC Energia S.A. with intervention and consent of BNDES Participações S.A. with validity for fifteen years. The agreement maintains the state of Minas Gerais as a hegemonic, isolated and sovereign controller of the Company and attributes a few prerogatives to AGC Energia in order to contribute to the Company’s continued sustainable growth, amongst other contractual terms.

Return of Advance for Future Capital Increase (“AFAC”)

In 1995, 1996 and 1998, by the State of Minas transferred financial resources intended for a capital increase in the historical amount of R$27. In 2011, the Ministry of Finance requested the return of the amounts of these resources for future capital increases of AFAC, monetarily updated, since the aforementioned year the funds had not been used for the payment of shares in a capital increase.

In response to this request, the Board of Directors, on December 27, 2011, decided to return the Advance for Future Capital Increase (“AFAC”) to the State of Minas Gerais, in the amount of R$93, corresponding to the historical amount of R$27, adjusted by the IGP-M (General Index of Market Price) for the period and the financial expense corresponding to the monetary update of the future capital increase, in the amount of R$66, was recorded in 2011.

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Capital increase to be proposed to the Annual Shareholders’ Meeting in April 2012

The General Meeting of Stockholders of Cemig held on April 27, 2012 approved increase in the share capital of Cemig from R$ 3,412 to R$ 4,265, with issuance of 170,603,646 new shares, via capitalization of R$ 822 of the Retained Earnings Reserve, and R$ 31 originating from incorporation of the portions of the contract to assign the credit of the remaining balance on the CRC Account, with distribution, as a result, to stockholders of a stock bonus of 25% in new shares of the same type as those held, and with nominal value of R$ 5.00.

(b) Reserves

The breakdown of Capital Reserves and Profit Reserves is presented as follows:

|  | 2012 |  | 2011 |  | 01/01/2011
Capital Reserves |  |  |  |  |  |
Interest on investments in fixed assets in progress – Own capital |  | 1,313 |  | 1,313 |  | 1,313
Donations and subsidies for investments |  | 2,573 |  | 2,573 |  | 2,573
Additional paid-in capital |  | 69 |  | 69 |  | 69
Treasury Shares |  | (1) |  | (1) |  | (1)
|  | 3,954 |  | 3,954 |  | 3,954

The reserve for interest on investments in fixed assets in progress – own capital refers to the interest over equity used in constructing assets and facilities, which is recorded in property, plant, and equipment as corresponding entries against equity. Cemig stopped forming this reserve as from 1999.

The reserve for Donations and Subsidies for Investments refers basically to the compensation by the Federal Government of the difference between the profitability obtained by CEMIG up to March 1993 and the minimum return guaranteed by the legislation in effect at the time. The funds were used in the amortization of various obligations payable to the Federal Government, and the remaining balance originated the CRC contract.

Treasury shares refer to the shares transferred from FINOR originating from funds invested in CEMIG’s projects in the area covered by SUDENE (Superintendency for the development of the Northeast) due to tax incentives.

|  | 2012 |  | 2011 |  | 01/01/2011
Profit Reserves |  |  |  |  |  |
Legal Reserve |  | 853 |  | 683 |  | 573
Statutory Reserve |  | 1,304 |  | 1,141 |  | 1,435
Profit retention Reserve |  | 71 |  | 1,383 |  | 799
Proposal for distribution of additional dividends |  | 628 |  | 86 |  | 67
|  | 2,856 |  | 3,293 |  | 2,874

Statutory Reserve

The Statutory reserve is for future payment of extraordinary dividends, in accordance with Article 28 of the by-laws.

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Profit Retention Reserve

The Profit Retention Reserve refers to profits not distributed in previous years to ensure the implementation of the Company’s Investment Program, and the retentions supported by capital budgets approved by the Board of Directors in the periods in question. The main acquisitions of interests in other companies are a result of the retention of the aforementioned funds which more detail is presented in Note 14.

Legal Reserve

This reserve is a requirement for all Brazilian corporations and represents the appropriation of 5% of annual net income up to a limit of 20% of share capital as established by Article 193 of Brazillian Coporate Law 6,404. Accordingly, the Company opted to appropriate 4.12% of the net income as at December 31, 2012, in the amount of R$171 in order to comply with the law.

(c) Dividends

Ordinary dividends

50% of the net income for the year must be used for distribution as a mandatory dividend to the Company’s shareholders, as established in the Company’s by-laws.

Preferred shares have priority in the reimbursement of capital and participate in the profit under equal conditions with common shares. Preferred shares have a right to an annual minimum dividend equal to the greater value between 10% of their par value; or 3% of the shareholders’ equity associated with the shares

Under the by-laws, CEMIG’s shares held by private individuals have the right to a minimum dividend of 6% per year on their par value in all years when Cemig does not obtain sufficient profits to pay dividends to its shareholders. This guarantee is given by the State of Minas Gerais in the terms of Article 9 of State Law 828 of December 14, 1951 and Article 1 of State Law 8796 of April 29, 1985.

Since preferred and common shareholders have different dividend, voting and liquidation rights, basic earnings per share have been calculated using the “two-class” method. The “two-class” method is an allocation formula that determines earnings per share for preferred and common shares according to the dividends to be paid as required by the Company’s by-laws and participation rights in undistributed earnings.

Under the Company’s bylaws, if the Company is able to pay dividends in excess of the minimum requirement for preferred shareholders and the remainder of the net income is sufficient to provide equal dividends to both common and preferred shareholders, then the dividends per share will be the same for both common and preferred shareholders. The Company distributed equal dividends per share for all years presented.

The declared dividends shall be paid in two equal installments, the first not later than June 30 and the second not later than December 30 of each year following the generation of profit. The Board of Directors is responsible for observing these deadlines and determining the place of payment and the process for payment.

The calculation of the dividends proposed for distribution to shareholders based on the Company’s profit for the year-ended December 31, 2012 is as follows:

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Minimum Dividend Distribution Calculation as required by the by-laws |  | 2012
Par value of preferred shares |  | 2,399
Percentage applied to the par value of preferred shares |  | 10.00%
Amount of dividends per first payment criteria |  | 240
Shareholders’ equity |  | 12,044
Preferred shares as a percentage of Shareholders’ equity (net of shares held in Treasury) |  | 56.27%
Portion of Shareholders’ equity represented by preferred shares |  | 6,777
Percentage applied to the portion of Shareholders’ equity represented by preferred shares |  | 3.00%
Value of the dividends per second payment criteria |  | 203
Minimum obligatory dividends required by the by-laws for preferred shares |  | 240
Mandatory Dividend Calculation |  |
Profit (loss) for the year |  | 4,272
Mandatory dividend – 50.00% of profit for the year |  | 2,136
Dividends proposed |  |
Interest on Capital |  | 1,700
Ordinary dividends |  | 590
|  | 2,290
Income tax withheld at source on Interest on Equity |  | (154)
|  | 2,136
Dividend per preferred shares |  | 1,202
Dividend per common shares |  | 934
Dividends per share – R$ |  |
Minimum obligatory dividend required by the by-laws for preferred shares |  | 0.50
Mandatory dividend |  | 2.68
Proposed dividend |  | 2.68

In December 2012 the Company declared payment of Interest on Equity, to be computed within the obligatory dividend for 2012, in the amount of R$ 1,700, corresponding to R$ 1.99 per share, to be paid in two equal installments, by June 30 and December 30, 2013. This gives rise to a tax benefit of R$ 578.

Extraordinary dividends

Cemig’s Bylaws establishes that, without prejudice to the mandatory dividend, each year, or more frequently if the availability of cash permits, the Company will use the specific profit reserve for the distribution of extraordinary dividends, up to the limit of the cash available, as decided by the Board of Directors subject to compliance with the Company’s Strategic Plan and the dividend policy specified therein.

The following extraordinary dividends were paid by the Company in 2012 and 2011:

n In a meeting held on December 20, 2012, the Board of Directors decided to declare an extraordinary dividend in the amount of R$1,600, or R$1.8765 per share, using the profit reserve established under the Bylaws for this purpose. The payment of these dividends took place in January, 2013.

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n In a meeting held on December 9, 2011, the Board of Directors decided to declare an extraordinary dividend, in the amount of R$850, or R$1.25 per share, using the profit reserve established under the Bylaws for this purpose. The payment of these dividends took place on December 28, 2011.

(d) Equity Valuation Adjustments

|  | 2012 |  | 2011 |  | 2010
Deemed Cost of the Generation Assets |  | 959 |  | 1,080 |  | 1,210
Foreign Currency Translation Adjustments |  | 10 |  | 5 |  | (1)
Cash Flow Hedge Instruments |  | - |  | 1 |  | 1
|  | 969 |  | 1,086 |  | 1,210

The translation adjustments refer to the foreign exchange difference calculated on the translation of Transchile’s financial statements based on the exchange rates for assets and liabilities at the end of the year, recorded directly in the abovementioned Shareholders’ Equity account.

The amounts recorded as deemed cost of generation assets are due to a new valuation of the generation assets, with the definition of their fair value by their replacement cost at the first time adoption of IFRSs as of January 1, 2009. The new valuation of the generation assets resulted in an increase in the value of these assets, recorded in a specific equity account, net of tax effects.

24. REVENUE

|  | 2012 |  | 2011 (Reclassified) |  | 2010 (Reclassified)
Supply of electric power (a) |  | 18,614 |  | 16,568 |  | 14,688
Revenue from use of the electricity distribution grid – TUSD (b) |  | 2,215 |  | 1,978 |  | 1,658
Revenue of the transmission system |  |  |  |  |  |
Transmission concession revenue (c) |  | 1,675 |  | 1,408 |  | 1,141
Transmission construction revenue (d) |  | 160 |  | 120 |  | 225
Transmission indemnity revenue (c) |  | 192 |  | - |  | -
Distribution construction revenue (d) |  | 1,446 |  | 1,412 |  | 930
Gas construction revenue (d) |  | 25 |  | 7 |  | 186
Transactions in electricity on the CCEE |  | 427 |  | 270 |  | 133
Other operational revenues (d) |  | 1,324 |  | 983 |  | 924
Taxes on revenue and regulatory charges (c) |  | (7,618) |  | (6,997) |  | (6,095)
Net operational revenue |  | 18,460 |  | 15,749 |  | 13,790

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(a) Supply of electric power

The breakdown of the supply of electric power by consumer class is as follows:

|  | GWh ( * ) |  | R$ |
|  | 2012 |  | 2011 |  | 2010 |  | 2012 |  | 2011 (Reclassified) |  | 2010 (Reclassified) |
Residential |  | 11,518 |  | 10,742 |  | 9,944 |  | 6,227 |  | 5,452 |  | 4,833 |
Industrial |  | 25,969 |  | 26,029 |  | 24,826 |  | 4,582 |  | 4,362 |  | 3,936 |
Commerce, services and others |  | 7,950 |  | 6,985 |  | 6,227 |  | 3,542 |  | 3,045 |  | 2,718 |
Rural |  | 2,874 |  | 2,647 |  | 2,467 |  | 785 |  | 708 |  | 632 |
Governmental entities |  | 1,344 |  | 1,191 |  | 1,083 |  | 609 |  | 531 |  | 467 |
Public lighting |  | 1,464 |  | 1,371 |  | 1,220 |  | 393 |  | 357 |  | 310 |
Public service |  | 1,549 |  | 1,439 |  | 1,360 |  | 464 |  | 425 |  | 394 |
Subtotal |  | 52,669 |  | 50,404 |  | 47,127 |  | 16,600 |  | 14,880 |  | 13,290 |
Own consumption |  | 62 |  | 57 |  | 53 |  | - |  | - |  | - |
Unbilled, net |  | - |  | - |  | - |  | 71 |  | 75 |  | (71 | )
|  | 52,731 |  | 50,461 |  | 47,180 |  | 16,671 |  | 14,955 |  | 13,219 |
Wholesale supply to other concession holders (**) |  | 13,868 |  | 14,458 |  | 14,205 |  | 1,903 |  | 1,577 |  | 1,445 |
Sales under the PROINFA program |  | 127 |  | 121 |  | 85 |  | 38 |  | 36 |  | 24 |
Total |  | 66,726 |  | 65,040 |  | 61,470 |  | 18,614 |  | 16,568 |  | 14,688 |

( * ) The MWh column includes of the total electricity sold by Light, proportional to the Company’s equity interest. Information unaudited

( ** ) Includes Contract for Trading of Electricity on the Regulated Market Sale (CCEAR) and bilateral contracts with other agents.

Annual tariff review – Cemig D

On April 8, 2012 Aneel approved the result of the Tariff Adjustment for Cemig D. The result approved by Aneel was for an upward adjustment of 5.24%, made up of two components: (i) The Structural component, of 2.90%, comprising the non-manageable costs (“Portion A”) and manageable costs (“Portion B”); and (ii) Financial components, of 2.34%. The adjustment is in effect until April 2013. With the withdrawal of the financial components considered in the 2011 tariff process, of 1.39%, the average effect on the Company’s captive consumers was an increase of 3.85%.

Periodic Tariff Review – Cemig D

In April 8, 2013 the Brazilian electricity sector regulator, Aneel (Agência Nacional de Energia Elétrica), published the result of the Third Tariff Review of Cemig D (Cemig Distribuição S.A.), which will result in positive repositioning of Cemig D’s tariffs. These tariffs will take effect from April 8, 2013 and the average effect for consumers will be an increase of 2.99%.

In this decision, Aneel is already applying the effects of Decree 7945/12, which governs the use of the funds from the Energy Development Account (Conta de Desenvolvimento Energético, or CDE) to attenuate distributors’ costs of acquisition of electricity in the Electricity Trading Chamber (Câmara de Comercialização de Energia Elétrica, or CCEE) as a result of the unfavorable hydrological conditions, which have led to the dispatching of thermal generation plants, and as a result to reduce the impact of the tariff adjustment, limiting it to 3%. The amount that exceeds this percentage will be passed through in a single payment, within 10

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business days from the date of publication of the Aneel Homologating Resolution. The amount of these funds coming from the CDE will be reimbursed by consumers in up to 5 years, updated by the IPCA inflation index.

According to the statement of calculation received by Cemig after the homologation of the result of the Tariff Review at the meeting of the Council of Aneel, the Net Regulatory Remuneration Base was R$ 5,511,768, and the Gross Regulatory Remuneration Base was R$ 15,355,843.

For more details about the Regulatory Remuneration Base (BRR) please see Explanatory Note 16 to the consolidated financial statements.

Annual tariff review – Light

On November 6, 2012, ANEEL approved the tariff adjustment of Light SESA for 2012. The result ratified by ANEEL represents a rate increase of 10.77%, consisting of two components: (i) Structural component of 7.17% for non-manageable (Portion A) and manageable (Portion B) costs and (ii) Financial component, which be effective until October 2012, of 3.60%. Considering the removal of the financial component present in Light’s rates in effect until this date, of -0.64%, the proposal represents an average rate increase for consumers of 11.41% from November 7, 2012.

(b) Revenue from use of the electricity distribution grid – TUSD

A representative portion of the Large Industrial Consumers in the concession area of Cemig Distribuição and Light that are allowed to choose their power suppliers such as Cemig Geração e Transmissão and other power generating companies, also referred to as “free” consumers. Accordingly, the charges for the use of the distribution network (“TUSD”) of these “free” consumers are charged separately and recorded under this caption.

(c) Revenue from use of the transmission system

For the transmission concessions, revenue includes the portion received from agents of the electricity sector relating to operation and maintenance of the transmission lines, and also updating of the value of the transmission financial asset constituted, primarily, during the period of construction of the transmission facilities. The rates used for updating of the asset correspond to the remuneration on the capital applied in the enterprise, and these vary in accordance with the type of enterprise and the investing company’s cost of capital.

In 2012 the Company reported the gain estimated to result from the indemnity of the transmission assets to which the criteria of PM 579 apply. There are more details in Note 4.

(d) Construction Revenue

Construction Revenue is fully offset by the construction costs and corresponds to the Company’s investments in the period in assets of the concession, where the operating income, in some cases, also includes the profit margin involved in the operation. More details are presented in note 25 of the consolidated Financial Statements.

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(e) Other operational revenues

|  | 2012 |  | 2011 (Reclassified) |  | 2010 (Reclassified) |
Supply of gas |  | 755 |  | 579 |  | 398 |
Charged service |  | 18 |  | 14 |  | 16 |
Telecommunications services |  | 162 |  | 158 |  | 131 |
Rendering services |  | 117 |  | 98 |  | 179 |
Low-income subsidy (*) |  | 176 |  | 56 |  | 133 |
Renting |  | 86 |  | 76 |  | 60 |
Others |  | 9 |  | 2 |  | 7 |
|  | 1,324 |  | 983 |  | 924 |

(*) Revenue recognized arising from the subsidy from Eletrobrás, for the discount given on tariffs charged to low-income consumers. The amounts were homologated by ANEEL and are reimbursed by Eletrobrás.

(f) Taxes on revenue and regulatory charges

|  | 2012 |  | 2011 |  | 2010 |
Income Taxes |  |  |  |  |  |  |
ICMS |  | 3,954 |  | 3,575 |  | 3,142 |
COFINS |  | 1,656 |  | 1,496 |  | 1,310 |
PIS and PASEP |  | 359 |  | 325 |  | 304 |
Others |  | 8 |  | 6 |  | 12 |
|  | 5,977 |  | 5,402 |  | 4,768 |
Charges to the consumer |  |  |  |  |  |  |
Global Reversion Reserve – RGR |  | 287 |  | 205 |  | 183 |
Energy Efficiency Program – PEE |  | 38 |  | 43 |  | 43 |
Energy Development Account – CDE |  | 616 |  | 516 |  | 423 |
Fuel Consumption Account – CCC |  | 565 |  | 718 |  | 532 |
Research and Development – R&D |  | 47 |  | 37 |  | 39 |
National Scientific and Technological Development Fund |  | 41 |  | 32 |  | 34 |
Energy System Expansion Research – EPE (Mining and Energy Ministry) |  | 21 |  | 16 |  | 17 |
Emergency Capacity Charge |  | - |  | - |  | 20 |
0.30% Surcharge (Law 12111/09) |  | 26 |  | 28 |  | 36 |
|  | 1,641 |  | 1,595 |  | 1,327 |
|  | 7,618 |  | 6,997 |  | 6,095 |

25. OPERATING COSTS AND EXPENSES

|  | 2012 |  | 2011 (Reclassified) |  | 2010 (Reclassified) |
Personnel (a) |  | 1,361 |  | 1,249 |  | 1,212 |
Employee’ and managers’ profit sharing |  | 244 |  | 221 |  | 325 |
Post-employment obligations |  | 134 |  | 124 |  | 107 |
Materials |  | 82 |  | 98 |  | 134 |
Outsourced services (b) |  | 1,127 |  | 1,031 |  | 923 |
Electricity purchased for resale (c) |  | 5,951 |  | 4,278 |  | 3,722 |
Depreciation and amortization |  | 1,001 |  | 983 |  | 927 |
Royalties for usage of water resources |  | 186 |  | 154 |  | 140 |
Provisions (reversals) for operating losses (d) |  | 782 |  | 257 |  | 138 |
Charges for the use of transmission facilities of the basic grid |  | 1,011 |  | 830 |  | 729 |
Gas purchased for resale |  | 495 |  | 329 |  | 225 |
Construction costs |  | 1,630 |  | 1,529 |  | 1,328 |
Other operating expenses, net (e) |  | 634 |  | 362 |  | 321 |
|  | 14,638 |  | 11,445 |  | 10,231 |

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a) Personnel Expenses

|  | 2012 |  | 2011 |  | 2010 |
Salary and payroll charges |  | 1,219 |  | 1,132 |  | 1,073 |
Supplementary pension contributions – defined-contribution plan |  | 72 |  | 67 |  | 66 |
Assistance benefits |  | 136 |  | 132 |  | 133 |
|  | 1,427 |  | 1,331 |  | 1,272 |
Temporary Voluntary Retirement Program |  | 33 |  | 20 |  | 40 |
( - ) Personnel costs transferred to construction in progress |  | (99) |  | (102) |  | (100) |
|  | (66) |  | (82) |  | (60) |
|  | 1,361 |  | 1,249 |  | 1,212 |

Employee special retirement programs

Incentive Retirement Program – PDP

From November 2011 to January 17, 2012 the Company offered the Incentive Retirement Program (Programa Desligamento Premiado – PDP), which had among its principal benefits: payment of one gross monthly salary and six months’ contribution to the health plan after retirement, deposit of the payment of 40% of the balance on the FGTS account (otherwise payable only in the event of non-voluntary termination of employment), and payment of the full advance notice period, from a minimum of 30 day’s up to a maximum of three months’ (90 days’) salary. In 2012, a total of 182 employees had subscribed to the program.

The PID Incentive Retirement Program

For the period January 17, 2013 to March 27, 2013, the Company created the PID, available only to employees who already satisfied the full condition for retirement under the National Social Security System (Instituto Nacional de Seguridade Social, or INSS), and also qualified for retirement through Forluz, and had been with the Company for a minimum of 20 years. This program offers four times the gross monthly remuneration, six months’ contribution to the health plan and the other indemnity payments specified by Law. The financial impact of the program will be reported in 2013, depending on how many employees accept it, and the period for termination will close in June 2013.

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b) Outsourced Services

|  | 2012 |  | 2011 |  | 2010 |
Collection agents / Meter readers / Bill delivery agents |  | 188 |  | 176 |  | 136 |
Communication |  | 106 |  | 90 |  | 79 |
Maintenance of electrical facilities and equipment |  | 249 |  | 205 |  | 198 |
Building maintenance and cleaning |  | 78 |  | 59 |  | 51 |
Contracted labor |  | 31 |  | 60 |  | 54 |
Freight and airfares |  | 14 |  | 12 |  | 12 |
Accommodation and meals |  | 20 |  | 19 |  | 24 |
Security |  | 24 |  | 23 |  | 19 |
Management consulting |  | 45 |  | 27 |  | 3 |
Maintenance of furniture and fixtures |  | 43 |  | 68 |  | 44 |
Vehicle maintenance |  | 11 |  | 22 |  | 29 |
Disconnections and reconnections |  | 44 |  | 53 |  | 62 |
Environment |  | 29 |  | 27 |  | 26 |
Electricity |  | 1 |  | 1 |  | 1 |
Tree pruning services |  | 26 |  | 25 |  | 17 |
Cleaning of power line pathways |  | 37 |  | 35 |  | 28 |
Others |  | 182 |  | 129 |  | 140 |
|  | 1,127 |  | 1,031 |  | 923 |

c) Electricity purchased for resale

|  | 2012 |  | 2011 |  | 2010 |
From Itaipu Binacional |  | 1,069 |  | 919 |  | 910 |
Spot market |  | 890 |  | 337 |  | 382 |
PROINFA |  | 265 |  | 204 |  | 192 |
Bilateral contracts |  | 612 |  | 538 |  | 315 |
Electricity acquired in Regulated Market auctions |  | 2,806 |  | 1,965 |  | 1,873 |
Electricity acquired on the Free Market |  | 717 |  | 637 |  | 348 |
PASEP and COFINS credits |  | (408) |  | (322) |  | (298) |
|  | 5,951 |  | 4,278 |  | 3,722 |

d) Operating provisions (reversals)

|  | 2012 |  | 2011 |  | 2010 |
Pension plan premiums |  | (3) |  | 3 |  | (22) |
Allowance for doubtful receivables |  | 315 |  | 163 |  | 105 |
Provision |  |  |  |  |  |  |
Labor Claims |  | 7 |  | 14 |  | (9) |
Civil Lawsuits |  | 38 |  | 35 |  | (16) |
Tax |  | 3 |  | 8 |  | (4) |
Environmental |  | 1 |  | 1 |  | - |
Regulatory |  | 420 |  | 18 |  | 92 |
Other |  | 1 |  | 15 |  | (8) |
|  | 470 |  | 91 |  | 55 |
|  | 782 |  | 257 |  | 138 |

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Cemig D provisioned the amount of R$ 159 as allowance for doubtful receivables in 2012, reflecting amounts receivable from industrial consumers due to non-payment of the ICMS applicable to the portions of invoices that comprise the TUSD charge.

e) Construction costs

|  | 2012 |  | 2011 |  | 2010 |
Employee’ and managers’ salaries |  | 107 |  | 101 |  | 28 |
Materials |  | 755 |  | 604 |  | 410 |
Outsourced services |  | 668 |  | 728 |  | 606 |
Other |  | 100 |  | 96 |  | 284 |
|  | 1,630 |  | 1,529 |  | 1,328 |

f) Other operating expenses, net

|  | 2012 |  | 2011 |  | 2010 |
Leases and rentals |  | 105 |  | 87 |  | 58 |
Advertising and publicity |  | 8 |  | 24 |  | 30 |
Own consumption of electric power |  | 14 |  | 19 |  | 10 |
Subsidies, grants and donations |  | 39 |  | 34 |  | 40 |
ANEEL inspection charge |  | 47 |  | 46 |  | 43 |
Onerous concessions |  | 26 |  | 21 |  | 23 |
Taxes and charges (IPTU, IPVA and others) |  | 38 |  | 26 |  | 21 |
Insurance |  | 11 |  | 8 |  | 11 |
CCEE annual fee |  | 6 |  | 6 |  | 5 |
License fee - TDRF ( * ) |  | - |  | 30 |  | 27 |
Net loss on deactivation and disposal of assets |  | 126 |  | 22 |  | 26 |
FORLUZ – Current Administration expense |  | 22 |  | 15 |  | 14 |
Other expenses |  | 192 |  | 24 |  | 14 |
|  | 634 |  | 362 |  | 322 |

(* )TFDR - License charge for use or occupation of land-adjoining highways.

In 2012 the Company posted losses for de-activation of assets arising from the carrying out of the physical inventory to comply with Aneel Resolution 367/2009.

Operating leases

The Company has operating lease agreements related mainly to vehicles and buildings used in its operatingl activities which are not material in relation to the Company’s total costs.

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26. NET FINANCIAL INCOME (EXPENSES)

|  | 2012 |  | 2011 Reclassified |  | 2010 Reclassified |
FINANCIAL INCOME |  |  |  |  |  |  |
Income from financial investments |  | 296 |  | 410 |  | 392 |
Charges on arrears of overdue electricity bills |  | 179 |  | 151 |  | 137 |
Interest and monetary gains on account receivables from the the Government of the State of Minas Gerais |  | 157 |  | 152 |  | 129 |
Foreign exchange gains |  | 44 |  | 20 |  | 51 |
PASEP and COFINS on financial revenues |  | (42) |  | (42) |  | (39) |
Gains on financial instruments |  | 28 |  | 16 |  | - |
Adjustment to present value |  | - |  | - |  | 17 |
Monetary updating on Finsocial (note 9) |  | 57 |  | 67 |  | - |
Monetary updating on escrow account (note 11) |  | - |  | 68 |  | - |
Monetary updating of Account receivable of State Government (Note 12) |  | 2,383 |  | - |  | - |
Other income |  | 108 |  | 153 |  | 154 |
|  | 3,210 |  | 995 |  | 841 |
FINANCIAL EXPENSES |  |  |  |  |  |  |
Interest on loans, financings and debentures |  | (1,243) |  | (1,311) |  | (1,076) |
Foreign exchange losses |  | (82) |  | (40) |  | (37) |
Monetary losses – loans, financing and debentures |  | (186) |  | (146) |  | (144) |
Monetary losses – onerous concessions |  | (34) |  | (21) |  | (42) |
Monetary updating – R&D and P.E.E. |  | (24) |  | (35) |  | (31) |
Monetary updating – Other |  | (48) |  | (92) |  | (21) |
Adjustment to present value |  | (1) |  | (1) |  | - |
Losses on financial instruments |  | - |  | - |  | (6) |
Monetary losses and charges on post-employment obligations |  | (132) |  | (163) |  | (142) |
Monetary losses on advance for capital increase (note 23) |  | - |  | (66) |  | - |
Other expenses |  | (208) |  | (90) |  | (95) |
|  | (1,958) |  | (1,965) |  | (1,594) |
NET FINANCIAL EXPENSES |  | 1,252 |  | (970) |  | (753) |

PASEP and COFINS expenses are due on the interest on shareholders’ equity.

27. RELATED PARTY TRANSACTIONS

The main balances and transactions with parties related to Cemig and its subsidiaries and jointly controlled subsidiaries are as follows:

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ENTITIES |  | ASSETS |  | LIABILITIES |  | REVENUES |  | EXPENSES |
| 2012 |  | 2011 |  | 2012 |  | 2011 |  | 2012 |  | 2011 |  | 2012 |  | 2011 |
Cemig Distribuição S.A. |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Cooperation agreement (1) |  | - |  | - |  | 23 |  | 22 |  | - |  | - |  | 9 |  | 12 |
Dividends and interest on Capital |  | 120 |  | 109 |  | - |  | - |  | - |  | - |  | - |  | - |
Operations with electricity (2) |  | 41 |  | 41 |  | 4 |  | 4 |  | 425 |  | 375 |  | (48) |  | (55) |
Non Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Cooperation agreement (1) |  | 29 |  | 11 |  | - |  | - |  | - |  | - |  | - |  | - |
Cemig Geração e Transmissão S.A. |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Cooperation agreement (1) |  | - |  | - |  | 18 |  | - |  | - |  | - |  | 1 |  | (7) |
Dividends and interest on Capital |  | 399 |  | - |  | - |  | - |  | - |  | - |  | - |  | - |
Operations with electricity (2) |  | 4 |  | 4 |  | 29 |  | 29 |  | 52 |  | 58 |  | (312) |  | (283) |
Non Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Cooperation agreement (1) |  | 19 |  | 25 |  | - |  | - |  | - |  | - |  | - |  | - |
Light S.A. |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Dividends and interest on Capital |  | 19 |  | 19 |  | - |  | - |  | - |  | - |  | - |  | - |
Operations with electricity (2) |  | - |  | - |  | 1 |  | 1 |  | 32 |  | 31 |  | (8) |  | (6) |
Cemig Capim Branco |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Dividends and interest on Capital |  | 9 |  | 3 |  | - |  | - |  | - |  | - |  | - |  | - |
Operations with electricity (2) |  | - |  | - |  | 7 |  | 7 |  | 5 |  | 4 |  | (91) |  | (73) |
Services (3) |  | 2 |  | 2 |  | - |  | - |  | 4 |  | 5 |  | - |  | - |
Cemig Telecomunicações |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Dividends and interest on Capital |  | - |  | 7 |  | - |  | - |  | - |  | - |  | - |  | - |
Operations with electricity (2) |  | - |  | - |  | - |  | - |  | 3 |  | 3 |  | - |  | - |
Sharing of infrastructure (4) |  | 2 |  | 1 |  | - |  | - |  | 5 |  | 6 |  | - |  | - |
Prestação de serviço (5) |  | - |  | - |  | 4 |  | 5 |  | - |  | - |  | (20) |  | (27) |
Non-current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Maintenance (6) |  | - |  | 1 |  | - |  | - |  |  |  |  |  | - |  | - |
Personnel seconded (7) |  | 1 |  | 1 |  | - |  | - |  | - |  | - |  | 2 |  | 2 |
Transmissora Aliança de Energia Elétrica |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Dividends and interest on Capital |  | 38 |  | 115 |  | - |  | - |  | - |  | - |  | - |  | - |
Operations with electricity (2) |  | - |  | - |  | 4 |  | 4 |  | - |  | - |  | (34) |  | (34) |
Cemig Serviços |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Services (8) |  | - |  | - |  | 3 |  | 1 |  | - |  | - |  | (12) |  | (1) |
Personnel seconded (7) |  | 1 |  | - |  | - |  | - |  | - |  | - |  | - |  | - |
Non-current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Personnel seconded (7) |  | 4 |  | 2 |  | - |  | - |  | - |  | - |  | - |  | - |
Empresa Paraense de Transmissão de Energia |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Operations with electricity (2) |  | - |  | - |  | - |  | - |  | - |  | - |  | (3) |  | (3) |
Baguari Energia |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Dividends and interest on Capital |  | 26 |  | 6 |  | - |  | - |  | - |  | - |  | - |  | - |
Operations with electricity (2) |  | - |  | - |  | 1 |  | - |  | - |  | - |  | (6) |  | (5) |
Companhia de Gás de Minas Gerais S.A |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Dividends and interest on Capital |  | 21 |  | 21 |  | - |  | - |  | - |  | - |  | - |  | - |
Empresa Regional de Transmissão de Energia S.A |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Dividends and interest on Capital |  | 8 |  | 9 |  | - |  | - |  | - |  | - |  | - |  | - |
Operations with electricity (2) |  | - |  | - |  | - |  | - |  | - |  | - |  | (1) |  | (1) |
Empresa Amazonense de Transmissão de Energia S.A |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Dividends and interest on Capital |  | - |  | 5 |  | - |  | - |  | - |  | - |  | - |  | - |
Operations with electricity (2) |  | - |  | - |  | 2 |  | 1 |  | - |  | - |  | (14) |  | (13) |

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|  | ASSETS |  | LIABILITIES |  | REVENUES |  | EXPENSES |
|  | 2012 |  | 2011 |  | 2012 |  | 2011 |  | 2012 |  | 2011 |  | 2012 |  | 2011 |
Minas Gerais state government |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Consumers and Traders (9) |  | 8 |  | 7 |  | - |  | - |  | 96 |  | 89 |  | - |  | - |
Consumers and Traders (10) |  | - |  | 25 |  | - |  | - |  | - |  | - |  | - |  | - |
Accounts receivable from Minas Gerais state government – CRC Account (11) |  | 2,422 |  | - |  | - |  | - |  | 70 |  | 103 |  | - |  | - |
Non-current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Accounts receivable from Minas Gerais state government – CRC Account C (11) |  | - |  | 1,830 |  | - |  | - |  | - |  | - |  | - |  | - |
Dividends and interest on Capital |  | - |  | - |  | 468 |  | 266 |  | - |  | - |  | - |  | - |
Debentures (12) |  | - |  | - |  | 53 |  | 47 |  | - |  | - |  | (6) |  | (10) |
Financings – Minas Gerais Development Bank (13) |  | - |  | - |  | 9 |  | 15 |  | - |  | - |  | - |  | - |
Forluz |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Employee post-retirement benefits (14) |  | - |  | - |  | 51 |  | 74 |  | - |  | - |  | (93) |  | (106) |
Personnel expenses (15) |  | - |  | - |  | - |  | - |  | - |  | - |  | (72) |  | (67) |
Administration costs (16) |  | - |  | - |  | - |  | - |  | - |  | - |  | (22) |  | (15) |
Non-current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Employee post-retirement benefits (14) |  | - |  | - |  | 764 |  | 772 |  | - |  | - |  | - |  | - |
Cemig Saúde |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Health Plan and Dental Plan (17) |  | - |  | - |  | 612 |  | 598 |  | - |  | - |  | (74) |  | (70) |
Andrade Gutierrez SA |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Construction - Santo Antonio Hydroelectric Plant (18) |  | 1 |  | - |  | 3 |  | 7 |  | - |  | - |  | - |  | - |
Light for Everyone (Luz para Todos) Program (20) |  | - |  | - |  | - |  | - |  | - |  | - |  | (2) |  | (9) |
Non-current |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Construction - Santo Antonio Hydro Plant (18) |  | 7 |  | 4 |  | - |  | - |  | - |  | - |  | - |  | - |

Main material comments on the above transactions:

(1) Technical Cooperation Working Agreement between Cemig, Cemig D and Cemig GT instituted by Aneel Dispatch 3924/2008. This includes, principally, reimbursement of expenses relating to sharing of infrastructure, personnel, transport, telecommunications and IT.

(2) The company has electricity purchase contracts with Cemig GT, Light, Baguari Energia, Santo Antônio Energia and Cemig Capim Branco, under public electricity auctions held over the period 2004 to 2011; for the bilateral contracts between Cemig D and Cemig Capim Banco the dates of the auctions are prior to 2004. The contracts have period of eight years from start of supply and annual updating of price by the IG PM index. These transactions were carried out on terms equivalent to arms-length transactions, since the electricity was purchased through an auction organized by the federal government, which subsequently specified the contracts that were to be signed between distributors and generators. The Company also has contracts for sale of electricity with Cemig D and Light, arising from the 2004 and 2011 public auctions of the existing generation capacity, for 8 years’ supply, with annual price adjustment by the IGP-M inflation index. For Cemig Telecomunicações, Transmissora Aliança de Energia Elétrica, Empresa Amazonense de Transmissão de Energia, Empresa Regional de Transmissão de Energia and Empresa Paraense de Transmissão de Energia the transactions in electricity refer to Charges for Use of the Network.

(3) This refers to the service contract for operation and maintenance of the Amador Aguiar I and II hydroelectric plants and other associated equipment signed between Cemig Geração e Transmissão and Cemig Capim Branco in 2011, with duration of two years, adjusted by the IGP-M index.

(4) Sharing of excess infrastructure of distribution, transmission and subtransmission comprising distribution network posts, building installments and other infrastructures, between Cemig and Cemig Telecom through a contract signed in 2000 with duration of 15 years. The amount received varies in accordance with revenue obtained for the use of the infrastructure by Cemig Telecom. There is no index for adjustment.

(5) Contract for provision of telecoms services through supply of network capacity between Cemig Telecom and Cemig D in 2009 and 2010 with duration of 5 years, updated by the IGP-M index;

(6) Preventive and corrective maintenance services on the transmission and subtransmission lines that are used jointly, including OPGW cables, transition cables and their accessories.

(7) Reimbursement of expenses relating to personnel seconded by Cemig to companies of the Group.

(8) Refers to the service contract for reading, printing and simultaneous delivery of electricity consumption invoices in kWh, through a technology developed for this, visual inspection of consumer units, collection and confirmation of client registry data, updating of postal addresses, allocation of routes, planning and change of urban and rural routes – signed by Cemig Serviços and Cemig Distribuição in 2011, with duration of two years. Amendments may be made for successive equal periods up to the period of 48 months. Extendable for up to four years, adjusted by the IGP-M index.

(9) Sale of electricity to Minas Gerais State government – terms equivalent to arm’s-length transaction, since the price of electricity is set by Aneel through a Resolution specifying the company’s annual Tariff Adjustment.

(10) This refers to the renegotiation of the debit arising from the sale of electricity to COPASA, which was settled in full in September 2012.

(11) Injection of the credits of the CRC into a Receivables Fund in senior and subordinated units. See Explanatory Note 10 to the Interim consolidated financial statements.

(12) Private issue of R$ 120,000 in non-convertible debentures, updated by the IGP–M inflation index, for completion of the Irapé hydroelectric plant, with redemption 25 years from issue date. The amount at December 31, 2009 was adjusted to present value.

(13) Financings of the subsidiaries Transudeste, Transleste and Transirapé, maturity in 2019 (TJLP long-term interest rate + 4.5% p.a. and UMBNDES + 4.54% p.a.) and of Transleste, in 2017 (US$ + 5%) and 2025 (9.5% p.a.);

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(14) The contracts of Forluz are updated by the Amplified Consumer Price Index (IPCA) calculated by the Brazilian Geography and Statistics Institute (IBGE) (See Explanatory Note 21) and will be amortized up to 2024.

(15)This refers to Cemig’s contributions to the Pension Fund related to the employees participating in the Mixed Plan (see Explanatory Note 16), calculated on the monthly remunerations in accordance with the regulations of the Fund.

(16) Funds for annual current administrative costs of the Pension Fund in accordance with the specific legislation of the sector. The amounts are estimated as a percentage of the Company’s total payroll.

(17) Contribution by the sponsor to the health plan and dental plan of the employees.

(18) Contracts with Construtora Andrade Gutierrez S.A for construction of the Santo Antônio Hydroelectric Plant, and, for transmission facilities specific to that plant, with the Santo Antônio Construction Consortium (Consórcio Construtor Santo Antônio, or CCSA), of which Construtora Andrade Gutierrez S.A. is a member, responsible for services of preparation of plans and for the civil works (Consórcio Santo Antônio Civil).

(20) Contract for works to implement one lot of the Light for Everyone (Luz Para Todos) rural electrification program in Cemig’s concession area, between Cemig D and the Iluminas Consortium, of which Andrade Gutierrez is a member.

For more information on the main transactions, see Notes 12, 19, 21 and 25.

Remuneration of Key Management Personnel

The total remuneration paid to the members of the Board of Directors and the Chief Officers during 2012 and 2011 years is as follows:

|  | 2012 |  | 2011 |
Remuneration |  | 8 |  | 9 |
Profit sharing |  | 2 |  | 2 |
Post-retirement benefits |  | 1 |  | 1 |
Assistance benefits |  | 1 |  | - |
Total |  | 12 |  | 12 |

For more information on the main transactions, see Notes 8, 12, 18, 19, 21, 24 and 25.

28. FINANCIAL INSTRUMENTS

The financial instruments of the Company, its subsidiaries and jointly-controlled subsidiaries are restricted to Cash and cash equivalents, marketable securities, accounts receivable from consumers and traders, accounts receivable from the Government of the State of Minas Gerais, financial assets of the concession, loans and financing, obligations with debentures, post-retirement benefits, and derivatives, where the gains and losses obtained in the transactions are fully recorded on an accrual basis.

The financial instruments of the Company, its subsidiaries and jointly-controlled subsidiaries were recognized at fair value and are classified as follows:

■ Loans and receivables: In this category are: Cash equivalents; Receivables from consumers; Traders and concession holders – Transport of electricity; Linked funds; and Financial assets not covered by Provisional Measure 579. They are recognized at their nominal realization value which is similar to fair value.

■ Financial instruments at fair value through profit or loss – In this category are Securities, and Derivative instruments (mentioned in item “b”). They are valued at fair value and the gains or losses are recognized directly in the Profit and loss account.

■ Financial instruments held to maturity – This category includes Securities for which there is a positive intention to hold them until maturity. They are measured at the amortized cost using the effective interest method.

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■ Financial Instructions available for sale – As from December 31, 2012, Financial assets of the concession covered by Provisional Measure 579 are in this category. They are measured at the New Replacement Value (VNR), equivalent to fair value on the date of the financial statements.

■ Non-derivative financial liabilities – In this category are: Loans and financings, Obligations under debentures, Debt agreed with the pension fund (Forluz); and Suppliers. These are measured at the amortized cost using the effective interest method. The Company has calculated the fair value of its Loans, financings and debentures using the CDI rate + 0.9%, based on its most recent funding. For the following instruments Company considered their fair value to be equal to book value: loans, financings and debentures with rates in the following ranges between: IPCA + 4.70% and IPCA + 5.10%; CDI + 0.65% to CDI + 0.73%; IGPM + 4.70% to IGPM + 5.10%; and fixed-rate at 8.5% to 10.07%. For the financings from BNDES and Eletrobras the fair value is identical to the book value, since there are no similar instruments with comparable maturity dates and interest rates.

■ Derivatives: These are measured at fair value and the effects recognized directly in the income statement, except for the cash flow hedge in the jointly-controlled subsidiary Madeira Energia S.A., for which the effective portion of the variations in fair value of the derivatives was recognized directly in Equity. These financial instruments of Madeira Energia were settled in full in 2012.

Financial instruments catagories |  | 2012 |  | 2011 |  | 01/01/2011 |
| Book value |  | Fair value |  | Book value |  | Fair value |  | Book value |  | Fair value |
Assets: |  |  |  |  |  |  |  |  |  |  |  |  |
Loans and receivables |  |  |  |  |  |  |  |  |  |  |  |  |
Cash and cash equivalentes – Financial Investments |  | 2,329 |  | 2,329 |  | 2,705 |  | 2,705 |  | 2,885 |  | 2,885 |
Consumers and traders |  | 2,662 |  | 2,662 |  | 2,709 |  | 2,709 |  | 2,359 |  | 2,359 |
Concession holders – transport of energy |  | 515 |  | 515 |  | 439 |  | 439 |  | 401 |  | 401 |
Account receivable from the State of Minas Gerais Government |  | 2,422 |  | 2,422 |  | 1,830 |  | 1,830 |  | 1,837 |  | 1,837 |
Financial assets of the concession |  | 6,622 |  | 6,622 |  | 10,206 |  | 10,206 |  | 8,297 |  | 8,297 |
|  | 14,55 0 |  | 14,55 0 |  | 17,88 9 |  | 17,88 9 |  | 15,77 9 |  | 15,77 9 |
Available for sale |  |  |  |  |  |  |  |  |  |  |  |  |
Financial assets of the concession |  | 5,585 |  | 5,585 |  | - |  | - |  | - |  | - |
Held to maturity |  |  |  |  |  |  |  |  |  |  |  |  |
Securities |  | 647 |  | 647 |  | - |  | - |  | - |  | - |
Fair value through profit or loss: |  |  |  |  |  |  |  |  |  |  |  |  |
Held for trading |  |  |  |  |  |  |  |  |  |  |  |  |
Securities |  | 1,073 |  | 1,073 |  | 359 |  | 359 |  | 322 |  | 322 |
Derivative instruments - Contract swap |  | 32 |  | 32 |  | - |  | - |  | - |  | - |
Liabilities: |  |  |  |  |  |  |  |  |  |  |  |  |
Stated at amortized cost |  |  |  |  |  |  |  |  |  |  |  |  |
Suppliers |  | 1,735 |  | 1,735 |  | 1,190 |  | 1,190 |  | 1,121 |  | 1,121 |
Debt agreed with pension fund (Forluz) |  | 815 |  | 815 |  | 847 |  | 847 |  | 868 |  | 868 |
Concessions payable |  | 210 |  | 210 |  | 138 |  | 138 |  | 118 |  | 118 |
Loans, financing and deentures |  | 16,170 |  | 16,799 |  | 15,779 |  | 15,767 |  | 13,226 |  | 13,226 |
|  | 18,930 |  | 19,559 |  | 17,954 |  | 17,942 |  | 15,333 |  | 15,333 |
Fair value through profit or loss : |  |  |  |  |  |  |  |  |  |  |  |  |
Derivative instruments - Contract swap |  | 1 |  | 1 |  | 24 |  | 39 |  | 67 |  | 62 |

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a) Risk management

Corporate risk management is a management tool that is part of the Company’s corporate governance practices and is aligned with the planning process which defines the Company’s strategic business objectives.

The Company has a Financial Risks Management Committee, the purpose of which is to implement guidelines and monitor the financial risk of transactions that could negatively affect the Company’s liquidity and profitability, recommending hedge strategies to control the Company’s exposures to foreign exchange rate, interest rate and inflation risks. These strategies are aligned with the Company’s overall strategy.

One of the most important objectives of the Financial Risks Management Committee is and to provide reasonable predictability to the Company’s cash flow for a maximum future period of 12 months, considering the economic scenario disclosed by an external consultant.

The principal risks to which the Company is exposed are as follows:

Exchange Rate Risk

Cemig and its subsidiaries and jointly-controlled subsidiaries are exposed to market risk from adverse changes in foreign currency rates, especially the U.S. Dollar against the Brazilian Real, which could potentially have a significant impact on their indebtedness, profit and cash flow. In order to reduce its exposure to adverse changes in foreign currency rates, as at December 31, 2012 the Company held certain hedge contracts, which are described in more detail in item b below.

The tables below provide summary information regarding the exposure to the exchange rate risk:

EXCHANGE RATES EXPOSURE |  | 2012 |  | 2011 |
|  | Foreign Currancy |  | R$ |  | Foreign Currancy |  | R$ |
U.S. Dollar |  |  |  |  |  |  |  |  |
Loans and Financing (note 19) |  | 240 |  | 489 |  | 170 |  | 319 |
Suppliers – Eletrobras – Electricity from Itaipu |  | 105 |  | 219 |  | 106 |  | 198 |
(+/–) Contracted hedge/swap |  | (8) |  | (19) |  | (27) |  | (46) |
|  | 337 |  | 689 |  | 249 |  | 471 |
Euro |  |  |  |  |  |  |  |  |
Loans and Financing – Euro (nota 19) |  | 14 |  | 39 |  | 15 |  | 37 |
(+/–) Contracted hedge/swap |  | (11) |  | 4 |  | - |  | - |
|  | 3 |  | 4 3 |  | 15 |  | 37 |
UMBndes ( * ) |  | - |  | - |  | 66 |  | 3 |
Net liabilities exposed |  |  |  | 732 |  |  |  | 511 |

( * ) UMBndes = BNDES Monetary Unit.

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Exchange Rate Sensitivity Analysis

Based on information received from its financial consultants, the Company estimates that in a probable scenario the depreciation of the exchange rates of foreign currencies against the Brazilian Real as at December 31, 2013 will be 0.29% for the U.S. Dollar (to US$1=R$2.05) and 2.67% for the Euro (to €1 = R$2.622). In the table below, the Company has performed a sensitivity analysis to demonstrate the adverse financial effects which would occur in scenarios assuming an additional 25% appreciation and a 50% appreciation of the foreign currencies as compared to the increase assumed in the probable scenario. The Company has designated these alternative appreciation scenarios as Possible and Remote, respectively.

Foreign Exchange Rate Exposure |  | Base scenario December 31,2012 |  | Probable scenario |  | Possible scenario: Foreign currency appreciation of 25% |  | Remote scenario: Foreign currency appreciation of 50% |
U.S. Dollar |  |  |  |  |  |  |  |  |
Loans and Financing (note 19) |  | 489 |  | 491 |  | 614 |  | 737 |
Suppliers – Eletrobras – Electricity from Itaipu |  | 219 |  | 220 |  | 275 |  | 330 |
(+/–) Contracted hedge/swap |  | (19) |  | (19) |  | (24) |  | (29) |
|  | 689 |  | 692 |  | 865 |  | 1,038 |
Euro |  |  |  |  |  |  |  |  |
Loans and Financing – Euro (nota 19) |  | 39 |  | 37 |  | 46 |  | 56 |
(+/–) Contracted hedge/swap |  | 4 |  | 5 |  | 5 |  | 5 |
|  | 43 |  | 42 |  | 51 |  | 61 |
Net liabilities exposed to exchange rate risk |  | 732 |  | 734 |  | 916 |  | 1,099 |
Net effect |  |  |  | 2 |  | 184 |  | 367 |

Interest Rate Risk

The Company and its subsidiaries and joiontly-controlled subsidiaries is exposed to the risk of increase in international interest rates, affecting loans and financings in foreign currency with floating interest rates, especially the Libor, in the amount of R$217 (R$207 on December 31, 2011).

The table below presents the Company’s net assets and liabilities exposed to a risk of an increase in domestic interest rates as of December 31, 2012 and December 31, 2011:

EXPOSURE TO CHANGES IN DOMESTIC INTEREST RATES |  | 2012 |  | 2011 |
Ativos |  |  |  |  |
Cash equivalents – Short-term investments (Nota 6) |  | 2,329 |  | 2,705 |
Securities (Note 7) |  | 1,720 |  | 359 |
Linked funds |  | 132 |  | 3 |
|  | 4,181 |  | 3,067 |
Passivos |  |  |  |  |
Loans, financings and debentures - CDI rate (Nota 19) |  | (7,569) |  | (9,274) |
Loans, financings and debentures – TJLP rate (Nota 19) |  | (2,087) |  | (1,991) |
Contracted interest rate hedges and swaps |  | (750) |  | (750) |
|  | (10,406) |  | (12,015) |
Net liabilities exposed |  | (6,225) |  | (8,948) |

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Sensitivity analysis

In estimating risk related to the most important interest rates, the Company and its subsidiaries estimate that in a “probable” scenario, on December 31, 2013 the Selic rate, and the TJPL inflation indices will be, respectively, 7.25% and 5.00%. The Company has performed a sensitivity analysis to show the adverse financial effects which would occur in scenarios assuming an additional 25% and 50% increase in the Selic rate compared to the increase assumed in the “probable” scenario – designating these alternative Selic rate increase scenarios as “Possible” and “Remote,” respectively. Variation in the CDI rate accompanies the variation in the Selic rate.

Estimation of the scenarios for the path of interest rates will consider the projection of the Company’s basic, optimistic and pessimistic scenarios, based on opinions from its financial consultants, as described in the Hedging Policy.

Risk – Increase in Brazilian domestic interest rates |  | Base scenario December 31, 2012 |  | “Probable” scenario: SELIC 7.25% TJLP 5.00% |  | “Possible” scenario: SELIC 9.06% TJLP 6.25% |  | “Remote” scenario: SELIC 10.88% TJLP 7.50% |
Assets |  |  |  |  |  |  |  |  |
Cash equivalents – Short-term investments (Note 6) |  | 2,329 |  | 2,498 |  | 2,540 |  | 2,582 |
Securities (Note 7) |  | 1,720 |  | 1,844 |  | 1,875 |  | 1,907 |
Linked funds |  | 132 |  | 142 |  | 144 |  | 147 |
|  | 4,181 |  | 4,484 |  | 4,559 |  | 4,636 |
Liabilities |  |  |  |  |  |  |  |  |
Loans, financings and debentures – CDI rate (Note 19) |  | (7,569) |  | (8,119) |  | (8,256) |  | (8,393) |
Loans, financings and debentures – TJLP index (Note 19) |  | (2,087) |  | (2,192) |  | (2,218) |  | (2,244) |
Contracted foreign exchange rate hedges and swaps |  | (750) |  | (802) |  | (815) |  | (832) |
|  | (10,406) |  | (11,113) |  | (11,289) |  | (11,469) |
Net liabilities exposed |  | (6,225) |  | (6,629) |  | (6,730) |  | (6,833) |
Net effect of variation |  |  |  | (404) |  | (505) |  | (608) |

Risk of increase in inflation

The Company is exposed to the risk of increase in inflation, on December 31, 2012. This exposure is as a result of the net liabilities indexed to the variation of the IPCA index and the IGP-M index, as shown below:

Risk – Increase in Brazilian inflation rates |  | 2012 |  | 2011 |
Assets |  |  |  |  |
Financial assets of the concession – IGP-M index (nota 13) |  | 5,585 |  | - |
Liabilities |  |  |  |  |
Loans, financings and debentures – IPCA index (Note 19) |  | (3,896) |  | (2,250) |
Loans, financings and debentures – IGP-M index (Note 19) |  | (467) |  | (443) |
|  | (4,363) |  | (2,693) |
Net effect of variation |  | 1,222 |  | (2,693) |

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Interest rate sensitivity analysis

In estimating risk related to the most important inflation rates, the Company and its subsidiaries estimate that in a “probable” scenario, on December 31, 2013 the IPCA and the IGP-M inflation indices will be, respectively, 5.42% and 5.21%. The Company has performed a sensitivity analysis to show the adverse financial effects which would occur in scenarios assuming an additional 25% and 50% increase in the Selic rate compared to the increase assumed in the “probable” scenario – designating these alternative Selic rate increase scenarios as “Possible” and “Remote,” respectively.

Risk – Increase in Brazilian inflation rates |  | Base scenario December 31,2012 |  | December 31,2013 |
|  | Book value |  | “Probable” scenario: IPCA 5,42% IGP-M 5,21% |  | “Possible” scenario: IPCA 6,78% IGP-M 6,51% |  | “Remote” scenario: IPCA 8,13% IGP-M 7,82% |
Assets |  |  |  |  |  |  |  |  |
Financial assets of the concession – IGP-M index (note 13) |  | 5,585 |  | 5,876 |  | 5,949 |  | 6,022 |
Liabilities |  |  |  |  |  |  |  |  |
Loans, financings and debentures – IPCA index (Note 19) |  | (3,896) |  | (4,108) |  | (4,161) |  | (4,213) |
Loans, financings and debentures – IGP-M index (Note 19) |  | (467) |  | (491) |  | (497) |  | (503) |
|  | (4,363) |  | (4,599) |  | (4,658) |  | (4,716) |
|  | 1,222 |  | 1,277 |  | 1,291 |  | 1,306 |
Net effect of variation |  |  |  | 55 |  | 69 |  | 84 |

Liquidity Risk

Cemig’s cash generation is sufficient to cover its short-term requirements and for its program for acquisitions and investments.

Management of liquidity risk is as important as the quality of management of the business’s operational cash flow, and the Company uses a group of methodologies, procedures and instruments that are coherent with the complexity of the business, which it applies in permanent control of the financial processes, to guarantee appropriate risk management.

CEMIG manages its liquidity risk by permanently monitoring its cash flow, in a conservative manner, from a budget-based perspective and it forecasts the monthly balances for each of its companies over a period of 12 months, and for the daily liquidity, which forecasts the daily balances for 180 days.

Short-term investments must also comply with rigid principles established in the Investment Policy, investing up to 20% of its funds in exclusive private credit investment funds, with no market risks, with the surplus margin invested directly in bank certificates of deposit (CDB) or repurchase operations which earn interest at the CDI rate.

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When managing its investments, the Company seeks to obtain profitability on its transactions through a rigid analysis of the financial institutions’ credit, in accordance with operating limits with banks based on assessments of the financial institutions’ ratings, risk exposures and equity position. It also seeks greater returns on investments by strategically investing in securities with longer investment maturities, while bearing in mind the Company’s minimum liquidity control requirements.

This table shows the flow of payments of the Company’s obligations on floating-rate and fixed-rate loans, financings and debentures:

|  | 1 month or less |  | 1 to 3 months |  | 3 months to 1 year |  | 1 to 5 years |  | Over 5 years |  | Total |
- Floating interest rates |  |  |  |  |  |  |  |  |  |  |  |  |
Loans, financings and debentures |  | 616 |  | 351 |  | 3,514 |  | 9,199 |  | 5,508 |  | 19,188 |
Concessions payable |  | 2 |  | 5 |  | 13 |  | 67 |  | 163 |  | 250 |
Debt agreed with pension fund (Forluz) |  | 8 |  | 16 |  | 76 |  | 459 |  | 949 |  | 1,508 |
|  | 626 |  | 372 |  | 3,603 |  | 9,725 |  | 6,620 |  | 20,946 |
- Fixed interest rates |  |  |  |  |  |  |  |  |  |  |  |  |
Loans, financings and debentures |  | 3 |  | 9 |  | 876 |  | 129 |  | 233 |  | 1,250 |
Suppliers |  | 1,735 |  | - |  | - |  | - |  | - |  | 1,735 |
|  | 1,738 |  | 9 |  | 876 |  | 129 |  | 233 |  | 2,985 |
|  | 2,364 |  | 381 |  | 4,479 |  | 9,854 |  | 6,853 |  | 23,931 |

Credit Risk

The risk resulting from losses on doubtful receivables for CEMIG and its subsidiaries is considered to be low. The Company carries out monitoring for the purpose of reducing default, on an individual basis, with its consumers. Negotiations are also entered into for receipt of any receivables in arrears.

The Allowance for Doubtful Accounts recorded in 2012, considered adequate in relation to overdue receivables of the Company and its subsidiaries and jointly controlled companies, was R$315.

In relation to the risk of losses arising from insolvency of the financial institutions at which the Company, its subsidiaries or jointly-controlled subsidiaries have deposits, a Cash Investment Policy was approved and has been in effect since 2004, in which each institution is analyzed for risk purposes according to criteria of current liquidity, degree of leverage, degree of default, profitability, and costs. Additionally, the Company takes into consideration the ratings given to the financial institutions by three financial risk rating agencies. The Company assigns each financial institution a maximum fund allocation limit, which is reviewed for appropriateness both periodically and also in the event of any change in the macroeconomic scenarios of the Brazilian economy.

Cemig manages the counterparty risk of financial institutions based on an internal policy approved by its Financial Risks Management Committee.

This Policy assesses and scales the credit risks of the institutions, the liquidity risk, the market risk of the investment portfolio and the Treasury operational risk.

All investments are made in financial securities that have the characteristics of fixed income, and are always indexed to the CDI rate.

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As a management instrument, Cemig divides the investment of its funds into: direct purchases of securities (own portfolio); and three investment funds, which hold approximately 20% of the total portfolio. These investment funds invest the funds exclusively in fixed income products, and companies of the Group are the only unit holders. They obey the same policy adopted in the investments of the Company’s own portfolio.

The minimum requirements of the Company and its principal subsidiaries for concession of credit to financial institutions are centered on three items:

1. Rating by two risk rating agencies.

2. Equity greater than R$400.

3. Basle ratio: 12 or above.

Exceeding these thresholds, banks are classified in three groups, by the value of their equity. From this classification as a starting point, limits of concentration by group and by institution are established:

Group |  | Shareholder´s equity |  | Concentration |  | Bank limit (% of shareholder´s equity)**
A1 |  | Over R$3.5 bilhion |  | Minimum of 80% |  | 7.0%
A2 |  | Between R$1.0 bilhion and R$3.5 bilhion |  | Maximum of 20% |  | Between 2.8% and 7.0%
B |  | Between R$400 milhion and R$1.0 bilhion |  | Maximum of 20% |  | Between 1.6% and 4.2%

** The percentage granted to each bank Will dependo n na individual examination of indexes, such as liquidity and quality of the credit portfólio, amongst others.

In addition to these points, Cemig also establishes two concentration limits:

1. No bank can have more than 30% of the Group’s portfolio;
2. No bank can have more than 50% of a company’s portfolio.

Risk of Early Maturity of Debt

The Company, its subsidiaries and jointly-controlled subsidiaries have contracts for loans and financings that include covenants, normally applicable to these types of transactions, related to complying with economic and/or financial indices, cash generation and other indexes. Non-compliance with these covenants could result in early maturity of debts.

As of December 31, 2012, the Company was not in compliance with some covenants. The Company is on process of obtaining consent from its creditors, affirming that they would not exercise their rights to demand immediate or early payment of amounts owed.

The company expects to obtain the consents, but since this will take place after December 31, 2012, the contracts of which the covenants were not complied with are recognized in Current liabilities. The amount transferred to Current liabilities as a result of the covenant clauses not complied with was R$ 1,206.

The Company has not suffered any significant adverse impacts resulting from events related to the risks described above.

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b) Financial Instruments – Derivatives

Cemig, its subsidiaries and jointly-controlled subsidiaries use derivative financial instruments to hedge its operations against exchange rate risk. Derivative financial instruments are not used for speculative purposes.

The amounts of the principal of operations with derivatives are not presented in the balance sheet, since they refer to transactions that do not require cash principal payments to be made. Only the gains or losses related to these instruments are actually recorded. As at December 31, 2012 the net result on these operations was a gain of R$28 (gain of R$16 at December 31, 2011) recorded under financial results.

The Company has a Financial Risk Management Committee, which was created to monitor the financial risks with respect to volatility and trends of the inflation indices, exchange rates and interest rates that affect its financial transactions and which could adversely affect liquidity and profitability. The committee implements action plans and sets guidelines to control the financial risk environment.

The Company has derivative instruments contracted by its indirect subsidiary Unisa, which is controlled jointly by Taesa. The purpose of these derivatives is to protect its operations against risks of variation in exchange rates; they are not used for speculative purposes.

Through the operations contracted by Unisa, the Company is exposed to the variation in the exchange rate under two types of financings from the InterAmerican Development Bank linked either in part to a basket of currencies or to the US dollar. To mitigate the effects of the variation of the exchange rate, Unisa used derivative hedge instruments and contracted purchase options during the business year.

Through the indirect jointly-controlled subsidiary Madeira, the Company had a cash flow hedge to protect the exposure to variability in cash flows attributable to a risk associated with an asset or liability or a highly probable future transaction which was fully redeemed.

The derivatives designated as “cash flow hedges”, and which qualify for hedge accounting, are required to be duly documented for this purpose. The Company considers instruments that offset between 80% and 125% of the change in price of the item for which the hedge protection was contracted, to be highly effective.

The Company has derivative instruments contracted by its subsidiary Light. The purpose of these derivatives is to protect its operations against risks of variation in exchange rates; they are not used for speculative purposes. Some of the loans and financings of the indirect subsidiary Light Sesa are denominated in foreign currency, Light Sesa uses derivatives (swap transactions) to protect the servicing associated with those debts (principal plus interest and fees) becoming due in up to 24 months, as well as the rate swaps previously referred to.

Methodology of calculation of the fair value of positions

The fair value of financial instruments has been calculated taking into consideration the market values of each security, or market information available to perform this calculation, as well as the future interest rates and foreign exchange rates of similar securities. The market value of the security corresponds to its value at maturity, discounted to present value using the factor obtained from the market yield curve in Reais.

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The table below shows the derivative instruments contracted by the subsidiaries Cemig Distribuição, Madeira Energia, Taesa and Light as of December 31, 2012.

|  |  |  |  |  |  |  |  |  |  |  | Unrealized loss |  | Accumulated effect
Cemig’s right |  | Cemig’s obligation |  | Maturity period |  | Trading market |  | Value of principal contracted |  | Amount according to contract |  | Fair value |  | Amount received |  | Amount paid
| 2012 |  | 2011 Reclassified |  | 2012 |  | 2011 Reclassified |  | 2012 |  | 2011 Reclassified |  | 2012 |  | 2012
Cemig Distribuição SA |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
US$ FX rate + 5.58% p.a. to 7.14% p.a.) |  | R$ 100% of CDI + 15% to 3.01% p.a.) |  | From 04/2009 To 06/2013 |  | Over-the-counter |  | US$8 |  | US$17 |  | (24) |  | (48) |  | (24) |  | (48) |  | - |  | (25)
Rate of 11.47% p.a. |  | Rate of 96% de CDI |  | On 05/10/2013 |  | Over-the-counter |  | R$600 |  | R$600 |  | 32 |  | 8 |  | 44 |  | 23 |  | - |  | -
Cemig Geração e Transmissão SA |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Madeira Energia SA |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
R$ IGP-M |  | R$ 5.86% Fixed-rate |  | In 12/2012 |  | Over-the-counter |  | - |  | R$120 |  | - |  | 1 |  | - |  | 1 |  | 2 |  | -
Euro |  | Variation in Euro FX rate |  | In 12/2012 |  | Options |  | - |  | R$2 |  | - |  | - |  | - |  | - |  | - |  | -
Taesa |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
ATE II Transmissora de Energia (*) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Libor6M + Over Libor |  | USD |  | In 11/2022 |  | Swap |  | 42 |  | 28 |  | - |  | - |  | - |  | - |  | - |  | -
Libor6M + Over Libor |  | USD |  | In 11/2018 |  | Swap |  | 5 |  | 3 |  | - |  | - |  | - |  | - |  | - |  | -
ATE III Transmissora de Energia (*) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Libor6M + Over Libor |  | USD |  | In 05/2020 |  | Swap |  | 60 |  | 39 |  | - |  | - |  | - |  | - |  | - |  | -
BRL |  | USD |  | In 11/2012 |  | Options |  | 5 |  | 3 |  | - |  | - |  | - |  | - |  | - |  | -
BRL |  | USD |  | In 05/2013 |  | Options |  | 5 |  | 3 |  | - |  | - |  | - |  | - |  | - |  | -
BRL |  | USD |  | In 05/2012 |  | Options |  | - |  | 3 |  | - |  | - |  | - |  | - |  | - |  | -
Light |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
101,9% CDI + (TJLP -6%) |  | Taxa de 0,85% + CDI |  | Em 10/2012 |  | Swap |  | R$150 |  | R$150 |  | - |  | - |  | 1 |  | - |  | - |  | -
US$ + variação entre (2,20% a 3,58%) |  | 100% CDI |  | Entre 09/2012 a 04/2014 |  | Swap |  | US$10 |  | US$9 |  | 1 |  | - |  | 1 |  | - |  | - |  | -
Libor + 2,5294% |  | 100% CDI + 0,65% |  | 10/2014 |  | Swap |  | U$50 |  | U$50 |  | 5 |  | 2 |  | 5 |  | 1 |  | - |  | -
Euro + 4,6823% |  | 100% CDI + 1,30% |  | 10/2014 |  | Swap |  | €35 |  | €35 |  | 3 |  | - |  | 4 |  | - |  | - |  | -
US$ + Libor + 1,66% |  | 100% CDI + 1,00% |  | Entre 02/17 a 02/18 |  | Swap |  | US$180 |  | - |  | - |  | - |  | (2) |  | - |  | - |  | -
|  |  |  |  |  |  |  |  |  |  |  | 17 |  | (37) |  | 29 |  | (24) |  | 2 |  | (25)

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(*) Subsidiaries of Taesa

1) Amounts shown give the part of the transaction proportional to Cemig GT’s equity interest.

2) The fair values show a gain for the Company.

3) Amounts in thousands of reais

4) Amount received is the accumulated amount for the year (Jan/12 to Dec/12)

The counterparties of the derivatives transactions are the banks Bradesco, Itaú, HSBC, Citibank, Bank of America, BNP Paribas and Banco Santander – ABN. The contracts are exchange rate and indexor swaps.

Sensitivity analysis

The derivative instrument described above shows that the Company and its subsidiaries are exposed to variation in the CDI rate. Based on opinions of its financial consultants, the Company estimates that, in a “Probable” scenario, on December 31, 2013 the CDI rate will be 7.25%, and the US dollar will have depreciated against the Real by 0.29% (to R$ 2.05/US$).

The Company has performed a sensitivity analysis to demonstrate the adverse financial effects on its profit that would occur in scenarios assuming further changes in the SELIX rate and the exchange rate of 25%, and 50%, in that period – designating these scenarios as “Possible” and “Remote,” respectively.

In the “Possible” scenario, the CDI rate at December 31, 2013 would be 9.06%, and in the “Remote” scenario it would be 10.88%.

a) Risk: effect of changes in the CDI rate in relation to changes in US dollar

|  | Base scenario: Dec 31, 2012 |  | Probable scenario: SELIC 7.25% |  | Possible scenario: SELIC 9.06% |  | Remote scenario: SELIC 10.88% |
Risk: Increase in Brazilian domestic interest rates |  |  |  |  |  |  |  |  |
Contracts updated at 100,00% of CDI rate |  | 24 |  | 26 |  | 26 |  | 26 |
Net effect of the change in the CDI rate |  |  |  | (2) |  | (2) |  | (2) |
Risk: Increase in US$ exchange rate |  |  |  |  |  |  |  |  |
Contracts updated at 100,00% of CDI rate |  | 24 |  | 24 |  | 30 |  | 36 |
Net effect of change in US$ |  |  |  | - |  | 6 |  | 12 |
Net effect |  |  |  | (2) |  | 4 |  | 10 |

b) Risk: effect of changes in the CDI rate in relation to changes in fixed rate of 11.47% p.a.

|  | Base scenario: Dec 31, 2012 |  | Probable scenario: |  | Possible scenario: |  | Remote scenario: |
Risk: Increase in Brazilian domestic interest rates |  |  |  |  |  |  |  |  |
Contracts updated at 96% of CDI rate |  | 600 |  | 642 |  | 652 |  | 663 |
Net effect of the change in the CDI rate |  |  |  | (42) |  | (52) |  | (63) |
Risck - Fixed interest rate |  |  |  |  |  |  |  |  |
Contracts updated at 11.47% p.a. |  | 600 |  | 669 |  | 669 |  | 669 |
Net effect of change in the interest rate |  |  |  | (69) |  | (69) |  | (69) |
Net effect |  |  |  | 27 |  | 17 |  | 6 |

Value and type of margins given in guarantee

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The Company does not make margin deposits for derivative instruments.

c) Capital Management

This table below shows the ratio of net debt to total equity as of December 31, 2012 and December 31, 2011:

|  | 2012 |  | 2011 |
Total liabilities |  | 28,729 |  | 25,264 |
(-) Cash and cash equivalents |  | (2,486) |  | (2,862) |
(-)Restricted cash |  | (132) |  | (3) |
Net liabilities |  | 26,111 |  | 22,399 |
Total equity |  | 12,044 |  | 11,745 |
Net liabilities / Total equity |  | 2.17 |  | 1.91 |

29. MEASUREMENT AT FAIR VALUE

Fair value is measured as market value based on assumptions in which market participants are able to price an asset or liability. The fair value hierarchy aims to increase consistency and comparabilityprioritizing the inputs used in measurement of value into three broad levels:

■ Level 1: Active market – Quoted price: A financial instrument is considered to be quoted on an active market if the quoted prices are promptly and regularly made available by an exchange or by an organized over-the-counter market, or by traders, brokers, a market association, entities whose purpose is to publish prices, or regulatory agencies, and provided that these prices represent market transactions that occur regularly in arm’s length transactions between independent parties.

■ Level 2: No active market – Valuation technique: For an instrument that does not have an active market, fair value should be found by using a method of valuation/pricing. Criteria such as data on the current fair value of another instrument that is substantially similar, or discounted cash flow analysis or option pricing models, may be used. The objective of the valuation technique is to establish what would be the transaction price on the measurement date in an arm’s-length transaction motivated by business considerations.

■ Level 3: No active market – Securities: Fair value of investments in securities for which there are no prices quoted on an active market, and of derivatives linked to them which are to be settled by delivery of unquoted securities. The fair value is determined based upon generaly accepted valuation techniques, mainly related to discounted cash flow analysis.

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A summary of the instruments that are measured at fair value as of December 31, 2012 is presented below:

Item |  | Balance at December 31, 2012 |  | Fair value at December 31, 2012 |
|  | Active market – quoted price (Level 1) |  | No active market – Valuation technique (Level 2) |  | No active market – Share capital (Level 3) |
Assets |  |  |  |  |  |  |  |  |
Securities |  |  |  |  |  |  |  |  |
Bank certificates of deposit |  | 685 |  | - |  | 685 |  | - |
National Treasury bonds (LFTs) |  | 46 |  | - |  | 46 |  | - |
Financial bonds – Banks |  | 225 |  | - |  | 225 |  | - |
Others |  | 117 |  | - |  | 117 |  | - |
|  | 1,073 |  | - |  | 1,073 |  | - |
Restricted cash |  | 132 |  | - |  | 132 |  | - |
Swap contracts |  | 32 |  | - |  | 32 |  | - |
Financial assets of the concession |  | 5,585 |  | - |  | - |  | 5,585 |
|  | 5,749 |  | - |  | 164 |  | 5,585 |
Liabilities |  |  |  |  |  |  |  |  |
Swap contracts |  | (1) |  | - |  | (1) |  | - |

Methodology for calculating the fair value

Financial assets of the concession Measured at New Replacement Value (VNR), equivalent to fair value, according to criteria established in regulations made by the Grantor based on the value of the assets in service belonging to the concession and which will be reversible at the end of the concession.

The Company recorded the financial assets of the concession at fair value at December 31, 2012. Hence there are no movements on profit and loss accounts, other than those stated in Note 4 to the financial statements, to be disclosed.

Cash investments: The fair value of cash investments is calculated taking into consideration the market prices of the security, or market information that makes such calculation possible, and future fixed-income market and FX rates applicable to similar securities. The market value of the security is its maturity value discounted to present value by the discount factor obtained from the market yield curve, in Reais.

Swap Contracts: The criteria for marking to market of derivative operations consists of establishing the present value of a transaction contracted in the past in such a way that its replacement provides the same results as a new operation. Swaps are priced by calculating the difference between the market values of each one of their end points, adjusted by their index. A swap contract based on the CDI (Interbank Certificates of Deposit) rate is priced as calculated from the start date of the transaction up to the specified future date, considering the future forecast for this index. Pricing of the dollar side of the swap is adjusted by the variation in the exchange rate, using a future expectation and an embedded risk premium.

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30. INSURANCE

Cemig, its subsidiaries and jointly-controlled subsidiarires have insurance policies to cover damages to certain assets, in accordance with orientation by specialists, as listed below, taking into account the nature and the degree of risk, for amounts considered sufficient to cover any significant losses related to its assets and legal responsibilities. The assumptions for the risks involved, due to their nature were not part of the scope of the audit of the financial statements and, consequently, were not examined by the independent auditors.

Assets Insured |  | Coverage |  | Effective period of coverage |  | Amount insured |  | Annual premium
Cemig, Cemig D e Cemig GT |  |  |  |  |  |  |  |
Air transport – Aircraft |  | Fuselage |  | 04/29/2012 a 04/29/2013 |  | US$14 |  | -
|  | Third party liability |  | 04/29/2012 a 04/29/2013 |  | US$24 |  |
Stores, building facilities and telecom equipment |  | Fire |  | 11/08/2012 a 11/08/2013 |  | R$ 939 |  | -
Operational risk – generators, turbines, and power equipment |  | Total |  | 12/07/2012 a 12/07/2013 |  | R$1,832(1) |  | R$ 2
Light |  |  |  |  |  |  |  |
Chief Officers and Board members |  | Total |  | 08/10/2012 a 08/10/2013 |  | R$ 40 |  | -
General third party liability |  | Total |  | 09/25/2012 a 09/25/2013 |  | R$ 20 |  | R$ 1
Operational risk |  | Total |  | 10/31/2012 a 10/31/2013 |  | R$ 4,881 (2) |  | R$ 2
Taesa |  |  |  |  |  |  |  |
Operational risk – substations, stores, institutional buildings (*) |  | Total (3) |  | 08/19/2012 a 08/19/2013 |  | R$ 933 |  | R$ 1
Operational risk – substations, stores, institutional buildings (**) |  | Total (3) |  | 12/13/2012 a 12/13/2013 |  | R$ 1,887 |  | R$ 1
Electricity generation and distribution companies (Concession holders or not) (*) |  | Third party liability |  | 08/19/2012 a 08/19/2013 |  | LMI R$10 |  | -
Electricity generation and distribution companies (Concession holders or not) (**) |  | Third party liability |  | 12/13/2012 a 12/13/2013 |  | LMI R$10 |  | -
Diretores e Gerentes (***) |  | Third party liability |  | 08/18/2012 a 08/18/2013 |  | LMG R$10 |  | -
Veículos (****) |  | 105% da Tabela Fipe |  | 08/19/2012 a 08/19/2013 |  | - |  | -
Madeira |  |  |  |  |  |  |  |
Guarantee of public liabilities |  | Obligations under the concession agreement |  | 03/07/2008 a 10/11/2016 |  | R$ 163 |  | R$ 20
Engineering risk – Construction, installation, assembly Guarantee maintenance |  | Total RE / Risks All of the equipment over a period of maintenance / warranty. (6) |  | 11/11/2008 a 11/03/2016 |  | Diversos (3) |  | R$ 135
Comprehensive multi-risk |  | Warehouse materials |  | 03/23/2011 a 11/302017 |  | R$ 4,515 |  | R$ 26
General third party liability |  | Works/employer (7) |  | 09/26/2012 a 09/26/2013 |  | R$ 65 |  | -
National transportation |  | Damage to property and transportation of products (8) |  | 04/06/2012 a 04/06/2015 |  | R$ 60 |  | -
Internacional transportation |  | Damage to property and transportation of products (9) |  | 01/31/2010 a 12/31/2015 |  | R$ 3,176 |  | R$ 2
Third party liability - concessionaries |  | Third party liability |  | 01/31/2010 a 12/31/2015 |  | USD 310 |  | -
Third party liability – directors and officers |  | Third party liability |  | 12/31/2011 a 12/31/2012 |  | R$ 50 |  | R$ 1
Guarantee of public liabilities |  | Obligations under the concession agreement |  | 08/15/2012 a 08/15/2013 |  | R$ 50 |  | -

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(1) The maximum limit for compensation is R$170.

(2) The maximum limit for compensation is R$300.

(3) R$10,000 for civil liability, R$12,719 for engineering risks – All Risk, R$1,630 for ALOP (Loss of income for delays in the work due to loss from damage to property), R$992 for Operational Risks: all the power station’s permanent services.

(4)Amounts included only in the NVT, TSN, ETEO concessions and Taesa

(5) Amounts included for Taesa, NTE, BRASNORTE and ETAU.

(6) The maximum limit for compensation is R$20, except for a policy for R$231 of the subsidiary NTE which R$50 .

(7) The maximum limit for compensation is R$50.

(*) Amounts included only of the concessions NVT, TSN, ETEO, NTE, BRASNORTE, ETAU and the company Taesa.

(**) Amounts included of ATE, ATE II, ATE III and STE.

(***) Taesa

(****) Amounts included of TSE, NVT, ETEO and BRASNORTE.

Cemig does not have general third-party liability insurance covering accidents , except for its aircraft, and has not requested proposals related to this type of insurance. The Company has not requested proposals for, nor does it carry, insurance coverage for major catastrophes affecting its facilities such as earthquakes and floods, for business interruption risks or system failures.

The Company has not undergone significant losses arising from the aforementioned risks.

31. COMMITMENTS

Cemig and its subsidiaries have contractual obligations and commitments which include amortization of loans and financing, contracts with contractors for construction of new ventures and purchase of electricity from Itaipu, amongst others, as presented in the folllowing table:

|  | 2013 |  | 2014 |  | 2015 |  | 2016 |  | 2017 |  | 2018 em diante |  | Total |
Loans and financings |  | 5,912 |  | 2,416 |  | 1,703 |  | 1,155 |  | 1,656 |  | 3,328 |  | 16,170 |
Purchase of electricity from Itaipu |  | 971 |  | 988 |  | 984 |  | 948 |  | 963 |  | 32,526 |  | 37,380 |
Transport of electricity from Itaipu |  | 27 |  | 25 |  | 26 |  | 26 |  | 29 |  | 1,464 |  | 1,597 |
Purchase of electricity at auctions |  | 2,249 |  | 2,102 |  | 2,210 |  | 2,326 |  | 2,422 |  | 63,180 |  | 74,489 |
Quotas under Provisional Measure 579/2012 |  | 334 |  | 215 |  | 785 |  | 736 |  | 684 |  | 36,186 |  | 38,940 |
Other electricity purchase contracts |  | 1,932 |  | 1,977 |  | 1,667 |  | 1,573 |  | 2,031 |  | 41,265 |  | 50,445 |
Debt to pension plan – FORLUZ |  | 51 |  | 54 |  | 58 |  | 61 |  | 65 |  | 526 |  | 815 |
Total |  | 11,476 |  | 7,777 |  | 7,433 |  | 6,825 |  | 7,850 |  | 178,475 |  | 219,836 |

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32. STATEMENT SEGREGATED BY COMPANY

STATEMENT SEGREGATED BY COMPANY ON DECEMBER 31, 2012 |
DESCRIPTION |  | HOLDING |  | CEMIG - GT |  | CEMIG -D |  | LIGHT |  | ETEP, ENTE, ERTE, EATE, ECTE |  | GASMIG |  | CEMIG TELECOM |  | SÁ CARVALHO |  | ROSAL |  | OTHERS |  | ELIMINATIONS / TRANSFERS |  | TOTAL |
ASSETS |  | 17,056 |  | 16,235 |  | 11,641 |  | 3,068 |  | 1,412 |  | 938 |  | 422 |  | 179 |  | 146 |  | 1,627 |  | (11,950) |  | 40,773 |
Cash and cash equivalents |  | 1,057 |  | 825 |  | 190 |  | 103 |  | 44 |  | 19 |  | 32 |  | 6 |  | 3 |  | 205 |  | - |  | 2,486 |
Consumers and traders |  | - |  | 678 |  | 1,888 |  | 457 |  | 32 |  | 74 |  | - |  | 5 |  | 4 |  | 134 |  | (77) |  | 3,198 |
Securities |  | 35 |  | 1,420 |  | 101 |  | 2 |  | - |  | 4 |  | 47 |  | 14 |  | 7 |  | 90 |  | - |  | 1,720 |
Recoverable Taxes |  | 452 |  | 250 |  | 1,361 |  | 305 |  | 5 |  | 64 |  | 34 |  | 1 |  | - |  | 84 |  | - |  | 2,555 |
Other Assets |  | 3,256 |  | 362 |  | 1,564 |  | 153 |  | 73 |  | 168 |  | 45 |  | 4 |  | - |  | 80 |  | (609) |  | 5,098 |
Investments/Property/Intangible/Financial Assets |  | 12,256 |  | 12,699 |  | 6,537 |  | 2,049 |  | 1,253 |  | 609 |  | 265 |  | 149 |  | 131 |  | 1,034 |  | (11,264) |  | 25,717 |
LIABILITIES AND EQUITY |  | 17,056 |  | 16,235 |  | 11,641 |  | 3,068 |  | 1,412 |  | 938 |  | 422 |  | 179 |  | 146 |  | 1,627 |  | (11,950) |  | 40,773 |
Suppliers |  | 12 |  | 291 |  | 1,117 |  | 225 |  | 32 |  | 43 |  | 11 |  | 1 |  | 5 |  | 64 |  | (65) |  | 1,735 |
Loans, Financing and Debentures |  | 1,103 |  | 8,140 |  | 4,610 |  | 1,216 |  | 399 |  | 172 |  | 143 |  | - |  | - |  | 388 |  | - |  | 16,170 |
Interest on capital and dividends |  | 3,479 |  | 311 |  | 120 |  | 19 |  | 9 |  | 22 |  | - |  | 7 |  | 4 |  | 21 |  | (513) |  | 3,479 |
Employee post-retirement benefits |  | 104 |  | 445 |  | 1,413 |  | 285 |  | - |  | - |  | - |  | - |  | - |  | 70 |  | - |  | 2,318 |
Taxes |  | 60 |  | 917 |  | 944 |  | 201 |  | 159 |  | 28 |  | 10 |  | 45 |  | 1 |  | 84 |  | 198 |  | 2,647 |
Other Liabilities |  | 254 |  | 635 |  | 975 |  | 271 |  | 43 |  | 191 |  | 10 |  | 3 |  | 2 |  | 101 |  | (105) |  | 2,379 |
Equity |  | 12,044 |  | 5,495 |  | 2,463 |  | 851 |  | 770 |  | 482 |  | 248 |  | 124 |  | 134 |  | 899 |  | (11,465) |  | 12,044 |
INCOME STATEMENT |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
REVENUE |  | - |  | 5,424 |  | 9,504 |  | 2,091 |  | 339 |  | 625 |  | 136 |  | 55 |  | 40 |  | 785 |  | (539) |  | 18,460 |
Operating Costs and Expenses |  | (519) |  | (2,428) |  | (9,007) |  | (1,803) |  | (77) |  | (573) |  | (118) |  | (14) |  | (24) |  | (614) |  | 539 |  | (14,639) |
Electricity purchased for resale |  | - |  | (729) |  | (4,180) |  | (1,038) |  | - |  | - |  | - |  | (1) |  | (10) |  | (267) |  | 272 |  | (5,951) |
Charges for the use of the basic transmission grid |  | - |  | (269) |  | (794) |  | (143) |  | - |  | - |  | - |  | - |  | (3) |  | (40) |  | 239 |  | (1,011) |
Gas purchased for resale |  | - |  | - |  | - |  | - |  | - |  | (495) |  | - |  | - |  | - |  | - |  | - |  | (495) |
Cost of construction |  | - |  | (118) |  | (1,228) |  | (174) |  | (39) |  | (25) |  | - |  | - |  | - |  | (45) |  | - |  | (1,630) |
Personnel and management |  | (34) |  | (311) |  | (830) |  | (77) |  | (11) |  | (21) |  | (39) |  | (1) |  | (1) |  | (35) |  | - |  | (1,361) |
Employees and manager profit sharing |  | (13) |  | (63) |  | (164) |  | - |  | - |  | - |  | (1) |  | - |  | - |  | (2) |  | - |  | (244) |
Post-employment obligations |  | (10) |  | (30) |  | (94) |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | (134) |
Materials |  | - |  | (19) |  | (52) |  | (7) |  | - |  | (1) |  | - |  | - |  | - |  | (3) |  | - |  | (82) |
Outsourced services |  | (22) |  | (218) |  | (695) |  | (109) |  | (14) |  | (8) |  | (22) |  | (2) |  | (3) |  | (60) |  | 28 |  | (1,127) |
Royalties for use of water resources |  | - |  | (179) |  | - |  | - |  | - |  | - |  | - |  | (2) |  | (1) |  | (4) |  | - |  | (186) |
Depreciation and amortization |  | -) |  | (357) |  | (393) |  | (101) |  | (7) |  | (20) |  | (36) |  | (6) |  | (4) |  | (77) |  | - |  | (1,001) |
Operating provisions |  | (401) |  | 2 |  | (269) |  | (95) |  | - |  | - |  | - |  | - |  | - |  | (19) |  | - |  | (782) |
Other, net |  | (39) |  | (136) |  | (307) |  | (61) |  | (5) |  | (3) |  | (19) |  | (1) |  | (1) |  | (63) |  | 1 |  | (635) |
Gross Profit |  | (519) |  | 2,996 |  | 497 |  | 287 |  | 262 |  | 52 |  | 18 |  | 41 |  | 17 |  | 171 |  | - |  | 3,821 |
Gain on issuance of shares of jointly controlled entities |  | - |  | 259 |  | - |  | 4 |  | - |  | - |  | - |  | - |  | - |  | 1 |  | - |  | 264 |
Equity gain (loss) in subsidiaries |  | - |  | (3) |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | (3) |
Financial Revenues |  | 2,477 |  | 258 |  | 289 |  | 52 |  | 5 |  | 31 |  | 11 |  | 1 |  | 1 |  | 85 |  | - |  | 3,210 |
Financial Expenses |  | (137) |  | (898) |  | (574) |  | (172) |  | (41) |  | (12) |  | (13) |  | - |  | - |  | (110) |  | - |  | (1,958) |
Profit before income taxes |  | 1,820 |  | 2,612 |  | 212 |  | 171 |  | 225 |  | 71 |  | 16 |  | 42 |  | 18 |  | 148 |  | - |  | 5,335 |
Income tax and Social Contribution |  | (119) |  | (632) |  | (313) |  | (55) |  | (37) |  | (14) |  | (4) |  | (14) |  | (2) |  | (314) |  | - |  | (1,504) |
Deferred income tax and Social Contribution |  | (68) |  | (61) |  | 292 |  | 9 |  | 8 |  | - |  | (2) |  | 1 |  | - |  | 262 |  | - |  | 441 |
Profit for the Year |  | 1,633 |  | 1,919 |  | 191 |  | 125 |  | 196 |  | 56 |  | 10 |  | 29 |  | 16 |  | 96 |  | - |  | 4,272 |

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STATEMENT SEGREGATED BY COMPANY ON DECEMBER 31, 2011 - Reclassified |
DESCRIPTION |  | HOLDING |  | CEMIG - GT |  | CEMIG-D |  | LIGHT |  | ETEP, ENTE, ERTE, EATE, ECTE |  | GASMIG |  | CEMIG TELECOM |  | SÁ CARVALHO |  | ROSAL |  | OTHERS |  | ELIMINATIONS / TRANSFERS |  | TOTAL |
ASSETS |  | 14,465 |  | 15,493 |  | 10,458 |  | 2,906 |  | 1,421 |  | 854 |  | 420 |  | 175 |  | 147 |  | 1,429 |  | (10,757) |  | 37,009 |
Cash and cash equivalents |  | 227 |  | 1,550 |  | 527 |  | 202 |  | 33 |  | 45 |  | 84 |  | 10 |  | 8 |  | 178 |  | - |  | 2,862 |
Consumers and traders |  | - |  | 635 |  | 1,923 |  | 438 |  | 37 |  | 166 |  | - |  | 5 |  | 4 |  | 135 |  | (174) |  | 3,169 |
Securities |  | 180 |  | 170 |  | 5 |  | 2 |  | - |  | - |  | - |  | - |  | - |  | 2 |  | - |  | 359 |
Recoverable Taxes |  | 521 |  | 288 |  | 927 |  | 244 |  | 13 |  | 67 |  | 36 |  | - |  | - |  | 67 |  | - |  | 2,162 |
Other Assets |  | 1,541 |  | 335 |  | 1,254 |  | 163 |  | 48 |  | 30 |  | 32 |  | 4 |  | - |  | 74 |  | 528 |  | 4,007 |
Investments/Property/Intangible/Financial Assets |  | 11,997 |  | 12,516 |  | 5,822 |  | 1,858 |  | 1,291 |  | 545 |  | 269 |  | 155 |  | 135 |  | 974 |  | (11,111) |  | 24,449 |
LIABILITIES AND EQUITY |  | 14,465 |  | 15,493 |  | 10,458 |  | 2,906 |  | 1,421 |  | 853 |  | 420 |  | 174 |  | 147 |  | 1,429 |  | (10,757) |  | 37,009 |
Suppliers |  | 12 |  | 177 |  | 753 |  | 197 |  | 8 |  | 37 |  | 10 |  | 1 |  | 2 |  | 59 |  | (66) |  | 1,190 |
Loans, Financing and Debentures |  | 1,030 |  | 8,348 |  | 3,511 |  | 1,085 |  | 406 |  | 131 |  | 98 |  | - |  | - |  | 350 |  | 820 |  | 15,779 |
Interest on capital and dividends |  | 1,243 |  | - |  | 109 |  | 19 |  | 14 |  | 22 |  | 7 |  | 2 |  | - |  | 22 |  | (197) |  | 1,243 |
Employee post-retirement benefits |  | 100 |  | 438 |  | 1,393 |  | 286 |  | - |  | - |  | - |  | - |  | - |  | 70 |  | - |  | 2,287 |
Taxes |  | 36 |  | 840 |  | 1,002 |  | 203 |  | 207 |  | 33 |  | 10 |  | 46 |  | 1 |  | 51 |  | - |  | 2,428 |
Other Liabilities |  | 299 |  | 603 |  | 1,033 |  | 275 |  | 32 |  | 184 |  | 8 |  | 2 |  | 2 |  | 98 |  | (200) |  | 2,337 |
Equity |  | 11,745 |  | 5,086 |  | 2,656 |  | 840 |  | 754 |  | 445 |  | 288 |  | 124 |  | 142 |  | 779 |  | (11,114) |  | 11,745 |
INCOME STATEMENT |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
REVENUE |  | - |  | 4,531 |  | 8,510 |  | 1,810 |  | 277 |  | 458 |  | 126 |  | 50 |  | 39 |  | 440 |  | (492) |  | 15,749 |
Operating Costs and Expenses |  | (92) |  | (2,116) |  | (7,281) |  | (1,592) |  | (55) |  | (383) |  | (104) |  | (13) |  | (34) |  | (265) |  | 492 |  | (11,445) |
Electricity purchased for resale |  | - |  | (583) |  | (2,936) |  | (874) |  | - |  | - |  | - |  | (1) |  | (1) |  | (113) |  | 230 |  | (4,278) |
Charges for the use of the basic transmission grid |  | - |  | (245) |  | (672) |  | (124) |  | - |  | - |  | - |  | - |  | (3) |  | (25) |  | 238 |  | (830) |
Gas purchased for resale |  | - |  | - |  | - |  | - |  | - |  | (329) |  | - |  | - |  | - |  | - |  | - |  | (329) |
Cost of construction |  | - |  | (92) |  | (1,175) |  | (207) |  | (23) |  | - |  | - |  | - |  | - |  | (31) |  | - |  | (1,529) |
Personnel and management |  | (37) |  | (300) |  | (767) |  | (64) |  | (10) |  | (19) |  | (28) |  | (1) |  | (1) |  | (21) |  | - |  | (1,249) |
Employees and manager profit sharing |  | (15) |  | (55) |  | (148) |  | - |  | - |  | - |  | (2) |  | - |  | - |  | - |  | - |  | (221) |
Post-employment obligations |  | (8) |  | (28) |  | (87) |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | (124) |
Materials |  | - |  | (23) |  | (64) |  | (7) |  | - |  | (1) |  | - |  | - |  | - |  | (1) |  | - |  | (98) |
Outsourced services |  | (13) |  | (164) |  | (681) |  | (107) |  | (15) |  | (6) |  | (21) |  | (3) |  | (3) |  | (38) |  | 19 |  | (1,031) |
Royalties for use of water resources |  | - |  | (148) |  | - |  | - |  | - |  | - |  | - |  | (2) |  | (1) |  | (3) |  | - |  | (154) |
Depreciation and amortization |  | - |  | (381) |  | (384) |  | (105) |  | (3) |  | (22) |  | (35) |  | (5) |  | (26) |  | (23) |  | - |  | (983) |
Operating provisions |  | 2 |  | (12) |  | (161) |  | (78) |  | - |  | - |  | (1) |  | - |  | 1 |  | (8) |  | - |  | (258) |
Other, net |  | (20) |  | (86) |  | (205) |  | (26) |  | (5) |  | (5) |  | (16) |  | (1) |  | - |  | (2) |  | 6 |  | (362) |
Gross Profit |  | (92) |  | 2,416 |  | 1,230 |  | 218 |  | 222 |  | 75 |  | 21 |  | 36 |  | 4 |  | 174 |  | - |  | 4,304 |
Equity gain (loss) on subsidiaries |  | 2,467 |  | (1) |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | - |  | (2,467) |  | (1) |
Financial Revenues |  | 173 |  | 277 |  | 310 |  | 45 |  | 17 |  | 26 |  | 11 |  | 2 |  | 1 |  | 133 |  | - |  | 995 |
Financial Expenses |  | (114) |  | (939) |  | (526) |  | (163) |  | (34) |  | (12) |  | (13) |  | - |  | 21 |  | (185) |  | - |  | (1,965) |
Profit before income taxes |  | 2,434 |  | 1,753 |  | 1,013 |  | 101 |  | 205 |  | 88 |  | 19 |  | 37 |  | 27 |  | 122 |  | (2,467) |  | 3,333 |
Income tax and Social Contribution |  | (143) |  | (469) |  | (355) |  | (27) |  | (34) |  | (20) |  | (6) |  | (13) |  | (2) |  | (43) |  | - |  | (1,111) |
Deferred income tax and Social Contribution |  | 125 |  | (15) |  | 61 |  | 7 |  | 8 |  | - |  | 5 |  | 1 |  | - |  | 1 |  | - |  | 194 |
Profit for the Year |  | 2,415 |  | 1,269 |  | 720 |  | 81 |  | 179 |  | 68 |  | 18 |  | 26 |  | 25 |  | 80 |  | (2,467) |  | 2,415 |

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33. CASH FLOW STATEMENT

The assent and liabilities related to acquisitions and dilutions of holdings in jointly-controlled subsidiaries, with the exception of Cash and cash equivalents, have been eliminated in the preparation of the cash flow statement. These assets and liabilities are shown in Explanatory Note 14.

The Company has excluded from the cash flow statement the amount of R$ 403 retained by the State and passed through to the federal government, arising from the Settlement Agreement signed to settle the legal action between Cemig and the federal government.

34. SUBSEQUENT EVENTS

a) Issue of Debentures by Cemig D

In March 2013, Cemig D concluded its third public issue of debentures: 2,160,000 unsecured, non-convertible debentures, in three series, with nominal unit value of R$ 1,000 (one thousand Reais) on the issue date (February 15, 2013), for a total of R$2,160. The net proceeds from the issue were used for 100% redemption of the commercial Promissory Notes of the Company’s 5th and 6th issues, placed on January 13, 2012, for their total nominal value plus remuneratory interest, and for investments in distribution infrastructure. 410,817 debentures of the first series, 1,095,508 debenture of the second series and 653,675 debentures of the third series were issued, with maturity respectively at 5, 8 and 12 years from the issue date. The debentures of the first series will pay remuneratory interest equal to the CDI rate plus 0.69%; those of the second and third series will have their nominal value updated by the Expanded National Consumer Price Index (Índice Nacional de Preços ao Consumidor Amplo, or IPCA), published by the Brazilian Geography and Statistics Institute (Instituto Brasileiro de Geografia e Estatística, or IBGE), and will further pay remuneratory interest at 4.70% and 5.10% per year, respectively. The controlling stockholder, Cemig, provided a surety guarantee for the 3rd debenture issue by Cemig D.

On February 1, 2013 the Company issued a Bank Credit Note (CCD) in favor of Banco do Brasil, in the amount of R$200, for use of proceeds in the purchase of electricity. The note has maturity of 721 days and annual interest of 99.5% of the CBI rate, guaranteed by duplicates of the Company’s sales invoices.

b) Transfer of control

Authorizing Resolution 3845 of January 15, 2013, published in federal Official Gazette No. 12 of January 17, 2013, in Section 01, on Page 53, consented to: the stockholding restructuring of Taesa, the jointly-controlled subsidiary of Cemig GT, through absorption of STE and ATE into Unisa, and immediately subsequent absorption of NTE and Unisa into Taesa, generating transfers of the respective concessions of the absorbed companies; and to transfer of control of ATE II and ATE III, held by Unisa, to Taesa. The holders of the concessions have 120 (one hundred twenty) days for implementation of the transfers; 30 (thirty) days, after implementation, for presentation of documents of proof; and 60 (sixty) days to sign the Amendments to the related Concession Contracts affected by the transactions authorized.

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c) Acquisition of the interest held by Suzano in the Capim Branco Energia Consortium

On March 12, 2013 Cemig Capim Branco Energia S.A., a wholly-owned subsidiary, signed the final contract with Suzano Papel e Celulose S.A. and its subsidiaries (“Suzano”) for the sale of Suzano’s interest in the Capim Branco Energia Consortium. The total price agreed, subject to any adjustments, for Suzano’s 17.8947% interest in the Consortium was R$320. Of this total, the percentage that pertains to Cemig Capim Branco, of 30.3030%, represents approximately R$97.

d) Approval of the Stockholding Restructuring with Taesa

Complementing the Material Announcement of May 17, 2012, on April 9, 2013, Aneel (National Electricity Agency) approved the transfer of stockholding control, to Transmissora Aliança de Energia Elétrica S.A. (Taesa), of the following companies holding electricity transmission concessions:

(i) Transfer of direct interest:

Empresa Catarinense de Transmissão de Energia S.A. | – | ECTE,
Empresa Regional de Transmissão de Energia S.A. | – | ERTE,
Empresa Norte de Transmissão de Energia S.A. | – | ENTE,
Empresa Paraense de Transmissão de Energia S.A. | – | ETEP,
Empresa Amazonense de Transmissão de Energia S.A. | – | EATE and
Empresa Brasileira de Transmissão de Energia S.A. | – | EBTE;

(ii) Transfer of indirect interest (by Cemig and its wholly-owned subsidiary Cemig Geração e Transmissão S.A. – Cemig GT)

Sistema de Transmissão Catarinense S.A. | – | STC,
Lumitrans – Companhia Transmissora de Energia, |  |
Empresa Santos Dumont de Energia S.A. | – | ESDE, and
Empresa de Transmissão Serrana | – | ETSE,

Final conclusion of the transfer of the assets in this Restructuring is still subject to consent from the financing banks, including in particular the Brazilian Development Bank (BNDES).

On the date of completion of the Restructuring, Taesa will disburse R$ 1,732 million, updated by the CDI rate from December 31, 2011, less dividends and/or Interest on Equity already declared, whether already paid or not.

e) Result of the Third Tariff Review of Cemig D

At a public meeting held on April 5, 2013 the Brazilian electricity sector regulator, Aneel (Agência Nacional de Energia Elétrica), published the result of the Third Tariff Review of Cemig D (Cemig Distribuição S.A.), which will result in positive repositioning of Cemig D’s tariffs. These tariffs will take effect from April 8, 2013. The average effect for consumers will be an increase of 2.99%. This effect comprises one part reflecting the revision per se, and one part comprising the associated financial components.

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In this decision, Aneel is already applying the effects of Decree 7945/12, which governs the use of the funds from the Energy Development Account (Conta de Desenvolvimento Energético, or CDE) to attenuate distributors’ costs of acquisition of electricity in the Electricity Trading Chamber (Câmara de Comercialização de Energia Elétrica, or CCEE) as a result of the unfavorable hydrological conditions, which have led to the dispatching of thermal generation plants, and as a result to reduce the impact of the tariff adjustment, limiting it to 3%. The amount that exceeds this percentage will be passed through in a single payment, within 10 business days from the date of publication of the Aneel Homologating Resolution. The amount of these funds coming from the CDE will be reimbursed by consumers in up to 5 years, updated by the IPCA inflation index.

According to the statement of calculation received by Cemig after the homologation of the result of the Tariff Review at the meeting of the Council of Aneel, the Net Regulatory Remuneration Base was R$ 5, and the Gross Regulatory Remuneration Base was R$ 15.

f) Increase of share capital of Cemig, with stock dividend

We hereby advise our stockholders that the Board of Directors, at its meeting held on March 26, 2013, decided to propose to the General Meeting of Stockholders to be held on April 30, 2013:

Approval of increase in the Share Capital, from R$ 4,265 to R$ 4,813, through issuance of 109,654,157 new shares, each with par value of R$ 5.00 (five Reais), through capitalization of R$ 548 from the Capital Reserve – Donations and Subsidies for Investments, with consequent distribution to the holders of preferred and common shares of a stock bonus of 12.854843355%, in new shares, of the same type as those held, each with par value of R$ 5.00 (five Reais).

All holders of shares on April 30, 2013 will be entitled to this benefit. The shares will trade “ex-” the right to the stock dividend on the day immediately following the date on which the said Meeting is held. The shares of the stock bonus will be credited on May 7, 2013 and will not have the right to the dividends proposed for the business year 2012.

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(Original report signed by the signataries below)

Djalma Bastos de Morais |  | Arlindo Porto Neto |  | Luiz Fernando Rolla
Chief Executive Officer |  | Vice Chief Executive Officer |  | Diretor of Finances, Investor Relations and Financial Control of Equity Interests
Frederico Pacheco de Medeiros |  | José Carlos de Matos |  | José Raimundo Dias Fonseca
Director of Corporate Management |  | Director of Gas |  | Commercial Director
Luiz Henrique de Castro Carvalho |  | Fernando Henrique Schüffner Neto |  | Ricardo José Charbel
Director of Generation and Transmission |  | Director of Business Development Officer |  | Director of Distribution and Trading
Luiz Henrique Michalick |  |  |  | Maria Celeste Morais Guimarães
Director of Institutional Relations and Communication |  |  |  | Legal director
Leonardo George de Magalhães |  |  |  | Mário Lúcio Braga
Superintendent of the Controller’s Department CRC-MG 53.140 |  |  |  | Accounting Manager Accountant – CRC-MG-47.822

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INDEPENDENT AUDITORS’ REPORTS ON THE FINANCIAL STATEMENTS

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders of
Companhia Energética de Minas Gerais - CEMIG
Belo Horizonte, MG, Brazil

We have audited the accompanying consolidated statement of financial position of Companhia Energética de Minas Gerais - CEMIG and subsidiaries (the “Company”) as of December 31, 2012, and the related consolidated statements of income, comprehensive income, changes in equity and cash flows for the year ended December 31, 2012. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of Companhia Energética de Minas Gerais - CEMIG and subsidiaries as of December 31, 2012, and the results of their operations and their cash flows for the year ended December 31, 2012, in accordance with International Financial Reporting Standards (IFRS), as issued by the International Accounting Standards Board (IASB).

As discussed in notes 2.6 (h) and 13, property, plant and equipment related to generation activities in accordance that fall under the regulation for independent producers are depreciated based on their estimated useful lives and certain concession financial assets related to distribution of gas are registered based on the estimated indemnification by the granting authority, considering facts and circumstances mentioned in the respective notes. As new information becomes available or decisions are taken by the granting authorities, the depreciation rates relating to property plant and equipment or realization of certain concession financial assets related to distribution of gas may change.

As discussed in note 1 (a), the Madeira Energia S.A. joint venture and its subsidiary are incurring capital expenditures related to the development of the Santo Antonio power plant project. As of December 31, 2012, the joint venture’s property, plant and equipment balance included in the Company’s consolidated financial statements amounts to R$1,453 million. During this development phase, the joint venture has presented

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recurring losses, and its current liabilities are higher than its current assets. As also mentioned in note 1 (a), Madeira Energia S.A’s management has plans to address the negative working capital issue. As of this date, Madeira Energia S.A. depends on either its shareholders’ financial support or on issuance of additional debt securities to continue to operate.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2012, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated April 26, 2013 expressed an unqualified opinion on the Company’s internal control over financial reporting.

/s/ Deloitte Touche Tohmatsu Auditores Independentes

Belo Horizonte, MG, Brazil

April 26, 2013

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Report of Independent Registered Public Accounting Firm

The Board of Directors and Shareholders

Companhia Energética de Minas Gerais – CEMIG

We have audited the accompanying consolidated balance sheets of Companhia Energética de Minas Gerais – CEMIG and subsidiaries (the “Company”) as of December 31, 2011, and the related consolidated statements of income, changes in shareholders’ equity and comprehensive income, and cash flows for each of the years in the two-year period ended December 31, 2011. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Companhia Energética de Minas Gerais – CEMIG and subsidiaries as of December 31, 2011, and the results of their operations and their cash flows for each of the years in the two-year period ended December 31, 2011, in conformity with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB).

/s/ KPMG Auditores Independentes

São Paulo, Brazil
April 29, 2013

KPMG Auditores Independentes, uma sociedade simples brasileira e firma-membro da rede KPMG de firmas-membro independentes e afiliadas à KPMG International Cooperative (“KPMG International”), uma entidade suíça. |  | KPMG Auditores Independentes, a Brazilian entity and a member firm of the KPMG network of independent member firms affiliated with KPMG International Cooperative (“KPMG International”), a Swiss entity.