20-F/A 1 elpform20f_2019a.htm 20-F/A

As filed with the Securities and Exchange Commission on November 18, 2020

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 20-F/A

(Amendment No. 1)

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2019

Commission file number: 001-14668

COMPANHIA PARANAENSE DE ENERGIA – COPEL

(Exact Name of Registrant as Specified in its Charter)

Energy Company of Paraná (Translation of Registrant’s Name into English) | The Federative Republic of Brazil (Jurisdiction of Incorporation or Organization)

Rua Coronel Dulcídio, 800

80420-170 Curitiba, Paraná, Brazil

(Address of Principal Executive Offices)

Daniel Pimentel Slaviero

+55 41 3331 4011 – ri@copel.com

Rua Coronel Dulcídio, 800, 3rd floor – 80420.170 Curitiba, Paraná, Brazil

(Name, telephone, e-mail and/or facsimile number and address of company contact person)

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

Title of Each Class | Trading Symbol(s) | Name of Each Exchange on Which Registered
Preferred Class B Shares, without par value* | CPLE6 | New York Stock Exchange
American Depositary Shares (as evidenced by American Depositary Receipts), each representing one Preferred Class B Share | ELP | New York Stock Exchange

* Not for trading, but only in connection with the listing of American Depositary Shares on the New York Stock Exchange.

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 December 31, 2019:

145,031,080 Common Shares, without par value

327,142 Class A Preferred Shares, without par value

128,297,153 Class B Preferred Shares, without par value

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Yes ☒ No ☐

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 ☐ No ☒

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 ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).

N/A

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” and ”emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934. (Check one):

Large accelerated filer ☒ Accelerated filer ☐

Non-accelerated filer ☐ Emerging growth company ☐

If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

†The term “new or revised financial accounting standard” refers to any update issued by the Financial Accounting Standards Board to its Accounting Standards Codification after April 5,2012.

Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:

U.S. GAAP ☐ IFRS ☒ Other ☐

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.

N/A

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (§ 15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☒

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 Securities Exchange Act of 1934).

Yes ☐ No ☒

Table of Contents

Explanatory Note | 3
Presentation of Financial and Other Information | 4
Forward-Looking Statements | 5
Item 1. Identity of Directors, Senior Management and Advisers | 5
Item 2. Offer Statistics and Expected Timetable | 5
Item 3. Key Information | 6
Selected Financial Data | 6
Risk Factors | 9
Item 4. Information on the Company | 34
The Company | 34
Business | 38
Concessions | 61
Competition | 70
Environment | 71
Plant, Property and Equipment | 72
The Expropriation Process | 73
The Brazilian Electric Power Industry | 74
Item 4A. Unresolved Staff Comments | 93
Item 5. Operating and Financial Review and Prospects | 93
Overview | 94
Critical Accounting Policies | 98
Analysis of Electricity Sales and Cost of Electricity Purchased | 104
Results of Operations for the Years Ended December 31, 2019, 2018 and 2017 | 106
Liquidity and Capital Resources | 114
Contractual Obligations | 120
Off-Balance Sheet Arrangements | 121
Item 6. Directors, Senior Management and Employees | 122
Board of Directors | 122
Board of Executive Officers | 125
Supervisory Board | 127
Audit Committee | 128
Appointment and Evaluation Committee | 129
Compensation of Directors, Officers, Fiscal Council Members and Audit Committee Members | 130
Employees | 131
Share Ownership | 133
Item 7. Major Shareholders and Related Party Transactions | 134
Major Shareholders | 134
Related Party Transactions | 135
Item 8. Financial Information | 137
Legal Proceedings | 138
Dividend Payments | 139
Item 9. The Offer and Listing | 142
Item 10. Additional Information | 143
Memorandum and Articles of Association | 143
Material Contracts | 148
Exchange Controls | 149
Taxation | 151
Dividends and Paying Agents | 157
Statement By Experts | 158
Subsidiary Information | 159
Documents on Display | 160
Item 11. Quantitative and Qualitative Disclosures about Market Risk | 160
Item 12. Description of Securities Other than Equity Securities | 160
Item 12A. Debt Securities | 160
Item 12B. Warrants and Rights | 160
Item 12C. Other Securities | 160
Item 12D. American Depositary Shares | 160
Item 13. Defaults, Dividend Arrearages and Delinquencies | 161

Item 14. Material Modifications to the Rights of Security Holders and Use of Proceeds | 161
Item 15. Control and Procedures | 161
Item 16A. Audit Committee Financial Expert | 167
Item 16B. Code of Ethics | 167
Item 16C. Principal Accountant Fees and Services | 168
Item 16D. Exemption from the Listing Standards for Audit Committees | 169
Item 16E. Purchases of Equity Securities by the Issuer and Affiliated Purchasers | 169
Item 16F. Changes in Registrant’s Certifying Accountant | 169
Item 16G. Corporate Governance | 169
Item 17. Financial Statements | 172
Item 18. Financial Statements | 172
Item 19. Exhibits | 172
Technical Glossary | 174
Signatures | 180

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EXPLANATORY NOTE

This Amendment No. 1 (“ Amendment No. 1 ”) to the Annual Report on Form 20-F of Companhia Paranaense de Energia – Copel (the “ Company”) for the fiscal year ended December 31, 2019 filed on April 27, 2020 (the “Original Form 20-F”) is being filed to amend Item 15(a) and Item 15(b) to correctly state that the Company’s disclosure controls and procedures and the Company’s internal controls over financial reporting, respectively, were not effective as of December 31, 2019.

Exhibits 12.1, 12.2, 13.1 and 13.2 to the Original Form 20-F were inadvertently filed without the requisite conformed signatures, although the original certifications were signed on April 27, 2020. Consequently, this Amendment No.1 includes the full report and the requisite signatures to Exhibits 12.1, 12.2, 13.1 and 13.2 thereto.

Other than as set forth above, this Amendment No. 1 does not, and does not purport to, amend, update or restate the information in any other item of the Original Form 20-F. As a result, this Amendment No. 1 does not reflect any events that may have occurred after the Annual Report was filed on April 27, 2020.

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PRESENTATION OF FINANCIAL AND OTHER INFORMATION

In this annual report, we refer to Companhia Paranaense de Energia ‒ Copel, and, unless the context otherwise requires, its consolidated subsidiaries as “Copel”, the “Company”, “we” or “us”.

References to (i) the “real”, “reais” or “R$” are to Brazilian reais (plural) and the Brazilian real (singular) and (ii) “U.S. dollars”, “dollars” or “US$” are to United States dollars. We maintain our books and records in reais. Certain figures included in this annual report have been subject to rounding adjustments.

Our audited consolidated financial statements as of December 31, 2019 and 2018, and for each of the years ended December 31, 2019, 2018 and 2017, are included in this annual report. We prepared our audited consolidated financial statements included in this annual report in accordance with International Financial Reporting Standards, or IFRS, as issued by the International Accounting Standards Board, or IASB.

References in this annual report to the “Common Shares”, “Class A Shares” (or “Class A”) and “Class B Shares” (or “Class B”) are to our common shares, class A preferred shares and class B preferred shares, respectively. References to “American Depositary Shares” or “ADSs” are to American Depositary Shares, each representing one Class B Share. The ADSs are represented by American Depositary Receipts (“ADRs”).

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 “kW” and “kWh” are to kilowatts and kilowatt hours, respectively, references to “MW” and “MWh” are to megawatts and megawatt hours, respectively, and references to “kV” are to kilovolts. These and other technical terms are defined in the “Technical Glossary” that begins on page 189.

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FORWARD-LOOKING STATEMENTS

This annual report contains forward-looking statements. We may also make written or oral forward-looking statements in our annual report to shareholders, in our offering circulars and prospectuses, in press releases and other written materials and in oral statements made by our officers, directors or employees. These statements are not historical facts and are based on management’s current view and estimates of future economic circumstances, industry conditions, company performance and financial results. The words “anticipates”, “believes”, “estimates”, “expects”, “plans” and similar expressions, as they relate to the company, are intended to identify forward-looking statements. Statements regarding the declaration or payment of dividends, the implementation of principal operating and financing strategies and capital expenditure plans, the direction of future operations and the factors or trends affecting the financial condition, liquidity or results of operations are examples of forward-looking statements. Forward-looking statements speak only as of the date they are made, and we undertake no obligation to update publicly any of them in light of new information or future events.

Forward-looking statements involve only the current view of management and are subject to a number of inherent risks and uncertainties. There is no guarantee that the expected events, trends or results will actually occur. We caution you that a number of important factors could cause actual results to differ materially from those contained in any forward-looking statement. Such factors include, but are not limited to:

| · | Brazilian political and economic conditions;

| · | economic conditions in the State of Paraná;

| · | technical and operational conditions related to the provision of electricity services;

| · | lawsuits;

| · | our ability to obtain financing;

| · | developments in other emerging market countries;

| · | changes in, or failure to comply with, governmental regulations;

| · | competition;

| · | electricity shortages;

| · | impacts of the coronavirus (COVID-19) pandemic; and

| · | other factors discussed below under “Item 3. Key Information―Risk Factors”.

All forward-looking statements are expressly qualified in their entirety by this cautionary statement, and you should not place undue reliance on any forward-looking statement contained in this annual report.

Item 1. Identity of Directors, Senior Management and Advisers

Not applicable.

Item 2. Offer Statistics and Expected Timetable

Not applicable.

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Item 3. Key Information

SELECTED FINANCIAL DATA

This section contains selected consolidated financial data presented in reais and derived from our consolidated financial statements that were prepared in accordance with IFRS as of and for each of the five years ended December 31, 2019, 2018, 2017, 2016 and 2015.

The following selected financial data should be read in conjunction with our audited consolidated financial statements (including the notes thereto), “Presentation of Financial and Other Information”, “Item 5. Operating and Financial Review and Prospects” and “Item 8. Financial Information”.

The selected financial data as of December 31, 2019 and 2018 and for the years ended December 31, 2019, 2018 and 2017 have been derived from our audited consolidated financial statements, prepared in accordance with IFRS, and included in this annual report. The selected financial data as of December 31, 2017, 2016 and 2015 and for the years ended December 31, 2016 and 2015, have been derived from our audited consolidated financial statements, prepared in accordance with IFRS, which are not included in this annual report.

As of January 1, 2019, IFRS 16 took effect, but without requiring restatement of balance sheets as of December 31, 2018 and earlier financial periods. The applicability of IFRS 16 should to be taken into account in the comparability of balances presented below. For further details see Note 4.16.1 to our audited consolidated financial statements, prepared in accordance with IFRS.

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| As of and for the year ended December 31,
| 2019 | 2018 | 2017 | 2016 | 2015
| (R$million)
Statement of income data(1): |  |
Operating revenues | 16,244 | 14,935 | 14,025 | 13,102 | 14,946
Cost of sales and services provided | (11,760) | (11,502) | (10,666) | (10,234) | (11,799)
Gross profit | 4,484 | 3,433 | 3,359 | 2,868 | 3,147
Operational expenses/income | (1,293) | (1,039) | (1,218) | (879) | (1,025)
Profit before financial results and taxes | 3,191 | 2,394 | 2,141 | 1,989 | 2,121
Financial results | (488) | (438) | (748) | (595) | (428)
Profit before income tax and social contribution | 2,702 | 1,956 | 1,393 | 1,394 | 1,694
Income tax and social contribution on profit | (639) | (512) | (275) | (520) | (532)
Net income for the year | 2,063 | 1,444 | 1,118 | 874 | 1,162
Statement of financial position data: |  |  |  |  |
Current assets | 7,909 | 6,678 | 5,702 | 4,237 | 6,822
Recoverable rate deficit (CRC)(1) | 1,350 | 1,445 | 1,516 | 1,523 | 1,383
Non-current assets | 10,863 | 10,014 | 8,608 | 8,313 | 4,952
Property, plant and equipment, net | 10,592 | 10,841 | 9,829 | 8,934 | 8,693
Total assets | 38,313 | 35,930 | 33,162 | 30,289 | 28,844
Loans and financing and debentures (current) | 1,420 | 3,298 | 2,417 | 2,602 | 1,233
Current liabilities | 5,346 | 6,695 | 6,110 | 5,656 | 4,789
Loans and financing and debentures (non-current) | 10,152 | 8,268 | 7,414 | 6,235 | 6,528
Non-current liabilities | 15,368 | 12,899 | 11,542 | 9,655 | 9,574
Equity | 17,598 | 16,336 | 15,510 | 14,978 | 14,480
Attributable to controlling shareholders | 17,252 | 16,033 | 15,208 | 14,718 | 14,162
Attributable to non-controlling interest | 346 | 303 | 302 | 260 | 318
Share capital | 10,800 | 7,910 | 7,910 | 7,910 | 6,910

(1) This item includes both current and non-current CRC Account receivables. Amounts due from the State of Paraná that were included in current assets totaled R$219 million on 2019, R$190.9 million in 2018, R$167.1 million in 2017, and R$111.7 million in 2015. Amounts due from the State of Paraná that were included in long-term assets totaled R$1,131 million in 2019, R$1,254.2 million in 2018, R$1,349.3 million in 2017, R$1,522.7 million in 2016 and R$1,271.6 million in 2015. In 2016 the entire amount due by the State of Paraná was included in long-term assets due to the negotiation of the Amendment to the CRC Agreement. See Note 8 to our audited consolidated financial statements.

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| As of and for the year ended December 31,
| 2019 | 2018 | 2017 | 2016 | 2015
| (R$, except for number of shares)
Basic and diluted earnings per share: |  |
Common Shares | 6.94 | 4.91 | 3.61 | 3.13 | 3.87
Class A Preferred Shares | 9.12 | 5.40 | 3.97 | 3.44 | 4.26
Class B Preferred Shares | 7.64 | 5.40 | 3.97 | 3.44 | 4.26
Number of shares outstanding at year end (in thousands): |  |  |  |  |
Common Shares | 145,031 | 145,031 | 145,031 | 145,031 | 145,031
Class A Preferred Shares | 327 | 329 | 329 | 349 | 380
Class B Preferred Shares | 128,297 | 128,295 | 128,295 | 128,275 | 128,244
Total | 273,655 | 273,655 | 273,655 | 273,655 | 273,655
Dividends per share at year end: |  |  |  |  |
Common Shares | 2.24 | 1.32 | 1.01 | 0.99 | 1.14
Class A Preferred Shares | 3.95 | 2.89 | 2.89 | 2.89 | 2.53
Class B Preferred Shares | 2.47 | 1.45 | 1.11 | 1.08 | 1.25

| As of and for the year ended December 31,
| 2019 | 2018 | 2017 | 2016 | 2015
| (US$¹, except for number of shares)
Basic and diluted earnings per share: |
Common Shares | 1.72 | 1.27 | 1.09 | 0.97 | 0.99
Class A Preferred Shares | 2.26 | 1.39 | 1.20 | 1.06 | 1.09
Class B Preferred Shares | 1.90 | 1.39 | 1.20 | 1.06 | 1.09
Number of shares outstanding at year end (in thousands): |  |  |  |  |
Common Shares | 145,031 | 145,031 | 145,031 | 145,031 | 145,031
Class A Preferred Shares | 327 | 329 | 329 | 349 | 380
Class B Preferred Shares | 128,927 | 128,295 | 128,295 | 128,275 | 128,244
Total | 273,655 | 273,655 | 273,655 | 273,655 | 273,655
Dividends per share at year end: |  |  |  |  |
Common Shares | 0.56 | 0.34 | 0.31 | 0.30 | 0.29
Class A Preferred Shares | 0.98 | 0.75 | 0.87 | 0.89 | 0.65
Class B Preferred Shares | 0.61 | 0.37 | 0.34 | 0.33 | 0.32

(1) 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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Risk Factors

Risks Relating to Our Company and our Operations

We are controlled by the State of Paraná, the policies and priorities of which directly affect our operations and may conflict with the interests of our investors.

We are controlled by the State of Paraná, which holds 58.6% of our outstanding common voting shares as of the date of this annual report, and whose interests may differ from other shareholders. As a major shareholder, the State of Paraná has the power to control all of our operations, including the power to elect a majority of the members of our Board of Directors and determine the outcome of any action requiring common shareholder approval, including transactions with related parties and corporate reorganizations.

Our operations have had and will continue to have an important impact on the commercial and industrial development of the State of Paraná. In the past, the State of Paraná 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 public policies or social objectives and not necessarily to meet the objective of improving our business and/or operational results.

We are involved in several lawsuits that could have a material adverse effect on our business if their outcome is unfavorable to us.

We are the defendant in several legal proceedings, mainly relating to civil, administrative, labor and tax claims. The outcome of these proceedings is uncertain and, if determined against us, may result in obligations that could materially affect our results of operations. On December 31, 2019, our provisions for probable (more likely than not) and reasonably estimated losses were R$1,606.7 million. For additional information, see “Item 8. Financial Information—Legal Proceedings”.

We are subject to limitations regarding the amount and use of public sector financing, which could prevent us from obtaining financing and implementing our investment program.

Our current budget anticipates capital expenditures for expansion, modernization, research, infrastructure and environmental projects of approximately R$2,087.2 million in 2020. As a state-controlled company, we are subject to Brazilian Central Bank Resolution no. 4,589/2017(Resolução nº 4,589/2017 do Banco Central do Brasil), which defines the limit of exposure and the annual global limit of credit to public sector entities to be observed by financial institutions and other institutions authorized to operate by the Brazilian Central Bank. The annual global limit that can be contracted in credit operations, with and without guarantee of the Union, by the bodies and entities of the public sector with the financial institutions and other institutions authorized to operate by the Brazilian Central Bank is defined by the National Monetary Council by means of inclusion of an annex to Brazilian Central Bank Resolution no. 4,589/2017, establishing, until the end of each fiscal year, the limit for the following year. The maximum amounts defined for the 2020 financial year are up to R$4.5 billion for Union guaranteed operations and up to R$3.5 billion for operations without Union guarantee. As a result of these limits, we may have difficulty in obtaining financing from financial institutions and other institutions authorized to operate by the Brazilian Central Bank, which could create difficulties in the implementation of our investment program. Additionally, some of our concession contracts have provisions that limit our permitted level of indebtedness, which could also affect our ability to obtain necessary financing. Furthermore, the requirements and other criteria adopted by financial institutions when approving new financing transactions may be related to certain Brazilian macroeconomic scenarios, as well as to our financial indicators, such as our indebtedness levels and other indicators usually considered by financial institutions in their credit risk assessments. We cannot ensure you that these requirements and criteria will be met. As a result of these regulations and provisions, our capacity to incur debt from certain sources is limited, which could negatively affect the implementation of our investment program.

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Breach of security of our data center by cyber attacks, or unauthorized disclosure of business or personal information, as well as our failure to comply with existing and future laws and regulations relating to data privacy and data security, may subject us to penalties or result in disruption of our operations.

We collect, store, process and use various confidential information related to our business and operations. In our ordinary course of business, we also collect and store personal data of our customers in our data centers.

Despite our security measures, our information technology and infrastructure may be vulnerable to (i) attacks by hackers, which can access our safety net and steal our information, paralyze our operations or even cause power outages, or (ii) breaches due to employee error, malfeasance or other disruptions. Any such breach could compromise our networks and the information stored there could be accessed, publicly disclosed, lost or stolen. Any such access, disclosure or loss of information could affect our operations and could result in legal claims or proceedings under Brazilian laws that protect the privacy of personal information (among others) and damage our reputation.

Aware of the increased risk of cyber threat, the Information Technology Superintendence carried out important measures during 2019, such as contracting intrusion testing services and maturity measurement services, seeking effective actions to reduce the Company's risks of such matter. The planning resulting from these measures became the Information Security Plan, which will be carried out during 2020, comprising several initiatives, the most significant of which are: (i) contracting Pentest services on a quarterly basis; (ii) implementation of a Security Operation Center (“SOC”) (Centro de Operação de Segurança); (iii) implementing IT actions to comply with Brazilian Federal Law No. 13,709/2018; (iv) review and update of the Information Security Incident Management and Response process; (v) adequacy of firewall security policies at Copel - Internet use by its users; (vi) strengthening of the Information Security Committee; and (vii) implementation of an Information Security awareness and training program.

Brazilian Federal Law No. 13,709/2018 (known as Lei Geral de Proteção de Dados Pessoais, or the “LGPD”) was enacted on August 14, 2018 and applies to any data processing operation performed by an individual or by a public or private entity, regardless of the environment where this operation is carried out. This statute provides the legal principles and requirements for the processing of personal data, as well as liabilities and penalties that data processing agents are subject to. These agents must be able to demonstrate the measures they adopted to comply with personal data protection rules, as well as the effectiveness of such measures. This statute is expected to come into force in August 2020, and, by then, all entities subject to it, including us, will be required to adapt their data processing activities to the new requirements. As a result of any violations to this statute, including any leakage of our clients’ personal data, we may be subject to penalties, such as (i) warning, with indication of a term for adoption of corrective measures; (ii) simple fine of up to 2% of the Company’s revenue in Brazil, limited to R$50 million per infringement; (iii) daily fine, limited to R$50 million per infringement; (iv) disclosure of the infringement after it has been duly confirmed; and (v) elimination of the personal data to which the infringement relates. These penalties may only be imposed as a result of an administrative proceeding, where we must be given the opportunity to present our defense, in accordance with the peculiarities of the case. These administrative sanctions can be imposed in addition to any other applicable civil and criminal penalties.

As of the date hereof, Bill No. 1179/2020 and No. 1198/2020 (the “Data Privacy Bills”), which provide, respectively, for the emergency and transitory legal regimes of the private sector during the coronavirus (COVID-19) crisis are under discussion by the Congress. The Data Privacy Bills are being considered in the context of measures entered into in response to the coronavirus (COVID-19) international health crisis, including Legislative Decree No. 06 which recognizes a state of public calamity in Brazil. The Data Privacy Bills also include, among others, an amendment to article 65 of the LGPD on timing of applicable sanctions. A revision of the LGPB is expected to go effective on January 1st, 2021 and the revised sanctions set forth therein shall be applicable starting August 2021

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We have engaged an external consulting firm to assist us in adapting our internal processes, proceedings, rules and controls to the new rules on data protection (especially the LGPD), and this process is still ongoing. As cyber threats continue to evolve, we may be required to expend additional resources to continue to modify or enhance protective measures or to investigate and remediate any security vulnerabilities that are discovered in the future.

If we are unable to conclude our investment program on schedule, the operation and development of our business could be adversely affected.

In 2020, we plan to invest approximately R$865.2 million in our generation and transmission activities (including wind farms and SPCs of transmission lines), R$1,073.8 million in our distribution activities, R$123.9 million in our telecommunications activities and R$24.3 million in others investments. Our ability to complete this investment program depends on multiple factors, including our ability to charge sufficient fees for our services and to obtain sufficient financing and a variety of regulatory and operational contingencies. There is no assurance that we will have the financial resources to complete our proposed investment program, and our inability to do so may adversely affect the operation and development of our business leading to the imposition of fines levied by ANEEL as well as a reduction in tariff levels.

The construction and expansion of our transmission and power generation projects involve significant risks that may have an adverse effect on us

In connection with the development of transmission and generation projects, we generally must obtain feasibility studies, governmental concessions or authorizations, permits and approvals, condemnation agreements, equipment supply agreements, engineering, procurement and construction contracts, sufficient equity and debt financing and site agreements, each of which involves the consent of third parties over which we have no control. In addition, project development is subject to environmental, engineering and construction risks that can lead to cost overruns, delays and other impediments to timely complete within a project’s budget. We cannot assure you that all required permits and approvals for our projects will be obtained, that we will be able to secure private sector partners for any of our projects, that we or any of our partners will be able to obtain adequate financing for our projects or that financing will be available on a non-recourse basis to us.

If we are unable to complete a project, whether at the initial development phase or after construction has commenced, or if the completion of a project is delayed, this may decrease our expected financial return from the project, which may lead to impairment. If we experience these or other problems relating to the expansion of our electricity transmission and power generation capacity, we may be exposed to increased costs, or we may fail to achieve the revenues we planned in connection with such expansion projects, which may have an adverse effect on our financial condition and results of operations.

We are largely dependent upon the economy of the State of Paraná.

Our distribution market for the majority of our sales of electricity is located in the State of Paraná. Although a more competitive market involving possible sales to customers outside Paraná might develop in the future, our business depends and is expected to continue to depend to a very large extent on the economic conditions of Paraná. We cannot assure you that economic conditions in Paraná will be favorable to us in the future. The GDP (gross domestic product) of the State of Paraná decreased 0,4% in 2019, while Brazil’s GDP increased 1.1% during the same period.

The weak economic growth of Brazil in recent years led to the reduction of energy consumption in the State of Paraná and in Brazil as a whole, resulting in leftover energy in the interconnected system, consequently reducing (i) short-term prices and (ii) prices negotiated in the Free Market. At the same time, prices in the regulated market have risen steadily as a result of supply deficiencies on the part of contracted energy by distributors and high prices in the short-term market in previous years. As a result, consumers consistently migrated into the Free Market and, therefore, the distributors’ captive market suffered a reduction since 2017, 2018 and 2019.

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On December 28, 2018, the MME enacted the Ministerial Ordinance No. 514, lowering the minimum energy amounts that consumers may purchase directly in the Free Market so that as of January 1, 2020 the minimum energy amount was reduced from an amount equal or superior to 2,500kW to 2,000 kW. Such ordinance was amended in December 2019 by Ministerial Ordinance No. 465/2019, which authorized consumers’ access to the Free Market in accordance with the following schedule and thresholds: (i) as from January 1, 2021: consumers with demand equal to or greater than 1,500 kW; (ii) from January 1, 2022: consumers with demand equal to or greater than 1,000 kW; and (iii) January 1, 2023: consumers with demand of 500 kW or more. Furthermore, by January 31, 2022, ANEEL and Electric Energy Trading Chamber (Câmara de Comercialização de Energia Elétrica, or “CCEE”) are required to consider which regulatory changes are necessary to allow access to the Free Market by consumers with an electric load lower than 500 kW. As a consequence of the changes introduced by Ministerial Ordinance No. 514/2018 and 465/2019, more consumers were authorized to access the Free Market as of January 1, 2020, and it is expected a greater migration to the Free Market following the new schedule proposed by the MME. Even though this ordinance intend to enable the migration from the captive market to the Free Market, we cannot predict their impact on our revenues and possible contractual exposure regarding the limits of energy purchase.

A reduction in the captive market often leads to distributors selling excess contracted energy in the short-term market, considering the limits established under Federal Decree No. 5,163/2004. This short-term market is subject to relevant price fluctuations. Whenever the distributor contracting price is above the regulatory limits (above 105%) and the short-term market price is lower than the price paid by the distributor in its long-term energy purchase agreement, the sale of energy in the short-term market is made at a loss, which may not be recovered in the future. However, the sale within the regulatory limits (between 100% to 105%) is neutral for the Company, in other words, it does not expose the distributor to financial risks.

Unfavorable economic conditions in the State of Paraná and increasing energy prices may affect both the ability of our distribution costumers to pay amounts they owe us, as well as increase the number of our commercial losses. An increase in our commercial losses or uncollected receivables could materially adversely affect our business, financial condition and results of operations.

An increase in electricity prices, as well as poor economic performance in the State of Paraná, would affect the ability of some of our distributions customers to pay amounts owed to us. As of December 31, 2019, our past due receivables with Final Customers were approximately R$667.3 million in the aggregate, or 10.4% of our net operating revenues from electricity sales to Final Customers for the year ended December 31, 2019, and our allowance for doubtful accounts related to these receivables was R$219.0 million. See Note 7 to our audited consolidated financial statements.

In addition, in the event of an economic recession combined with high energy prices, the number of our distribution customers connecting illegally to our distribution grid may increase, which would then decrease our revenue from electricity sales to Final Customers. Furthermore, energy we lose to these illegal connections is considered a commercial loss (non-technical), and we may incur regulatory penalties if our commercial losses exceed certain established regulatory thresholds calculated by ANEEL. If ANEEL determines that we were not efficient in inspecting and controlling the non-technical losses in the distribution grid, the agency may limit the transfer of such losses to the Final Customers.

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

The operation of complex electricity generation, transmission and distribution systems and networks involves various risks, such as operational setbacks and unexpected interruptions, caused by accidents, breakdown or failure of equipment or processes, performance below expected levels of availability and efficiency of assets, or disasters (such as explosions, fires, natural phenomena, landslides, sabotage, vandalism, and similar events). In addition, operational decisions by authorities responsible for the electricity network, environment matters, operations and other issues affecting the electricity

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generation, transmission or distribution could have an adverse effect on the performance and profitability of the operations of our generation, transmission and distribution systems. If these issues occurred, our insurance may be insufficient to wholly account for the costs and losses that we may incur as a result of the damages caused to our assets, or due to outages.

Further, the revenues that our subsidiaries generate from establishing, operating and maintaining their facilities are related to the availability of equipment and assets, and to the quality of the services (continuity and service in accordance with levels demanded by regulations). Under the related concession contracts, we and our subsidiaries are subject to: (i) a reduction of the distributor revenue as a result of the reduction of the so-called “Portion B” allocation in the revenue calculation formula; (ii) a reduction of the Permitted Annual Revenue - APR (Receita Anual Permitida, or RAP), for the transmission companies; (iii) the effects of the Availability Factor (Fator de Disponibilidade, or FID) and the offtake guarantee levels for the generation facilities; and (iv) the application of penalties and payment of compensation amounts, depending on the scope, severity and duration of non-availability of the services and equipment. Under Brazilian Law, we are strictly liable for direct and indirect damages resulting from the inadequate supply of electricity such as abrupt interruptions arising from the generation, transmission or distribution systems. Therefore, outages or stoppages in our generation, transmission and distribution facilities, or in substations or networks, may cause a material adverse effect on our business, financial situation and results of operations.

We are subject to risks related to social and environmental impacts of our projects.

The construction and operation of our assets may modify the ecosystem, particularly the natural state of the water resources and of the vegetation of the flooded river basin in the case of hydroelectric power plants. Our projects may cause direct and indirect impacts in the local communities, such as housing displacement. Moreover, they may affect the economic outputs of the local communities, lead to the loss of cultural identity or increase the demand for government services. In these eventualities, we may implement specific plans in order to minimize and mitigate those impacts.

Failures in dams under our responsibility may cause serious damages to the affected communities, to our results and to our reputation.

Dams are important infrastructures to our business, and are fundamental components of our hydroelectric power plants for the purposes of diking and storing water, accounting for the majority of our energy generation capacity. However, in any dam, there is an intrinsic risk of ruptures caused by different internal or external factors. Therefore, we are subject to the risk of a dam failure that could have repercussions much greater than just the loss of hydroelectric power generation capacity. A dam failure may result in economic, social, regulatory and environmental damages and potential loss of human life in the communities downstream from the dams, which may have a material adverse effect in the image, business, operational results and financial conditions of the Company.

ANEEL carried out on-site inspections in 2019 to verify the regulatory compliance of the Dam Safety Plans and Emergency Action Plan of the hydroelectric power plant dams, including the inspection of the dams and structures associated with them. The inspections demonstrated compliance of the procedures in relation to dam safety practices with the current applicable legislation.

In 2019, Copel also had meetings with state and municipal civil defense coordinating teams with respect to the Emergency Action Plans (“PAEs”), which support the preparation of the Municipal Contingency Plans. Fifteen meetings were held with the Civil Defense coordinators of 28 Municipalities and with coordinators of the State Civil Defense.

We are exposed to behaviors that are incompatible with our ethical and compliance standards, and we may be unable to prevent, detect or remediate them in time, which may cause material adverse effects in our operational results, financial condition and reputation.

We have a range of internal rules and controls, including a Governance, Risk and Compliance Office, with the aim to guide our directors, officers, managers, employees and third-party contractors, and

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to reinforce our ethical principles and rules of professional conduct. However, due to the wide distribution and outsourcing of the production chains of our suppliers, we are not able to control all possible irregularities of the latter and we are not able to ensure that our selection processes will be sufficient to avoid that our suppliers have problems related to compliance with applicable law, sustainability or outsourcing of the production chain under inadequate safety conditions.

Furthermore, we are subject to the risk that our directors, officers, managers, employees, contractors or any person that may do business with us may involve themselves in fraudulent activities, corruption or bribery, circumventing our internal controls and procedures, misappropriating our assets or using them for private benefit to the detriment of the Company’s interests. We are also subject to the risk that any other material violations of applicable laws by our directors, officers, managers, employees, or any person that may do business with us, or any material legal or administrative proceeding, arbitration or investigation in connection with those violations, may adversely affect our reputation. These risks are increased by the fact that our portfolio includes affiliated companies, such as special purpose companies, some of which we do not hold a controlling interest in.

Although the Company has an integrity program with timely updates, with a robust process for investigating complaints, our systems may not be effective in all circumstances. Any failure in our capacity to prevent or detect noncompliance with the applicable governance rules or regulatory obligations may cause damages to our reputation or other material adverse effects to our results of operation or financial condition.

The rules for electricity trading and market conditions may affect the sale prices of electricity.

Our energy trading business is strongly affected by regulatory changes that impact the methodology used for short term energy price formation.

We perform trading activities through power purchase and sale agreements, mainly in the Free Market, through our generation and trading companies. Agreements in the Free Market may be entered into with other generation and trading entities and mainly with Free Customers.

Energy trading is affected by changes in the methodology used to calculate energy price in the short-term (Preço de Liquidação de Diferenças, or PLD). PLD is currently determined by the results of optimization models of operation of the interconnected systems used by the ONS (Operador Nacional do Sistema Elétrico) and by CCEE. In such determination, there may be data entry errors or errors in the model, which may lead to an unexpected change of the PLD and possible future republications of the PLD. Thus, there is a risk for the commercial business with respect to the alteration of these models, data entry errors and republishing of the PLD, which may cause market uncertainty, reduction of liquidity, and financial losses with unexpected price variation. CCEE is expected to implement a new calculation model for the PLD as of January 2021, which will consider an hourly base in the energy price.

Additionally, any change in the energy trading rules related to the increase of restrictions for the entry of new consumers in the Free Market may affect the expansion of our energy trading business.

On December 28, 2018, the MME enacted the Ministerial Ordinance No. 514, lowering the minimum energy amounts that consumers may purchase directly in the Free Market, so that as of January 1, 2020 the minimum energy amount was reduced to from an amount equal or superior to 2,500kW to 2,000 kW. Even though this ordinance enabled more migration from the captive market to the Free Market, we cannot predict its effect. As a Free Costumer is responsible for contracting its own consumption directly with a generation or trading company, an increase of the number of Free Customers may increase the trading in the Free Market and consequently affect energy prices. In parallel, distribution companies may face energy contract surpluses and have to participate in the Mechanism for Compensation of Surpluses and Deficits (Mecanismo de Compensação de Sobras e Déficits, or MCSD) to mitigate financial losses.

Our energy trading companies, Copel Comercialização and Copel GeT, that operate in the Free Market may decide, based on market conditions, to operate in long and short positions and may present financial losses for certain periods. To operate in long positions means that we buy electricity that will be delivered to us only in the future and sell it before the delivery is due, expecting the price to go up in the short-term market. To operate in short positions means that we sell electricity that needs to be delivered

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only in the future, but buy it before the delivery is due expecting the price to go down in the short-term market.

We assess the market exposure risk of our commercialization company on a weekly basis, based on risk limits and methodology approved by the board of directors of Copel. Our methodology for calculating the risk of market exposure was developed internally using financial market concepts.

Our management has identified a material weakness in our internal controls over impairment of fixed assets of Copel Telecomunicações and UEGA

Our management assesses the effectiveness of our controls framework and reporting procedures in accordance with SEC rules, including the effectiveness of our internal controls over financial reporting. This analysis adopts the criteria established in the Internal Control - Integrated Framework (2013) published by the Committee of Sponsoring Organizations of the Treadway Commission – COSO.

In the context of this assessment, our management identified a material weakness in our 2019 internal controls over assumptions and calculation of impairment of fixed assets of both Copel Telecomunicações, a wholly-owned subsidiary of Copel, and UEGA, an entity controlled by Copel.

Although we have developed plans and actions to remedy this material weakness, we cannot assure you that there will be no other weaknesses in our internal control in the future.

Our affiliated companies may not be successful in their businesses.

There is no assurance that our investments in affiliated companies will have the expected outcome. Our activities and financial and operational conditions may be affected as a result of (i) regulatory, economic, environmental matters, among other issues, or (ii) corporate disputes.

The lack of equipment and workforce in the appropriate timeframe may affect our business.

We cannot assure that the equipment and services hired from third parties will be timely delivered. If they are delivered with delay, we may incur in additional costs and fines.

The services and equipment hired from third parties may not have the expected quality.

Being a mixed capital publicly-held company, the acquisition of equipment, materials and services are subject to Paraná State Law No. 15,340/2006, Brazilian Federal Law No. 13,303/2016 and Brazilian Federal Law No. 8,666/1993, when applicable. Therefore, we are legally obliged to engage a bidding process, which may not guarantee the best quality of services, equipment and materials.

Our wind farms’ operations are subject to climate factors and to uncertainties related to the speed of wind and non-compliance with minimum performance covenants set forth in our authorization agreements may adversely impact our results.

The authorization agreements that govern our power generation activities in wind farms set forth certain performance covenants, which require us to generate minimum amounts of energy on annual and four-year bases in accordance with the energy amounts sold in the correspondent auctions. The operations of our wind farms are subject to climate factors and to uncertainties related to the speed of wind and non-compliance with the above mentioned agreements may adversely impact our results.

We may acquire other companies in the electric sector or new energy concessions, as we already did in the past, which may increase our financial leverage and adversely affect our consolidated performance.

We constantly prospect for businesses that are related to our corporate purpose and aligned with our strategic plan. To expand our business, we may participate in auctions for the construction and operation of new power generation and transmission ventures, as well as invest in other companies from the energy sector, as we have done in the past. These acquisitions can increase our financial leverage or reduce our profits. In addition, the integration of the new businesses may not result in the synergy we expect in terms of efficiency gains and economies of scale for our operations, which may adversely affect our operational and financial performance.

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Strikes, work interruptions or other events carried out by our employees or by the employees of our suppliers or contractors, may adversely affect our operating results and our businesses.

Our employees are represented by unions. Disagreements regarding issues related to divestitures, changes to our business strategy, and reductions in the professional staff may lead to employee reactions. Strikes, work interruptions, or other forms of protests in any of our major suppliers or contractors or at their facilities may undermine our ability to complete relevant projects on time, negatively impacting our results of operations, and affect our ability to achieve long-term strategic goals.

Risks Relating to the Brazilian Electricity Sector and Other Sectors that We Operate

We are uncertain as to the renewal of certain of our generation and transmission concessions.

Under Federal Law No. 12,783/2013, or the 2013 Concession Renewal Law, we may only renew our concessions that were in effect as of 1995 (and, in the case of generation facilities, generation concession contracts entered into prior to 2003) for an additional 30-year period (or an additional 20-year period in the case of thermal plants), if we agree to amend the terms of the concession contract that is up for renewal to reflect certain new terms and conditions imposed by the 2013 Concession Renewal Law, which vary depending on whether the concession is for generation, transmission or distribution. If we do not agree to amend the concession contract to reflect these new conditions, the concession contract cannot be renewed and will be subject to a competitive bidding process upon its expiration, which we might not win. If we do not renew our generation and transmission concessions or if they are renewed under less favorable conditions, our financial condition and results of operations could be materially adversely affected. For more information, see “Item 4. Information on the Company—Concessions”.

The concession agreement of our controlled company Compagas is under discussion with the granting authority.

Compagas has entered into a concession agreement with the State of Paraná, as granting authority, pursuant to which the concession shall expire on July 6, 2024. The purpose of this concession is to provide piped gas distribution services and other related activities, to all segments of the consumer market, either as raw material or for the purpose of power generation or other uses made possible by technological advances.

The gas concession agreement is part of the so called “bifurcated model”, where part of the investments made by the concessionaire is paid by the users of the public service and the remaining part is indemnified by the granting authority, the State of Paraná, at the end of the concession.

On December 7, 2017, the State of Paraná enacted Complementary Law No. 205, setting forth a new interpretation regarding the expiration date of the concession, leading to the understanding that the new expiration date was January 20, 2019. The management of Compagas, its controlling shareholder and other shareholders are analyzing and questioning the effects of such law, as they understand that these effects are not consistent with the terms set forth in the current concession agreement.

Compagás filed a lawsuit challenging the early termination of the concession and, on October 30, 2018, a preliminary injunction was granted, which can be subject to an appeal by the State of Paraná. The Company is awaiting the trial of the merit of the case.

Therefore, in the event of non-extension of the concession, even if Compagas is entitled to compensation for the investments made in the last 10 years prior to the end of the concession, the financial condition and results of operations of our controlled company may be adversely affected. For more information see Note 2.1.1 to our audited consolidated financial statements.

Our operating results depend on prevailing hydrological conditions, which have been volatile recently. The impact of water shortages and resulting measures taken by the government to conserve energy may have a material adverse effect on our business, financial condition and results of operations.

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We are dependent on the prevailing hydrological conditions throughout Brazil and in the geographic region in which we operate. According to data from ANEEL, approximately 64.0% of Brazil’s installed capacity currently comes from hydroelectric generation facilities. Hydrological conditions in our region, and Brazil in general, are frequently subject to changes because of non-cyclical deviations in average rainfall.

From 2012 to 2015, Brazil experienced a period of low rainfall. Poor hydrological conditions could lead the Brazilian government to institute a rationing program, which would require that our distribution business distribute less energy to Final Customers. Our distribution business would be adversely affected by a mandatory rationing program because its revenues are partially based on the volume of electricity it provides through our distribution grid to Final Customers. However, a mandatory rationing program involves a predictable decrease in energy, which would allow our distribution business to better estimate the amount of electricity it must purchase in order to sell to Final Customers. In addition, in the context of a formal rationing program, our distribution business would be fully compensated for the amount of energy that it purchased prior to the rationing period in excess of the amount of energy it is allowed to distribute under the rationing program, through automatic adjustment in its energy supply contracts.

In contrast, the Brazilian federal government in the past has reacted to poor hydrological conditions not by implementing a formal rationing program, but rather by seeking to reduce the consumption of electricity by Final Customers by other means, for example through general conservation campaigns to raise public awareness. The effect of these campaigns is less predictable, making it difficult for our distribution business to accurately estimate the volume of energy it needs to purchase for sale to Final Customers. Furthermore, in the absence of a formal rationing program, our distribution business is not compensated for the amount of energy it had previously contracted that now exceeds the newly-depressed Final Customer demand. Even after a conservation or rationing program ends, it may take several years for demand by Final Customers to fully recover, if at all. Deteriorating hydrological conditions may, therefore, have a material adverse effect on our distribution business.

In 2014 and 2015 the Brazilian Federal Government provided and facilitated various forms of assistance to distribution concessionaires experiencing cash flow difficulties arising from poor hydrological conditions, which had increased their energy acquisitions costs thereby resulting in mismatches of cash flow in the short-term. These forms of assistance included funding from the CDE Account (as defined below), credit facilities contracted by the CCEE through the ACR Account and the new “Bandeira Tarifária” system. There is no assurance that the Federal Government will continue this assistance, or that the Federal Government will continue it on favorable terms or that it will be sufficient to cover our losses. See “Item 4. Information on the Company—The Brazilian Electric Power Industry—Energy Sector Regulatory Charges—CDE” and “Item 4. Information on the Company—Energy Sector Regulatory Charges— Regulated Market Account—ACR Account”.

With respect to our generation business, in order to compensate for poor hydrological conditions and to maintain adequate water levels in reservoirs, the ONS may order the reduction of generation from hydroelectric power plants, which would be partially compensated by increased generation by thermoelectric plants. This mechanism for replacing hydroelectric production with thermoelectric production may not provide all of the energy we need to fulfill our obligations under existing energy supply contracts. To compensate for this deficit, our generation business can be required to purchase energy in the Spot Market, typically at higher prices, and we would not be able to pass on these increased costs. This mechanism impacts all generation companies in Brazil regardless of whether the geographical region in which a specific generator is located is experiencing low rainfall, and could have a material adverse effect on our generation business.

The Generation Scaling Factor, or GSF, is a factor used to adjust the guaranteed power output and represents the ratio between the total power produced by the hydroelectric plants that integrate the Energy Reallocation Mechanism (Mecanismo de Realocação de Energia, or MRE) and their guaranteed power outputs. This represents, on average, the amount of energy committed to energy generation contracts. If there are excessively low flow rates, the GSF equals to less than 1 and the hydroelectric

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generators that contracted their guaranteed power outputs have to incur additional costs to acquire energy in the Spot Market to fulfill their obligations. As Brazil experienced an unusually severe drought between 2012 and 2015, its energy generation was below its expected levels.

In 2015, the financial effects of the GSF on the generation companies were discussed. There was a broad sector debate on the effects of, and solutions for the GSF from an administrative, regulatory, business and legal perspective. Accordingly, Law No. 13,203, dated December 8, 2015, and ANEEL Resolution No. 684, dated December 11, 2015, established the criteria for the approval and the conditions for the renegotiation of the hydrological risks borne by certain hydroelectric generation companies. Pursuant to such new rules, the generators could share their hydrologic risks with consumers, through the payment of a “risk premium”. Copel Geração e Transmissão and Elejor filed a request for the renegotiation of the hydrological risk of HPPs Mauá, Foz do Areia, Santa Clara and Fundão, which was consented through ANEEL Decisions No. 84/2016 and 43/2016, respectively. Subsequently, in 2017 Copel Geração e Transmissão filed another request for the renegotiation of the hydrological risk of HPPs Cavernoso II e Baixo Iguaçu, which was consented through ANEEL Decision No. 4,101/2017, and, in 2018, ANEEL approved the renegotiation of the hydrological risk of HPP Colíder through ANEEL Decision No. 2,889/2018. For more information, see Note 14.1 to our audited consolidated financial statements.

In addition, in an extreme scenario, given the increased presence of thermal generation in the national electric matrix, if a shortage of natural gas were to occur, this would increase the general demand for hydroelectric energy in the market and therefore increase the risk that a rationing program would be instated.

Regarding our energy trading business, the effect of volatility in hydrological conditions is the increase of the variation of energy price, which in turn increases the Spot Market volatility, thus affecting our operating results.

Spot price (PLD) is determined by mathematical models that consider the prevalence of hydroelectric plants in the Brazilian generation context, hydrological conditions, energy demand, fuel prices, deficit costs, the entry of new projects and the availability of generation and transmission equipment, and aim to find an optimal balance between the present benefit of water usage and the future benefit of its storage, measured in terms of the expected economy of the fuels in thermoelectric plants. The energy average prices in the short term ("spot") are calculated by CCEE every week and are set for each region.

When there is great availability of hydrological resources, the spot price tends to remain at lower levels, which may not be enough to (i) cover the generation costs of this very same energy (when related to our generation business) and (ii) cover the cost of the power purchase and sale agreement in our energy trading business.

Conversely, if hydrological availability is affected, spot prices tend to increase significantly, in addition to occasionally impacting the GSF, which may adversely impact our costs of energy purchases, as the price set forth in power purchase and sale agreements may not be sufficient.

The construction, expansion and operation of our generation, transmission and distribution facilities and equipment involve significant risks that may cause the loss of revenues or increase of expenses.

The construction, expansion and operation of our generation, transmission and distribution of electricity facilities and equipment involve many risks, including the inability to obtain required governmental permits and approvals, supply interruptions, strikes, climate and hydrological interference, unexpected environmental and engineering problems, increase in losses of electricity (including technical and commercial losses), the unavailability of adequate financing and the unavailability of equipment.

In the event we experience these or other problems, we might not be able to generate, transmit and distribute electricity in favorable quantities and on favorable terms, which may adversely affect our financial condition and the results of our operations.

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ANEEL could penalize us for failing to comply with the terms of our concessions or with applicable laws and regulations, and we may not recover the full value of our investment in the event that any of our concessions are terminated.

Our concessions are for terms of 20 to 35 years and may be extended if certain conditions are met. In the event that we fail to comply with any term of our concessions or applicable law or regulation, ANEEL may impose penalties on us, which may include warnings, the imposition of potentially substantial fines (in some instances, up to 2% of our revenues from concessions in the twelve-month period preceding any infraction notice or, in case of independent production, the estimated amount of energy produced in the same period) and restrictions on our operations, among others. ANEEL may also terminate our concessions prior to the expiration of their terms if we fail to comply with their provisions or if they determine that terminating our concessions would be in the public interest, in both cases through an expropriation proceeding. In particular, our renewed distribution concession agreement contains both quality and financial metrics that become more restrictive over time, and that we must meet to ensure that our distribution concession agreement is not terminated. If ANEEL terminates any of our concessions before its expiration, we would not be able to operate the segment(s) of our business that had been authorized by the concession. Furthermore, any compensation that we may receive from the federal government for the unamortized portion of our investment may not be sufficient for us to recover the full value of our investment. The early termination or non-renewal of any of our concessions or the imposition of severe fines or penalties by ANEEL could have a material adverse effect on our financial condition and results of operations. See “Item 4. Information on the Company—The Brazilian Electric Power Industry—Concessions”.

Our operating revenues could be adversely affected if ANEEL makes decisions relating to our tariffs that are unfavorable to us.

The tariffs that we charge for sales of electricity to Captive Customers are determined pursuant to a concession agreement with the Brazilian government through ANEEL. ANEEL has substantial discretion to establish the tariff rates we charge our customers, which are determined pursuant to a concession agreement with ANEEL and in accordance with ANEEL’s regulatory decision-making authority.

It is also incumbent upon ANEEL to determine the revenues to be charged by the generating companies, holding assets with renewed concession agreements or resulting from concessions auctions (both cases in accordance with 2013 Concession Renewal Law). The Annual Generation Revenue (“RAG”) is the amount which the generating companies are entitled to in accordance with the physical guarantee of a hydroelectric plant that is allocated to the regulated/quota market. RAG is calculated taking into account the regulatory costs of operation, maintenance, administration, compensation and amortization of the hydroelectric plant, being adjusted annually, in addition to being reviewed every 5 years.

Our distribution concession agreement and Brazilian law establish a price cap mechanism that permits three types of tariff adjustments: (i) annual adjustment (reajuste anual), (ii) periodic revision (revisão periódica), and (iii) extraordinary revision (revisão extraordinária). We are entitled to apply each year for the annual adjustment, which is designed to offset some effects of inflation on tariffs and pass through to customers certain changes in our cost structure that are beyond our control, such as the cost of electricity we purchase from certain sources and certain other regulatory charges, including charges for the use of transmission facilities. In addition, ANEEL carries out a periodic revision every five years that is aimed at identifying variations in our costs as well as setting a factor based on our operational efficiency that will be applied against the index of our ongoing annual tariff revision, the effect of which is to ensure that we share the benefits of improved economies of scale with our customers. At any time, we may also request an extraordinary revision of our tariffs in the case of a significant and unexpected event, including if such an event significantly alters our cost structure.

As is the case for distribution companies, the regulation mechanisms for transmission companies are the tariff review, which occurs every five years, and the annual tariff readjustment, which is a

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monetary adjustment of the tariffs charged. These mechanisms depend on the concession agreement of each company. At the time of the tariff review, the objective of ANEEL is to recalculate the costs for the efficient operation and maintenance of the system managed by the transmission company.

We cannot assure you that ANEEL will establish tariffs at rates that are favorable to us. To the extent that any of our requests for adjustments are not granted by ANEEL in a timely manner, our financial condition and results of operations may be adversely affected. In addition, ANEEL’s decisions relating to our tariffs may be contested by public authorities or by our customers. Administrative and judicial decisions resulting from these challenges may modify ANEEL’s decisions in a manner that is unfavorable to us, which may adversely affect our financial condition and results of operations.

We are subject to comprehensive regulation of our business, which fundamentally affects our financial performance.

Our business is subject to extensive regulation by various Brazilian legal and regulatory authorities, particularly the MME and ANEEL, which regulate and oversee various aspects of our business and establish our tariffs. Changes to the laws and regulations governing our operations, which have occurred in the past, could adversely affect our financial condition and results of operations.

For example, the Brazilian government has taken action to reduce tariffs in recent years. In order to substantially reduce the price paid by Final Customers for electricity, the Brazilian government enacted the 2013 Concession Renewal Law, which significantly changed the conditions under which concessionaires are able to renew concession contracts. Under the 2013 Concession Renewal Law, most generation, transmission and distribution concessionaires may be renewed at the request of the concessionaire for an additional period of 30 years, but only if the concessionaire agrees to amend the terms of the concession contract to reflect certain new terms and conditions. For more information, see “Item 4. Information on the Company—Concessions”.

If any further regulations or new laws are passed by the Brazilian government to lower electricity prices, these new laws and regulations could have a material adverse effect on our results of operations. If we are required to conduct our business in a manner substantially different from our current operations as a result of regulatory changes, our results of operations and financial condition may be adversely affected.

The regulatory framework under which we operate is subject to legal challenge.

The Brazilian government implemented fundamental changes in the regulation of the electric power industry under the 2004 legislation known as the New Industry Model Law (Lei do Novo Modelo do Setor Elétrico). Challenges to the constitutionality of New Industry Model Law are still pending before the Brazilian Supreme Court. If all or part of this statute were held to be unconstitutional, it would have uncertain consequences for the validity of existing regulation and the further development of the regulatory framework. The outcome of the legal proceedings is difficult to predict, but they could have an adverse impact on the entire energy sector, including our business and results of operations.

Certain customers in our distribution concession area may cease to purchase energy from our distribution business.

Our distribution business generates a large portion of its revenues by selling energy that it purchases from generation companies. Large electricity customers within the geographic area of our concession that meet certain regulatory requirements may qualify as free customers (“Free Customers”). A Free Customer in our distribution concession area is entitled to purchase energy directly from generation and energy trading companies rather than through our distribution business, in which case that Free Customer would cease to pay our distribution business for that energy that we previously supplied. Therefore, if the number of Free Customers within the geographic area of our concession increases and to the extent these Free Customers purchase energy from sources other than our generation and trading companies, our revenues and results of operations would be adversely affected. Furthermore, prices in the

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Free Market have recently been lower than those in the regulated market in the past years, which has been leading to an increase in the number of Free Customers within the geographic area of our concession.

In addition, ANEEL has recently improved regulations related to micro and mini distributed generation, which has been facilitating customers to purchase or to lease power generation equipment, especially solar photovoltaic modules, to produce energy for their own consumption. Therefore, if the number of customers with micro and mini distributed generation within the geographic area of our concession increases, our revenues and results of operations could also be adversely affected.

We generate a portion of our operating revenues from Free Customers who may seek other energy suppliers upon the expiration of their contracts with us.

As of December 31, 2019, we had 425 Free Customers, representing approximately 5.7% of our consolidated operating revenues and approximately 13.8% of the total volume of electricity sold by us.

Regarding our energy trading company, as of December 31, 2019, our energy trading company had 375 Free Customers, representing approximately 8.3% of our consolidated operating revenues and approximately 5.5% of the total volume of electricity we sold in 2019.

Without the addition of new contracts in 2019, Copel GeT had 50 Free Costumers on December 31, 2019. Approximately 17.67% of the megawatts-hours sold under contracts to such customers by Copel GeT expired in 2019. These customers represented approximately 4.88% of the total volume of electricity we sold in 2019, and approximately 4.09% of total net operating revenue from energy sales for that year. Our contracts with Free Customers are typically for periods ranging between two years and five years in our generation business. There can be no assurance that Free Customers will enter into contracts or extend their current contracts to purchase energy from us.

Additionally, it is possible that our large industrial clients could be authorized by ANEEL to generate electric energy for their own consumption or sale to other parties, in which case they may obtain an authorization or concession for the generation of electric power in a given area, which could adversely affect our results of operations.

We may be forced to purchase or sell energy in the Spot Market at higher or lower prices if our forecasts for energy demand are not accurate, if there is a shortage of energy supply available in the regulated market or if energy we contract is not delivered, and we may not be entitled to pass on any increased costs or incurred losses to our Final Customers in a timely manner, or at all.

Under the New Industry Model Law, electric energy distributors, including us, must contract, through public bids conducted by ANEEL, 100% of the forecasted electric energy demand for their respective distribution concession areas. The auctions in which the distributors are allowed to purchase energy are held up to seven years prior to the actual delivery of electric energy. We cannot guarantee that our forecasts for energy demand in our distribution concession area will be accurate. If our forecasts fall short of actual electricity demand, or if we are unable to purchase energy through the regulated market due to lack of energy supply in the market, or if a generation company fails to deliver energy that was previously contracted, we may be forced to make up for the shortfall by entering into short-term agreements to purchase electricity in the Spot Market where we may pay significantly more for energy without being able to pass on these increased costs to our Final Customers. In addition, if we underestimate our distribution energy needs, we may be subject to penalties imposed by the CCEE. Moreover, if our forecasts surpass actual demand by more than the allowed margin (105% of actual demand), including where demand is depressed due to government campaigns in response to poor hydrological conditions or due to reduced economic activity, we will not be able to pass on to our Final Customers the cost of the excess energy that we acquire.

In 2016, as a consequence of the country’s economic crisis and the increase in the number of Free Customers who were attracted by lower prices in the Free Market, several distribution companies, including Copel Distribuição, were contracted above 105% of their actual demand. As a result, those

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companies may incur losses due to sale of the excess energy at lower prices in the Spot Market. On the other hand, facing this same scenario in 2017, Copel Distribuição and other distribution companies sold the surplus energy at a higher price in the Spot Market, resulting in the possibility of earnings. On August 28, 2017, Brazilian Decree No. 9,143/2017 recognized the involuntary nature of energy surplus arising from the migration of consumers to the Free Market. However, we cannot guarantee the results of such rules and their impact on our future operations.

In 2018, purchases made by Copel Distribuição did not exceed the regulatory margin of 105% of the forecasted energy amount. Even though Copel Distribuição plans on adopting the same strategies onwards, we cannot ensure you that it will be able to comply with the regulatory requirements in the future.

In 2019, although Copel Distribuição maximized its efforts to manage the surplus of contracting energy, the supply and demand scenarios point out to the occurrence of contracting above the regulatory limits, in the order of 105.8%. However, considering that this situation arises mainly from the migration of consumers to the Free Market, it is considered that the distributor maintains the guarantee of energy surplus tariff’s pass-through, since this factor is subject to the recognition of involuntary over-contracting. Although the regulator does not recognize involuntary exposure for amounts above the regulatory limit, this surplus is not a loss for the distributor, since in 2019 the spot price was above the average purchase price of energy.

We are subject to a counterparty’s credit risk, and, in case the purchasers or sellers that are parties to power purchase and sale agreements entered into with Copel Comercialização default on their obligations, we may have to sell or purchase energy at a different base price.

Copel Comercialização is subject to a counterparty’s credit risk. When Copel Comercialização sells energy, the counterparties to power purchase agreements may default on their contractual obligations, which may cause Copel Comercialização to sell energy at a different base price. In cases where Copel purchases energy, whether from energy generation projects, in operation or under construction, or even from energy trading, the selling counterparties may also default on the relevant contracts, and, consequently, Copel Comercialização may have to buy energy at a different base price and be subject to regulatory penalties imposed by CCEE due to insufficient contractual guarantees. Even though the Company performs credit analyses in accordance with market standards and requires its counterparties to provide guarantees in connection with the power purchase and sale agreements, we cannot guarantee that our counterparties will not fail to comply with their payment obligation or with their obligation to deliver energy to Copel, as the case may be, which may adversely affect our results.

We are subject to the risk of exchange rate variation if we start to perform energy import business, as well as if we perform business involving natural gas

Our subsidiary Copel Comercialização obtained authorization from the Ministry of Mines and Energy to import energy from neighboring countries, Argentina and Uruguay, and if we start doing business in this regard, we will be subject to the risk of exchange rate fluctuation.

This subsidiary was also authorized by the National Agency of Petroleum, Natural Gas and Biofuels to operate in the sale of natural gas within Brazil. Although the natural gas business still has an incipient market in Brazil, if we do business in this area, we will be subject to the risk of exchange rate variation, considering that these transactions are carried out in foreign currencies.

We are subject to unrealized losses or net gains arising out from the mark-to-market of the purchase and sale of energy contracts, which may expose the Company to the risk of future energy prices

Our subsidiary Copel Comercialização negotiates energy purchase and sale transactions, and part of its agreements are classified as derivative financial instruments measured at fair value through its results. Unrealized net losses or gains resulting from the mark-to-market of these contracts (difference

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between contracted prices and market prices) are recognized in the results of the fiscal year. This activity may expose the Company to the risk of future energy prices.

Our equipment, facilities and operations are subject to numerous environmental and health regulations, which may become more stringent in the future and may result in increased liabilities and increased capital expenditures.

Our distribution, transmission and generation activities are subject to comprehensive federal, state and local legislation, as well as supervision by Brazilian governmental agencies that are responsible for the implementation of environmental and health laws and policies. These agencies could take enforcement action against us for our failure to comply with their regulations and with requirements established for the maintenance of our environmental licenses. These actions could result in, among other things, the imposition of fines, embargoes and revocation of licenses, which could have a material adverse effect on our financial condition and results of operations. It is also possible that enhanced environmental and health regulations will force us to allocate capital towards compliance, and consequently, divert funds away from planned investments. Such a diversion could have a material adverse effect on our financial condition and results of operations.

We are strictly liable for any damages resulting from inadequate provision of electricity services and our insurance policies may not fully cover such damages.

We are strictly liable under Brazilian law for damages resulting from the inadequate provision of electricity distribution services. In addition, our distribution, transmission and generation utilities may be held liable for damages caused to others as a result of interruptions or disturbances arising from the Brazilian generation, transmission or distribution systems, whenever these interruptions or disturbances are not attributed to an identifiable member of the National Electric System Operator, the Operador Nacional do Sistema Elétrico (“ONS”). We cannot assure you that our insurance policies will fully cover damages resulting from inadequate rendering of electricity services, which may have an adverse effect on us.

We are the controlling shareholders of a company that operates a gas distribution business (Compagas) and we are consequently exposed to risks inherent to this sector.

We control a business in the gas distribution sector, which is operated by Companhia Paranaense de Gas – Compagas. This company is entitled to exclusive rights with respect to the supply of piped gas in the State of Paraná. The clients of this business are thermoelectric plants, cogeneration plants, gas stations, other companies and residences.

Businesses in the gas distribution sector are subject to a broad set of risks inherent to its operation, including among the main ones:

• Regulatory instability,

• Shortage of natural gas,

• Depending on a single supplier in Brazil,

• Capacity of financing expansion,

• Operational failures and accidents in distribution,

• Performance of outsourced service providers,

• Alternative energy sources,

• Quality in service.

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As a result of these uncertainties, there is no guarantee that the purposes of our gas distribution business will be achieved, which may have an adverse effect on our results of operations and our business.

We are the controlling shareholders of a company that operates a telecommunications business (Copel Telecomunicações S.A.) and we are consequently exposed to the risks inherent to this sector.

We control a business in the telecommunications sector under an authorization granted by the National Telecommunications Agency (Agência Nacional de Telecomunicações – ANATEL). This business provides telecommunications services through the use of fiber optics. It also provides a number of telecommunications services to other companies of the Copel group.

Businesses in the telecommunications sector are subject to a broad set of risks inherent to its operation, such as:

• Regulatory instability,

• Increase in competition,

• Technological changes,

• Capacity of financing our expansion,

• Failures in technological systems and information security,

• Performance of outsourced service providers,

• Exchange rate fluctuations,

• Variation in operating costs,

• Operational failures,

• Quality in service.

As a result of these uncertainties, there is no guarantee that the purposes of our telecommunications business will be achieved, which may have an adverse effect on our results of operations and our business.

If it is not possible to implement our proposal to divest control of Copel Telecomunicações S.A., we will need to reevaluate our strategy in the telecommunications sector

Considering that the process of potential divestment in the control of the subsidiary Copel Telecomunicações SA is in progress, as approved by the Board of Directors, this process may not be materialized, either due to the lack of interested parties, due to judicial decisions or restrictions imposed by regulatory bodies or other governmental entities. Failure to complete such sale may force us to reevaluate our divestment strategy in the telecommunications sector.

We are uncertain as to the outcome of the administrative proceeding brought by ANATEL against Sercomtel S.A. Telecomunicações to terminate concessions and authorizations previously awarded to this company and also on the success of a new privatization attempt, in a way that we may be adversely affected considering the financial capacity of that company

We own 45% of the stock of Sercomtel Telecomunicações S.A. (“Sercomtel”). Sercomtel holds a concession to provide fixed telephony services and an authorization to provide mobile services in the

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municipalities of Londrina and Tamarana, located in the State of Paraná. In addition, Sercomtel has two (2) other authorizations from ANATEL that allow it to provide fixed telephony and broadband internet services in all other municipalities of the State of Paraná. Currently, Sercomtel operates with its own network in fifteen (15) municipalities of the State of Paraná, providing voice services and fixed broadband.

In September 2017, ANATEL determined that Sercomtel was not in compliance with certain financial indicators set forth by the agency in connection with the concessions granted to Sercomtel and required for the company’s operations to continue. As a consequence of this determination, ANATEL brought an administrative proceeding against Sercomtel to assess whether the concession and the authorizations granted to this company should be terminated. In March 2019, ANATEL decided to suspend the above mentioned proceeding for a 120-day period, so that Sercomtel could present to the agency alternative plans for meeting the relevant regulatory indicators.

In June 2019, the municipal legislature of Londrina approved the sale of the stake held by the Londrina City Hall as the controlling shareholder of Sercomtel (Municipal Law no 12.871, dated June 12, 2019). In November 2019, the City Hall published the bidding notice for the privatization process of Sercomtel, which provides for the assignment of the City Hall’s preemptive right to subscribe shares in a future capital increase of Sercomtel. This process can result in the dilution of the stake held by the City Hall and Copel in Sercomtel. However, a bid for the sale of such preemptive rights was scheduled for February 5, 2020, and no participants attended. We understand that alternative procedures are under consideration by Sercomtel’s controlling shareholder for the company. Considering the uncertainties regarding company's financial capacity to maintain the normality of its operations, including commitments to customers and suppliers, we may be adversely affected if Sercomtel's services are impaired, even if partially. In case a new attempt for the privatization of Sercomtel is not successful, or if ANATEL determines the termination and forfeiture of the licenses held by Sercomtel, we can be adversely affected in view of our stake in Sercomtel’s capital stock.

We cannot assure the speed of our innovation capacity and our responses in view of the changes the energy sector has been going through as a result of technology advances.

The electric energy sector has been going through changes driven by (i) the decentralization of the power generation systems; (ii) advances in energy storage technologies; (iii) dissemination of digital technologies that improve the efficiency of energy generation, transmission and consumption; (iv) increase of renewable energy sources, such as wind and solar energy; and (v) a tendency of reducing carbon footprints in the energy system, as part of the global efforts to mitigate the effects of climate change. These changes present many challenges and we may not be able to keep up with the effects of the increasing adoption of digital technologies in the electric energy sector and the significant potential of new technology solutions (both with respect to the improvement of processes and services provided to consumers and with respect to the development of new products that may lead to higher productivity gains, more affordable prices, higher competition and the creation of new markets). Investments in research and development may contribute to mitigate the risks related to the transformations of the energy sector and create new opportunities.

Risks Relating to Brazil

The Brazilian Government has significant influence over the Brazilian economy. Brazilian economic and political conditions— and investor perception of these conditions— have a direct impact on our business, financial condition, results of operation and prospects.

Historically, the country’s political situation has influenced the performance of the Brazilian economy, and political crises have affected the confidence of investors and the general public, which resulted in economic deceleration, the downgrading of credit ratings of the Brazilian government and Brazilian issuers, and heightened volatility in the securities issued abroad by Brazilian companies.

Additionally, the Brazilian government has exercised, and continues to exercise, significant influence over the Brazilian economy and often changes monetary, credit, exchange and other policies to influence Brazil’s economy. Our business, financial condition, results of operations and prospects may be

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adversely affected by changes in government policies, as well as other factors including, without limitation:

• fluctuations in the exchange rate;

• inflation;

• changes in interest rates;

• exchange control policies;

• fiscal policy and changes in tax laws;

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

• controls on capital flows; and/or

• limits on foreign trade.

In the last few years, Brazil faced a mild economic growth, adverse fiscal developments and political instability. Brazilian GDP grew by 1,1% in 2019, grew by 1.1% in 2018 and grew by 1.3% in 2017. Unemployment rate was 11.9% in 2019, 11.6% in 2018 and 12.7% in 2017. Inflation, as reported by the consumer price index (IPCA), was 4.31% in 2019, 3.75% in 2018 and 2.95% in 2017. The Brazilian Central Bank’s base interest rate (SELIC) was 4.5% on December 31, 2019, 6.5% on December 31, 2018 and 7.00% on December 31, 2017. Future economic, social and political developments in Brazil may impair our business, financial condition or results of operations, or cause the market value of our securities to decline.

Changes in, or uncertainties regarding the implementation of, the policies above, might generate or contribute to uncertainties in the Brazilian economy. This would increase the volatility of the domestic capital market and the value of Brazilian securities traded abroad, and adversely affect our business, results of operations and financial condition.

Moreover, taking into account the Brazilian presidential system of government, and the considerable influence of the executive power, it is not possible to predict whether the present government or any successive governments will have an adverse effect on the Brazilian economy, and consequently on our business.

The effects of the coronavirus (COVID-19)outbreak and the strong expectation of lower growth, zero growth, or even a recession in some economies, including the Brazilian Economy, may negatively affect our operations and results

The performance of the Brazilian economy may be directly affected by lower or zero-level worldwide economic growth or an economic recession caused by the coronavirus (COVID-19) pandemic. The results of Copel’s operations are directly related to the performance of the Brazilian economy.

On March 24, 2020, ANEEL issued ANEEL Resolution No. 878 establishing measures to preserve public electricity distribution services during the coronavirus (COVID-19) pandemic. These measures include, inter alia, ANEEL prohibitions on suspension of electricity supply by distribution companies due to lack of payment with respect to specific categories of services including (i) essential services and activities, (ii) limited autonomy equipment, (iii) low-income residencies, and (iv) locations with no operational collection posts.

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The Federal Government also enacted a number of measures in response to the coronavirus (COVID-19) pandemic, including but not limited to:

| · | Provisional Measure No. 950/2020, which provides for temporary emergency measures for the electricity sector, including (i) establishing a discount of 100% for low-income residential consumers with electricity consumption below or equal to 220 kWh/month for the period from April 1, 2020 to June 30, 2020, and (ii) charging a tariff to revert to electricity distributors.

Provisional Measure No. 950/2020 does not apply nor is it expected to apply to free market energy services contracts. Copel may suffer an impact on collections due to reductions in contracted volumes, or the postponement of the expiration of customers' electricity bills.

| · | Provisional Measures No. 927/2020 which provides for emergency labor and public health related measures; and

| · | Provisional Measures No. 936/2020 which institutes the Emergency Program for Employment and Income Maintenance and provides for additional emergency labor and public health related measures.

States throughout Brazil have also imposed operational impediments (both commercial and industrial) that directly impact Copel’s operations. Particularly with respect to the State of Paraná, on April 23, 2020, the State government enacted Law No. 20,187/2020 prohibiting providers from cutting power to (i) low-income families, (ii) costumers of age 60 and above or that have been diagnosed with coronavirus (COVID-19) or other serious or infectious diseases or that have disabilities; (iii) informal workers; and (iv) entrepreneurs classified as micro and small companies or individual micro-entrepreneurs.

With regards to the captive distribution market, Copel may experience in the near term (i) a significant reduction in revenue and collection from energy supply chains, (ii) defaults of large high voltage customers, and (iii) defaults of commercial class clients. In the medium term, Copel negative impacts may extend to other customer classes, especially residential ones.

A possible increase in payment defaults by residential consumers, coupled with the decrease in collection and the standstill of several commercial and industrial activities resulting from social isolation measures can adversely affect the financial and economic results involving the activities of the electricity sector, mainly the electricity distributors. Eventually, with the decrease in energy consumption, the Company may be in a position above the permitted regulatory limit for overcontracting electricity.

Copel has followed the load projections issued by official bodies in the electricity sector, which already show signs of retraction in 2020, strongly impacted by the drop in consumption in the commercial and industrial segments. This fall has caused notifications by energy buyers, under the perspective and allegation of unforeseeable circumstances and force majeure generated by the coronavirus (COVID-19) pandemic, requiring a reduction in the amounts of energy contracts and/or installments of defaulted bills.

Both the projections of PLD and GSF for the remainder of 2020 already show a significant decrease in light of the coronavirus (COVID-19) pandemic. Adverse impacts of the coronavirus (COVID-19) pandemic can also be felt on the implementation of generation and transmission projects, or on the availability of existing assets resulting from local actions, preventing access to facilities or problems with suppliers in the sector, also affected by the coronavirus (COVID-19) pandemic.

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To the extent the government does not adopt a joint solution for the energy sector as a means to control or remove a systemic risk, the Company may suffer, among other impacts, cash damages, decreases in its profitability and the impossibility of performing certain operational activities.

The Brazilian government may propose or enact either temporary or permanent changes to its tax policies in 2020. We are continuously assessing the impact of any new proposed changes on our applicable tax rate and planning and will continue to monitor any changes and their related impact on us.

The Company has established a Contingency Committee in light of the coronavirus (COVID-19) pandemic with the objective of monitoring and mitigating current and futures impacts and consequences in the Company’s activities. The Contingency Committee has four main focus objectives: (i) people’s safety, (ii) continuation of essential activities of the Company, (iii) monitoring guidelines and requirements of regulatory bodies, and (iv) preservation of adequate financial conditions to support the crisis. The Company has also continuously been (A) monitoring the impacts of the pandemic on (i) its contracts and (ii) the liquidity of the energy market and its short-term pricing, as well as (B) involved and negotiating with the relevant authorities for the implementation of guidelines that guarantee the maintenance of the economic and financial sustainability of Brazil’s electricity power generation, transmission, commercialization and distribution chain.

Fluctuations in the value of the Brazilian real against foreign currencies may result in uncertainty in the Brazilian economy and the Brazilian securities market, which could have a material adverse effect on our net income and cash flow.

In recent years, the Brazilian real has fluctuated in value against foreign currencies, and the value of the real may rise or decline substantially from current levels. Over the course of 2015, the value of the Brazilian real declined more than 48% against the U.S. Dollar. In contrast, in the course of 2016, the Brazilian real appreciated 16.5% against the U.S. Dollar, following a year of intense volatility. In 2017, the Brazilian real was subject to relative stability. As of December 31, 2019, the real vs. U.S. dollar exchange rate recorded was R$4.03 to US$1.00, depreciating 4.0% against the U.S. Dollar, compared to the exchange rate recorded on December 31, 2018. Depreciation of the real increases the cost of servicing our foreign currency-denominated debt and the cost of purchasing electricity from the Itaipu – a hydroelectric facility which is one of our major suppliers and adjusts its electricity prices based in part on its U.S. dollar costs. Depreciation of the real also creates additional inflationary pressure in Brazil that may negatively affect us. Indeed, depreciation generally curtails access to international capital markets and may prompt government intervention. It also reduces the U.S. dollar value of our dividends and the U.S. dollar equivalent of the market price of our common shares and the ADSs.

Inflation and governmental measures to curb inflation may contribute to economic uncertainty in Brazil, and could reduce our margins and the market price of the Class B Shares and ADSs.

Brazil has in the past experienced extremely high rates of inflation. More recently, Brazil’s annual rates of inflation, measured in accordance with the variation of the Índice Geral de Preços - Disponibilidade Interna (“IGP-DI”) index, were 1.75% for the three-month period ended March 31, 2020, 7.7% in the year 2019, 7.1% in the year 2018, (0.4)% in the year 2017 and 7.2% in 2016. The Brazilian government has in the past taken measures to combat inflation, such as raising the basic Selic interest rate to elevated levels, and public speculation about possible future government actions has had significant negative effects on the Brazilian economy. Although our concession contracts provide for annual adjustments based on inflation indexes, if Brazil experiences substantial inflation in the future, and the Brazilian government adopts inflation control policies similar to those adopted in the past, our costs may increase faster than our revenues, our operating and net margins may decrease and, if investor confidence lags, the price of the Class B Shares and ADSs may fall. Inflationary pressures may also curtail our ability to access foreign financial markets and could lead to further government intervention in the economy, including the introduction of government policies that may adversely affect the overall performance of the Brazilian economy.

Allegations of political corruption against the Brazilian federal government and the Brazilian legislative branch could create economic and political instability.

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Currently, several former and current members of the Brazilian executive and legislative branches of government are being investigated as a result of allegations of unethical and illegal conduct identified by the Operation Car Wash (Operação Lava-Jato) being conducted by the Office of the Brazilian Federal Prosecutor, and a number of politicians and businessmen have been arrested. The potential outcome of these investigations is unknown, but they have already had an adverse impact on the image and reputation of the investigated companies, in addition to adversely impacting general market perception of the Brazilian economy, including our business, financial condition and results of operations, as well as the trading price of our common shares and ADSs. Moreover, the conclusion of these proceedings or further allegations of illicit conduct could have additional adverse effects on the Brazilian economy. We cannot predict whether such allegations will lead to further instability or whether new allegations against key Brazilian government officials will arise in the future. In addition, we cannot predict the outcome of any such allegations and their effect on the Brazilian economy.

Changes in Brazilian tax policies may have an adverse effect on us and our shareholders.

The Brazilian government has in the past changed its tax policies in ways that affect the electricity sector, and it may do so again in the future. These changes include increases in the tax rates affecting energy companies and, occasionally, the collection of temporary taxes related to specific governmental purposes. If we are unable to adjust our tariffs accordingly, we may be adversely affected.

There are also bills under discussion at the National Congress of Brazil that may change the way in which taxes are collected in Brazil, including the collection of income tax on dividends, which may adversely affect our shareholders.

In 2020, in response to the global spread of the coronavirus (COVID-19) virus and the resulting disruptions to financials markets and business operations, the Brazilian government has proposed or enacted changes to its tax policies that include both temporary and permanent changes. The impact of these new rules on us and on our effective tax rate and tax planning is not yet clear.

Negative developments in other national economies, especially those in developing countries, may negatively impact foreign investment in Brazil and the country’s economic growth.

International investors generally consider Brazil to be an emerging market. Historically, adverse developments in the economies of emerging markets have resulted in investors’ perception of greater risk from investments in such markets. Such perceptions regarding emerging market countries have significantly affected the market value of securities of Brazilian issuers. Furthermore, although economic conditions are different in each country, investors’ reactions to developments in one country can impact the prices of securities in other countries, including those in Brazil, and this may diminish investors’ interest in securities of Brazilian issuers, including ours.

Risks Relating to the Class B Shares and ADSs

As a holder of ADSs, you will generally not have voting rights at our shareholders’ meetings.

In accordance with Brazilian Corporate Law and our bylaws, holders of the Class B Shares, and thus of the ADSs, are not entitled to vote at our shareholders’ meetings except in limited circumstances. That means, among other things, that you, as a holder of the ADSs, are not entitled to vote on corporate transactions, including any proposed merger.

In addition, in the limited circumstances where the holders of Class B Shares are entitled to vote, holders may exercise voting rights with respect to the Class B Shares represented by ADSs only in accordance with the provisions of the deposit agreement relating to the ADSs. There are no provisions under Brazilian Corporate Law or under our bylaws that limit ADS holders’ ability to exercise their voting rights through the Depositary with respect to the underlying Class B Shares. However, the procedural steps involved create practical limitations on the ability of ADS holders to vote. For example, holders of our Class B Shares will be able to exercise their voting rights by either attending the meeting in

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person or voting by proxy. In accordance with the Deposit Agreement, we will provide the notice to the Depositary, which will in turn, as soon as practicable thereafter, mail to holders of ADSs the notice of such meeting and a statement as to the manner in which instructions may be given by holders. To exercise their voting rights, ADS holders must then instruct the Depositary how to vote their shares. Because of this extra procedural step involving the Depositary, the process for exercising voting rights will take longer for ADS holders than for direct holders of Class B Shares. ADSs for which the Depositary does not receive timely voting instructions will not be voted.

As a holder of ADSs, you will have fewer and less well-defined shareholders’ rights in Brazil than in the United States and certain other jurisdictions.

Our corporate affairs are governed by our bylaws and Brazilian Corporate Law, which may differ from the legal principles that would apply if we were incorporated in a jurisdiction in the United States or in certain other jurisdictions outside Brazil. Under Brazilian Corporate Law, you and the holders of the Class B Shares may have fewer and less well-defined rights to protect your interests in connection with actions taken by our Board of Directors or the holders of Common Shares than under the laws of the United States and certain other jurisdictions outside Brazil.

Although Brazilian law imposes restrictions on insider trading and price manipulation, the Brazilian securities markets are not as highly supervised as the United States securities markets or markets in certain other jurisdictions outside Brazil. For instance, rules and policies against self-dealing and regarding the preservation of minority shareholder interests may be less developed and not as robustly enforced in Brazil as in the United States and certain other jurisdictions outside Brazil, which could potentially disadvantage you as a holder of the preferred shares and ADSs. In addition, shareholders in Brazilian companies must hold 5% of the outstanding share capital of a corporation in order to have standing to bring shareholders’ derivative suits, and shareholders in Brazilian companies ordinarily do not have standing to bring a class action suit.

You may be unable to exercise preemptive rights relating to the preferred shares.

You will not be able to exercise the preemptive rights relating to the Class B Shares underlying your ADSs unless a registration statement under the Securities Act, is effective with respect to those rights or an exemption from the registration requirements of the Securities Act is available. Therefore, the Depositary will not offer rights to you as a holder of the ADSs unless the rights are either registered under provisions of the Securities Act or are subject to an exemption from the registration requirements. We are not obligated to file a registration statement with respect to the shares or other securities relating to these rights, and we cannot assure you that we will file any such registration statement. Accordingly, 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. If you are unable to participate in rights offerings, your holdings may also be diluted.

Sales of a substantial number of shares, or the perception that such sales might take place, could adversely affect the prevailing market price of our shares or ADSs.

As a consequence of the issuance of new shares, sales of shares by existing share investors, or the perception that such a sale might occur, the market price of our shares and, by extension, of the ADSs may decrease significantly.

Future equity issuances may dilute the holdings of current holders of our shares or ADSs and could materially affect the market price for those securities.

We may in the future decide to offer additional equity to raise capital or for other purposes. Any such future equity offering could reduce the proportionate ownership and interests of holders of our shares and ADSs, as well as our earnings and net equity value per share or ADS. Any offering of shares and ADSs by us or our main shareholders, or a perception that any such offering is imminent, could have an adverse effect on the market price of these securities.

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You may not receive dividend payments if we incur net losses or our net profit does not reach certain levels.

Under Brazilian Corporate Law and our by-laws, we must pay our shareholders a mandatory distribution equal to at least 25% of our adjusted net profit for the preceding fiscal year, with holders of preferred shares having priority of payment. According to our bylaws, Class A Shares and Class B Shares are entitled to receive annual, non-cumulative minimum dividends, which dividend per share shall be at least 10% higher than the dividends per share paid to the holders of the Common Shares. Class A Shares have a dividend priority over the Class B Shares, and Class B Shares have a dividend priority over the Common Shares.

If we realize a net profit in an amount sufficient to make dividend payments, at least the mandatory dividend is payable to holders of our preferred and common shares. After payment of the mandatory dividend, we can retain profits as statutory profit reserves for investments or capital reserves. If we incur net losses or realize net profits in an amount insufficient to make dividend payments, including the mandatory dividend, our management may recommend that dividend payments be made using the statutory profit reserve after accounting for the net losses for the year and any losses carried forward from previous years. In the event that we are unable to declare dividends, our management may nevertheless decide to defer payment of dividends or, in limited circumstances, not to declare dividends at all. We cannot make dividend payments from our legal reserve and capital reserve accounts.

Additionally, in accordance with Brazilian Corporate Law, in fiscal years in which the amount of mandatory dividends exceeds the amount of realized net profits, according to the parameters set forth in this law, management may suggest the formation of a reserve for realizable profits. This reserve can be offset with any losses and then used for paying mandatory dividends.

Holders of our ADSs 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 holders of our ADSs to effect service of process upon us or our directors and officers within the United States or other jurisdictions outside Brazil, attach their assets or enforce against us or our directors and officers judgments obtained in the United States or other jurisdictions outside of Brazil. Because judgments of U.S. courts for civil liabilities based upon the U.S. federal securities laws may only be enforced in Brazil if certain requirements are met, holders of ADSs may face greater difficulties in protecting their interest in actions against us or our directors and officers than would shareholders of a corporation incorporated in a state or other jurisdiction of the United States.

Judgments of Brazilian courts with respect to our shares will be payable only in reais.

If proceedings are brought in the courts of Brazil seeking to enforce our obligations in respect of our shares, we will not be required to discharge any such obligations in a currency other than reais (R$). Under Brazilian exchange control limitations, an obligation in Brazil to pay amounts denominated in a currency other than reais (R$) may only be satisfied in Brazilian currency at the exchange rate, as determined by the Central Bank, in effect on the date the judgment is obtained, and any such amounts are then adjusted to reflect exchange rate variations through the effective payment date. The then prevailing exchange rate may not afford non Brazilian investors with full compensation for any claim arising out of, or related to, our obligations under our shares.

If you exchange your ADSs for Class B Shares, you risk increased taxes and the inability to remit foreign currency abroad.

Brazilian law requires that parties obtain a registration before the Central Bank in order to be allowed to remit foreign currencies, including U.S. dollars, abroad. For the ADSs, the Brazilian custodian for the Class B Shares has obtained the necessary certificate from the Central Bank for the payment of dividends or other cash distributions relating to the preferred shares or upon the disposition of the preferred shares. If you exchange your ADSs for the underlying Class B Shares, however, you must obtain your own certificate of registration or register in accordance with Central Bank and CVM rules in

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order to obtain and remit U.S. dollars abroad upon the disposition of the Class B Shares or distributions relating to the preferred shares. If you do not obtain a certificate of registration, you may not be able to remit U.S. dollars or other currencies abroad and may be subject to less favorable tax treatment on gains with respect to the preferred shares. Pursuant to Central Bank rules, obtaining this registration requires exchange transactions, which are subject to taxes in Brazil. For more information, see “Item 10. Additional Information—Taxation—Brazilian Tax Considerations—Other Brazilian Taxes”. If you attempt to obtain your own registration, you may incur expenses or suffer delays in the application process, which could delay your ability to receive dividends or distributions relating to the preferred shares or the return of your capital in a timely manner. The custodian’s registration before the Central Bank and any certificate of foreign capital registration you obtain may be affected by future legislative changes. Additional restrictions may be imposed in the future on the disposition of the underlying Class B Shares or the repatriation of the proceeds from disposition.

The Brazilian government may impose exchange controls and restrictions on remittances abroad which may adversely affect your ability to convert funds in reais into other currencies and to remit other currencies abroad.

In the past, the Brazilian government has imposed restrictions on the remittance to foreign investors of the proceeds of their investments in Brazil and the conversion of Brazilian currency into foreign currencies. The Brazilian government could again choose to impose this type of restriction if, among other things, there is deterioration in Brazilian foreign currency reserves or a shift in Brazil’s exchange rate policy. Reintroduction of these restrictions would hinder or prevent your ability to convert dividends, distributions or the proceeds from any sale of Class B Shares, as the case may be, from reais into U.S. dollars or other currencies and to remit those funds abroad. We cannot assure you that the Brazilian government will not take similar measures in the future.

The relative volatility and illiquidity of the Brazilian securities markets may impair your ability to sell the Class B Shares underlying the ADSs.

The Brazilian securities markets are substantially smaller, less liquid, more concentrated and more volatile than major securities markets in the United States and certain other jurisdictions outside Brazil, and are not as highly regulated or supervised as some of these other markets. The illiquidity and relatively small market capitalization of the Brazilian equity markets may cause the market price of securities of Brazilian companies, including our ADSs and Class B Shares, to fluctuate in both the domestic and international markets, and may substantially limit your ability to sell the Class B Shares underlying your ADSs at a price and time at which you wish to do so.

Instability of the exchange rate could adversely affect the value of remittances of dividends outside of Brazil and also the market price of the ADSs.

Many Brazilian and global macroeconomic factors have an influence on the exchange rate. In this context, the Brazilian federal government, through the Central Bank, has in the past occasionally intervened for the purpose of controlling unstable variations in exchange rates. We cannot predict whether the Central Bank or the federal government will continue to allow the real to float freely or whether it will intervene through a system involving an exchange rate band, or the use of other measures.

As a result, the real might fluctuate substantially in relation to the United States dollar, and other currencies, in the future. That instability could adversely affect the equivalent in US dollars of the market price of our shares, and as a result the prices of our ADSs and also outward dividends remittances from Brazil.

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, preferred ADS and common ADSs.

The market value of the 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

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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 the securities of Brazilian issuers. Crises in other emerging market countries might reduce investors’ interest in the securities of Brazilian issuers, including our Company. In the future, this could make it more difficult for us to access the capital markets and finance our operations 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 program and refinancing our obligations, and this could adversely affect our business, results of operations and financial condition.

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

Law No. 10,833 of December 29, 2003, provides that the disposition 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 disposition occurs outside or within Brazil. This provision results in the imposition of income tax on the gains arising from a disposition of our common or preferred shares by a nonresident 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 dispositions of our ADS between nonresidents of Brazil. However, in the event that the disposition of assets is interpreted to include a disposition of our ADS, this tax law would accordingly result in the imposition of withholding taxes on the disposition of our ADS by a non-resident of Brazil to another non-resident of Brazil.

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Item 4. Information on the Company

The Company1

We engage in the generation, transmission, distribution and sale of electricity mainly in the Brazilian State of Paraná, pursuant to concessions granted by ANEEL, the Brazilian regulatory agency for the electricity sector. We also provide telecommunications and other services. While our activities are more concentrated in the Brazilian State of Paraná, we also operate in 10 different Brazilian states through our generation and transmission businesses.

As of December 31, 2019, we generated electricity from nineteen (19) hydroelectric plants, twenty five (25) wind plants and one (1) thermoelectric plant, for a total installed capacity of 5,742.0 MW, of which, approximately 99.7% is derived from renewable sources. Including the installed capacity of generation companies in which we have an equity interest, our total installed capacity is 6,397.8 MW. Our electric power business is subject to comprehensive regulation by ANEEL.

We hold concessions to distribute electricity in 394 of the 399 municipalities in the State of Paraná and in the municipality of Porto União in the State of Santa Catarina. As of December 31, 2019, we owned and operated 3,389 km of transmission lines and 199,952.6 km of distribution lines, constituting one of the largest distribution networks in Brazil. Of the electricity volume we supplied in 2019 to our Final Customers:

| · | 33.8% was to industrial customers;

| · | 28.1% was to residential customers;

| · | 19.7% was to commercial customers; and

| · | 18.4% was to rural and other customers.

Key elements of our business strategy include the following:

| · | bringing together sustainable growth, profitability, adequate indebtedness levels and allocation of profits;

| · | preparing the Company to go from consumer to client;

| · | seeking profitable opportunities related to new businesses and services in the energy sector;

| · | managing an integrated and strategic energy portfolio, including strategic partnerships and maximizing synergies and profitability;

| · | divesting from non-strategic assets;

| · | maintaining discipline in allocating capital and technical rigor in planning and implementing projects;

| · | achieving the same efficiency standards as the best companies from the energy sector, promoting innovation, investment in technology and optimization of the workforce;

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| · | ensuring and raising levels of corporate sustainability, environmental, governance, risk management and compliance;

| · | developing and implementing a culture based on meritocracy and consequence management towards building high performance teams;

| · | seeking greater protagonism in our interaction with regulators and institutions;

| · | consolidating a culture focused on safety, health and quality of life.

Our revenues for each of the last three (3) financial years by activity are described in “Item 5. Operating and Financial Review and Prospects —Results of operations for the years ended December 31, 2019, 2018 and 2017”.

Historical Background

We were formed in 1954 by the State of Paraná to engage in the generation, transmission and distribution of electricity, as part of a plan to bring the electric energy sector under state control. We acquired the principal private power companies located in the State of Paraná in the early 1970s. From 1970 to 1977, we significantly expanded our transmission and distribution grid and worked to increase the connectivity of our network to networks in other Brazilian states. In 1979, a change in state law permitted us to extend our generating activities to include production from sources other than hydroelectric and thermal power plants.

Currently, we are the largest energy company in the State of Paraná. We are a corporation incorporated and existing under the laws of Brazil, with the legal name Companhia Paranaense de Energia – Copel. Our head offices are located at Rua Coronel Dulcídio, 800, CEP 80420-170 Curitiba, Paraná, Brazil. Our telephone number at the head office is +55 (41) 3331-4011. Our website is www.copel.com and any filings we make electronically with the SEC will be available to the public over the Internet at the SEC’s website. The commercial name of each of our businesses is provided as follows.

Relationship with the State of Paraná

The State of Paraná owns 58.6% of our Common Shares and, consequently, has the ability to control the election of the majority of the members of our Board of Directors, members of our Supervisory Board, the appointment of senior management and our direction, future operations and business strategy.

Corporate Structure

Prior to 2001, we operated as a single corporation engaged in the generation, transmission and distribution of electricity and in certain related activities. In compliance with the new regulatory regime, we transferred our operations to four wholly-owned subsidiaries (one each for generation, transmission, distribution and telecommunications) and our investments in other companies to a fifth wholly-owned subsidiary. This corporate restructuring was completed in July 2001.

In 2007, to comply with energy sector legislation, we divided the assets of our transmission business (“Copel Transmissão S.A.”) between our distribution business (“Copel Distribuição S.A.”) and our generation business, (“Copel Geração S.A.”). As a result, we changed the name of the latter entity to Copel Geração e Transmissão S.A.

In 2013, the Company was restructured in order to enhance the efficiency of our corporate structure and reduce our operating costs.

On January 28, 2016, our board of directors approved the amendment of the bylaws of Copel Participações S.A., in order to change its corporate purpose and denomination to Copel Comercialização S.A. The corporate purpose of this company is the sale of energy and rendering of related services. The

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restructuring that created Copel Comercialização S.A. is aimed at strengthening Copel’s positioning in the energy trading market and to improve its efficiency, allowing for greater agility and flexibility in the sale of energy.

In September 2017, in order to optimize the management of operating activities, the Company carried out an organizational restructuring of its wholly-owned subsidiary Copel Renováveis S.A., whose activities were absorbed by Copel Geração e Transmissão S.A,

On August 30, 2018, Copel GeT signed a Share Exchange Agreement with Eletrosul with respect to the joint ventures Costa Oeste Transmissora de Energia S.A. (51% - Copel GeT and 49% - Eletrosul), Marumbi Transmissora de Energia S.A. (80% - Copel GeT and 20%- Eletrosul) and Transmissora Sul Brasileira de Energia S.A. (20% - Copel GeT and 80% - Eletrosul). Under this agreement, Copel GeT started holding share of interest of 100% in the joint ventures Costa Oeste and Marumbi, in addition Eletrosul started to hold share of interest of 100% in Transmissora Sul Brasileira. The business combinations occurred on August 31, 2018, date of transfer of the shares. For additional information, see Note 1.2 to our audited consolidated financial statements.

In March 2019, Copel GeT signed a purchase and sale agreement with Centrais Elétricas Brasileiras S.A. and Fundação Eletrosul de Previdência e Assistencial Social - Elos to transfer 100% of the shares issued by SPE Uirapuru Transmissora de Energia SA. In June 2019, Copel GeT took over control of the company.

In order to renew the concession of HPP Gov. Bento Munhoz (or HPP Foz do Areia) for another 30 years, Copel incorporated the special-purpose entity SPE F.D.A. Geração de Energia Elétrica S.A. (“FDA”)and, on March 03, 2020, requested the Ministry of Mines and Energy to apply Federal Decree no. 9,271/2018 (as amended by Federal Decree no. 10,135/2019), which conditions the renewal to the sale of the concession's corporate control in up to 18 months before the end of the current concession. On the same date, FDA signed with ANEEL the Brazilian Electricity Regulatory Agency, the Concession Contract that transfers the concession of the HPP Foz do Areia from Copel GeT to FDA, for the exploration of the plant until the end of the current concession, on September 17, 2023.

On October 18, 2019, Copel GeT, through a consortium with its subsidiary Cutia Empreendimentos Eólicos, participated in the A-6 new energy generation auction, having sold 14.4 average MW of the Jandaíra Wind Complex. The Jandaíra Wind Complex, which has 90.1 MW of installed capacity and 47.6 average MW of assured power, will be built in the northeastern state of Rio Grande do Norte, a region where Copel has other wind generation assets.

Copel currently has five wholly-owned subsidiaries, which are Copel Geração e Transmissão S.A., Copel Distribuição S.A., Copel Telecomunicações, Copel Comercialização S.A. and Copel Renováveis S.A.

Copel also holds 100% shareholding stake in several Special Purpose Companies (SPC).

The current organization of the group is as described as follows. All of our subsidiaries are incorporated in the Federative Republic of Brazil and subject to the Brazilian law.

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BUSINESS

In the past, our generation and distribution businesses were integrated, and we sold most of the electricity we generated to the customers of our distribution business. This changed as a result of the implementation of the New Industry Model Law, enacted in 2004. Today, open auctions on the regulated market are still one of the primary channels by which our distribution business purchases energy to resell to Captive Customers and one of the channels by which our generation business generates revenues. Our generation business only sells energy to our distribution business through auctions in the regulated market. Moreover, our distribution business, like other certain Brazilian distribution companies, is also required to purchase energy from Itaipu, in an amount determined by the Brazilian government based on our proportionate share in the Brazilian electricity market. For more information, see “Item 4. Information on the Company—The Brazilian Electric Power Industry”.

The following table shows the total electricity we (i) generated through entities in which we hold a 100.0% shareholding stake and the 51.0% and 30,0% of energy generated by Mauá and Baixo Iguaçu Hydroelectric Plants respectively (corresponding to the interest we hold in each of these assets) and (ii) purchased in the last five years, broken down by the total amount of electricity generated and purchased by Copel Geração e Transmissão and our wind farm generation facilities described below (“Wind Farms”) and the total amount of electricity purchased by Copel Distribuição and Copel Comercialização.

| Year ended December 31,
| 2019 | 2018 | 2017 | 2016 | 2015
| (GWh)
Copel Geração e Transmissão(1) |  |  |  |  |
Electricity generated(2) | 17,199 | 18,029 | 19,583 | 25,319 | 24,494
Electricity purchased from Copel Comercialização | 155 | 180 | 627 | - | -
Electricity purchased from others | 140 | 141 | 428 | 141 | 257
Electricity received from the Interconnected System | 445 | 142 | 425 | 2 | 7
Total electricity generated and purchased by Copel Geração e Transmissão | 17,939 | 18,492 | 21,063 | 25,462 | 24,758
Wind Farms(1) (3) |  |  |  |  |
Electricity generated(2) | 1,912 | 1,067 | 989 | 1,175 | 621
Electricity purchased from others | 61 | - | - | - | 295
Total electricity generated and purchased by Wind Farms | 1,973 | 1,067 | 989 | 1,175 | 916
Copel Distribuição |  |  |  |  |
Electricity purchased from Itaipu(4) | 5,532 | 5,726 | 5,934 | 5,958 | 5,941
Electricity purchased from Auction – CCEAR – affiliates | 153 | 92 | 87 | 157 | 215
Electricity purchased from Auction – CCEAR – other | 12,361 | 10,691 | 9,860 | 13,387 | 14,419
Electricity purchased from others(5) | 8,093 | 9,242 | 10,209 | 10,361 | 8,419
Total electricity purchased by Copel Distribuição | 26,139 | 25,751 | 26,090 | 29,863 | 28,994
Copel Comercialização |  |  |  |  |
Electricity purchased from Copel Geração e Transmissão | 5,124 | 2,422 | 27 | - | -
Electricity purchased from others(5) | 3,331 | 4,101 | 2,644 | 59 | -
Electricity purchased from Spot Market – CCEE | 34 | 2 |  |  |
Total electricity purchased by Copel Comercialização | 8,489 | 6,525 | 2,671 | 59 | -
Total electricity generated and purchased by Copel Geração e Transmissão, Copel Distribuição, Wind Farms and Copel Comercialização | 54,540 | 51,835 | 50,813 | 56,559 | 54,668

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(1) | In 2018, Copel adopted the criteria set forth by the CCEE to determine the energy flows in sale and purchase transactions. The energy amounts reflected in this table, even with respect to past years, were calculated in accordance with the criteria adopted by the CCEE.

(2) | Includes the electrical losses of wiring and interconnecting station and technical losses by delivering energy to the Interconnected System.

(3) | Electricity generated and purchased by our wind farm generation facilities which were under the supervision of Copel Renováveis until 2015. In December 2015, Copel Geração e Transmissão became responsible for the operation of these facilities.

(4) | Distribution companies operating under concessions in the Midwest, South and Southeast regions of Brazil purchase electricity generated by Itaipu.

(5) | These numbers do not include assignments related to the Mechanism for Compensation of Surpluses and Deficits of New Energy (Mecanismo de Compensação de Sobras e Déficits de Energia Nova, or MCSD-EN).

The following table shows the total electricity we sold to Free Customers, Captive Customers, distributors, energy traders and other utilities service providers in the south of Brazil through the Interconnected Transmission System in the last five years.

| Year ended December 31,
| 2019 | 2018 | 2017 | 2016 | 2015
| (GWh)
Copel Geração e Transmissão(1) |  |  |  |  |
Electricity delivered to Free Customers | 4,146 | 3,960 | 3,860 | 3,600 | 3,921
Electricity delivered to Bilateral Agreements (Copel Comercialização) | 5,123 | 2,969 | 27 | - | -
Electricity delivered to Bilateral Agreements | 3,724 | 5,826 | 8,477 | 7,908 | 6,675
Electricity delivered under auction – CCEAR – affiliates(2) | 122 | 92 | 86 | 157 | 215
Electricity delivered under auction – CCEAR – other(2 | 2,215 | 876 | 838 | 3,154 | 4,391
Electricity delivered to Spot Market – CCEE(2) | (594) | 213 | 1,246 | (252) | (640)
Electricity delivered to the Interconnected System | 3,203 | 4,556 | 6,529 | 10,895 | 10,196
Total electricity delivered by Copel Geração e Transmissão | 17,940 | 18,492 | 21,063 | 25,462 | 24,758
Wind Farms(1) (3) |  |  |  |  |
Electricity delivered under auction – CCEAR – affiliates | 31 | - | - | - | -
Electricity delivered under auction – CCEAR – other | 1,288 | 840 | 840 | 842 | 724
Electricity delivered under auction – CER – other | 914 | 334 | 357 | 358 | 337
Total electricity delivered by Wind Farms | 2,233 | 1,174 | 1,197 | 1,200 | 1,061
Copel Distribuição |  |  |  |  |
Electricity delivered to Captive Customers | 19,784 | 19,594 | 19,743 | 22,328 | 24,043
Electricity delivered to distributors in the State of Paraná | 164 | 279 | 521 | 614 | 699
Spot Market – CCEE(4) | 1,319 | 2,401 | 2,510 | 3,611 | 910
Total electricity delivered by Copel Distribuição | 21,267 | 22,274 | 22,774 | 26,553 | 25,652
Copel Comercialização |  |  |  |  |
Electricity delivered to Free Customers | 2,715 | 2,096 | 771 | 58 | -
Electricity delivered to Bilateral Agreements (Copel GeT) | 216 | 180 | 628 | - | -
Electricity delivered to Bilateral Agreements | 5,722 | 4,223 | 1,254 | - | -
Electricity delivered to Spot Market – CCEE | 52 | 26 | 18 | 1 | -
Total electricity delivered by Copel Comercialização | 8,490 | 6,525 | 2,671 | 59 | -
Subtotal | 49,930 | 48,465 | 47,705 | 53,274 | 51,471
Losses by Copel Distribuição and Wind Farms5) | 2,808 | 3,370 | 3,108 | 3,285 | 3,197
Total electricity delivered by Copel Geração e Transmissão, Copel Renováveis, Copel Distribuição and Copel Comercialização, including losses | 52,738 | 51,835 | 50,813 | 56,559 | 54,668

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(1) | In 2018, Copel adopted the criteria set forth by the CCEE to determine the energy flows in sale and purchase transactions. The energy amounts reflected in this table, even with respect to past years, were calculated in accordance with the criteria adopted by the CCEE.

(2) | Amounts indicated as less than zero (negative numbers) refer to the consolidated purchase of electricity from the Spot Market along the year.

(3) | Electricity generated and purchased by our wind farm generation facilities which were under the supervision of Copel Renováveis until 2015. In December 2015, Copel Geração e Transmissão became responsible for the operation of these facilities.

(4) | Includes the MCSD.

(5) | Includes Technical, Non-technical and Basic network losses of Copel Distribuição and losses related to the Wind Farms.

Generation

As of December 31, 2019, considering only the entities in which we hold a 100.0% shareholding stake and 51.0% and 30.0% of the energy generated by Mauá and Baixo Iguaçu Hydroelectric Plants, respectively (corresponding to the interest we hold in each of these assets), we operated and sold energy through nineteen (19) hydroelectric plants, twenty eight (28) wind plants and one (1) thermoelectric plant, with a total installed capacity of 5,560.0 MW. Our assured energy totaled an average of 2,494.9 MW in 2019. Our generation varies yearly as a result of hydrological conditions and other factors. We generated 19,029 GWh in 2019, 19,121 GWh in 2018, 20,891 GWh in 2017, 27,068 GWh in 2016 and 25,960 GWh in 2015.

Considering the installed capacity of all of the generation companies in which we have an interest (equity or otherwise), our total installed capacity as of December 31, 2019, was 6,397.8 MW.

The generation of electrical energy at our power plants is supervised, coordinated and operated by our Generation and Transmission Operation Center in the city of Curitiba. This operation center is responsible for coordinating the operations related to approximately 100% of our total installed capacity, including some of the plants in which we hold only partial ownership interests.

Hydroelectric Generation Facilities

The following table sets forth certain information related to our main hydroelectric plants in operation during 2019:

Plant | Installed capacity | Assured energy (1) | Placed in service | Concession expires
| (MW) | (GWh/yr) |  |
Foz do Areia | 1,676.0 | 5,284.91 | 1980 | September, 2023
Segredo | 1,260.0 | 5,067.66 | 1992 | November, 2029
Salto Caxias | 1,240.0 | 5,305.06 | 1999 | May, 2030
Capivari Cachoeira(2) | 260.0 | 954.84 | 1971 | January, 2046
Mauá | 185.2(3) | 883.24 | 2012 | July, 2042
Baixo Iguaçu | 105,06(4) | 452.89 | 2019 | October, 2049
Colíder | 300 | 1,560.16 | 2019 | January, 2046
Others | 102.7 | 556.30 | N/A | N/A

(1) | Values used to determine volumes committed for sale.

(2) | On January 5, 2016, Copel Geração e Tramissão executed a concession agreement with ANEEL so that it will continue to operate this plant under an operation and maintenance regime until 2046.

(3) | Corresponds to 51.0% of the installed capacity of the plant (361.0 MW), corresponding to the interest we hold in this plant, as we operate this plant through a consortium.

(4) | Corresponds to 30.0% of the installed capacity of the plant (350.2 MW), corresponding to the interest we hold in this plant, as we operate this plant through a consortium.

Governador Bento Munhoz da Rocha Netto (“Foz do Areia” Plant). The Foz do Areia Hydroelectric Power Plant is located on the Iguaçu River, approximately 350 kilometers southwest of the city of Curitiba.

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Copel Geração e Transmissão SA (“Copel GeT”) held the concession for the exploration rights of the Governador Bento Munhoz da Rocha Netto Hydroelectric Power Plant (“UHE GBM”), in accordance with the Concession Agreement No. 045/1999, with the term of such concession until September, 2023. On the occasion of the termination of such concession, it is the Federal Government’s responsibility to launch a new competitive bidding process for UHE GBM 's exploration rights, with wide competition between agents in the sector. Decree 9.271/18 allows the Federal Government to grant a new concession contract for a period of up to 30 years to the winning legal entity of the privatization bidding of a public electricity generation service concessionaire under the control of the States.

The Company carried out studies to analyze the feasibility of becoming the winner in the future bidding process, and in the administrators’ assessment, the appetite of foreign investors represents a high risk for Copel, which may not be sufficiently competitive in the event of more efficient agents, or with lower financial cost for investments.

In this context, Copel GeT incorporated FDA and requested ANEEL for the transfer of the public electricity generation service for the plant in question. The transfer of the concession rights of UHE GBM to FDA took place under the terms of ANEEL Authorization Resolution No. 8,578, of February 11, 2020 and the Concession Contract for Generation of Electricity destined to the Public Service between FDA No. 002/2020.

On March 3, 2020, for the purposes of the provisions of Article 1st §2nd, item II of Decree No. 9.271/2018 (as amended by Decree No. 10.135/2019), Companhia Paranaense de Energia - Copel and Copel Geração e Transmissão S.A. filed a petition with the Ministry of Mines and Energy, through which they expressed their intention to privatize, by means of the sale of FDA’s control, associated with obtaining a Concession Agreement for 30 (thirty) years, counted as from its signing date, for the Governador Bento Munhoz da Rocha Netto Hydroelectric Plant. The petition provided that the privatization bidding, by means of the sale of FDA’s control, will be effected only after the acknowledgement and evaluation of the conditions involved in obtaining the concession rights, especially those related to the payment of the concession rights, in addition to the respective procedures and governance therefore.

Governador Ney Aminthas de Barros Braga (“Segredo” Plant). The Segredo Hydroelectric Power Plant is located on the Iguaçu River, approximately 370 kilometers southwest of the city of Curitiba.

Governador José Richa (“Salto Caxias” Plant). The Salto Caxias Hydroelectric Power Plant is located on the Iguaçu River, approximately 600 kilometers southwest of the city of Curitiba.

Governador Pedro Viriato Parigot de Souza (“Capivari Cachoeira” Plant). The Capivari Cachoeira Hydroelectric Power Plant is the largest underground hydroelectric plant in Southern Brazil. The reservoir is located on the Capivari River, approximately 50 kilometers north of the city of Curitiba, and the power station is located on the Cachoeira River, approximately 15 kilometers from the reservoir.

Our former concession agreement for the Capivari Cachoeira Plant expired on July 7, 2015. Although Copel Geração e Transmissão did not elect to renew the original concession pursuant the 2013 Concession Renewal Law, it participated in the new competitive bidding process and won. On January 5, 2016, Copel GeT executed a concession agreement with ANEEL, allowing it to continue to operate this plant under an operation and maintenance regime until January 5, 2046. We paid a total of R$574.8 million as the signing bonus for this concession and we received an annual generation revenue (AGR) of R$144.1 million from January 5, 2016 to December 31, 2016. This AGR is subject to an annual tariff adjustment. In July 2017, the AGR was adjusted to R$114.1 million for the period from July 2017 to June 2018 pursuant to the ANEEL Resolution No. 2,265/2017, and in 2018 the AGR was adjusted to R$119.2 million for the period from July 2018 to June 2019 pursuant ANEEL Resolution No. 2,421/2018. In 2019 the AGR was adjusted to R$123,7 million for the period from July 2019 to June 2020 pursuant ANEEL Resolution No. 2,587/2019.

The Capivari Cachoeira Plant has 260.0 MW of installed capacity and assured energy of 954.8 GWh/year. Since January 1, 2017, 70.0% of the energy generated by this plant has been allocated in quotas to

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the regulated market. Copel GeT will no longer bear the hydrological risk for the energy allocated in quotas under the MRE associated with the Capivari Cachoeira Plant.

Mauá. The Jayme Canet Júnior Hydroelectric Power Plant (Mauá Plant) is located on the Tibagi River, in the State of Paraná. It was constructed between 2008 and 2012 by Consórcio Energético Cruzeiro do Sul, in which we hold a 51.0% interest and CGT Eletrosul holds the remaining 49.0%. The facility is located approximately 250 kilometers from Curitiba, in the Municipality of Telêmaco Borba.

Colíder Hydroelectric Power Plant has an installed capacity of 300.0 MW and it is located on the Teles Pires River, in the State of Mato Grosso, between the municipalities of Nova Canaã do Norte and Itaúba, with the municipalities of Colíder and Cláudia are also affected by the reservoir. The construction of the plant began in 2011 and the work was totally concluded in 2019. The first generating unit entered commercial operation on March 9, 2019 and the last unit started operating on December 21, 2019.

Baixo Iguaçu Hidroelectric Power Plant has an installed capacity of 350.2 MW and it is located on the Iguaçu River, in the municipalities of Capanema, Capitão Leonidas Marques, Planalto, Realeza and Nova Prata do Iguaçu, State of Paraná. Baixo Iguaçu HPP is the last large energy project planned for the main Iguaçu and it is located around 30 km downstream from Governador José Richa HPP - the Salto Caxias Hydroelectric Power Plant, which is 100.0% owned by Copel. It was constructed by a consortium in which Copel GeT holds a 30% interest and Geração Céu Azul S.A. holds the remaining 70.0%. This power plant became fully operational on April 10, 2019.In addition to our generation facilities, we have ownership interests in several other hydroelectric generation companies as detailed below.

Between 2004 and 2010, we were required by law to retain a majority of the voting shares of any company in which we obtained an ownership interest. Starting in 2010, it became possible for us to hold non-controlling interests in companies.

The following table sets forth information regarding the hydroelectric generation plants in which we had a partial equity interest as of December 31, 2019:

Plant | Installed capacity | Assured energy | Placed in service | Our ownership | Concession expires
| (MW) | (GWh/yr) |  | (%) |
Elejor Facility (Santa Clara, Santa Clara I, Fundão and Fundão I) | 246.5 | 1,229.0 | July, 2005 June, 2006 | 70.0 | May, 2037(1) December, 2032
Dona Francisca | 125.0 | 664.9 | February, 2001 | 23.0 | August, 2033
SHP Arturo Andreoli (Foz do Chopim) | 29.1 | 178.7 | October, 2001 | 35.8 | April, 2030
UHE Baixo Iguaçu | 350.2 | 1,513.72 | April, 2019 | 30.0 | August, 2047

(1) | Elejor Facility adhered on January 14, 2015, with the renegotiation of the hydrological risks, which caused the expiration date to be extended from 2036 to 2037.

Elejor Facility. The Elejor Facility consists of the Santa Clara and Fundão Hydroelectric Power Plants, both of which are located on the Jordão River in the State of Paraná. The aggregate total installed capacity of the units is 246.5 MW, which includes two smaller hydroelectric generation units installed in the same location. Elejor signed a concession agreement with a term of 35 years for the Santa Clara and Fundão plants in October 2001. As of December 31, 2019, we own 70.0% of the common shares of Elejor, and Paineira Participações owns the remaining 30.0%.

Elejor is required to make monthly payments to the federal government for the use of hydroelectric resources, which in 2001 totaled R$19.0 million. This amount is adjusted on an annual basis by the IGP-M Index.

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We had a power purchase agreement with Elejor, which provides that we will purchase all of the energy produced by the Santa Clara and Fundão facilities at a set rate until April 2019, to be adjusted annually in accordance with the IGP-M Index.This agreement was terminated, there was no renewal and Elejor is selling the energy in the Free Market. In 2019, Elejor’s net revenues and net profits were R$218.4 million and R$26.1 million, respectively, while in 2018 its net revenues and net profits were R$293.9 million and R$76.3 million, respectively.

Dona Francisca. We own 23.03% of the common shares of Dona Francisca Energética S.A. (“DFESA”). The other shareholders are Gerdau S.A. with a 51.82% interest, Celesc S.A. with a 23.03% interest and Statkraft S.A. with a 2.12% interest. DFESA Hydroelectric Power Plant is located on the Jacuí River in the State of Rio Grande do Sul. The plant began full operations in 2001. In April 2015, we signed a new ten year power purchase agreement with DFESA, valued at R$17.0 million annually, under which Copel purchases 23.03% of DFESA’s assured energy (proportional to Copel’s stake).

In 2019, DFESA’s net revenues and net profits were R$70.1 million and R$42.8 million, respectively, while in 2018 its net revenues and net profits were R$70.1 million and R$43.8 million, respectively.

SHP Arturo Andreoli (“Foz do Chopim” Hydroelectric Plant). The Foz do Chopim Hydroelectric Plant is located on the Chopim River in the State of Paraná. We own 35.8% of the common shares of Foz do Chopim Energética Ltda., the entity that owns the Foz do Chopim Hydroelectric Plant. Silea Participações Ltda. owns the remaining 64.2%. The operation and maintenance of Foz do Chopim Hydroelectric Plant is performed by Copel Geração e Transmissão S.A. Energy supply agreements were executed at an average tariff of R$220.07/MWh. Foz do Chopim Energética Ltda. also had the authorization to operate Bela Vista SHP, a hydroelectric power plant that is located on the same river and has similar capacity, which was transferred to Bela Vista Geração de Energia S.A. (“Bela Vista Geração”), through the ANEEL’s Authorizing Resolution no. 7.802/2019. In 2019, Foz do Chopim’s net revenues and net profits were R$56.9 million and R$38.9 million, respectively, while in 2018 its net revenues and net profits were R$46.6 million and R$36.9 million, respectively.

Wind Farm Generation Facilities

Since 2013 we have been expanding our energy generation capacity and diversifying our energy matrix through the development of renewable energy sources, like the construction and acquisition of wind farms in the State of Rio Grande do Norte. The following table sets forth certain information relating to our wind farm plants in operation as of December 31, 2019:

Plant | Installed capacity | Assured Power | Placed in Service | Concession Expires
| (MW) | (Average MW) |  |
São Bento Energia | 94.0 | 46.3 |  |
Boa Vista | 14.0 | 6.3 | February, 2015 | April, 2046
Olho d'Água | 30.0 | 15.3 | February, 2015 | May, 2046
São Bento do Norte | 30.0 | 14.6 | February, 2015 | May, 2046
Farol | 20.0 | 10.1 | February, 2015 | April, 2046
Palmas | 2.5 | 0.5 | November, 1999 | September, 2029
Copel Brisa Potiguar Wind Complex | 183.6 | 98.4 |  |
Asa Branca I | 27.0 | 14.2 | August, 2015 | April, 2046
Asa Branca II | 27.0 | 14.3 | September, 2015 | May, 2046
Asa Branca III | 27.0 | 14.5 | September, 2015 | May, 2046
Eurus IV | 27.0 | 14.7 | August, 2015 | April, 2046
Santa Maria | 29.7 | 15.7 | April, 2015 | May, 2047
Santa Helena | 29.7 | 16.0 | May, 2015 | April, 2047

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Ventos de Santo Uriel | 16.2 | 9.0 | May, 2015 | April, 2047
Voltália São Miguel do Gostoso I(1) | 108.0 | 57.1 |  |
Carnaúbas | 27.0 | 13.1 | June, 2015 | April, 2047
Reduto | 27.0 | 14.4 | June, 2015 | April, 2047
Santo Cristo | 27.0 | 15.3 | June, 2015 | April, 2047
São João | 27.0 | 14.3 | June, 2015 | March, 2047
Cutia Empreendimentos Eólicos(2) | 312.9 | 126.2 |  |
Cutia |  |  |  |
Dreen Cutia | 23.1 | 9.6 | December, 2018 | January, 2042
Dreen Guajiru | 21.0 | 8.3 | December, 2018 | January, 2042
Esperança do Nordeste | 27.3 | 9.1 | December, 2018 | May, 2050
GE Jangada | 27.3 | 10.3 | December, 2018 | January, 2042
GE Maria Helena | 27.3 | 12.0 | December, 2018 | January, 2042
GE Paraíso dos Ventos do Nordeste | 27.3 | 10.6 | January, 2019 | May, 2050
Potiguar | 27.3 | 11.5 | December, 2018 | May, 2050
Bento Miguel |  |  |  |
São Bento do Norte I | 23.1 | 9.7 | January, 2019 | August, 2050
São Bento do Norte II | 23.1 | 10.0 | January, 2019 | August, 2050
São Bento do Norte III | 23.1 | 9.6 | April, 2019 | August, 2050
São Miguel I | 21.0 | 8.7 | February, 2019 | August, 2050
São Miguel II | 21.0 | 8.4 | February, 2019 | August, 2050
São Miguel III | 27.3 | 8.4 | February, 2019 | August, 2050

(1) | Copel has a 49.0% interest in Voltália São Miguel do Gostoso .

(2) | In January 2019, São Bento do Norte I, II and III began their commercial operations with 100% of their installed capacity, while the São Miguel I,II and III began their operation with 100% of their installed capacity in February 2019.

São Bento Energia. On February 25, 2015, the four wind farms (Boa Vista, Olho d’Água, São Bento do Norte and Farol) which are part of the São Bento Wind Farm Complex, located in the State of Rio Grande do Norte, began operations. With an installed capacity of 94 MW and assured energy of 46.3 average-MW. In August 2010, 43.7 average-MW of the energy generated at a weighted average price of R$134.40/MWh (annually adjusted by IPCA index) was sold to fifteen distribution concessionaires in ANEEL public auctions. The energy generated by these wind farms is sold through 20-year term contracts.

Copel Brisa Potiguar Wind Complex. On September 15, 2015, Copel concluded the installation of the Brisa Potiguar Wind Complex with an installed capacity 183.6 MW and assured energy of 98,4 average-MW. An assured energy of 57.7 average-MW (from Asa Branca I, Asa Branca II, Asa Branca III and Eurus IV wind farms) was committed under contract to electric power distributors in the alternative energy auction in August 2010 at a weighted average price of R$135.40/MWh (adjusted annually by IPCA inflation index) and an average of 40.7 MW (from WPPs Santa Helena, Santa Maria and Ventos de Santo Uriel) was committed under contract in the 6th Reserve Energy Auction held in August 2011 at a weighted average price of R$101.98/MWh (annually adjusted by the IPCA inflation index). The energy to be generated was sold through 20-year term contracts with payments beginning in April 2015.

Voltália São Miguel do Gostoso I. In June 2014, we negotiated with Voltalia Energia do Brasil Ltda. (Voltalia) the acquisition of a 49.0% interest in the São Miguel do Gostoso I Wind Farm Complex, in the State of Rio Grande do Norte. The São Miguel do Gostoso wind farm complex has 108.0 MW of installed capacity and assured energy of 57.1 average-MW, and its energy was sold in the 4th Reserve Energy Auction at an average price of R$98.92/MWh through 20-year term contracts. In April 2015, we concluded the construction of this wind farm complex and ANEEL, in July and August 2015, classified it as ready for commercial operation. This wind farm complex began production in June 2017 after completion of the necessary transmission lines.

Cutia. Cutia Empreendimentos Eólicos, which is Copel’s largest wind farm business, is divided into two large complexes totaling 312.9 MW of installed capacity: (a) Cutia Complex, composed of seven wind

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farms (Guajiru, Jangada, Potiguar, Cutia, Maria Helena, Esperança do Nordeste and Paraíso dos Ventos do Nordeste), with a total installed capacity of 180.6 MW, 71.4 average MW of physical guarantee and located in the State of Rio Grande do Norte; and (b) Bento Miguel Complex, composed of six wind farms (São Bento do Norte I, São Bento do Norte II, São Bento do Norte III, São Miguel I, São Miguel II and São Miguel III) with 132.3 MW of total installed capacity, 58.7 average MW of physical guarantee and located in the State of Rio Grande do Norte, in the same region of other wind farm complexes that belong to us. On October 31, 2014, at the 6th Reserve Energy Auction, we sold 71.2 average MW from the Cutia Complex for R$144.00/MWh (maximum auction price). In addition, at the 20th New Energy Auction (A-5), held on November 28, 2014, we sold 54.8 average MW from the six Bento Miguel wind farms for R$136.97/MWh, through Availability Agreements with a 20-year term.

In December 2018, the wind farms of Cutia, Guajiru and Esperança do Nordeste, all part of the Cutia Complex, began their operations with 100% of their installed capacity. The parks of Jangada, Maria Helena and Potiguar, also part of the Cutia Complex, began their commercial operations in December 2018 with 85%, 54% and 77% of their installed capacity, respectively. On September 20, 2019, according to ANEEL Order No. 2,593 / 2019, the last three generating units of the Maria Helena Wind Power Plant were released. With this, the Cutia Wind Complex became fully operational in 2019.

In January 2019, São Bento do Norte I, São Bento do Norte II began their operations, while in February 2019, São Miguel I, São Miguel II e São Miguel III began theirs. In April 2019, São Bento do Norte III began their operations. With this, the Bento Miguel Complex became fully operational.

Thermoelectric Generation Facilities

The following table sets forth certain information about our thermoelectric plants in operation as of December 31, 2019:

Plant | Installed capacity | Assured energy | Placed in service | Our ownership | Concession/ authorization expires
| (MW) | (GWh/yr) |  | (%) |
TPP Araucária | 484.1 | 2,338.92(1) | September, 2002 | 81.2 (2) | December, 2029
TPP Figueira | 20.0 | 90.2 | April, 1963 | 100.0 | March, 2019(3)

(1) The annual assured energy of thermal plants such as Araucária varies depending on the price of natural gas, according to criteria established by the MME.

(2) Held 20,3% by Copel and 60,9% by Copel GeT.

(3) We are currently waiting for the granting authority to amend our concession agreement with respect to TPP Figueira, extending the concession of the thermoelectric plant for another 20 years, pursuant to the Concession Extension Law of 2013

Araucária. We have an 81.2% interest in UEG Araucária Ltda., which owns the Araucária Thermoelectric plant, a natural gas thermoelectric power plant, located in the state of Paraná. The Araucária Thermoelectric plant has 484.2 MW of installed capacity, does not have Availability Agreements currently in force and operates under a business model in which revenue depends on the plant’s operation. When produced, energy will be sold in the Spot Market as directed by the ONS.

As of November 2019, the plant may also have the possibility of being activated in the form of an assignment of energy credits, in accordance with the agreement signed with Petróleo Brasileiro SA - Petrobrás and in accordance with Normative Resolution No. 614/2014 from ANEEL. Based on this agreement, in force until December 31, 2020, the plant may be dispatched outside of out-of-merit-order, and the UTE Araucária gas supplier will inform, weekly, if it will activate the plant. In this scenario, the order will not be at the price of the CVU approved by ANEEL, but at a price agreed between the parties, considering, among other factors, market opportunities and margins considered adequate for the plant's operation, thus enabling recovery fixed cost for the order period.

A gas supply agreement was signed between Petróleo Brasileiro S.A - Petrobras and UEG Araucária

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Ltda - UEGA. The agreement is valid from February 21th to December 31th, 2020 and it provides for the delivery of up to 2,150,000 cubic meters of natural gas per day, without take-or-pay clauses. As a result, TPP Araucária will remain available to the National Interconnected System - SIN and can therefore be dispatched at the discretion of ONS. However, UEG Araucária signed an amendment to the Transfer of Energy Credits agreement with Petróleo Brasileiro S.A. - Petrobras, in accordance with ANEEL's Normative Resolution No. 614/2014, for the same duration as the gas supply agreement. The amendment will allow the plant to be dispatched out-of-merit-order, and the gas supplier will inform TPP Araucária weekly whether it will activate the plant. In this context, dispatch will not be charged at the CVU approved by ANEEL but at the value agreed by the parties, taking into account, among other factors, market opportunities and margins considered adequate for the operation of the plant, thus enabling the recovery of the fixed cost related to the dispatch period. With an installed capacity of 484 MW, the combined cycle power plant is one of the most efficient in Brazil.

TPP Araucária was activated on March 8, 2020, according to the schedule for the operational week of ONS. The dispatch order is part of the exceptional measures adopted at the meeting of March 4, 2020 by the Electric Sector Monitoring Comittee (“CMSE”) for the recovery of hydroelectric reservoirs in the southern region of the country. The plant's remuneration, therefore, will be based on the Variable Cost per Unit - CVU approved by ANEEL, in the amount of R$681.79/MWh.

Figueira. The Figueira plant is located in the city of Figueira, in the northeast of the state of Paraná (where the main coal basin of Paraná is located). This plant is currently in a modernization process, which consists of replacing the old equipment for new equipment. This process aims to make this plant more efficient, reduce emissions of gases and particles resulting from the burning of coal and comply with applicable environmental legislation.

After the modernization, the plant will have the installed capacity of 20.0 MW with only one generating unit and the physical guarantee of 17.7 MW, so that it is in compliance with Normative Resolution No. 801/2017, which defines a minimum efficiency of 25% for installations with installed capacity up to 50.0 MW.

Expansion and Maintenance of Generating Capacity

We expect to spend R$654.1 million in 2020 to expand and maintain our generation capacity, including participation in new businesses, of which R$118.6 million will be invested in SHP Bela Vista, , R$80.5 million will be invested in the Colíder Hydroelectric Power Plant and R$25.8 million will be invested in the Baixo Iguaçu Hydroelectric Power Plant. The remaining amount will be spent on equipment maintenance, the modernization of the HPP Foz do Areia, the modernization of the Figueira Thermal Power Plant] and other projects.

Hydroelectric Power Plant Projects

We have interests in several hydroelectric generation projects. The following table sets forth information regarding our major hydroelectric generation projects under construction.

Facility | Installed capacity | Estimated assured energy (1) | Budgeted completion cost | Beginning of operation | Our ownership | Status
| (MW) | (GWh/year) | (R$million) |  | (%) |
SHP Bela Vista | 29 | 145 | 200 | January, 2024 | 100.0 | Concession granted

(1) | Values used to determine volumes committed for sale.

Bela Vista. In August 2018, we participated in the A-6 auction as a member of the Consórcio Bela Vista Geração and sold 14.7 MW of the SHP Bela Vista, at a price of R$195.70 / MWh. With an estimated investment of R$200.0 million, the Bela Vista SHP has 29 MW of installed capacity and 16.6 MW of assured

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power and is under construction in the Chopim river, in the São João and Verê Municipalities, located in the southwest of the State of Paraná. The energy sales agreement will be in force as of January 1, 2024, for a 30-year term and will be subject to an annual readjustment by the IPCA. The construction of this facility began in the first semester of 2019.

Wind Farm Projects

The following table sets forth information regarding our wind farm projects, all of which currently refer to the Jandaíra wind farm (Complexo Eólico Jandaíra). In October 2019, Copel GeT and its subsidiary Cutia wind farm (Cutia Empreendimentos Eólicos) joined the Auction ANEEL A-6 for new energy generation and sold an average of 14.4 MW from the Jandaíra wind farm for R$98.00 MW/h. We expect to invest R$400 million in this new wind farm, which has an installed capacity equivalent to 90.1 MW and a physical guarantee equivalent to 47.6 MW. The Jandaíra wind farm will be built in the state of Rio Grande do Norte, and, as other wind farm assets of Copel are located in the same region, we believe that this project may benefit from operational synergies related to our projects that are already operating.

The amount of energy sold in October 2019 corresponds to 30% of the project’s physical guarantee. Pursuant to the power purchase agreement executed in connection with the above, such amount of energy shall be supplied as from January 1, 2025, this agreement will be in force for 20 years and prices will be adjusted pursuant to the IPCA index. Any additional energy generated by the Jandaíra wind farm will be negotiated in the Free Market.

Wind Farm | Installed capacity | Estimated Assured Power | Budgeted completion cost | Beginning of commercial operation | Our ownership | Concession expires
| (MW) | (Average MW) | (R$million) |  | (%) |
Jandaíra | 90.1 | 47.6 | 400.0 | January 1, 2025 | 100.0 | April 2055
Jandaíra I | 10,4 | 5.3 | - | January 1, 2025 | 100 | April 2055
Jandaíra II | 24,3 | 13.5 | - | January 1, 2025 | 100 | April 2055
Jandaíra III | 27.7 | 14.6 | - | January 1, 2025 | 100 | April 2055
Jandaíra IV | 27.7 | 14.2 | - | January 1, 2025 | 100 | April 2055

Development Projects

We are involved in various initiatives to study the technical, economic and environmental feasibility of certain hydroelectric, wind, solar photovoltaic and thermoelectric generation projects. The following table sets forth information regarding our proposed generation projects that are considered feasible under a technical, economic, social, environmental and land-related perspective pursuant to the above-mentioned studies.

Proposed Projects(1) | Estimated Installed Capacity | Estimated Assured Energy | Our Ownership
| (MW) | (GWh/yr) | (%)
HPP São Jerônimo | 331.0 | 1,560.2 | 41.2
WPP Complexo Alto Oriente | 60.0 | 247.5 | 100.0
HPP Salto Grande | 47.0 | 235.8 | 99.9
SHP Salto Alemã | 29.0 | 173.8 | 19.0
TOTAL | 467.0 | 2,217.3 | -

| (1) | Do not include other proposed projects of Copel whose technical, economic, social, environmental and land-related feasibility is still under analysis.

Copel is also a member of Consortium Geração Luz Paranaense - CGLP, which was granted with exploration rights related to the following projects: (i) SHP Foz do Curucaca, (ii) SHP Salto Alemã, (iii) SHP

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Alto Chopim and (iv) SHP Rancho Grande. After obtaining the applicable authorization from ANEEL and evaluating the hydraulic potential of each project, the consortium decided to carry out the studies only with respect to SHP Salto Alemã and SHP Foz do Curucaca and to return the exploration rights for SHP Alto Chopim and SHP Rancho Grande projects to ANEEL. The basic design of SHP Salto Alemã had already been approved by ANEEL in 2017 and the environmental studies related to this project were registered in the competent entity for analysis in October 2018. In December 2018, the basic design of SHP Foz do Curucaca was submitted to ANEEL approval.

Since 2017, Santa Clara Indústria de Pasta e Papel Ltda. (“Santa Clara”) had demonstrated that it had no interest in maintaining the partnership with COPEL in Dois Saltos Empreendimentos de Geração de Energia Elétrica Ltda. (“Dois Saltos”), a company that owns the rights to exploit SHP Dois Saltos. In October 2017, Santa Clara made an offer for the entire stake held by COPEL in Dois Saltos. After engaging an independent consulting firm in January 2018 and determining the fair value of its stake in Dois Saltos, COPEL presented to Santa Clara its terms for reaching an agreement. In October 2018, Santa Clara adjusted its proposal, based on the conditions and price requested by COPEL. This proposal was accepted by the Board of Directors of COPEL in November 2018, and a share purchase agreement was signed by the parties in December 2018. The closing of the transaction, with the settlement of the amounts provided for in the contract and transfer of quotas, occurred in the first half of 2019.

In 2020, we plan to bid for concessions to construct and operate new hydroelectric and solar photovoltaic plants or wind farms in power auctions in the regulated market for new generation projects. We are studying the feasibility of our participation in the hydroelectric, wind farms and solar photovoltaic projects planned to be listed in the auctions of 2020, or sell the energy in the unregulated electricity market (Free Market). We will also conduct studies of new hydroelectric power plants. For instance, we have partnered with BE - Empresa de Estudos Energéticos S.A., Minas PCH S.A. and SILEA Participações Ltda. to develop studies in the lower region of the Chopim River, which may lead to the development of another four (4) hydroelectric projects. We are also conducting studies related to future government auctions for wind farms, solar photovoltaic and hydropower plants, small hydroelectric plants and thermoelectric power plants in which we may eventually participate. Other renewable energy projects under study or development include the use of municipal solid waste in power generation, and thermosolar energy. For instance, since 2017, Copel has conducted solarimetric measurements in two solarimetric stations located in areas leased by Copel Brisa Potiguar. The development of solar energy projects in such areas is still under analysis and the corresponding studies are expected to be concluded as to be able to submit such projects to energy auctions in 2020.

We are also developing studies for the implementation / acquisition of projects related to Generation Distribution, Biomass (sugar cane and forest residues), Biogas and Natural Gas. In addition to energy generation projects, investment opportunities in new energy transmission assets whose concession will be auctioned by the Federal Government or existing assets that have synergy with the Company's current portfolio are also being studied.

Transmission and Distribution

General

Electricity is transferred from power plants to customers through transmission and distribution systems. Transmission is the bulk transfer of electricity from generating facilities to the distribution system by means of the Interconnected Transmission System, in tension greater than or equal to 230 kV. Distribution is the transfer of electricity to Final Customers, in tension lesser or equal to 138 kV.

The following table sets forth certain information concerning our transmission and distribution grids on the dates presented.

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| As of December 31,
| 2019 | 2018 | 2017 | 2016 | 2015
Transmission lines (km): |  |  |  |  |
230 kV and 500 kV | 3,074.6 | 3,025.4 | 2,691. 8 | 2,514.0 | 2,398.8
138 kV | 13.4 | 7.2 | 7.2 | 7.2 | 7.2
69 kV(1) | - | - | - | - | -
Distribution lines (km): |  |  |  |  |
230 kV(2) | - | - | - | 165.5 | 129.6
138 kV | 6,506.7 | 6,264.8 | 5,935.0 | 5,970.3 | 5,866.6
69 kV | 755.6 | 751.2 | 866.4 | 695.4 | 695.3
34.5 kV | 85,734.5 | 85,185.2 | 84,639.2 | 84,071.3 | 83,347.4
13.8 kV | 106,955.7 | 106,172.4 | 105,510.6 | 104,556.0 | 103,488.2
Transformer capacity (MVA): |  |  |  |  |
Transmission and distribution substations (69 kV – 500 kV)(3) | 23,860.2 | 22,825.1 | 22,849.3 | 22,535.4 | 21,727.2
Generation (step up) substations | 6,691.0 | 6,355.0 | 6,335.0 | 6,335.0 | 6,312.4
Distribution substations (34.5 kV) | 1,545.8 | 1,502.3 | 1,537.9 | 1,488.5 | 1,517.2
Distribution transformers | 13,800.9 | 13,404.6 | 12,956.9 | 12,548.2 | 12,032.7
Total energy losses(4) (5) | 7.0% | 8.3% | 7.8% | 8.1% | 7.8%

(1) | As approved by ANEEL in 2008, these 69 kV transmission lines held by Copel Distribuição were transferred to Copel Geração e Transmissão, since they were part of our transmission business segment.

(2) | Due to improvements to registration and control systems used by Copel Distribuição to classify and register its transmission lines, lines were classified pursuant to its insulation voltage, and not according to its structure and isolate components. Consequently, all lines previously registered by Copel Distribuição were reclassified and there are no lines classified as 230 kV anymore.

(3) | This figure includes transformers with primary tensions of 69 kV and 138 kV which belong to Copel Distribuição but are implemented in 230 kV and 525 kV substations, which belong to Copel Geração e Transmissão.

(4) | Percentage of losses on the energy injected in the distributor (technical and non-technical losses on injected energy). Does not consider losses in the basic network.

(5) | We note that percentages measured until 2016 and reported in previous reports of the Company reflected the amounts of physical losses (Technical), commercial losses (Non-Technical) and losses on the basic network (allocation of agreements on the gravity center of the submarket) of Copel Distribuição, as well as the losses related to the allocation of agreements of Copel GeT. Those percentages were calculated taking into account the total of power purchased and sale agreements entered into by both Copel Distribuição and Copel GeT. For a better representation and comparison of the percentage of losses, we considered the percentage obtained by dividing the total amount of technical and non-technical losses by the energy injected into the network of Copel Distribuição. This percentage may be compared to other companies and has a more accurate physical meaning as it utilizes the database of measured data and not information taken from agreements of the period being analyzed.

Transmission

Our transmission system consists of all our assets of 230 kV and greater and a small portion of our 69 kV and 138 kV assets, which are used to transmit the electricity we generate and the energy we receive from other sources. In addition to using our transmission lines to provide energy to customers in the State of Paraná, we also transmit energy through the Interconnected Transmission System. Two companies owned by the federal government, Companhia de Geração e Transmissão de Energia Elétrica do Sul do Brasil – CGT Eletrosul and Furnas, also maintain significant transmission systems in the State of Paraná. Furnas is responsible for the transmission of electricity from Itaipu, while CGT Eletrosul’s transmission system links the states in the south of Brazil. Copel, like all other companies that own transmission facilities, is required to allow third party access to its transmission facilities in exchange for compensation at a level set by ANEEL.

Currently, we carry out the operation and maintenance of 3,382 km of transmission lines, forty one (41) substations in the State of Paraná and two (2) substation in the State of São Paulo. In addition, we have partnerships with other companies to operate 4,028 km of transmission lines and seven (7) substations through special purpose companies (SPCs).

The table below sets forth information regarding our transmission assets in operation:

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Subsidiary / SPC | Transmission Lines | TL Extension (km)5 | Number of Substations | Concession Expiration Date | Our Ownership | APR ¹ (R$million)
COPEL GeT | Main Transmission Concession(1) | 2,026 | 34 | December, 2042 | 100.0% | 469.5
COPEL GeT | TL Bateias - Jaguariaiva | 137 | - | August, 2031 | 100.0% | 10.9
COPEL GeT | TL Bateias - Pilarzinho | 32 | - | March, 2038 | 100.0% | 1.1
COPEL GeT | TL Foz - Cascavel Oeste | 116 | - | November, 2039 | 100.0% | 12.5
COPEL GeT | Cerquilho III Substation | - | 1 | October, 2040 | 100.0% | 5.1
COPEL GeT | TL Londrina – Figueira Foz do Chopim – Salto Osório | 102 | - | August, 2042 | 100.0% | 6.1
COPEL GeT | TL Assis – Paraguaçu Paulista Paraguaçu Paulista II Substation | 83 | 1 | February, 2043 | 100.0% | 8.2
COPEL GeT | Curitiba Norte Substation TL Bateias – Curitiba Norte | 31 | 1 | January, 2044 | 100.0% | 9.9
COPEL GeT | Realeza Sul Substation TL Foz do Chopim- Realeza Sul | 52 | 1 | September, 2044 | 100.0% | 7.8
COPEL GeT | TL Assis – Londrina | 122 | - | September, 2044 | 100.0% | 20.4
COPEL GeT | TL Araraquara II – Taubaté | 334 | - | October, 2040 | 100.0% | 31.4
COPEL GeT | TL Baixo Iguaçu – Realeza TL Curitiba Centro - Uberaba | 46 | 3 | April, 2046 | 100% | 79.0
Uirapuru (Copel GeT – 100%)(2) | TL Ivaiporã - Londrina | 120 | - | March, 2035 | 100% | 32.4
Costa Oeste (Copel GeT – 100%) | LT Cascavel Oeste - Cascavel Norte TL Cascavel Norte - Umuarama Sul | 152 | 1 | January, 2042 | 100% | 12.5
Marumbi (Copel GeT – 100%) | TL Curitiba – Curitiba Leste | 29 | 1 | May, 2042 | 100% | 19.5
Subtotal Copel GeT | 3,382 | 43 |  |  | 726.3
Caiuá Transmissora | TL Guaíra - Umuarama Sul TL Cascavel Norte - Cascavel Oeste Santa Quitéria Substation / Cascavel Norte Substation | 142 | 2 | May, 2042 | 49.0%(3) | 11.6
Integração Maranhense | LT Açailandia-Miranda II | 365 | - | May, 2042 | 49.0%(3) | 17.1
Matrinchã | TL Paranaíta - Ribeirãozinho | 1,005 | 3 | May, 2042 | 49.0%(3) | 91.52
Guaraciaba | TL Ribeirãozinho - Marimbondo | 600 | 1 | May, 2042 | 49.0%(3) | 49.5
Paranaíba | TL Barreiras II - Pirapora II | 953 | - | May, 2043 | 24.5%(3) | 33.5
Cantareira | TL Estreito – Fernão Dias | 342 | - | September, 2044 | 49.0%(3) | 50.1
Mata de Santa Genebra(4) | TL Araraquara II - Atatiba TL Bateias - Atatiba | 621 | 1 |  | 50.1%(3) | 80.8
Subtotal SPCs |  | 4,028 | 7 |  |  | 334.1
Total |  | 7,410 | 50 |  |  | 1,060.4

(1) | Our main transmission concessions encompasses several transmission lines.

(2) | In March 2019, Copel GeT signed a purchase and sale agreement with Centrais Elétricas Brasileiras SA and Fundação Eletrosul de Previdência e Assistencial Social - Elos to transfer 100% of shares issued by SPE Uirapuru Transmissora de Energia S.A.. In June, 2019 Copel GeT took over the stake control of the company.

(3) | Refers to the equity interest held by Copel Geração e Transmissão.

(4) | Refers to transmission lines that are already in commercial operation, representing 66.2% of the project's total RAP

(5) | Considers double circuits as a single extension.

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Expansion and Maintenance of Transmission Facilities

The construction of new transmission facilities of 230 kV and higher must be awarded in a bidding process or otherwise authorized by ANEEL. We are permitted by ANEEL to make minor improvements to some of the existing 230 kV and 500 kV facilities.

In November 2013, SPC Mata de Santa Genebra Transmissora, a strategic partnership between Copel (50.1%) and Furnas (49.9%), won the right to build and operate 847 km of transmission lines and three substations in the States of Paraná and São Paulo. The construction schedule of the Mata de Santa Genebra project was affected by successive vandalism events, which resulted in the collapse of towers and theft of aluminum cables in transmission lines already installed and commissioned, in different sections of the project. On February 25, 2019, all the stages planned for the test run period of the Santa Bárbara d’Oeste substation (300MVar/-300MVar static compensator), belonging to the SPE Mata de Santa Genebra, were concluded, allowing the operation of this substation under the commercial operation regime. The Annual Permitted Revenue (APR) related to the Santa Bárbara d’Oeste substation is R$10.8 million. On March 28, 2020 the transmission line 500 kV Araraquara 2 – Itatiba (207 Km of extension), the transmission line 500kV Itatiba –Bateias (414 km of extension) and the Itatiba substation (300 MVar) started the commercial operations. Thus, together with Santa Bárbara d’Oeste substation, the SPC Mata de Santa Genebra is authorized to receive an APR of R$161.3 million, approximately 66.2% of the total APR. The transmission line 500kV Araraquara 2 – Fernão Dias and the Fernão Dias SE are scheduled to become fully operational by May, 2020. The project’s total expected APR is R$243.5 million, of which R$122.0 million related to COPEL's stake, and full receipt is subject to the startup of the other stages of the project.

In November 2015, Copel GeT won ANEEL’s public auction No. 005/2015 for the construction and operation of 188 km of transmission lines in the States of Paraná and Santa Catarina, and three (3) substations in the State of Paraná, with a total capacity of 900 MVA. With an APR of R$116.9 million, the corresponding concession agreement was signed in April 2016, and, except for the transmission line Blumenau – Curitiba Leste, which is still under construction and scheduled to become operational in March 2021, the remaining facilities are already in commercial operation.

The table below summarizes information regarding our transmission assets currently under construction:

Subsidiary / SPC | Transmission Lines | State | Km* | Number of Substations | Our Ownership | Beginning of Operation (expected)
COPEL GeT | TL Curitiba Leste-Blumenau | PR/SC | 142 | 3 | 100.0% | March, 2021
Subtotal Copel GeT |  | 142 | 3 |  |
Mata de Santa Genebra | TL Araraquara II - Bateias | SP / PR | 264 | 1 | 50.1% | May, 2020
Subtotal SPC |  |  | 264 | 1 |  |
Total |  |  | 406 | 4 |  |

* Proportional to the section under construction.

Distribution

Our distribution system consists of a widespread network of overhead lines and substations with voltages up to 138 kV assets. Higher Voltage electricity is supplied to bigger industrial and commercial customers and lower voltage electricity is supplied to residential, small industrial, and commercial customers in addition to other customers. As of December 31, 2019, we provided electricity in a geographic area encompassing approximately 97% of the State of Paraná and served 4.7 million customers.

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Our distribution grid includes 199,953 km of distribution lines, 440,691 distribution transformers and 227 distribution substations of 34.5 kV, 36 substations of 69 kV and 111 substations of 138 kV. During 2019, 75,436 new captive customers were connected to our network, including customers connected through the rural and urban electrification programs. We are continuing to implement compact grid design distribution lines in urban areas with large concentration of trees in the vicinity of the distribution grid.

We have two (2) captive customers that are directly supplied with energy at a high voltage (69 kV and above) through connections to our distribution lines. These customers accounted for approximately 0.7% of the total volume of electricity sold by Copel in 2019.

We are also responsible for expanding the 138 kV and 69 kV distribution grid within our concession area to meet any future demand growth.

On October 16, 2019 Copel Distribuição launched a program to modernize its distribution grid called “Transformation Program” (Programa Transformação). The Transformation Program is comprised of three projects: “Total Reliability” (Confiabilidade Total), “Three-phase Paraná” (Paraná Trifásico) and “Smart Grid Copel”. The goal is to improve infrastructure, particularly in rural areas, in order to enhance quality of energy supply and reduce supply restoration period in case of power outages. With investments of up to R$2.9 billion until 2025, which shall compose the Regulatory Remuneration Base, the Transformation Program involves the construction of approximately twenty-five 25,000 kilometers of power grids, 15,000 new automated power connections and the setting up of smart grid technology in the State of Paraná.

Performance of the Distribution System

Total losses are commonly divided into a technical and non-technical component. Technical losses are inherent to the transportation of electricity and consist mainly of power dissipation in the line network. Non-technical (or commercial) losses are caused by actions external to the power system (for instance, electricity theft). Since total losses are comprised of both technical and non-technical parcels, the latter is easily calculated as the difference between total losses and the estimated technical losses inherent to the system.

Total losses in our distribution system are segmented between (i) losses in the basic network (tension equal to or greater than 230kV), which are external to our distribution grid and have a technical cause, and (ii) losses in the distribution network (internal to our distribution grid), which are usually caused by both technical and non-technical reasons.

Losses in the basic network are calculated monthly by the CCEE as the difference between the total generation and the energy effectively delivered to the distribution networks. The total losses from our distribution grid are calculated as the difference between the energy allocated to the system and the energy supplied to the customers.

Our total energy distribution losses (including transmission system, technical and commercial losses) totaled 8.4% of the total energy amount available in 2019, being (i) 1.4% related to losses in the basic network, (ii) 6.0% of technical losses and (iii) 1.0% of non-technical losses.

ANEEL grants the transfer of all energy losses to the final consumers when the real losses are less than regulatory losses. The calculation is made within the regulatory period, that is different from a civil year, and thereby we will know the result just in the next tariff adjustment, in June 2020. But our simulation indicates that in the civil year, from January through December 2020, we will have all losses transferred to the final consumers.

Furthermore, ANEEL requires distributors to observe certain standards for “energy supply continuity”, namely (i) duration of outages per customer per year or DEC – Duração Equivalente de Interrupção por Unidade Consumidora and (ii) frequency of outages per customer per year or FEC – Frequência Equivalente de Interrupção por Unidade Consumidora. Information regarding the duration and frequency of outages for our customers is set forth in the following chart for the years indicated.

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Quality of supply indicator | 2019 | 2018 | 2017 | 2016 | 2015
DEC – Duration of outages per customer per year (in hours) | 09h07min | 10h19min | 10h28min | 10h49min | 13h40min
FEC – Frequency of outages per customer per year (number of outages) | 6.02 | 6.22 | 6.83 | 7.23 | 8.33

We comply with the quality indicators defined by ANEEL for 2019, which penalizes power outages in excess of an average number of hours per customer, in each case calculated on an annual basis. These limits vary depending on the geographic region, and the average limit established by ANEEL for our distribution company was 9 hours and 07 minutes of outages per customer per year, and a total of 6.22 outages per customer per year. Failure to comply with these predetermined standards with a Final Customer results in a reduction of the amount we can charge such Final Customer in future periods.

In addition, quality target indicators are taken into consideration by ANEEL during distribution concession renewal proceedings, and also influence ANEEL’s calculation of our tariff adjustments. For more information, see “Distribution Concessions” and “Distribution Tariffs”.

Purchases for the captive market

The following table contains information concerning volume, cost and average tariff for the main sources of the electricity we purchased for the captive market in the last three years.

Source | 2019 | 2018 | 2017
Itaipu |  |  |
Volume (GWh) | 5,533 | 5,726 | 5,934
Cost (R$millions) | 1,317 | 1,272.2 | 1,118.0
Average tariff (R$/MWh) | 238 | 222.18 | 188.41
Angra |  |  |
Volume (GWh) | 979 | 1,009 | 1,023
Cost (R$millions) | 248 | 250.3 | 231.7
Average tariff (R$/MWh) | 253 | 248.07 | 226.49
CCGF |  |  |
Volume (GWh) | 6,274 | 6,520 | 7,271
Cost (R$millions) | 642 | 593.0 | 447.5
Average tariff (R$/MWh) | 102.32 | 90.95 | 61.55
Auctions in the regulated market |  |  |
Volume (GWh)(1) | 12,515 | 10,783 | 9,860
Cost (R$millions)(2) | 2,257 | 2,080.8 | 2,014.8
Average tariff (R$/MWh) | 180.34 | 192.97 | 204.34

(1) | These numbers do not include assignments related to MCSD-EN and MVE.

(2) | These numbers do not include short-term energy purchased through the CCEE.

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Itaipu

We purchased 5,533 GWh of electricity from Itaipu in 2019, which constituted 11.3% of our total available electricity in 2019 and 21.1% of Copel Distribuição’s total available electricity in 2019. Our purchases represented approximately 9.2% of Itaipu’s total production. Distribution companies operating under concessions in the midwest, south and southeast regions of Brazil are required by law to purchase Brazil’s portion of the energy generated by Itaipu in a proportion that correlates with the volume of electricity that they provide to customers. The rates at which these companies are required to purchase Itaipu’s energy are fixed to cover Itaipu’s operating expenses and payments of principal and interest on Itaipu’s U.S. dollar-denominated borrowings, as well as the cost of transmitting the power to their concession areas. These rates are denominated in U.S. dollars, and have been set for 2020 at US$28.41 per kW per month.

In 2019, we paid an average tariff of R$237.94/MWh for energy from Itaipu, compared to R$227.03/MWh in 2018. These figures do not include the transmission tariff that distribution companies must pay for the transmission of energy from Itaipu.

ANGRA

Because Eletronuclear renewed the generation concession of Angra under the 2013 Concession Renewal Law, the energy generated by Angra is no longer sold in auctions in the regulated market. Rather, under the 2013 Concession Renewal Law, this energy is sold to distributors in accordance with the quota system established by said law. For more information, see “Item 4. Information on the Company—The Brazilian Electric Power Industry”. As a result, Copel Distribuição was legally required to purchase 979 GWh from Angra in 2019, 1,009 GWh from Angra in 2018 and 1,023 GWh in 2017.

Assured Power Quota Contract – CCGF

Under the 2013 Concession Renewal Law, certain generation concessionaires renewed their concession contracts, and therefore these concessionaires no longer sell the energy produced by these generation facilities at auctions in the regulated market. Rather, this energy is sold to distribution companies in accordance with the quota system established by the 2013 Concession Renewal Law. For more information, see “Item 4. Information on the Company—The Brazilian Electric Power Industry”. Copel Distribuição is obligated to purchase energy from these generation concessionaires that have renewed generation concessions under this quota system. Copel Distribução was legally required to purchase 6,274 GWh in CCGF contracts in 2019, 6,520 GWh in CCGF contracts in 2018 and 7,271 GWh in CCGF contracts in 2017.

Auctions in the Regulated Market

In 2019, we purchased 12,514 GWh of thermoelectric and hydroelectric energy through auctions in the regulated market. This energy represents 48% of the total electricity purchased by the Copel Distribuição. For more information on the regulated market and the Free Market, see “Item 4. Information on the Company—The Brazilian Electric Power Industry”.

Sales to Captive Customers

During 2019, we supplied approximately 98.6% of the energy distributed directly to Captive Customers in the State of Paraná. Our concession area includes nearly 4.7 million customers located in the State of Paraná and in one municipality in the State of Santa Catarina, located in the south of the State of Paraná. During 2019, the total power consumption of our Captive Customers was 19,784 GWh, a 1.0% increase as compared to 19,594 GWh during 2018.

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| Year ended December 31,
Categories of purchaser | 2019 | 2018 | 2017 | 2016 | 2015
| (GWh)
Industrial customers | 2,648 | 2,935 | 3,254 | 5,753 | 6,929
Residential | 7,499 | 7,238 | 7,126 | 6,932 | 6,957
Commercial | 4,730 | 4,652 | 4,651 | 5,059 | 5,530
Rural | 2,361 | 2,288 | 2,257 | 2,180 | 2,256
Other(1) | 2,546 | 2,481 | 2,455 | 2,404 | 2,371
Total(2) | 19,784 | 19,594 | 19,743 | 22,327 | 24,043

(1) | Includes public services such as street lighting, electricity supply for municipalities and other governmental agencies, as well as our own consumption.

(2) | Total GWh does not include our energy losses.

Sales to Free Customers

We operate in the Free Energy Contracting Environment (“ACL”) through our wholly owned subsidiaries Copel Geração e Transmissão and Copel Comercialização. As of December 31, 2019, we had 425 Free Customers (of which 375 were customers of our energy trading company and 50 of Copel GeT), representing approximately 5.7% of our consolidated operating revenue and approximately 13.8% of the total quantity of electricity sold by us. During 2019, the total power consumption of our Free Customers was 6,860 GWh, a 13.3% increase as compared to 6,055 GWh during 2018.

| Year ended December 31,
Categories of purchaser | 2019 | 2018 | 2017 | 2016 | 2015
| (GWh)
Industrial customers | 6,352 | 5,728 | 4,435 | 3,821 | 3,894
Commercial | 508 | 327 | 196 | 2 | 12
Total | 6,860 | 6,055 | 4,631 | 3,823 | 3,906

The following table sets forth the number of our Final Customers, considering both Captive and Free Customers, in each category as of December 31, 2019.

Category | Number of Final Customers
Industrial | 72.328
Residential | 3,825,989
Commercial | 406,856
Rural | 349,914
Other(1) | 58,578
Total | 4,713,665

(1) | Includes street lighting, as well as electricity for municipalities and other governmental agencies, public services and own consumption.

Industrial and commercial customers accounted for approximately 12.2% and 20.8%, respectively, of our total revenues from sales to Final Customers during 2019. In 2019, 31.8% of our total revenues from energy sales were from sales to residential customers.

Tariffs

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Retail Tariffs. We classify our customers in two groups (“Group A Customers” and “Group B Customers”), based on the voltage level at which electricity is supplied to them and on whether they are considered as industrial, commercial, residential or rural customers. Each customer falls within a certain tariff level defined by law and based on the customer’s classification, although some flexibility is available according to the nature of each customer’s demand. Under Brazilian regulation, low voltage customers such as residential customers (other than Low-income Residential Customers, as defined as follows) pay the highest tariff rates, followed by 13.8 kV and 34.5 kV voltage customers (usually commercial customers), and 69 kV and 138 kV voltage customers (usually industrial customers).

Group A Customers receive electricity at 2.3 kV or higher and the tariffs applied to them are based on the actual voltage level at which energy is supplied and the time of day the energy is supplied. Tariffs are comprised of two components: a “capacity charge” and an “energy charge”. The capacity charge, expressed in reais per kW, is based on the higher of (i) contracted firm capacity and (ii) power capacity actually used. The energy charge, expressed in reais per MWh, is based on the amount of electricity actually consumed as evidenced by our metering.

Group B Customers receive electricity at less than 2.3 kV, and the tariffs applied to them are comprised solely of an energy charge and are based on the classification of the customer.

ANEEL restates our tariffs annually, usually in June. For more information about the distribution tariff adjustments that have been made by ANEEL in recent years, see “Item 5. Operating and Financial Review and Prospects—Overview—Rates and Prices”.

The following table sets forth the average tariffs for each category of final customer in effect in 2019, 2018 and 2017.

Tariffs | 2019 | 2018 | 2017
| (R$/MWh)
Industrial | 488.78 | 767.87 | 389.04
Residential | 504.36 | 505.08 | 425.26
Commercial | 574.41 | 527.31 | 419.27
Rural | 466.9 | 345.80 | 286.96
Other customers | 364.49 | 375.99 | 311.37
All Final Customers | 534.32 | 514.94 | 387.90

Low-income Residential Customers. Under Brazilian law, we are required to provide low level rates to certain low-income residential customers (“Low-income Residential Customers”). In December 2019, we served approximately 292,173 low-income residential customers. For servicing these customers, in 2019 we received an approximately R$70.3 million grant from the Brazilian Federal Government, which was approved by ANEEL.

The following table sets forth the current minimum discount rates approved by ANEEL for each category of Low-income Residential Customer.

Consumption | Discount from base tariff
Up to 30 kWh per month | 65%
From 31 to 100 kWh per month | 40%
From 101 to 220 kWh per month | 10%

Special Customers. A customer of our distribution business that consumes at least 500 kW (a “Special Customer”) may choose its energy supplier if that supplier derives its energy from alternative sources, such as small hydroelectric plants, wind plants or biomass plants. A Special Customer that chooses to purchase energy from a supplier other than Copel Geração e Transmissão continues to use our distribution grid and pay our distribution tariff. However, as an incentive for Special Customers to purchase from alternative sources, we are

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required to reduce the tariff paid by Special Customers by 50%. This discount is subsidized by the Brazilian federal government, and therefore does not impact the revenues of our distribution business.

Transmission Tariffs. A transmission concessionaire is entitled to annual revenues based on the transmission network it owns and operates. These revenues are annually readjusted according to criteria stipulated in the concession contract. We are directly a party to twelve (12) transmission concession contracts, eleven (11) of which are in the operational stage and one (1) of which includes a transmission line that is still under construction. Not all of the transmission concession contracts employ the same revenue model. 1.5% of our transmission revenues are updated on an annual basis by the IGP-M and the other 98.5% are subject to the tariff review process.

The first periodic revision related to our main transmission concession scheduled for 2005 was only carried out in 2007, at which point ANEEL reduced the tariffs by 15.08%. This adjustment was applied retroactively to July 2005, and was passed on to our final customers until June 2009. In addition, in July 2010 pursuant to a second periodic revision of our principal concession, ANEEL granted provisional approval of a reduction in our transmission tariff by 22.88%, applied to the revenues of new installations in the Interconnected Transmission System, and applied retroactively from July 1, 2009 onward. In June 2011, ANEEL reviewed the figures of the second periodic revision and reduced the annual revenues by 19.94%. The remainder of our annual revenues was subject to adjustment by IGP-M or IPCA, as applicable.

By late 2012, Copel decided to anticipate the extension of its main transmission concession agreement (corresponding to 78% of the Company’s transmission lines then in operation) that would expire in 2015, pursuant to the new rules of the 2013 Concession Renewal Law. In December 2012, Copel executed the Third Addendum to the Concession Agreement 060/2001, extending this transmission concession agreement until December 31, 2042. In order to adjust these assets’ annual permitted revenue to the new rules of 2013 Concession Renewal Law, ANEEL reduced the transmission tariffs we charged by 61.9%.

Of all our transmission concessions in operational stage, our main transmission concession (which involves our main transmission facilities) accounted for about 71% of our gross transmission revenues in 2019. In addition, we have ten (10) concession agreements for transmission lines and substations in operation and one (1) partially in operation, which correspond to an aggregate of 29% of our transmission revenues. The amount of revenues we are entitled to receive pursuant to one (1) of these contracts is updated on an annual basis by the IGP-M and is not subject to the tariff review process, but, pursuant to the terms set forth in this agreement, our revenues were reduced by 50% starting in June 2018. Other ten (10) agreements revenues are subject to the tariff review process and adjustments by the IPCA.

In relation to our main concession agreement, on April 22, 2016, Ordinance No. 120/2016 of the Ministry of Mines and Energy determined that the amounts ratified by ANEEL related to the non-depreciated transmission assets existing on May 31, 2000 (Existing Basic Network System “RBSE”) should be incorporated to the Regulatory Remuneration Base, and that their cost of capital should be added to APR. The Ordinance also determined that the cost of capital would be composed of compensation and depreciation installments, plus related taxes, and recognized as of the 2017 tariff revision process, with adjustments and revisions in accordance with contractual conditions.

Also pursuant to the above mentioned Ordinance, the cost of capital not incorporated between the concessions’ extensions and the 2017 tariff revision process should be restated at the real cost of own capital of the transmission segment defined by ANEEL (10.4%) and, after the tariff revision process, it should be remunerated at the Weighted Average Cost of Capital (WACC) of 6.6%, also defined by that agency.

On May 9, 2017, ANEEL approved the result of the inspection of the appraisal report of the transmission assets existing on May 31, 2000 (RBSE and Other Transmission Facilities - RPC) related to our main transmission concession agreement. The Agency recognized the amount of R$667.6 million as the net value of the assets for the purposes of indemnification as of December 31, 2012. As of December 31, 2017, the net value of those assets for the purposes of indemnification amounted to R$1,418.4 million.

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On June 27, 2017, ANEEL approved the Annual Permitted Revenue (Receita Anual Permitida, or APR) of the transmission assets of Copel GeT for the 2017/2018 cycle, including the commencement of receipt of the RBSE indemnification of our main transmission concession agreement.

In 2017(i) our main transmission concession agreement was adjusted by the IPCA and by the portion related the commencement of receipt of the RBSE indemnification (average increase of 151.3%) (ii) one of our transmission concession agreements was adjusted by the IPCA and improvements to the system were approved by ANEEL (average increase of 3.7%), (iii) six transmission concession agreements were adjusted by the IPCA (3.6%), (iv) one transmission concession agreement was adjusted by the IGP-M (1.6%), and (v) one transmission agreement became operational in August 2017, adding R$18.9 million of annual permitted revenues. As a result, the annual permitted revenues for the 2017/2018 cycle for our transmission assets reflected an increase of 121.2% over our annual permitted revenues for the 2016/2017 cycle.

In June 2018, ANEEL approved the APR for the 2018/2019 cycle, considering (i) an adjustment of relevant amounts by the IGP-M and IPCA indexes, and (ii) the expansion of our transmission system with strengthening works and revenues from other works classified as improvement measures.

Compared to our total APR for the 2017/2018 cycle, the APR of our main concession for the 2018/2019 cycle was reduced by 8.1%, as a result of the correction of a prior calculation made by ANEEL, which take into account certain financial and economic portions of unamortized and unrepaired assets related to the RBSE when determining the assets of the Regulatory Remuneration Base in the prior cycle.

The APR of concession No. 075/2001 was reduced by approximately 30.5%, as a result of a 50% reduction of the APR starting at the 16th anniversary of commercial operation, which occurred during the 2018/2019 cycle. Two of our concession agreements (022/2012 and 002/2013) were subject to a periodic review, which resulted in a lower APR in connection with increasing revenues related to strengthening works.

In June 2019, ANEEL approved the APR for the 2019/2020 cycle, considering (i) an adjustment of relevant amounts by the IGP-M and IPCA xes, and (ii) the expansion of our transmission system with strengthening works and revenues from other works classified as improvement measures.

The table below shows our APR (R$ million) for the last four cycles of transmission lines over which we hold a 100% ownership:

Contract | Transmission Line / Substation | Jul. 2019 Jun.2020 | Jul. 2018 Jun. 2019 | Jul. 2017 Jun. 2018 | Jul.2016 Jun.2017
|  |  | APR (R$ million)
060/2001 | Main Transmission Concession(1) | 469.5 | 450.4 | 482.7 | 192.1
075/2001 | Bateias – Jaguariaiva | 10.9 | 13.5 | 19.4 | 19.1
006/2008 | Bateias – Pilarzinho | 1.1 | 1.1 | 1.0 | 1.0
027/2009 | Foz do Iguaçu - Cascavel Oeste | 12.5 | 11.9 | 11.6 | 11.2
015/2010 | Cerquilho III | 5.1 | 4.8 | 4.7 | 4.5
022/2012 | Foz do Chopim – Salto Osório | 6.1 | 5.8 | 5.8 | 5.6
002/2013 | Assis-Paraguaçu Paulista II SE Paraguaçu Paulista II | 8.2 | 7.9 | 7.7 | 7.7
005/2014 | Bateias – Curitiba Norte | 9.9 | 9.5 | 8.7 | 8.4
021/2014 | Foz do Chopim - Realeza(2) | 7.8 | 7.5 | 7.3 | 7.1
022/2014 | Assis – Londrina(3) | 20.4 | 19.5 | 18.9 | -
010/2010 | Araraquara 2 – Taubaté(4) | 31.4 | 30.0 | - | -
006/2016 | Baixo Iguaçu – Realeza Curitiba Centro - Uberaba | 79.0 | - | - | -

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Total |  | 661.9 | 561.9 | 567.8 | 256.7

(1) | Our main transmission concessions encompasse several transmission lines.

(2) | This transmission line became operational in January 2017.

(3) | This transmission line became operational in August 2017.

(4) | This transmission line became operational in July 2018.

Other Businesses

Telecommunications

Copel Telecomunicações S.A. Pursuant to an authorization from the Brazilian National Telecommunication Agency, Agência Nacional de Telecomunicações (“ANATEL”), we provide telecommunication services within the States of Paraná and Santa Catarina. We have been offering these services since August 1998 through the use of our fiber optics network (totaling 35.1 thousand km of fiber optic cables by the end of 2019). In addition we have been involved in an educational project aimed at providing broadband internet access to public elementary and middle schools in the State of Paraná.

COPEL currently serves 399 municipalities in the State of Paraná. All of these municipalities are connected to COPEL’s optical backbone.

In addition to the high transmission capacity in its backbone, Copel Telecom serves 85 municipalities in the State of Paraná, with GPON (Gigabit-Capable Passive Optical Networks) access technology, providing several network services with symmetry rates, in different types of FTTx services.

We provide services to most of the major Brazilian telecommunication companies that operate in the State of Paraná. In total, we have corporate clients that include supermarkets, universities, banks, internet service providers and television networks in addition to retail clients. We also provide a number of different telecommunication services to our subsidiaries.

On April 17, 2019, Copel's Board of Directors resolved, unanimously, that we should continue to analyze alternatives for a potential transfer of control of Copel Telecomunicações S.A.

Sercomtel. We own 45% of the stock of Sercomtel Telecomunicações S.A. (“Sercomtel”). Sercomtel holds a concession to provide fixed telephony services and an authorization to provide mobile services in the municipalities of Londrina and Tamarana, located in the State of Paraná. In addition, Sercomtel has two (2) other authorizations from ANATEL that allow it to provide fixed telephony and broadband internet services in all other municipalities of the State of Paraná. Currently, Sercomtel operates with its own network in fifteen (15) municipalities of the State of Paraná, providing voice services and fixed broadband. Pursuant to a commercial agreement between COPEL and Sercomtel in force since March 2012, Sercomtel can provide voice services over COPEL’s network in one hundred and eighty three (183) cities within the State of Paraná, including Curitiba. .

As of December 31, 2019, Sercomtel provided a total of 232.2 thousand accesses in fixed telephone services, 53.8 thousand mobile accesses and 89 thousand fixed broadband accesses in operation.

In addition to the telecommunications business, Sercomtel S.A. – Telecomunicações currently holds the following equity interest: (i) 100% of the capital stock of Sercomtel Participações, a company whose purpose is to provide added value services, design, deploy and maintain internet service providers, operate a service center for users of telecommunications services, offer integrated IT solutions, among others activities; and (ii) 18.92% (common shares) and 18.73% (preferred shares) of the capital stock of Companhia de Tecnologia e Desenvolvimento S.A., a mixed capital company incorporated from the transformation of Sercomtel Contact Center S.A. in accordance with Law No. 12,912 of September 12, 2019, approved and sanctioned by the City Council and the Municipality of Londrina, respectively. In addition, Sercomtel Participações S.A. holds 10% (common shares) of the capital stock of Sercomtel Iluminação S.A., a company

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that provides public lighting maintenance services in the city of Londrina, State of Paraná. In September 2017, pursuant to Decision (Acórdão) no. 366, ANATEL determined that Sercomtel was not in compliance with certain financial indicators set forth by the agency in connection with the concessions granted to Sercomtel and required for the company’s operations to continue. As a consequence, ANATEL brought an administrative proceeding against Sercomtel to assess whether the concession and the authorizations granted to this company should be terminated. In March 2019, ANATEL decided to suspend the above mentioned proceeding for a 120-day period, so that Sercomtel could present to the agency alternative plans for meeting the relevant regulatory indicators. Even though this proceeding has not been concluded yet, ANATEL published a bidding notice proposal in September 2019 with respect to the licenses held by Sercomtel. ANATEL’s proposal is subject to review by the Federal Audit Court (Tribunal de Contas da União). If a bidding process is indeed carried out by ANATEL, Sercomtel’s licenses can be forfeited and terminated.

In June 2019, the municipal legislature of Londrina approved the sale of the stake held by the Londrina City Hall as the controlling shareholder of Sercomtel (Municipal Law No 12.871, dated June 12, 2019). In November 2019, the City Hall published the bidding notice for the privatization process of Sercomtel, which provides for the assignment of the City Hall’s preemptive right to subscribe shares in a future capital increase of Sercomtel. This process can result in the dilution of the stake held by the City Hall and Copel in Sercomtel. However, a bid for the sale of such preemptive rights was scheduled for February 5, 2020, and no participants attended. We understand that alternative procedures are under consideration by Sercomtel’s controlling shareholder.

Sercomtel has had losses in previous years and is facing financial difficulties for carrying out its operations, so it may need additional financial contributions from its shareholders. In view of the accumulated losses and uncertainties regarding its operational feasibility, we carried out in 2013 the write-off of this investment in our financial statements.

Gas

Gas Distribution

We are engaged in the distribution of natural gas through Companhia Paranaense de Gás (“Compagas”), the company that holds the exclusive rights to supply piped gas in the State of Paraná. Compagas operates the gas distribution grid in the State of Paraná under a concession agreement with a term of 30 years, with expiry on July 6, 2024. Such date has always been announced and considered for assessment of the balances of the prior-year financial statements. The concession agreement may be extended for an equal 30-year period upon request of the concessionaire.

On December 7, 2017, however, the State of Paraná published Supplementary Law 205, introducing a new interpretation of the expiry of the concession, which should have occurred on January 20, 2019. Notwithstanding the new expiration date provided by the state law, this concession has not been subject to neither an extension nor a new bidding process. Pursuant to applicable law, Compagas, as the current concessionaire, may continue to operate the concession until a new concessionaire is appointed.

In addition, the management of Compagas, we and other shareholders are challenging the effects of the aforesaid law, understanding that it conflicts with the provisions of the concession agreement currently in force. Compagas filed a lawsuit challenging the anticipating of the expiration date of such concession and was granted with a provisional remedy on October 30, 2018. A final decision on this lawsuit is still pending. However, such discussion has not yet been concluded and that law continues in force, and the effects of such law on our financial statements for 2019 had to be taken into consideration. For more information, see Note 2.1.1 to our audited consolidated financial statements for December 31, 2019.

Management will continue to make its best efforts to protect the Company interests, aiming to appropriately settle the impacts of the new interpretation given by the concession grantor and find alternatives necessary to maintain the concession in a sustainable manner. For more information see Note 2.1.1 to our audited consolidated financial statements.

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Compagas covered 833 kilometers in 2019, increase of 1.1% compared to 824 kilometers covered in 2018. Compagas’s net revenues were R$866.9 million, an increase of 47.3%, compared to 2018 (R$588.5 million), and its net income was R$173.0 million, an increase of R$113.4 million or 190.1% compared to 2018. Compagas’ customers include industries, gas stations, other businesses and residences and Araucária Thermoelectric plan. Compagas is focusing its business strategy on increasing the volume of gas it distributes to customers by marketing the benefits of substituting oil and other fuels by gas as a mean of achieving greater energy efficiency. Compagas’ customer base increased 8%, to 47,238 customers in 2019 from 43,943 in 2018.

Compagas registered an increase of 15% in the average daily volume of natural gas distributed to Final Customers, to 1,368,915 cubic meters per day in 2019 (not including the volume of gas supplied to Araucária Thermoelectric plant) compared to 1,190,302 cubic meters per day in 2018 (not including the volume of gas supplied to Araucária Thermoelectric plant). In addition, Compagas makes its distribution grid available to transport natural gas to Araucária TPP. The volume of natural gas supplied from Petrobras and distributed by Compagas to Araucária TPP, was 68,050 cubic meters per day in 2019, compared tp 5.0 cubic meters per day in 2018.

As of December 31, 2019, we owned a controlling stake (51%) of the capital stock of Compagas and consolidated this equity interest in our financial statements. The minority shareholders of Compagas are Petrobras and Mitsui Gás, each of which owns 24.5% of the capital stock of Compagas.

Gas Exploration

In the 12th bidding round of National Petroleum Agency (Agência Nacional do Petróleo “ANP”), held at the end of 2013, the consortium formed by us (30%), Bayar Participações (30%), Tucumann Engenharia (10%) and Petra Energia (30%), the latter acting as operating company, won the right to explore, research, develop and produce oil and natural gas in four blocks located in the central southern region of the State of Paraná, in a 11,327 km² area. The minimum investment in the first phase of the research is approximately R$78.1 million for a 4-year term. We and our partners have signed the concession contracts for 2 blocks in May 2014. However, because of a public civil action, the first phase of exploration for these two blocks was halted and the signing of the other two concession contracts was prohibited. On June 7th, 2017, a court decision held that all the bidding round and the agreements related thereto should be deemed null and void. Moreover, the Government of the State of Paraná enacted Law No. 19,878 (July 3, 2019), forbidding the exploration of shale gas through the drilling / fracking method.

As a result of the above-mentioned events, our consortium requested ANP to release it from its contractual obligations, with no liabilities and with reimbursement of the signing bonuses, reimbursement of all costs incurred in connection with guarantees and release of such guarantees for the four blocks. Even though this request was submitted to ANP on September 6th, 2017, it is still subject to analysis. All the activities for the four blocks were interrupted due to the suspension of the effects of the12th bidding round of ANP because of an injunction granted in connection with the above mentioned public civil action, which awaits a decision from the Federal Court of Appeals of the 4th Region. For this reason, in October 2018, the consortium approved the establishment of an institutional arbitration procedure with the ANP for the four blocks awarded in the 12th bidding round of ANP, asking for the refund of the contributions made. Arbitral proceedings have already been initiated.

CONCESSIONS

We operate under concessions granted by the Brazilian government for our generation, transmission and distribution businesses. Under Brazilian law, concessions are subject to competitive bidding processes at the end of their respective terms.

2013 Concession Renewal Law

Until 2013, the Brazilian rules governing generation concessions gave concessionaires the right to renew for additional 20 year concession contracts that were entered into prior to December 11, 2003. For

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transmission and distribution concessions granted after 1995, concessionaires had the right to renew these contracts for an additional 30-year period.

On September 11, 2012, the Brazilian federal government enacted the Provisional Measure No. 579, subsequently converted into the 2013 Concession Renewal Law, which significantly changed the conditions under which concessionaires are able to renew concession contracts. Under the 2013 Concession Renewal Law, generation, transmission and distribution concessionaires may renew the concessions that were in effect as of 1995 (and, in the case of generation facilities, generation concession contracts entered into prior to 2003) for an additional period of 30 years (or an additional 20-year period in the case thermal plants), provided that the concessionaire agrees to amend the concession contract to reflect a series of new conditions that aim to ensure that services are provided in a continuous and efficient fashion and subject to low tariffs. Under the 2013 Concession Renewal Law, concessionaires must decide 60 months before the end of each concession term (or 24 months with respect to thermal plant concessions that it is 24 months) whether to amend and renew a concession contract or to terminate each concession contract at the end of its respective term.

For concessionaires of generation facilities existing at that time, the 2013 Concession Renewal Law changed the scope of the concession contracts at the moment they were renewed. Previously, a generation concessionaire had the right to sell the energy generated by the facilities subject to its concession for profit. In contrast, generation concessions renewed pursuant to the 2013 Concession Renewal Law do not grant concessionaires the right to sell the energy generated by these facilities. Instead, these concessions only cover the operation and maintenance of the generation facilities, subject to quality standards determined by Brazilian authorities. The energy generated by these facilities are allocated by the Brazilian federal government in quotas to the regulated market, for purchase by distribution concessionaires. For new generation facilities (i.e., generation facilities operated after the 2013 Concession Renewal Law), on the other hand, the concessionaire still has the right to sell the energy produced by the generation facility.

In addition to changing the scope of generation concessions, the 2013 Concession Renewal Law establishes a new tariff regime that significantly affects the treatment of amounts to be invested by concessionaires to improve and maintain generation plants. To this effect, several regulations were issued by MME and ANEEL to regulate the compensation due to concessionaires as a result of their investments to improve and maintain generation plants.

The 2013 Concession Renewal Law affects transmission and distribution concessions differently. The principal change is that amounts invested in modernization projects, structural reforms, equipment and contingencies are subject to prior ANEEL approval. However, the 2013 Concession Renewal Law does not affect the manner in which distribution and transmission concessionaires may recover amounts invested in transmission infrastructure.

With respect to the transmission agreements, the conditions for renewal set forth in the 2013 Concession Renewal Law are the acceptance of a fixed income as determined by ANEEL and compliance with quality standards set forth in applicable regulation. With respect to distribution agreements, the conditions are set forth in the amendment to the concession agreement and are related to compliance with quality standards, economic-financial sustainability indicators and corporate governance as set forth in the amendment to the concession agreement according to the parameters provided in the 2013 Concession Renewal Law.

The 2013 Concession Renewal Law applies to all generation, transmission and distribution contracts that were in effect as of 1995 (and, in the case of generation concessions, entered into prior to 2003), regardless of whether a contract grants to the concessionaire the right to renew a concession on its original terms. For example, several of our concession contracts contain provisions allowing us to renew these concessions for a period of 20 years. Under the 2013 Concession Renewal Law, in order to renew these contracts, we nonetheless would be required to accept the application of the conditions imposed by the 2013 Concession Renewal Law to the contract, and the concession contract would then be renewed for 30 years, rather than 20 years. If we choose to renew a concession contract that contains a renewal provision, we would be indemnified by the Brazilian government using funds from the RGR Fund (see Energy Sector Regulatory Charges) in an amount equal to the portion of our investments related to the concession that have not yet been amortized or depreciated, as calculated by ANEEL.

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If a concessionaire decides not to accept the new tariff regime with respect to a concession contract and therefore decides not to renew the contract, the concession will terminate at the end of its original term, and the Brazilian government will conduct a new competitive bidding process for the concession. The original concessionaire may participate in the new competitive bidding process.

In the case of hydroelectric generation concessions with an installed capacity of more than 5,000 kW, upon the expiration of their original term and provided that the concessionaire does not request the extension of such term, the granting authority may submit the concession to a new bidding process. In the case of concessions for hydroelectric generation units with an installed capacity of 5,000 kW or less, upon the expiration of their original term, the concessions may be granted to the current concessionaire in the form of registration, for an indefinite term.

Generation Concessions

Of the nineteen (19) hydroelectric plants we operated in 2019, fourteen (14) were operated under the generation concession contracts that were in force prior to the 2013 Concession Renewal Law, and five (5) were operated in accordance with the 2013 Concession Renewal Law (Capivari Cachoeira HPP, Chopim I HPP, Marumbi HPP, Baixo Iguaçu HPP and Colíder HPP). In 2013, 12 of the 13 hydro and thermoelectric generation concessions operated by the Company in 2013 (exception made only to Rio dos Patos HPP) were extended pursuant to the old regime and could be renewed again under the 2013 Concession Renewal Law.

However, at the time the 2013 Concession Renewal Law was enacted, the Company elected not to renew the following generation concessions: Rio dos Patos (2014), Mourão I (2015), Chopim I (2015) and Capivari Cachoeira (2015), all of which had remaining terms of 60 months or less. Please see below for further information on each of these concessions.

Foz do Areia HPP. Copel Geração e Transmissão did not elect to renew the original concession pursuant the 2013 Concession Renewal Law for the Foz do Areia HPP (Governador Bento Munhoz da Rocha Netto). However, in order to obtain a new concession for the Foz do Areia HPP for another 30 years, Copel GeT transferred the ownership of this HPP to its subsidiary, the SPC F.D.A. Geração de Energia Elétrica S.A (F.D.A) on March 3, 2020, and, on the same date, requested a new concession from the Ministry of Mines and Energy pursuant to Federal Decree no. 9,271/2018 (as amended by Federal Decree no. 10,135/2019), which conditions that, to obtain a new concession, the sale of the concession's corporate control (F.D.A) must occur. On the same date, F.D.A. signed with ANEEL the Concession Contract that transfers the concession of the HPP Foz do Areia from Copel GeT to the F.D.A., for the exploration of the plant until the end of the current concession, on September 17, 2023.

Rio dos Patos HPP. The concession of Rio dos Patos HPP was terminated and not submitted to a further bidding process due to the lack operational conditions.

Mourão I and Capivari Cachoeira HPP. The granting authority submitted the concessions for HPP Capivari Cachoeira and Mourão I to new bidding processes, pursuant to which new agreements should be in force for a 30-year period. Copel GeT was the winner in the bidding process related to HPP Capivari Cachoeira. With respect to Capivari Cachoeira, although Copel GeT did not elect to renew the original concession for the Capivari Cachoeira HPP, it participated in the new competitive bidding process and won. On January 5, 2016, Copel GeT executed a concession agreement with ANEEL so that it will continue to operate this plant under an operation and maintenance regime until 2046. We paid a total amount of R$574.8 million as signing bonus for this concession agreement. 100.0% of the energy generated by this plant in 2016 was allocated in quotas to the regulated market, and reduced to 70.0% on January 1, 2017. Copel GeT can sell remaining amount of energy generated by this plant on the Free Market or Spot Market.

Chopin I HPP. As the installed capacity of Chopin I HPP does not exceed the 5,000 kW, the concession regime of this plant has been changed to a registration in favor of the Company, valid for an indefinite term.

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Figueira TPP. Our concession for the Figueira TPP expired on March 26, 2019. We had filed an extension request with respect to this plant on May 24, 2017, but we are still waiting for the granting authority to amend our concession agreement, extending its term for an additional 20-year period in accordance with the 2013 Concession Renewal Law. This plant has an installed capacity equivalent to 20 MW and subject to a modernization process.

With respect to the concessions granted between 2011 and 2017 with no renewal right attached, we acquired the right to renew only one of the hydroelectric plants (HPP Cavernoso II) for a 30-year period, as a result of an amendment to the 2013 Concession Renewal Law by Law No. 13,360, of November 17, 2016.

In accordance with the 2013 Concession Renewal Law, Copel could have flagged to the granting authority by 2019 its intention to renew the concession of HPP São Jorge. However, Copel elected not to renew such concession and, consequently, it will be able to operate such HPP until December 2024 and request the conversion of this operating regime into a registration regime, as the installed capacity does not exceed 5,000 kW.

As the installed capacity of Chopin I HPP also does not exceed 5,000 kW, the concession regime of this plant has been changed to a registration in favor of the Company, valid for an indefinite term. In addition, pursuant to the same statute, the Company may flag to the granting authority its intention to extend: (i) in 2020, the concession of HPP Apucaraninha; and (ii) in 2021, the concessions of HPP Guaricana and Chaminé. In the event the Company does not request the extension of these concessions, they will be subject to new bidding processes conducted by the granting authority.

Concessions for generation projects granted after December 11, 2003 were not affected by the 2013 Concession Renewal Law and are non-renewable, meaning that upon expiration of their 35-year term, the concession will be granted subject to a new competitive bidding process. In 2019, we had three (3) hydroelectric plants operating in this condition (HPP Mauá, HPP Colíder and HPP Baixo Iguaçu).

The following tables sets forth information relating to the terms as well as the renewals of our main generation hydroelectric, thermoelectric and wind farm plants and all of which we hold a direct ownership interest in:

Hydroelectric Plants | Initial concession date | First expiration date | Extension Date | Final expiration date
Foz do Areia (1) | May, 1973 | May, 2003 | January, 2001 | September, 2023
Apucaraninha | October, 1975 | October, 2005 | April, 2003 | October, 2025
Guaricana | August, 1976 | August, 2006 | August, 2005 | August, 2026
Chaminé | August, 1976 | August, 2006 | August, 2005 | August, 2026
Segredo | November, 1979 | November, 2009 | September, 2009 | November, 2029
Derivação do Rio Jordão | November, 1979 | November, 2009 | September, 2009 | November, 2029
Salto Caxias | May, 1980 | May, 2010 | September, 2009 | May, 2030
Mauá (2) | June, 2007 | July, 2042 | Not extendable | July, 2042
Colíder(3) | January, 2011 | January, 2046 | Not extendable | January, 2046
Cavernoso II | February, 2011 | February, 2046 | Not extendable | February, 2046
Baixo Iguaçu(4) | August, 2012 | August, 2047 | Not extendable | September, 2049
SHP Bela Vista (5) | May, 2007 | January, 2041 | Extendable | January, 2071

(1) | In March 3, 2020, the concession of Foz do Areia was transferred from Copel GeT to FDA pursuant to ANEEL Authorizing Resolution no. 8.578/2020. Copel GeT owns 100% of FDA Geração de Energia S.A.

(2) | Mauá was constructed by Consórcio Energético Cruzeiro do Sul, of which Copel owns 51.0% and Eletrosul owns the remaining 49.0%.

(3) | The commercial operations of generation units 1, 2 and 3 of Colíder’s began in March 2019, May 2019 and December 2019, respectively.

(4) | Baixo Iguaçu was constructed by Consórcio Empreendedor Baixo Iguaçu, of which Copel owns 30% and Geração Céu Azul the remaining 70%. The commercial operations of generation units 1, 2 and 3 of Baixo Iguaçu’s began in February 2019, Feburary 2019 and April 2019, respectively.

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(5) | The consortium CBVG, formed by Copel GeT and Foz do Chopim Energética Ltda., won ANEEL Auction No. 003/2018 for SHP Bela Vista. In April 2019, the authorization to operate SHP Bela Vista was transferred from Foz do Chopim Energética Ltda. to Bela Vista Geração de Energia S.A through the Aneel’s Authorizing Resolution no. 7.802/2019. In December 2019, Copel GeT became the owner of 100% of Bela Vista Geração de Energia. This power plant is still under construction. .

Thermoelectric Plants | Initial concession date | First expiration date | Extension date | Final expiration date
Figueira | March 1969 | March 1999 | June 1999 | March 2019

Wind Plants | Initial concession date | First expiration date
Asa Branca I | April, 2011 | April, 2046
Asa Branca II | May, 2011 | May, 2046
Asa Branca III | May, 2011 | May, 2046
Nova Eurus IV | April, 2011 | April, 2046
Santa Maria | May, 2012 | May, 2047
Santa Helena | April, 2012 | April, 2047
Ventos de Santo Uriel | April, 2012 | April, 2047
Boa Vista | April, 2011 | April, 2046
Farol | April, 2011 | April, 2046
Olho D'Água | June, 2011 | May, 2046
São Bento do Norte | May, 2011 | May, 2046
Cutia(1) | January, 2012 | January, 2042
Guariju(1) | January, 2012 | January, 2042
Jangada(1) | January, 2012 | January, 2042
Maria Helena(1) | January, 2012 | January, 2042
Palmas | September, 1999 | September, 2029
Potiguar(1) | May, 2015 | May, 2050
Esperança do Nordeste(1) | May, 2015 | May, 2050
Paraíso dos Ventos do Nordeste(1) | May, 2015 | May, 2050
São Bento do Norte I(1) | August, 2015 | August, 2050
São Bento do Norte II(1) | August, 2015 | August, 2050
São Bento do Norte III(1) | August, 2015 | August, 2050
São Miguel I(1) | August, 2015 | August, 2050
São Miguel II(1) | August, 2015 | August, 2050
São Miguel III(1) | August, 2015 | August, 2050
Jandaíra I(2) | April, 2020 | April, 2055
Jandaíra II(2) | April, 2020 | April, 2055
Jandaíra III(2) | April, 2020 | April, 2055
Jandaíra IV(2) | April, 2020 | April, 2055

(1) | Wind plants located at Copel’s Cutia wind farm complex.

(2) | The consortium formed by Copel GeT and Cutia Empreendimentos Eólicos S.A.., won ANEEL Auction no. 004/2019 for Jandaíra Wind Complex (I, II, III and IV) and granting process is still ongoing.

The following table sets forth information relating to the terms of our generation hydroelectric plant, whose concession agreement has been executed under the terms and conditions of the 2013 Concession Renewal Law:

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Hydroelectric Plants | Initial concession date | First expiration date | Extension Date | Final expiration date
Capivari Cachoeira (Gov Parigot de Souza) | January, 2016 | January, 2046 | Not subject to extension | January, 2046

The following table sets forth information relating to the terms of our generation hydroelectric plants which, once respective original concession period expires, will no longer be subject to a concession regime but rather to a registration proceeding with the ANEEL:

Hydroelectric Plants(1) | Initial concession date | Concession expiration date | Final expiration date
Chopim I | March, 1964 | July, 2015 | Indefinitely
São Jorge | December, 1974 | December, 2024 | -
Cavernoso | January, 1981 | January, 2031 | -
Melissa | May, 2002 | Indefinitely | -
Pitangui | May, 2002 | Indefinitely | -
Salto do Vau | May, 2002 | Indefinitely | -
Marumbi | March, 1956 | May, 2018 | Indefinitely

(1) | Upon the expiration of concessions or authorizations for hydroelectric energy generation with installed capacity equal to or less than 5,000 KW, the relevant projects are subject to a registration regime in accordance with Brazilian Federal Law No. 9,074/1995, as amended by Brazilian Federal Law No. 13,360/2016. The operation of hydroelectric and thermoelectric plans with installed capacity of up to 5,000 KW are not subject to any concession, permission or authorization and require solely the registration with the granting authority.

We also have ownership interests in eleven (11) other generation projects. The following table sets forth information relating to the terms of the concessions of the generation facilities in which we had such partial ownership interest as of December 31, 2019.

Generation Facility | Company | Initial concession date | Expiration date | Extension
HPP Dona Francisca | Dona Francisca Energética SA ‒ DFESA | July, 1979 | August, 2033 | Possible
HPP Santa Clara | Centrais Elétricas do Rio Jordão S.A. - ELEJOR | October, 2001 | May, 2037 | Possible
HPP Fundão | Centrais Elétricas do Rio Jordão S.A. - ELEJOR | October, 2001 | May, 2037 | Possible
SHP Santa Clara I | Centrais Elétricas do Rio Jordão S.A. - ELEJOR | December, 2002 | December, 2032 | Possible
SHP Fundão I | Centrais Elétricas do Rio Jordão S.A. - ELEJOR | December, 2002 | December, 2032 | Possible
TPP Araucária | UEG Araucária Ltda. | December, 1999 | December, 2029 | Possible
HPP Arturo Andreoli | Foz do Chopim Energética | April, 2000 | April, 2030 | Possible
WPP Carnaúbas | São Miguel do Gostoso I | April, 2012 | April, 2047 | Not possible
WPP Reduto | São Miguel do Gostoso I | April, 2012 | April, 2047 | Not possible
WPP Santo Cristo | São Miguel do Gostoso I | April, 2012 | April, 2047 | Not possible
WPP São João | São Miguel do Gostoso I | March, 2012 | March, 2047 | Not possible

Transmission Concessions

Pursuant to the 2013 Concession Renewal Law and the terms of our transmission concessions, we have the right to request 30-year extensions of the concessions from ANEEL, provided that such request is delivered within 60 months prior to the expiration of the contract. Our principal transmission concession, from which 71%

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of our transmission revenues in 2019 derived, has been renewed pursuant to the 2013 Concession Renewal Law, and will therefore now expire in December 2042.

In addition, in 2019, an aggregate of 29% of our transmission revenues derived from eleven (11) other concession contracts for transmission lines and substations that are currently in operation and whose terms and extensions are set forth in the next table. In accordance with the 2013 Concession Renewal Law, each of these contracts can be extended for an additional 30-year period.

We intend to continue requesting extensions for all of our transmission concessions.

The following table sets forth certain information relating to the terms and extension terms of our main transmission concessions (all of which we hold a direct ownership interest), including the concession contracts for transmission lines and substations both in operation or under construction:

Transmission Facility | Initial concession Date | First expiration Date | Possibility of extension | Expected (or final) expiration date
Main transmission concession | July, 2001 | July, 2015 | Extended | December, 2042
Bateias – Jaguariaíva | August, 2001 | August, 2031 | Possible | August, 2061
Bateias – Pilarzinho | March, 2008 | March, 2038 | Possible | March, 2068
Foz do Iguaçu – Cascavel Oeste | November, 2009 | November, 2039 | Possible | November, 2069
Substation Cerquilho III | October, 2010 | October, 2040 | Possible | October, 2070
Araraquara 2 – Taubaté | October, 2010 | October, 2040 | Possible | October, 2070
Foz do Chopim - Salto Osorio | August, 2012 | August, 2042 | Possible | August, 2072
Assis – Paraguaçu Paulista II | February, 2013 | February, 2043 | Possible | February, 2073
Bateias – Curitiba Norte | January, 2014 | January, 2044 | Possible | January, 2074
Realeza Sul – Foz do Chopim | September, 2014 | September, 2044 | Possible | September, 2074
Assis - Londrina | September, 2014 | September, 2044 | Possible | September, 2074
Curitiba Leste – Blumenau(1) | April, 2016 | April, 2046 | Possible | April, 2076

(1) | Facility under construction.

We have ownership interests in ten (10) other transmission projects, through special purpose companies. The following table sets forth information relating to the terms of the concessions of the transmission facilities in which we had such partial ownership interest as of December 31, 2019:

Transmission Facility | Special Purpose Company (SPC) | Initial concession date | First Expiration date | Possibility of Extension | Expected (or final) expiration date
Cascavel Oeste – Umuarama | Costa Oeste Transmissora de Energia S.A | January, 2012 | January, 2042 | Possible | January, 2072
Umuarama - Guaira | Caiuá Transmissora de Energia S.A | May, 2012 | May, 2042 | Possible | May, 2072
Açailândia Miranda II | Integração Maranhense Transmissora de Energia S.A. | May, 2012 | May, 2042 | Possible | May, 2072
Curitiba - Curitiba Leste | Marumbi Transmissora de Energia S.A. | May, 2012 | May, 2042 | Possible | May, 2072
Paranaíta – Ribeirãozinho | Matrinchã Transmissora de Energia S.A. | May, 2012 | May, 2042 | Possible | May, 2072
Ribeirãozinho – Marimbondo II | Guaraciaba Transmissora de Energia S.A | May, 2012 | May, 2042 | Possible | May, 2072
Barreiras II – Pirapora II | Paranaíba Transmissora de Energia S.A | May, 2013 | May, 2043 | Possible | May, 2073

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Itatiba – Bateias | Mata de Santa Genebra Transmissora S.A | May, 2014 | May, 2044 | Possible | May, 2074
Estreito – Fernão Dias | Cantareira Transmissora de Energia S.A. | September, 2014 | September, 2044 | Possible | September, 2074
Ivaiporã – Londrina | Uirapuru Transmissora de Energia S.A. | March, 2005 | March, 2035 | Possible | March 2065

Distribution Concessions

We originally operated our distribution business pursuant to a concession contract that was signed on June 24, 1999 (retroactive to July 7, 1995), and was set to expire on July 7, 2015. Under the 2013 Concession Renewal Law, we had the right to renew this concession for an additional 30-year period by accepting an amendment to the concession contract. Notwithstanding the changes introduced by the 2013 Concession Renewal Law, we concluded that the renewal of our distribution concession in accordance with the 2013 Concession Renewal Law would not materially affect our results of operations. Accordingly, after a careful evaluation of the conditions imposed by the Brazilian federal government for the extension of our distribution concession, we decided to request the renewal of this contract and our renewal request was approved by the MME on November 11, 2015. On December 9, 2015, we have executed the fifth amendment to the public Electricity Distribution Service Concession Agreement No. 46/1999 of Copel Distribuição S.A.

This amendment imposes efficiency conditions to Copel Distribuição that are measured through two different metrics: quality of the service and economic-financial sustainability of the company. Failure to comply with any of these metrics (i) for two consecutive years within the first four years of this renewed concession or (ii) in the fifth year of this concession, may, in each case, result in the termination of our distribution concession. From January 1, 2021 on, failure to comply with the quality indicator for three consecutive years or the economic-financial sustainability indicator for two consecutive years may also result in the termination of the distribution concession.

Additionally, non-compliance with quality indicator targets for two consecutive years or three times in five years may lead to restrictions in the payment of dividends and interest on equity to the controlling shareholders of Copel Distribuição, while non-compliance with the economic-financial sustainability indicators may require capital contributions from Copel Distribuição controlling shareholders.

The table below presents the economic and financial and quality indicators established for the first five (5) years after the execution of this amendment.

| Economic and Financial Indicators | Quality Indicators (1)
Year |  | DECi(2) | FECi(2)
2016 | N/A | 13.61 | 9.24
2017 | EBITDA(3) ≥ 0 | 12.54 | 8.74
2018 | [EBITDA (-) QRR (4)] ≥ 0 | 11.23 | 8.24
2019 | {Net Debt(5)/[EBITDA(3) (-) QRR(4)]} ≤ 1/(0.8*SELIC(6)) | 10.12 | 7.74
2020 | {Net Debt(5)/[EBITDA(3) (-) QRR(4)]} ≤ 1/(1.11*SELIC(6)) | 9.83 | 7.24

(1) | According to ANEEL’s Technical Note No. 0335/2015.

(2) | DECi – Duration of outages per customer per year (in hours); and FECi – Frequency of outages per customer per year (number of outages).

(3) | Earnings before interest, tax depreciation and amortization, as calculated according to ANEEL regulations.

(4) | QRR: Regulatory Reintegration Quota or Regulatory Depreciation Expense. This is the value defined in the most recent Periodic Tariff Review (RTP), plus the General Market Price inflation index (IGP-M) between the month preceding the Periodic Tariff Review and the month preceding the twelve-month period of the economic and financial sustainability measurement.

(5) | As calculated according to ANEEL regulations.

(6) | Selic base rate: limited to 12.87% per year.

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We have complied with the quality indicators for 2019 both with respect to DECi totaling 9.10 in 2019) and FECi (totaling 6.0 in 2019).

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COMPETITION

We have concessions to distribute electricity in substantially all of the State of Paraná, and we do not face competition from the five utilities that have been granted concessions for the remainder of the state. As a result of legislation passed in 2004, however, other suppliers are able to offer electricity to our existing Free Customers at prices lower than those we currently charge. However, when a Captive Customer becomes a Free Customer, it is still required to pay to use our distribution grid. The reduction in net revenue of our distribution business is therefore compensated with a reduction in our costs for energy that we would otherwise acquire to sell to these customers.

Furthermore, under certain circumstances, Free Customers may be entitled to connect directly to the Interconnected Transmission System rather than our distribution grid. Unlike a Free Customer’s choice of another energy supplier, in which case that customer must still use our distribution grid and thus pay us the appropriate tariff, our distribution business ceases to collect tariffs from a customer that connects directly to the Interconnected Transmission System. The migration of customers from the distribution grid to the transmission network therefore results in the loss of revenues for our distribution business.

Distribution and transmission companies are required to permit the use of their lines and ancillary facilities for the distribution and transmission of electricity by other parties upon payment of a tariff.

Free Customers are limited to:

| · | as from July 1, 2019, customers with demand of at least 2.5 MW; after January 1, 2020, with demand of at least 2 MW; after January 1, 2021, with demand of at least 1.5 MW; after January 1, 2022, with demand of at least 1.0 MW at any voltage; and, after January 1, 2023, with demand of at least 500 kW at any voltage; and

| · | customers with demand of at least 500 kW that opt to be supplied energy by means of alternative sources, such as wind power projects, small hydroelectric power plants, biomass projects, solar plants and others.

As of December 31, 2019, we had 425 Free Customers (of which 375 were customers of our energy trading company and 50 of Copel GeT), representing approximately 5.7% of our consolidated operating revenue and approximately 13.8% of the total quantity of electricity sold by us.

Without the addition of new contracts in 2019, Copel GeT had 50 Free Costumers as of December 31, 2019. Approximately 17.67% of the megawatts-hours sold under contracts to such customers by Copel GeT expired in 2019. These customers represented approximately 4.88% of the total volume of electricity we sold in 2019, and approximately 4.09% of total net operating revenue from energy sales for that year.

In the generation business, any producer may be granted a concession to build or manage thermoelectric and small hydroelectric generating facilities in the State of Paraná. Brazilian law provides for competitive bidding for generation concessions for hydroelectric facilities and, since 2017, this requirement applies only to facilities with capacity higher than 50 MW.

In the transmission business, Brazilian law provides for competitive bidding for transmission concessions for facilities with a voltage of 230 kV or greater that will form part of the Interconnected Transmission System.

Brazilian law requires that all of our generation, transmission and distribution concessions be subject to a competitive bidding process upon their expiration. We may face significant competition from third parties in bidding for renewal of such concessions or for any new concessions. The loss of certain concessions could adversely affect our results of operations.

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ENVIRONMENT

Our construction and operation activities for the generation, transmission and distribution of electric energy, distribution of natural gas and our telecommunications operations are subject to federal, state and municipal environmental regulations.

All of our activities follow our Sustainability Policy, which integrates corporate planning and sustainability management in order to optimize our financial, social and environmental performance. Also our activities follow our Climate Change Policy, which establishes guidelines for the mitigation of greenhouse gas emission and changes in our business, evaluating risks and opportunities related to climate change.

We request and renew our environmental licenses in accordance with the environmental regulation issued by applicable federal, state and municipal level authorities. We are in compliance with all material environmental regulations and our more recent (post-1986) generation, transmission and distribution projects are in compliance with federal, state and municipal regulations.

Being a signatory to the Global Compact since 2000, we are committed to sustainability. As a founding member of the Brazilian Global Compact Network Committee, created in 2003, we support the movement to disseminate the principles of the Global Compact in promoting effective and consistent articulations between governments, companies and social organizations in favor of social, environmental and economic challenges for sustainability, as well as raising awareness among other Brazilian companies to engage and adopt corporate citizenship as a standard for managing their businesses.

We adopt best market practices to guide and evaluate our performance, and compare practices with global and local references: B3 Corporate Sustainability Index - ISE, Ethos Indicators for Sustainable and Responsible Business Models, and other evaluations and classifications related to ESG (Environmental, Social and Governance) matters.

Through an annual report, we reinforce our commitment to sustainable development and are accountable for our performance related to economic, social, environmental and governance aspects (Integrated Report Copel). This report follows the international guidelines of the Standards model of the Global Reporting Initiative (GRI), and the International Integrated Reporting Initiative (IIRC), and is submitted to independent assurance, to ensure the reliability of the information disclosed.

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PLANT, PROPERTY AND EQUIPMENT

Our principal properties consist of the generation and telecommunications facilities described in “Business”. Of the net book value of our total property, plant and equipment as of December 31, 2019 (including construction in progress), generation facilities represented 58.5%, wind farms represented 27.5%, telecommunications represented 7.9%, Elejor represented 3.5%, and Araucária Thermoelectric plant represented 2.7%. We believe that our facilities generally are adequate for our present needs and suitable for their intended purposes.

In addition, the infrastructure used by transmission and distribution business is classified as a financial, contract and intangible assets as described in Notes 4.4, 4.5 and 4.9 to our audited consolidated financial statements.

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THE EXPROPRIATION PROCESS

Although we receive concessions from the Brazilian government to construct hydroelectric facilities, we do not receive title to the land on which the facilities are to be located. In order for us to construct, the land must be expropriated. The land required for the implementation of a hydroelectric facility may only be expropriated pursuant to specific legislation, after proving its public interest. We generally negotiate with communities and individual owners occupying the land so as to resettle such communities in other areas and to compensate individual owners. Our policy of resettlement and compensation generally has resulted in the settlement of expropriation disputes, with friendly settlements for most of them. As of December 31, 2019, we estimated our liability related to the settlement of such disputes to be approximately R$118.7 million. This amount is in addition to amounts for land expropriation included in each of our hydroelectric facility budgets.

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The Brazilian eLECTRIC Power Industry

General

In February 2020, according to Ordinance No. 38/2020, MME approved the Decennial Energy Plan - PDE 2029, which projects that the installed capacity of electricity generation in Brazil will be 221 in GW in 2029 (not including distributed generation and self-production). It is projected in the 2020 PDE that 81% of this total will be renewable (47% is projected to be hydroelectric and 34% will be alternative sources of energy, such as wind, biomass and small hydroelectric plants), 18% will be thermoelectric, 5% will be solar, and 2% will be nuclear.

As of 2019, approximately 30% of the installed power generating capacity of Brazil is currently owned by Eletrobras (including its wholly-owned subsidiary Eletronuclear and its 50% participation interest in Itaipu). Through its subsidiaries, Eletrobras is also responsible for approximately 45% of the installed transmission capacity equal or above 230 kV within Brazil. In addition, some Brazilian states control entities involved in the generation, transmission and distribution of electricity. They include Companhia Energética de Minas Gerais – CEMIG and us, among others.

Principal Regulatory Authorities

Ministry of Mines and Energy – MME

The MME is the primary regulatory institution of the power industry and acts as the Brazilian governmental authority empowered with policymaking, regulatory and supervisory powers.

National Energy Policy Council – CNPE

The National Energy Policy Council (Conselho Nacional de Política Energética - “CNPE”), created in August 1997, provides advice to the President of the Republic of Brazil regarding the development and creation of a national energy policy. The CNPE is chaired by the MME and is composed of six ministers of the Federal Government and three members chosen by the President of Brazil. The CNPE was created in order to optimize the use of energy resources in Brazil and ensure the national supply of electricity.

National Electric Energy Agency – ANEEL

The Brazilian power industry is regulated by ANEEL, an independent federal regulatory agency. ANEEL’s primary responsibility is to regulate and supervise the power industry in accordance with the policies set forth by the MME and to respond to matters which are delegated to it by the Brazilian government and the MME. ANEEL’s current responsibilities include, among others, (i) administering concessions for electric energy generation, transmission and distribution, including the approval of electricity tariffs, (ii) enacting regulations for the electric energy industry, (iii) implementing and regulating the utilization of energy sources, including the use of hydroelectric power, (iv) promoting, monitoring and managing the public bidding process for new concessions, (v) settling administrative disputes among electricity sector entities and electricity purchasers, and (vi) defining the criteria and methodology for the determination of transmission and distribution tariffs.

National Electric System Operator – ONS

The ONS (Operador Nacional do Sistema Elétrico) is a non-profit private entity comprised of electric utilities engaged in the generation, transmission and distribution of electric energy, in addition to other private participants such as importers, exporters and Free Customers. The primary role of the ONS is to coordinate and regulate the generation and transmission operations in the Interconnected Transmission System, subject to the ANEEL’s regulation and supervision. The objectives and principal responsibilities of the ONS include, among others, operational planning for the generation industry, organizing the use of the domestic Interconnected Transmission System and international interconnections, ensuring that industry participants have access to the transmission network in a non-discriminatory manner, assisting in the expansion of the electric energy system,

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proposing plans to the MME for extensions of the Interconnected Transmission System, and formulating regulations regarding the operation of the transmission system for ANEEL’s approval.

Electric Energy Trading Chamber – CCEE

The CCEE (Câmara de Comercialização de Energia Elétrica) is a non-profit private entity subject to authorization, inspection and regulation by ANEEL. The CCEE is responsible for, among other things, (i) registering all energy purchase agreements in the regulated market, Contratos de Comercialização de Energia no Ambiente Regulado (“CCEAR”) and in the Free Market, (ii) accounting for and clearing short-term transactions and (iii) managing funds generated by some of the regulatory charges. The CCEE is composed of holders of concessions, permissions and authorizations in the electricity industry and Free Customers, and its board of directors is composed of four members appointed by these agents and one by the MME, who is the chairman of the board of directors.

Energy Sector Monitoring Committee – CMSE

The CMSE (Comitê de Monitoramento do Setor Elétrico) was created by the New Industry Model Law to monitor service conditions and to recommend preventative measures to ensure energy supply adequacy, including demand-side action and contracting of energy reserves.

Energy Research Company – EPE

In August 2004, the Brazilian government created the Energy Research Company (Empresa de Pesquisa Energética - “EPE”), a federal public company responsible for conducting strategic studies and research in the energy sector, including the industries of electric power, petroleum, natural gas, coal and renewable energy sources. The studies and research conducted by the EPE subsidize the formulation of energy policy by the MME.

Eletrobras

Eletrobras serves as a holding company for the following federally-owned energy companies: Companhia Hidro Elétrica do São Francisco – CHESF, Furnas Centrais Elétricas S.A., CGT Eletrosul, Centrais Elétricas do Norte do Brasil S.A. – Eletronorte, Companhia de Geração Térmica de Energia Elétrica – CGTEE and Eletrobras Termonuclear S.A. – Eletronuclear, Centro de Pesquisas de Energia Elétrica – Cepel and Itaipu Binacional. Eletrobras manages the commercialization of energy from Itaipu and from alternative energy sources, under the Program for incentive to alternative energy sources (Programa de Incentivo às Fontes Alternativas de Energia – “Proinfa”).

Historical Background of Industry Legislation

The Brazilian constitution provides that the development, use and sale of electric energy may be undertaken directly by the Brazilian federal government or indirectly through the granting of concessions, permissions or authorizations. Historically, the Brazilian electric energy industry has been dominated by generation, transmission and distribution concessionaires controlled by the federal or state governments. Since 1995, the Brazilian government has taken a number of measures to reform the Brazilian electric energy industry. in general, these measures were aimed at increasing the role of private investment and eliminating foreign investment restrictions in order to increase overall competition and productivity in the industry.

The following is a summary of the principal developments in the regulatory and legal framework of the Brazilian electricity sector:

| · | In 1995, (i) the Brazilian constitution was amended to authorize foreign investment in power generation; (ii) the Concessions Law was enacted, requiring that all concessions for energy-related services be granted through public bidding processes, providing for the creation of independent producers and Free Customers and granting electricity suppliers and Free Customers open access to all distribution and transmission systems; and (iii) a portion of the controlling interests held by Eletrobras and various Brazilian states in generation and distribution companies were sold to private investors.

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| · | In 1998, the Power Industry Law was enacted, providing for, among other things, the creation of the ONS and the appointment of Banco Nacional de Desenvolvimento Econômico e Social (“BNDES”), a development bank wholly owned by the Brazilian government, as the financing agent of the power industry, especially to support new generation projects.

| · | In 2001, Brazil faced a serious energy crisis that lasted through February 2002. During this period, the Brazilian government implemented an energy-rationing program in the most adversely affected regions, namely the southeast, central-west and northeast regions of Brazil. In April 2002, the Brazilian government for the first time implemented the extraordinary tariff adjustment to compensate the electricity suppliers for financial losses incurred as a result of the rationing period.

| · | In 2004, the Brazilian government enacted the New Industry Model Law (Law No. 10,848), in an effort to further restructure the power industry with the ultimate goal of providing customers with a stable supply of electricity at reasonable prices. The New Industry Model Law introduced material changes to the regulation of the electric energy industry, in order to (i) provide incentives to private and public entities to build and maintain generation capacity, and (ii) ensure the supply of electricity in Brazil at low tariffs through a competitive electricity public bidding process. The key elements of the New Industry Model Law include:

| o | Ensuring the existence of two markets: (i) the regulated market, a more stable market in terms of supply of electricity, and (ii) a market specifically addressed to certain participants (i.e., Free Customers and energy-trading companies), called the Free Market, that permits a certain degree of competition vis-à-vis the regulated market.

| o | Restrictions on certain distribution activities, including requiring distributors to focus on their core business of distribution activities in order to promote more efficient and reliable services to Captive Customers.

| o | Elimination of self-dealing by providing an incentive for distributors to purchase electricity at the lowest available prices rather than buying electricity from related parties.

| o | Upholding contracts executed prior to the New Industry Model Law, in order to provide regulatory stability for transactions carried out before its enactment.

| · | In 2004, Decree No. 5,163 was enacted to governor the purchase and sale of electricity in the regulated market and the Free Market, as well as the granting of authorizations and concessions for electricity generation projects. This decree includes, among other items, rules relating to auction procedures, the form of power purchase agreements and the mechanism for passing costs through to final customers. Among other matters, this decree:

| o | provides for the guidelines under which electricity-purchasing agents must contract their electricity demand. Electricity-selling agents must show that the energy to be sold comes from existing or planned power generation facilities. Agents that do not comply with such requirements are subject to penalties imposed by ANEEL.

| o | requires electricity distribution companies to contract for 100% of their energy needs primarily through public auctions. In addition to these auctions, distribution companies can purchase limited amounts (up to 10% of their demand) from: (i) generation companies that are connected directly to a distribution company (except for hydroelectric power plants with capacity higher than 30 MW and certain thermoelectric power plants) (ii) electricity generation projects participating in the initial phase of the Proinfa Program, (iii) the Itaipu Power Plant and (iv) quotas from those generation concession contracts extended or subject to a new competitive bidding process in accordance with the 2013 Concession Renewal Law.

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| o | provides that the MME shall establish the total amount of energy that will be contracted in the regulated market, including the number and the type of generation projects that will be auctioned each year.

| o | requires all electricity generation, distribution and trading companies, independent producers and Free Customers to notify MME, by August 1st of each year, of their estimated electricity demand or estimated electricity generation, as the case may be, for each of the subsequent five years. In advance of each electricity auction, each distribution company is also required to inform MME of the amount of electricity that it intends to contract in the auction. In addition, distribution companies are required to specify the portion of the contracted amount they intend to use to supply potentially Free Customers.

| · | In 2012, the Brazilian government enacted two Provisional Measures that brought important changes to the Brazilian electricity regulatory framework: (i) Provisional Measure No. 577, dated as of August 29, 2012 (converted into Law No. 12,767 dated as of December 27, 2012); and (ii) Provisional Measure No. 579, dated September 11, 2012 (converted into the 2013 Concession Renewal Law). Provisional Measure No. 577 established the obligation of the granting authority to render electricity services in the event of termination of an electricity concession, as well as new rules related to the intervention by the granting authority in electricity concessions to ensure adequate performance of Utility services. The 2013 Concession Renewal Law established new rules that changed concessionaires’ ability to renew concession contracts. Under this Law, generation and distribution concessionaires may renew their concession contracts that were in effect as of 1995 and transmission concessionaires may renew their concession contracts that were in effect prior to and as of 1995 for an additional period of 30 years, provided that the concessionaires agree to amend the concession contracts to reflect a new tariff regime to be established by ANEEL. See “Concessions”.

| · | In 2013, the 2013 Concession Renewal Law was enacted. This statute changed the nature of the concession agreements for generation facilities existing at the time. Prior to 2013, a generation concessionaire had the right to sell the energy generated by the facilities subject to its concession for profit. In contrast, generation concessions for existing generation facilities (including those renewed pursuant to the 2013 Concession Renewal Law) could no longer grant concessionaires the right to sell the energy generated by these facilities. Instead, these concessions started to cover the operation and maintenance of the generation facilities. The energy generated by these facilities was then allocated by the Brazilian federal government in quotas to the regulated market, for purchase by distribution concessionaires. In case of generation facilities created after the 2013 Concession Renewal Law, the concessionaire has the right to sell the energy produced by the facility. For further information, see “Item 4. Information on the Company—Concessions—2013 Concession Renewal Law.”

| · | In 2015, the Brazilian government enacted Provisional Measure No. 688, dated as of August 18, 2015, converted into Federal Law No. 13,203, dated as of December 8, 2015, to revise the allocation of the hydrological risks borne by hydroelectric power plants that share hydrological risks under Energy Reallocation Mechanism. In 2014 and 2015, given poor hydrological conditions, the MRE participants generated less electricity than their assured energies, which was confirmed by a significant decrease of the Generating Scaling Factor (“GSF”), a measurement of the proportion between the electricity generated by the MRE participants and their respective assured energy. These generation deficits resulted in losses for the MRE participants given their exposure to hydrological risks. As a consequence, Federal Law No. 13,203 established an optional mechanism that allows each generation plant to transfer these risks to Final Customers upon payment of a risk premium to the Brazilian federal government, as well as certain temporary extensions of generation concessions to compensate for losses in 2015. We decided to opt-in with respect to all of Copel GeT´s and Elejor´s eligible Energy Agreements under this new hydrological risk allocation mechanism, which represented approximately 16% of Copel GeT´s total assured energy.

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| · | In 2016, the Brazilian government enacted Provisional Measure No. 735, dated as of June 22, 2016, converted into Federal Law No. 13,360, dated as of November 17, 2016, which changed several federal laws mainly to: (i) revise certain rules related to regulatory charges (CDE, CCC and RGE) and appoint CCEE as the new manager of such charges in lieu of Eletrobras; (ii) facilitate the privatization of generation, transmission and distribution companies, (iii) change certain requirements of the generation concession and authorization regimes; (iv) change rules related to the MRE; (v) allow distribution companies to sell energy excess in the Free Market; (vi) extension of terms for commencement of the supply under energy auctions in the regulated market; and (vii) transfer back from MME to ANEEL the authority to decide about generation and transmission companies’ requests for extension of their facilities construction schedules.

| · | In July 2017, the MME released the Public Consultation No. 033/2017, named “Proposal for improvement of the legal framework of the electricity sector”. This public consultation marks an important step to guide the MME in preparation of specific legislative proposals capable of providing measures of economic rationalization and modernization of the electricity sector.

| · | In August 2017, Decree No. 9,143/2017 changed the frequency of the auctions for new energy and authorized the distribution companies to negotiate contracts for the sale of energy in the Free Market to Free Consumers and other agents (generators, marketers, and self-producers), provided that these contracts are linked to excess in energy contracted in auctions.

| · | In January 2018, Decree No 9,271/2018 regulated the granting of a new energy concession in the event of privatization of an energy generation concession holder that provides public services, in accordance with Law No 9.074, dated July 7, 1995. Pursuant to this decree, the Brazilian Federal Government may grant a new concession contract for a period of up to 30 years to the entity that results from a bidding process for the privatization of a concessionaire previously controlled directly or indirectly by a federal, state or municipal governmental entity. This decree determined that [the concessionaire shall request a new concession contract during the remaining period of its concession (up to 60 months counted from the end of the concession)]. This decree was amended in November 2019 pursuant to Decree No 10,135 in order to reduce the deadline for the concessionaire to request the granting of a new agreement, from 60 months to 42 months counted from the end of the concession and required the privatization process to be concluded no later than 18 months prior to the termination of the prior concession.

| · | During 2018, the Brazilian federal government concluded the privatization of Eletrobras’ distribution companies Companhia Energética do Piauí - Cepisa, Companhia Energética de Rondônia S.A. - Ceron, Companhia de Eletricidade do Acre - Eletroacre, Boa Vista Energia S.A. - Boa Vista Energia, Companhia Energética de Alagoas - Ceal and Amazonas Distribuidora de Energia S.A. - Amazonas Distribuidora.

| · | In June 2019, the National Energy Policy Council (Conselho Nacional de Política Energética – CNPE) launched a program pursuant to its Resolution No. 16 to boost the natural gas market and foster competition by promoting free competition and using thermoelectric plants as a vehicle for creating demand for the better use of natural gas from the Pre-Salt layer.

| · | In December 2019, MME published the Ordinance No. 465/2019, determining that MME will gradually decrease, over the next years, the power limits to contract electric power by consumers served at any voltage, allowing them to purchase energy from conventional sources, considering the following schedule: (i) from January 1, 2021: consumers with demand equal to or greater than 1,500 kW; (ii) from January 1, 2022: consumers with demand equal to or greater than 1,000 kW; and (iii) January 1, 2023: consumers with demand of 500 kW or more. Furthermore, by January 31, 2022, ANEEL and CCEE shall present studies on the regulatory measures necessary to allow the opening of the Free Market for consumers with electric load below 500 kW.

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| · | In January 2020, the ONS implemented the Short Term Hydrothermal Dispatch Model (Modelo de Despacho Hidrotérmico de Curtíssimo Prazo - DESSEM), in order to optimize the operations of National Interconnected System (Sistema Interligado Nacional – SIN), and to reduce the difference between the planned dispatch and the one that is actually carried out by taking into account factors related to the electric grid, the operation of hydroelectric power plants, thermoelectric plants and other sector components. The execution of DESSEM meets the schedule set forth in Ordinance MME nº 301, dated July 31, 2019.

Potential New Regulatory Framework

The following potential changes to the Brazilian regulatory framework may have a direct impact in our operations, as our business is subject to comprehensive regulation by various Brazilian legal and regulatory bodies, especially the MME (which proposes sector policies) and ANEEL (which regulates, supervises and inspects various aspects of our business, including our tariff rates).

| · | In February 2018, the MME published on its website a report of the public hearing, reflecting the final proposal for improvements to the energy regulatory framework, which were especially motivated by technological, social and environmental matters, as well as difficulties arising from the current business models. Among the discussed topics, the following stand out:

| o | Termination of the quota system applicable to hydropower plants (HPP) concessions that have been extended or granted through competitive biddings, in accordance with Federal Law No. 12,783/2013, and allocation of part of the economic benefit of grants to the Energy Development Account (Conta de Desenvolvimento Energético, or CDE) in order to reduce what is charged to the population;

| o | Lowering the minimum thresholds for accessing the Free Market;

| o | Approach between the short-term price formation and the operating cost of the system;

| o | Whether energy and ballast (currently combined for commercialization purposes) should be segregated;

| o | Effects of the migration of consumers to the Free Market;

| o | Market for environmental attributes;

| o | Attraction of foreign capital for investments in the Brazilian energy sector;

| o | More efficient tariff discounts;

| o | Allocation of resources from the global reversion reserve to the transmission segment;

| o | Guidelines for the use of research and development resources;

| o | Modernization of the regulated market; and

| o | Reduction of judicial disputes regarding the hydrological risk.

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| · | In May 2018, most of the improvements proposed by the MME with respect to the regulatory framework applicable to the energy sector were included in Bill No. 1,917/2015 of the House of Representatives, known as the bill for the energy bill portability (Projeto de Lei da Portabilidade da Conta de Luz). This bill is still subject to analysis in the House of Representatives and, if approved, will depend on further approval by the Senate and the President of Brazil.

| · | Another legislative initiative waiting for approval is the Senate Bill No. 10,985/2018 (formerly, Bill No. 209/2015), which addresses the judicial disputes in the short-term energy market known as GSF. This bill is currently under analysis in the Senate.

| · | Also, there are initiatives in order to promote the modernization of the energy sector. Ordinance MME No. 187/2019 established a working group in order to develop proposals for the modernization of the energy sector, which released a report in October, 2019 with measures that should be adopted or studied, including topics such as (i) opening of the consumer market; (ii) pricing mechanism for the short-market; (iii) expansion of the Free Market accommodating new technologies and new business models; (iv) Energy Reallocation Mechanism; (v) cost and risk allocation; (vi) introduction of new technologies; and (vii) sustainable distribution services. This working group has been appointed for a 2-year term, which may be extended for 1 additional year.

| · | In November 2019, the Brazilian Federal Government submitted to Brazilian Congress Bill No. 5,877, which, among other matters, address the privatization of Centrais Elétricas Brasileiras S.A. - Eletrobras. Such bill determines the privatization of Eletrobras pursuant to a capital increase and public offering of new common shares (that entitle their holders to voting rights), resulting in the dilution of the stake held by the Brazilian Federal Government in Eletrobras.

| · | In November 2019, ANEEL submitted a proposed amendment to Resolution No. 482/2012 to a public hearing. This resolution refers to the distribution of micro and mini energy generation. The update of such rules was required in 2015 by Resolution 687/2015 and suggests improvements to the credit compensation system in view of changes to distributed generation in recent years.

| · | In December 2019, CNPE approved its Resolution No. 29, pursuant to which (i) it reviewed the general criteria adopted with respect to supply guarantee in studies on offer expansion, planning of the SIN operations, and calculations of energy physical guarantees and power of a generation project. However, MME shall determine the specific thresholds for such criteria, which is used in the calculation of physical guarantees and plans for expansion.

These potential changes to the regulatory framework applicable to the Brazilian Energy Sector may impact our operations in the coming years.

Concessions

The companies or consortia that wish to build or operate facilities for generation, transmission or distribution of electricity in Brazil must participate in a competitive bidding process or must apply to the MME or to ANEEL for a concession, permission or authorization, as the case may be. Concessions grant rights to generate, transmit or distribute electricity in a specific concession area for a specified period. This period is 35 years for generation concessions granted after 2003, and 30 years for new transmission or distribution concessions. In accordance with the 2013 Concession Renewal Law, generation and distribution concessionaires may renew their concession contracts that were in effect as of 1995 and transmission concessionaires may renew their concession contracts that were in effect prior to and as of 1995 for an additional period of 30 years, provided that the concessionaires agree to amend the concession contracts to reflect certain new terms and conditions established by the law. The 2013 Concession Renewal Law does not impact generation concessions granted after 2003, as they are non-renewable.

The Concessions Law establishes, among others, the conditions that the concessionaire must comply with when providing electricity services, customers’ rights and the respective rights and obligations of the concessionaire and the granting authority. In addition to the Concessions Law, the concessionaire must also

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comply with the general regulations governing the electricity sector. The main provisions of the Concessions Law and related ANEEL regulations are summarized as follows:

Adequate service. The concessionaire must render adequate service to all customers in its concession and must maintain certain standards with respect to regularity, continuity, efficiency, safety and accessibility.

Use of land. The concessionaire may use public land or request that the granting authority expropriate necessary private land for the benefit of the concessionaire. In the latter case, the concessionaire must compensate the affected private landowners.

Strict liability. The concessionaire is strictly liable for all damages arising from the provision of its services.

Changes in controlling interest. The granting authority must 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, through ANEEL, to ensure the adequate performance of services, as well as the full compliance with applicable contractual and regulatory provisions. Once ANEEL determines the intervention, limited to one year, but extendable for additional two years, it must designate a third party to manage the concession. Within 30 days of the determination of the intervention, the granting authority’s representative must commence an administrative proceeding in which the concessionaire is entitled to contest the intervention. The administrative proceeding must be completed within 1 year. The shareholders of the concessionaire under intervention must submit to ANEEL, within 60 days of the determination of the intervention, a recovery and correction plan. If ANEEL approves such plan, the intervention is terminated. In the event ANEEL does not approve the plan, the granting authority may: (i) declare forfeiture of the concession; (ii) determine the spin-off, incorporation, merger or transformation of the concessionaire, incorporation of a subsidiary or assignment of quotas/shares to a third party; (iii) determine the change of control of the concessionaire; (iv) determine a capital increase of the concessionaire; or (v) determine the incorporation of an special purpose company.

Termination of the concession. The termination of the concession agreement may occur by means of expropriation and/or forfeiture. Expropriation is the early termination of a concession for reasons related to the public interest. An expropriation must be specifically approved by law or decree. Forfeiture must be declared by the granting authority after ANEEL or the MME has made a final administrative ruling that the concessionaire, among other things, (i) has failed to render adequate service or comply with an applicable law or regulation, (ii) no longer has the technical, financial or economic capacity to provide adequate service, or (iii) has not complied with penalties assessed by the granting authority. The concessionaire may contest any expropriation or forfeiture in the courts.

A concession agreement may also be terminated (i) through the mutual agreement of the parties, (ii) upon the bankruptcy or dissolution of the concessionaire, or (iii) following a final, non-appealable judicial decision rendered in a proceeding filed by the concessionaire.

When a concession agreement is terminated, all assets, rights and privileges that are materially related to the rendering of electricity services revert to the Brazilian government. Following termination, the concessionaire is entitled to indemnification for its investments in assets that have not been fully amortized or depreciated, after deduction of any amounts due by the concessionaire related to fines and damages.

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 indemnification for its investments in assets that have not been fully amortized or depreciated as of the expiration.

Penalties. ANEEL regulations govern the imposition of sanctions against electricity sector participants and determine the appropriate penalties based on the nature and importance of the breach (including warnings, fines, temporary suspension from the right to participate in bidding procedures for new concessions, licenses or

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authorizations and forfeiture). For each infraction, the fines can be up to 2% of the revenue (net of value-added tax and services tax) of the concessionaire in the 12-month period preceding any penalty notice. Some infractions that may result in fines relate to the failure to request ANEEL’s approval to, among other things: (i) execute certain contracts between related parties; (ii) sell or assign the assets related to services rendered as well as impose any encumbrance (including any security, bond, guaranty, pledge and mortgage) on these or any other assets related to the concession or the revenues from electricity services; (iii) effect a change in the controlling interest of the holder of the authorization or concession; and (iv) make certain changes to the bylaws. In the case of contracts executed between related parties that are submitted for ANEEL’s approval, ANEEL may seek to impose restrictions on the terms and conditions of these contracts and, in extreme circumstances, require that the contract be rescinded.

Parallel Environment for the Trading of Electric Energy

Under the New Industry Model Law, the purchase and sale of electricity is carried out in two different segments: (i) the regulated market, which contemplates that distribution companies will purchase by public auction all the electricity they need to supply their customers; and (ii) the Free Market, which provides for the purchase of electricity by non-regulated entities (such as the Free Customers and energy traders).

However, the electricity arising from the following is subject to specific rules different from the rules applicable to the regulated market and to the Free Market: (i) low capacity generation projects located near consumption points (such as certain co-generation plants and small hydroelectric power plants), (ii) plants qualified under the Proinfa Program, an initiative established by the Brazilian government to create incentives for the development of alternative energy sources, such as wind power projects, small hydroelectric power plants and biomass projects, (iii) Itaipu, (iv) Angra 1 and 2 as from 2013 and (v) those generation concession contracts extended or subject to a new bidding process in accordance with the 2013 Concession Renewal Law.

The electricity generated by Itaipu will continue to be sold by Eletrobras to the distribution concessionaires operating in the South, Southeast and Midwest portions of the Interconnected Transmission System. The rates at which Itaipu-generated electricity is traded are denominated in U.S. dollars and established pursuant to a treaty between Brazil and Paraguay. As a consequence, Itaipu rates rise or fall in accordance with the variation of the real/U.S. dollar exchange rate. Changes in the price of Itaipu-generated electricity are, however, subject to the Parcel A cost recovery mechanism discussed as follows under “Distribution Tariffs”.

Beginning January 2013, the energy generated by nuclear plants Angra 1 and 2 started to be sold by Eletronuclear to the distribution concessionaires at a rate calculated by ANEEL.

The New Industry Model Law does not affect Bilateral Agreements entered into before 2004.

The Regulated Market

In the regulated market, distribution companies must purchase their expected electricity requirements for their Captive Customers in the regulated market through a public auction process. The auction process is administered by ANEEL, either directly or through the CCEE, under certain guidelines provided by the MME.

Electricity purchases are generally made through three types of Bilateral Agreements: (i) Energy Agreements (Contratos de Quantidade de Energia), (ii) Availability Agreements (Contratos de Disponibilidade de Energia) and (iii) allocation of energy quotas, as defined by the ANEEL. Under an Energy Agreement, a generator commits to supply a certain amount of electricity and assumes the risk that its electricity supply could be adversely affected by hydrological conditions and low reservoir levels, among other conditions, which could interrupt the supply of electricity. In such case, the generator would be required to purchase electricity elsewhere in order to comply with its supply commitments. Under an Availability Agreement, a generator commits to making a certain amount of capacity available to the regulated market. In such case, the generator’s revenue is guaranteed and the distributors must bear the risk of a supply shortage. With respect to the third method (introduced by the 2013 Concession Renewal Law), the plants that have had their concession renewed under the 2013 Concession Renewal Law lost the right to sell their energy, and from now on will only receive compensation under the energy quota system as a result of the operation and maintenance of such facilities. As a

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result, energy generated by these generation concessionaires are passed on to distributors at a lower cost through quotas that match the size of the markets served.

With respect to the generation plants with expired concessions, which are subject to a new competitive bidding process, the winner of the competitive bidding process may be required to allocate up to 100% of the energy generated by this plant in quotas to the regulated Market depending on the criteria adopted in the relevant auction process.

The estimate of demand from distributors is the principal factor in determining how much electricity the system as a whole will contract. A distributor is obligated to contract all of its projected electricity needs. A deviation in actual demand from projected demand could result in penalties to distributors. In the event of under-contracting, the distributor is penalized directly in an amount that increases as the difference between the amounts of energy contracted for and actual demand increases. An under-contracting distributor must also pay to meet its demand by purchasing energy in the Spot Market.

In the event of over-contracting, where the contracted volume falls between 100% and 105% of actual demand, the distributor is not penalized and the additional costs are compensated customers’ tariffs. Where the contracted volume is over 105% of actual demand, the distributor must sell energy in the Spot Market. If the contract price proves lower than the current Spot Market price, the distributor sells its excess energy for a profit. On the other hand, if the contract price is higher than the Spot Market price, the distributor sells its excess energy at a loss. ANEEL Normative Resolution No. 711, dated April 19, 2016, allowed distribution companies to renegotiate their energy purchase agreements in the regulated market to reduce the contracted amounts. The Federal Law No. 13,360, dated November 17, 2016, also permitted the sale of excess energy by distribution companies in the Free Market. Resolutions No. 824, dated July 10, 2018, and 833, dated December 4, 2018, have recently provided additional rules on the methodology to be adopted by distribution companies with respect to the Mechanism of Surplus Sales (Mecanismo de Venda de Excedentes, or MVE).

With respect to the granting of new concessions, regulations provide that bids for new hydroelectric generation facilities may include, among other things, the minimum percentage of electricity to be supplied in auctions in the regulated market. Concessions for new generation projects, such as Mauá and Colíder in our case, are non-renewable, meaning that upon expiration, the concessionaire must again complete a competitive bidding process.

The Free Market

The Free Market covers transactions between generation concessionaires, Independent Power Producers – IPPs, self-generators, energy traders, exporters and importers of electric energy and Free Customers. The Free Market also covers bilateral agreements between generators and distributors signed under the old model, until they expire. Upon expiration, such contracts must be executed under the New Industry Model Law guidelines.

A consumer that is eligible to choose its supplier may only do so upon the expiration of its contract with the local distributor and with advance notice or, in the case of a contract with no expiration date, upon 15 days’ notice in advance of the date on which the distributor must provide MME with its estimated electricity demand for the year. In the latter case, the contract will only be terminated in the following year. Once a consumer has chosen the Free Market, it may only return to the regulated system with five years prior notice to its regional distributor, provided that the distributor may reduce such term at its discretion. This extended period of notice seeks to assure that, if necessary, the distributor can buy additional energy in auctions on the regulated market without imposing extra costs on the captive market.

Private generators may sell electricity directly to Free Customers. State-owned generators may sell electricity directly to Free Customers but are obligated to do so only through private auctions carried out by the state-owned generators exclusively to Free Customers or by the Free Customers.

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As mentioned above, recently, Federal Law No. 13,360, dated November 17, 2016, also permitted the sale of excess energy by distribution companies in the Free Market, but the effectiveness of the rule is still subject to further regulation by ANEEL.

Focusing on the future of the electricity sector, the Ministry of Mines and Energy launched Public Consultation No. 33/2017 with the purpose of obtaining the view of different participants around improvements in the business model of the sector. Issues such as the expansion of the Free Market and removal of barriers to the entry of its participants, hourly energy price, adequate allocation of risks, security of supply and socio-environmental sustainability were discussed. Further regulation is expected for the years to come with bills being discussed in the Brazilian Congress in order to implement reforms in the power sector. For more information see “Potential New Regulatory Framework”.

Regulation under the New Industry Model Law and further rules enacted

A July 2004 decree governs the purchase and sale of electricity in the regulated market and the Free Market, as well as the granting of authorizations and concessions for electricity generation projects. This decree includes, among other items, regulations relating to auction procedures, the form of power purchase agreements and the mechanism for passing costs through to final customers.

These regulations establish the guidelines under which electricity-purchasing agents must contract their electricity demand. Electricity-selling agents must show that the energy to be sold comes from existing or planned power generation facilities. Agents that do not comply with such requirements are subject to penalties imposed by ANEEL.

These regulations also require electricity distribution companies to contract for 100% of their energy needs primarily through public auctions. In addition to these auctions, distribution companies can purchase limited amounts (up to 10% of their demand) from: (i) generation companies that are connected directly to the distribution company (except for hydroelectric power plants with capacity higher than 30 MW and certain thermoelectric power plants) (ii) electricity generation projects participating in the initial phase of the Proinfa Program, (iii) the Itaipu Power Plant and (iv) quotas from those generation concession contracts extended or subject to a new competitive bidding process in accordance with the 2013 Concession Renewal Law.

The MME establishes the total amount of energy that will be contracted in the regulated market, the number and the type of generation projects that will be auctioned each year.

All electricity generation, distribution and trading companies, independent producers and Free Customers are required to notify MME, by August 1st of each year of their estimated electricity demand or estimated electricity generation, as the case may be, for each of the subsequent five years. In advance of each electricity auction, each distribution company is also required to inform MME of the amount of electricity that it intends to contract in the auction. In addition, distribution companies are required to specify the portion of the contracted amount they intend to use to supply potentially Free Customers.

Auctions in the Regulated Market

Electricity auctions for new generation projects are held from the third to the seventh year before the initial delivery date of electricity (“A-3 to A-7 Auctions”). Electricity auctions for existing generation projects are held (i) from the first to the fifth year before the initial delivery date (“A to A-5 Auctions”), and (ii) up to four months before the initial delivery date (“Adjustment Auctions”).

New and existing power generators may participate in the Reserve Energy Auctions as long as these generators increase the power system capacity or if they did not achieve commercial operation by January 2008. Invitations to bid in the auctions are prepared by ANEEL in accordance with guidelines established by the MME, including the requirement that the lowest bid wins the auction. Each generation company that participates in the auction executes a contract for the purchase and sale of electricity with each distribution company, in proportion to the distribution companies’ respective estimated demand for electricity, except for the market adjustment and Reserve Energy Auctions.

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The contracts for new generation projects have a term between 15 and 35 years, and the contracts for existing generation projects have a term between 1 and 15 years. Contracts arising from market Adjustment Auctions are limited to a two-year term. The reserve energy contracts are limited to a 35-year term.

The quantity of energy contracted from existing generation facilities may be reduced for three reasons: (i) to compensate for Captive Customers that become Free Customers; (ii) to compensate for market deviations from the estimated market projections (up to 4% per year of the annual contracted amount, beginning two years after the initial electricity demand is estimated); and (iii) to adjust the quantity of contracted energy in bilateral agreements entered into prior to the enactment of the New Industry Model Law.

With regard to (i) above, the reduction in net revenue caused when a Captive Customer becomes a Free Customer is partially compensated by the increased amounts that Free Customers are required to pay to use our distribution system. However, a Free Customer may disconnect from our distribution grid (and therefore cease to pay us a distribution tariff) if it chooses to connect directly to the Interconnected Transmission System or if it generates energy for self-consumption and transports this energy without using our distribution grid. Because a Free Customer that connects directly to the Interconnected Transmission System no longer pays us a distribution tariff, we might not be able to fully recover this loss in revenues.

Since 2004, CCEE has conducted twenty-seven (27) auctions for new generation projects, twenty two (22) auctions for energy from existing power generation facilities, ten (10) auctions for reserve energy in order to increase energy supply security, three (3) auctions from alternative energy sources and thirteen (13) auctions for market adjustments. No later than August 1 of each year, the generators and distributors provide their estimated electricity generation or estimated electricity demand for the five subsequent years. Based on this information, MME establishes the total amount of electricity to be traded in the auction and determines which generation companies will participate in the auction. The auction is carried out electronically in two phases.

After the completion of the auction (except in the case of reserve energy auction), generators and distributors execute the CCEAR, in which the parties establish the price and amount of the energy contracted in the auction. The price is adjusted annually based on price variations published by the IPCA. The distributors grant financial guarantees to the generators (mainly receivables from the distribution service) to secure their payment obligations under the CCEAR.

Also after completion of the Reserve Energy Auction, the generation concessionaire and the CCEE execute the Contrato de Energia de Reserva, in which the parties establish the price and amount of the energy contracted for in the auction. The distributors, Free Customers and self-producing customers then execute the Contrato de Uso da Energia de Reserva (“CONUER”) with CCEE, in order to provide for the terms of the use of the reserve energy. The reserve energy customers grant financial guarantees to CCEE to secure their payment obligations under CONUER.

The 2013 Concession Renewal Law established that generation concessions entered into prior to 2003 that were not renewed would be subject to a new competitive bidding process and that the energy generated by these facilities will be allocated by the Brazilian federal government in quotas to the regulated market, for purchase by distribution concessionaires. On November 25, 2015, ANEEL carried out a competitive bidding process for the grant of new 30-year concessions of 29 hydroelectric plants in accordance with the 2013 Concession Renewal Law. Until December 31, 2016, 100% of the electricity generated by such 29 hydroelectric plants must be destined to the regulated market and, as of January 1, 2017, the percentage was reduced to 70%. On September 27, 2017, the ANEEL carried another competitive bidding process for the grant of new 30-year concessions of 4 hydroelectric plants in accordance with the 2013 Concession Renewal Law. In this auction, the percentage destined to the regulate market was 70% since the beginning of the concession.

The Annual Reference Value

Brazilian regulation establishes a mechanism (“Annual Reference Value”) that limits the costs that can be passed through to final customers.

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The regulation establishes certain limitations on the ability of distribution companies to pass-through costs to customers, such as no pass-through of costs for electricity purchases that exceed 105% of actual demand.

The MME establishes the maximum acquisition price for electricity generated by existing projects. If distributors do not comply with the obligation to fully contract their demand, the pass-through of costs from energy acquired in the short-term market is the lower of the Spot Market price and the Annual Reference Value.

Electric Energy Trading Convention

The Electric Energy Trading Convention (Convenção de Comercialização de Energia Elétrica) regulates the organization and functioning of the CCEE and defines, among other things, (i) the rights and obligations of CCEE participants, (ii) the penalties to be imposed on defaulting agents, (iii) the means of dispute resolution, (iv) trading rules in the regulated and Free Markets, and (v) the accounting and clearing process for short-term transactions.

Restricted Activities of Distributors

Distributors in the Interconnected Transmission System are not permitted to (i) engage in activities related to the generation or transmission of electric energy, (ii) hold, directly or indirectly, any interest in any other company, corporation or strategic agreement, or (iii) engage in activities that are unrelated to their respective concessions, except for those permitted by law or the relevant concession agreement. According to Law No. 13,360/2016, distributors are allowed to sell energy to Free Customers. This possibility is regulated by ANEEL through REH No. 824/2018, with the application of the Electricity Surplus Sale Mechanism - MVE.

Elimination of Self-Dealing

Since the purchase of electricity for Captive Customers is now performed through auctions in the regulated market, “self-dealing” (under which distributors were permitted to meet up to 30% of their energy needs using energy that was either self-produced or acquired from affiliated companies) is no longer permitted.

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 Brazilian 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 Supreme Court has not reached a final decision and we do not know when such a decision may be reached. While the Supreme Court is reviewing the law, its provisions have remained in effect. 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 Customers and the elimination of self-dealing, are expected to remain in full force and effect.

Tariffs for the Use of the Distribution and Transmission Systems

ANEEL regulates access to the distribution and transmission systems and establishes tariffs for the use of these systems. The tariffs are (i) network usage charges, which are charges for the use of the proprietary local grid of distribution companies (“TUSD”) and (ii) for the use of the transmission system, which is the Interconnected Transmission System and its ancillary facilities (“TUST”).

TUSD

Users of a distribution grid pay the distribution concessionaire a tariff known as the TUSD (Tarifa de Uso dos Sistemas Elétricos de Distribuição). The TUSD is divided into two parts: one related to the contracted power in R$/kW and another related to the regulatory charges in R$/kWh. The amount paid by the users of a distribution grid is calculated by multiplying the maximum contracted power for each of the customer’s points

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of connection to the concessionaire’s distribution grid, by the tariff in R$/kW, plus the product of the power consumption by the tariff in R$/kWh, per month.

In relation to the Captive Customers, the TUSD is part of the supply tariff that is calculated based on the voltage used by each customer.

TUST

The TUST (Tarifa de Uso do Sistema de Transmissão) is paid by distribution companies, generators and Free Customers to transmission companies for the use of the Interconnected Transmission System (electrical transmission system with a voltage equal or higher than 230 kV). This tariff is revised annually according to (i) the location of the user of the Interconnected Transmission System and (ii) the annual revenues that a transmission company is permitted to collect for the use of its assets in the Interconnected Transmission System. The ONS, an entity that represents all transmission companies that own assets in the Interconnected Transmission System, coordinates the payment of transmission tariffs to these transmission companies. Users of the Interconnected Transmission System sign contracts with the ONS, which allows them to use the transmission grid in return for paying TUST.

Distribution Tariffs

Distribution tariff rates to final customers are subject to review by ANEEL, which has the authority to adjust and review these tariffs in response to changes in energy purchase costs and market conditions. When adjusting distribution tariffs, ANEEL divides the costs of distribution companies into (i) costs that are beyond the control of the distributor, (“Parcel A costs”), and (ii) costs that are under control of distributors (“Parcel B costs”). ANEEL’s tariff adjustment formula treats these two categories differently.

Parcel A costs include, among others, the following:

| · | costs of electricity purchased by the concessionaire to attend Captive Customers, in accordance to the regulatory model in force;

| · | charges for the connection to and use of the transmission and distribution grids; and

| · | energy sector regulatory charges.

Parcel B costs include, among others, the following:

| · | a component designed to pay the distributor for the investments made by the distributor on the concession assets;

| · | depreciation costs; and

| · | a component designed to compensate the distributor for its operating and maintenance costs.

Each distribution company’s concession agreement provides annual readjustments. In general, Parcel A costs are fully passed through to customers. Parcel B costs, however, are adjusted for inflation in accordance with the IPCA Index, minus the X factor.

Electricity distribution concessionaires are also entitled to periodic tariff revisions (revisão periódica) every four or five years. In these processes, Parcel B is recalculated, taking into account incentives for efficiency, quality improvement and reasonable tariff. These revisions are aimed at (i) assuring necessary revenues to cover efficient Parcel B operational costs and adequate compensation for investments deemed essential for services provided within the scope of each such company’s concession and (ii) determining the “X factor”. The fifth amendment to our concession agreement, which establishes the renewal of our concession agreement, determines the Periodic Tariff Review every five years.

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The X factor for each distribution company is calculated based on the following components:

| · | P, based on the concessionaire’s productivity, which is calculated through the productivity of the distribution segment (PTF), determined by the relation between the variation of the billed market and the operating and capital costs, plus the average growth of the billed market and the consumer units of the concessionaire itself;

| · | T, based on the trajectory of the concessionaire’s operating costs, measured as the difference between the cost benchmarks established by ANEEL and the concessionaire’s actual operating costs; and

| · | Q, based on quality target indicators that measure the interruption of energy supply to final customers, and other quality indicators.

In addition, a distribution concessionaire may request an Extraordinary Tariff Review of its tariffs in case of evident economic-financial imbalance, according to the admissibility criteria established through the Tariff Regulation Procedures (PRORET), sub-module 2.9. Extraordinary tariff adjustments were granted (i) in June 1999 to compensate for increased costs of electricity purchased from Itaipu as a result of the devaluation of the real against the dollar; (ii) in 2000 to compensate for the increase in Social Security Financing Contribution (Contribuição para o Financiamento da Seguridade Social - COFINS) from 2% to 3%; (iii) in December 2001 to compensate for losses caused by the Rationing Program; (iv) in January 2013, due to the enactment of 2013 Concession Renewal Law; (v) in March 2015, to compensate the costs related to the quotas of the Electric Development Account (CDE) and increased costs with the purchase of energy, and (vi) in March 2017, to compensate the amount unduly included in the tariffs for captive consumers in 2016, referring to the Angra III plant.

Since October 2004, on the date of a subsequent tariff adjustment or tariff revision, whichever occurs earlier, distribution companies have been required to execute separate contracts for the connection and use of the distribution grid and for the sale of electricity to their potentially Free Customers.

Tariff Flags (Bandeiras Tarifárias)

Effective as of January 1, 2015, a new system has been introduced by the ANEEL to permit distribution concessionaires to pass on to their final customer certain variable cost increases attributable to changes in hydrological conditions in Brazil, prior to the formal tariffs periodic revisions made by ANEEL.

In accordance with this model, a green, yellow or red flag, as determined by ANEEL, is included in invoices sent to final customers, reflecting nationwide hydrological conditions (except for the State of Roraima). If a green flag is added to final customers’ invoices due to satisfactory hydrological conditions, no additional charges are added. On the other hand, if these invoices contain yellow or red flags, this indicates that distribution concessionaires are facing higher variable costs from the acquisition of electricity and will pass these costs on to final customers.

Incentives

In 2000, a Federal decree created the Thermoelectric Priority Program, (Programa Prioritário de Termoeletricidade, or “PPT”), for the purposes of diversifying the Brazilian energy matrix and decreasing Brazil’s strong dependence on hydroelectric plants. The incentives granted to the thermoelectric plants included in the PPT were: (i) guarantee of gas supply for 20 years, as per a MME regulation, (ii) assurance that the costs related to the acquisition of the electric energy produced by thermoelectric plants will be passed on to customers through tariffs up to the normative value established by ANEEL, and (iii) guarantee of access to a special BNDES financing program for the electric energy industry.

In 2002, the Brazilian government established the Proinfa Program to encourage the generation of alternative energy sources. Under the Proinfa Program, Eletrobras would purchase the energy generated by alternative sources for a period of 20 years. In its initial phase, the Proinfa Program was limited to a total

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contracted capacity of 3,300 MW. In its second phase, which should start after the 3,300 MW cap has been reached, the Proinfa Program intends to purchase up to 10% of Brazil’s annual electric energy consumption from alternative sources. The first phase of the Proinfa program commenced in 2004 and it so far has supported the construction of 131 alternative energy plants which is expected to reach the production of 11.2 million MWh. According to a decision of ANEEL, the total investment to the Proinfa Program in 2020 will be R$3.3 billion.

Energy Sector Regulatory Charges

EER

The Encargo de Energia de Reserva (“EER”) is a regulatory charge designed to raise funds for energy reserves that have been contracted through CCEE and which are deposited in the Reserve Energy Account (Conta de Energia de Reserva – CONER). These energy reserves, which are mandatory, were created in order to attempt to ensure a sufficient supply of energy in the Interconnected Transmission System. The EER shall be collected from final customers of the Interconnected Transmission System. Beginning in 2010, this charge has been collected on a monthly basis.

RGR Fund

In certain circumstances, electric energy companies are compensated for certain assets used in connection with a concession if the concession is revoked or is not renewed. In 1971, the Brazilian Congress created a reserve fund designed to provide these compensatory payments (“RGR Fund”). In February 1999, ANEEL established a fee requiring public-industry electric companies to make monthly contributions to the RGR Fund at an annual rate equal to 2.5% of the company’s fixed assets in service, not to exceed 3% of total operating revenues in any year. Since the enactment of the 2013 Concession Renewal Law, the RGR Fund has been used to fund the compensations arising from the termination of non-renewed concessions. The 2013 Concession Renewal Law also allowed the funds from the RGR Fund to be transferred to the CDE.

According to 2013 Concession Renewal Law, as from January 1, 2013, the concession contracts from concessionaires of (i) distribution; (ii) transmission which competitive bidding process occurred after September 12, 2012; and (iii) transmission and generation which had their concession contract renewed or had their underlying facilities subject to a new competitive bidding process are no longer obliged to pay the annual RGR fee.

UBP

Some hydroelectric generation enterprises (except small hydroelectric power plants) are required to make contributions for using a public asset, Uso de Bem Público (“UBP”) according to the rules of the corresponding public bidding process for the granting of concessions. Eletrobras receives the UBP payments in a specific account. See Note 27 to our audited consolidated financial statements.

ESS

The costs related to maintaining system reliability and stability when thermoelectric plants generate energy to meet demand in the National Connection System (SIN) are called System Service Charges, or Encargos de Serviços de Sistema (ESS). These amounts are paid by each entity that purchases energy in the Spot Market (CCEE), proportional to each such entity’s consumption.

ESS is expressed in R$/MWh and paid only to thermoelectric plants that generate energy in response to requests by the Electricity System National Operator (ONS).

CDE

In 2002, the Brazilian government instituted the Electric Energy Development Account, Conta de Desenvolvimento Energético (“CDE Account”). The CDE Account is funded by (i) annual payments made by

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concessionaires for the use of public assets, (ii) penalties imposed by ANEEL, (iii) the annual fees paid by agents offering electric energy to final customers, by means of an additional charge added to the tariffs for the use of the transmission and distribution grids and (iv) transfer of resources from the Federal General Budget. The CDE Account was originally created, amongst others, to promote the availability of electric energy services to all of Brazil and the competitiveness of the energy produced by alternative sources.

Currently, CDE aims to fund several public policies in the Brazilian electricity sector, such as: universalization of the electricity service throughout the national territory; granting of tariff discounts to various users of the service (low income; rural; Irrigating; public water, sewage and sanitation services; incentive energy generation and consumption, etc.); low tariff on isolated electricity systems (Fuel Consumption Account - CCC); competitiveness of electricity generation from the national coal source; among others. The CDE is managed by CCEE since May, 2017, pursuant to Federal Law No. 13,360/2016. This charge had been substantially reduced by the 2013 Concession Renewal Law (approximately 75% compared to its December 31, 2011 amount) in an attempt to reduce the cost of electricity paid by final customers. The 2013 Concession Renewal Law also allowed the funds from the RGR Fund to be transferred to the CDE Account, provided that the Federal Treasury would also contribute with the CDE Account and permit the funds deposited in the CDE Account to be used in support of the electricity generation program in non-integrated electric grids (sistemas elétricos isolados) as well as to partially offset the increased costs borne by distribution concessionaires for the purchase of energy in the Spot Market as a result of the non-renewal of generation concessions due to the 2013 Concession Renewal Law.

On March 7, 2014, the Brazilian government also permitted the transfer to distribution concessionaires of funds deposited in the CDE Account to cover their respective costs arising from involuntary exposure to the Spot Market in January 2014 as a result of poor hydrological conditions in 2013 and 2014, which mandated the acquisition of thermoelectric energy at higher prices in the Spot Market, costs which distribution concessionaires were not able to pass on to Final Customers through regular Retail Tariffs prior to annual readjustments or formal tariffs periodic revisions made by ANEEL.

Distribution concessionaires will be able to pass on to its final customer a CDE Account charge, to the extent necessary to repay their respective financing obligations contracted by the CCEE through the ACR Account. See “Regulated Market Account – ACR Account.”

On February 27, 2015, ANEEL approved a significant increase of the CDE fee charged to cover all of these additional costs supported by the CDE Account. ABRACE, an association of Free Customers filed lawsuits to contest the increase of the CDE fee. Since July 2015, the Free Customers associated with ABRACE benefit from an injunction suspending the increase of the CDE fee. Associations of distributors of energy (ABRADEE, with whom Copel Distribuição is associated) also obtained injunctions suspending its obligation to withhold such CDE fees while ABRACE´s and other consumers’ injunction remains in force.

Federal Law No. 13,360/2016 established that the Federal Government must prepare a plan for a structural reduction of the CDE charge until December 31, 2017, and it also provided that the revenues, expenses and beneficiaries of the CDE Account must be published monthly by CCEE, among other changes. As a result, Decree nº 9,642/2018 was published, which determined the gradual reduction, in 5 years, of discounts granted to consumer units classified as Rural and Public Service of Water, Sewage and Sanitation, in Groups A (high voltage) and B (low voltage).

Regulated Market Account – ACR Account.

On April 2014, the Brazilian government created the Regulated Market Account, Conta no Ambiente de Contratação Regulada – Conta-ACR (“ACR Account”), to assist distribution concessionaires to cover their respective costs for the acquisition of thermoelectric energy for the period from February 2014 to December 2014, incurred as a result of poor hydrological conditions. Distributors incurred higher costs as a result of adverse hydrological conditions because they were required to buy thermoelectric energy at higher prices in theSpot Market, and were unable to pass all these costs on to Final Customers prior to a formal tariff periodic revision made by ANEEL. To fund the ACR Account, the Brazilian federal government authorized the CCEE to enter into credit agreements with certain Brazilian financial institutions. An aggregate of R$21.7 billion,

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composed of nine tranches, was deposited in the ACR Account. Distribution concessionaires have been repaying this loan since 2015 by charging its final customers with additional CDE Account amounts on a monthly basis. At first, the amount deposited in the ACR Account should be repaid by 2020. However, in March 2019, ANEEL authorized CCEE to negotiate with the creditor financial institutions and seek early termination of the corresponding loans, which occurred in September 2019

Itaipu Transmission Fee

The Itaipu Hydroelectric Plant has an exclusive transmission grid and is not part of the Interconnected Transmission System. Companies that are entitled to receive electricity from Itaipu pay a transmission fee in an amount equal to their proportional share of the Itaipu generated electricity.

Use of Water Resources Tax

Holders of concessions and authorizations that allow for the exploitation of water resources must pay a total tax of 6.75% of the value of the energy they generate, which for the purposes of this calculation is based on a rate set by ANEEL. Beginning on January 1, 2020, ANEEL set this rate at R$79.62/MWh. The proceeds of this tax are shared among the states and municipalities where the plant or the plant’s reservoir is located, as well as with certain federal agencies.

ANEEL Inspection Fee (TFSEE)

The ANEEL Inspection Fee is an annual fee due by the holders of concessions, permissions or authorizations equal to an ANEEL determined percentage of their revenues. The ANEEL Inspection Fee requires these holders to pay up to 0.4% of their annual revenue to ANEEL in 12 monthly installments.

Default on the Payment of Regulatory Charges

The failure to pay required contributions to the RGR Fund, Proinfa Program or CDE Account or to make certain payments, such as those due from the purchase of electric energy in the regulated market or from Itaipu, will prevent the defaulting party from receiving adjustments or reviews of their tariffs (except for an extraordinary review) and will also prevent the defaulting party from receiving funds from the RGR Fund or CDE Account. We comply with payment obligations related to Regulatory Charges.

Energy Reallocation Mechanism

The Energy Reallocation Mechanism (Mecanismo de Realocação de Energia, or MRE) attempts to mitigate the risks borne by hydroelectric generators due to variations in river flows (hydrological risk).

Under Brazilian law, each hydroelectric plant is assigned a determined amount of “assured energy”, according to an energy supply risk criteria defined by MME, based on historical river flow records. The assured energy also represents the maximum energy that can be sold by the generator, which is set forth in each concession agreement, irrespective of the volume of electricity actually generated by the facility.

The MRE tries to guarantee that all participating plants receive the revenue corresponding to their assured energy, irrespective of the volume of electricity generated by them. In other words, the MRE effectively reallocates the electricity, transferring the surplus from those who have produced in excess of their assured energy to those that have produced less than their assured energy. The relocation, which occurs in the Interconnected Transmission System, is determined by the ONS, considering the nationwide electricity demand and hydrological conditions, regardless of the power purchase agreement of each individual generator. The volume of electricity actually generated by the plant, whether more or less than their assigned assured energy quotient, is priced pursuant to a tariff known as the “Energy Optimization Tariff”, designed to cover only the variable operation and maintenance costs of the plant, so that generators are largely unaffected by the actual dispatch of their plants.

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Each hydroelectric plant which has its concession contract renewed in accordance to 2013 Concession Renewal Law will no longer participate in the MRE, and the hydrological risk from those plants will be borne by the distribution concessionaires under the National Interconnected Power Grid. For the generation plants with expired concessions, which were subject to a new competitive bidding process under the 2013 Concession Renewal Law, 30% of the generated energy available for the generation concessionaire to sell in the market is also subject to the MRE hydrological risk allocation mechanism. This risk does not impact our distribution business, since we are allowed to increase the tariffs of our distribution customers to compensate any costs arising from this hydrological risk.

Research and Development

The companies holding concessions and permissions for distribution of electricity must invest a minimum of 0.50% of their annual net operational revenues in research and development and 0.50% in energy efficiency programs. Beginning on January 1, 2023, these percentages will become 0.75% and 0.25%, respectively.

A company holding concessions and authorizations for generation and transmission of electricity must invest a minimum of 1% of its annual net operational revenues in research and development. A company that generates electricity exclusively from small hydroelectric power plants, cogeneration or alternative energy projects is not subject to this requirement.

The amount to be invested in research and development must be distributed as follows:

| · | 40% to the company research and development projects, under the supervision of ANEEL;

| · | 40% to the Ministry of Sciences and Technology, to be invested in national research and development projects; and

| · | 20% to the MME, to defray EPE.

Environmental Regulations

The Brazilian Federal Constitution includes environmental matters among the ones that are subject to concurrent legislative competence, meaning that the Brazilian federal government enacts general rules, which are supplemented by rules passed by states; municipalities, in turn, enact local rules or supplement federal and/or state legislation.

In 1981, the National Environmental Policy was enacted in Brazil (Federal Law No. 6,938/1981). The Federal Environmental Crimes Act (Federal Law No. 9,605/1998), which took effect in 1998, establishes a general framework of liability for environmental crimes. Federal laws and statutes have established the National System for Management of Water Resources and the National Council of Water Resources to address the major environmental issues facing the hydroelectric sector and users of water resources. In 2000, the Brazilian government created an independent agency, the National Water Agency, to regulate and supervise the use of water resources. In 2008, the Federal Decree No. 6,514/2008 was enacted to prescribe the administrative liability due for environmental infractions.

The Brazilian Forestry Code (Federal Law No. 12,651/2012) and related regulations establish rules regarding the maintenance and acquisition of areas affected by hydroelectric plant reservoirs. These regulations may result in increased maintenance, reforestation and expropriation costs to energy industry concessionaires. We have been developing conservation actions in our power plants, as established in the Forestry Code, since their construction.

Under Brazilian environmental Law, one single action that causes risk to the environment can trigger three types of liability: civil, administrative and criminal.

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Thus, a violator of an environmental law may be subject to administrative and criminal sanctions and, in case environmental damage occurs, will have an obligation to repair or provide compensation to the affected party. Administrative sanctions may apply to both the company and the individual representatives of the company concomitantly and may include substantial fines and the suspension of activities. Criminal sanctions may include fines and, for individuals, including for directors and employees of companies that commit environmental crimes, possible imprisonment.

Our energy generation, distribution and transmission facilities are subject to prior environmental licensing procedures, which may include the preparation of environmental impact assessments before such facilities are constructed. As a condition for the regularity of these procedures, we must also request authorization from certain regulatory entities, such as Brazilian Institute of National Historic and Artistic Heritage (Instituto do Patrimônio Histórico e Artístico Nacional – IPHAN), an oversight body that is in charge of the protection and preservation of Brazilian cultural heritage (archeological, material and immaterial). Once the respective environmental licenses are obtained, their maintenance is still subject to compliance with certain requirements.

Item 4A. Unresolved Staff Comments

None.

Item 5. Operating and Financial Review and Prospects

The information presented in this section should be read together with our audited consolidated statements of income for the years ended December 31, 2019, 2018 and 2017 that have been prepared in accordance with IFRS as issued by the IASB. For more information see “Presentation of Financial and Other Information” and Note 3 to our audited consolidated financial statements for the year ended December 31, 2019.

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OVERVIEW

Brazilian Economic Conditions

All of our operations are in Brazil, and we are affected by general Brazilian economic conditions. In particular, the general performance of the Brazilian economy affects demand for electricity, and inflation affects our costs and our margins. The Brazilian economic environment faced periods of instability in recent years, impacting the performance of the Brazilian GDP growth rates, with an increase of 2.3% in 2013 and 0.1% in 2014 and a decrease of 3.8% in 2015. The growth rate was equally negative in 2016, with a decrease of 3.3%. The economic environment showed signs of recovery in 2017, with an increase of 1.0% in growth rate. In 2018 and 2019, the economic environment continued to recover, with an increase of 1.1% and 1.1%, respectively, in growth rate, but mainly due to the uncertainties caused by the Brazilian presidential election, the real has depreciated in comparison to the U.S. dollar.

The following table shows selected economic data for the periods indicated:

| Year ended December 31, |
| 2019 | 2018 | 2017 |
Inflation (IGP-DI) | 7.70% | 7.10% | (0.42)% |
Appreciation (depreciation) of the real vs. U.S. dollar | (4.0%) | (17.13)% | (1.48)% |
Period-end exchange rate – US$1.00(1) | 4.0307 | 3.8748 | 3.3080 |
Average exchange rate – US$1.00 | 3.9461 | 3.6558 | 3.2031 |
Change in real GDP | 1.1 | 1.1% | 1.0% |
Average interbank interest rates(2) | 4.40% | 6.40% | 9.80% |

(1) | The real/U.S. dollar exchange rate at December 31, 2019 was R$4.03 per US$1.00.

(2) | Calculated in accordance with Central Clearing and Custody House, or Central de Custódia e Liquidação Financeira de Títulos (“CETIP”), methodology (based on nominal rates).

| Sources: | FGV ‒ Fundação Getúlio Vargas, the Brazilian Central Bank, the Brazilian Geography and Statistics Institute IBGE and CETIP.

Rates and Prices

Our operational results are significantly affected by changes in the prices at which our generation business sells energy, and by the prices at which our distribution business buys and resells energy.

Our generation business sells energy at unregulated prices in the regulated market, in the Free Market and in the Spot Market. Our generation business allocates the amount of energy that it sells in each of these markets seeking to maximize returns, based on factors such as: (i) the requirements of its concession contracts, many of which set a minimum percentage of energy generated in a particular concession that must be sold in the regulated market; (ii) the volume of energy that we plan to sell to Free Customers for a given year; and (iii) the outlook of the short-term, medium-term and long-term for energy prices generally. Although sales in the Free Market and the Spot Market are not directly regulated, they are influenced by energy regulatory policy. The prices at which our generation business sells energy are not regulated.

Our distribution business purchases enough energy to meet 100% of the demand we forecast for our final customers in auctions at unregulated prices in the regulated market. Our distribution business resells that energy to final customers at regulated tariffs that take into consideration the price at which the energy was purchased. If our forecasts fall short of the actual electricity demand of our final customers, we may be forced to make up for the shortfall by entering into short-term agreements to purchase electricity in the Spot Market. If our forecasts exceed the actual demand of our final customers, our distribution business sells the excess energy in the Spot Market. The margins in our distribution business tend to be relatively stable due to the regulated nature of the distribution business, while the margins in our generation business are typically larger but less stable, since they are substantially market regulated.

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Sales to final customers (which include sales by our distribution business to Captive Customers, sales by our generation business and sales by our trading business to Free Customers) represented approximately 53.5% of the volume of electricity we made available in 2019, and accounted for 69.1% of our energy sales revenues. Almost all of such sales were to Captive Customers. For more information, see “Item 4. Information on the Company—The Brazilian Electric Power Industry—Distribution Tariffs”. In general, if our costs for energy increase, the tariff process permits us to recover these costs from our customers through higher rates in future periods. However, if we do not receive tariff increases to cover our costs, if the recovery of these costs is delayed, or if our Board of Directors elects to reduce the tariff increase awarded by ANEEL, our profits and cash flows may be adversely affected.

ANEEL modifies our Retail Tariffs annually, generally in June. Since January 2013, the adjustments have been as follows.

| · | In January 2013, due to the enactment of 2013 Concession Renewal Law, we were subject to an extraordinary revision that has been approved by ANEEL. The average impact of this extraordinary review in the tariffs we charge our customers was a decrease of 19.28%.

| · | In June 2013, ANEEL approved the annual revision of our Retail Tariffs, increasing them by an average of 13.08%, of which 11.40% related to the tariff increase and 1.68% referred to an increase in recovery of deferred regulatory accounts (CVA). After giving effect to the recovery of Parcel A costs, the average effect of this tariff readjustment on our Captive Customers was an increase of 14.61%. However, Copel Distribuição requested a partial deferral of this adjustment, which was authorized by ANEEL and approved on July 9, 2013. The amount of R$255.9 million was therefore deferred, and to be included as a financial component in the 2014 annual revision. This deferral reduced the average effect of the tariff adjustment to 9.55%.

| · | In June 2014, ANEEL approved the annual adjustment of our Retail Tariffs, increasing them by an average of 35.38%, of which 25.05% related to the tariff increase and 10.34% related to an increase in recovery of deferred regulatory accounts (CVA). After giving effect to the recovery of Parcel A costs, the average effect of this tariff adjustment on our Captive Customers was an increase of 39.71%. However, Copel Distribuição requested a partial deferral of this adjustment, which was authorized by ANEEL and approved on July 22, 2014. The amount of R$898.3 million was therefore deferred, and to be included as a financial component in the 2015 annual readjustment. This deferral reduced the average effect of the tariff revision to 24.86%.

| · | In March 2015, ANEEL approved an extraordinary revision due to a series of events that significantly impacted the distribution concessionaires’ costs, which were not originally foreseen in the 2014 Retail Tariff increase, such as the increase of Itaipu tariffs (46.14%) and higher prices to purchase energy in recent energy auctions. Copel Distribuição’s average tariff revision approved by ANEEL was 36.79% starting from March 2, 2015. Of this total, 22.14% related to CDE Account charges that have been passed to customers and 14.65% relates to (i) Itaipu’s tariff increase and (ii) the higher prices paid by us to purchase energy in recent energy auctions that have been passed to customers.

| · | In June 2015, ANEEL authorized the annual revision of Copel Distribuição’s tariff to final customers, increasing them by an average of 15.32%, of which (i) 20.58% related to the inclusion of the financial components, which will be recovered in the 12 months subsequent to the adjustment (including the amount of R$935.3 million corresponding to the deferrals in 2013 and 2014), (ii) 0.34% related to the restatement of Portion B, (iii) (3.25)% related to the adjustment of Portion A, and (iv) (2.35)% reflected the removal of the financial components from the previous process. The adjustment was fully applied to Copel Distribuição’s tariffs as of June 24, 2015.

| · | In June 2016, ANEEL approved the fourth periodic review of our Retail Tariffs, decreasing them by 12.87%, of which: (1.73)% related to the inclusion of financial components; 4.48% due to the update of Portion B; (2.57)% related to the update of Portion A; and (13.05)% reflecting the removal of the financial components of the previous tariff process.

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| · | In March 2017, ANEEL approved an extraordinary tariff revision to correct the amount unduly included in the tariffs for captive consumers in 2016. The return corresponded to the energy that was to be generated by the Angra III power plant; however, the plant was not yet in commercial operation. The refund of the amount charged the most was made in a single installment during the month of April 2017, and, as of May 2017, the tariffs were adjusted to disregard the amount that was being charged. The decision, of extraordinary character, affected 90 distributors of electric power of the country. Copel’s retail tariff was reduced by an average of 11.8% during April 2017, and in May 2017, the tariff was close to its previous value, retaining an average discount of 1.27% until June 2017.

| · | In June 2017, ANEEL approved the annual revision of our Retail Tariffs, increasing them by an average of 3.13%, of which 3.86% related to the tariff increase and (0.73)% related to the inclusion of financial components. After the removal of the financial components of the previous tariff process, the average effect of this tariff adjustment on our Customers was an increase of 5.85%.

| · | In June 2018, ANEEL approved the annual revision of our Retail Tariffs, increasing them by an average of 14.32%, of which 7.80% related to the tariff increase and 6.52% related to the inclusion of financial components. After the removal of the financial components of the previous tariff process, the average effect of this tariff adjustment on our Customers was an increase of 15.99%.

| · | In June 2019, ANEEL approved the annual readjustment of our Tariffs, increasing them on average by 8.57%, with -1.96% related to the variation in economic revenue and 10.54% related to the inclusion of financial components. After removing the financial components from the previous tariff process, the average effect of the tariff adjustment on our consumers was an increase by 3.41%.

Purchase and Resale of Energy

Our distribution business purchases energy from generation companies and resells this energy to final customers at regulated rates. For more information, see “Item 4. Information on the Company— Business—Generation” and “Item 4. Information on the Company—Business—Purchases for the captive market”. Our major long-term contracts or purchase obligations are described as follows.

| · | We purchase energy from Itaipu at prices that are determined based on the Itaipu project’s costs, including servicing its U.S. dollar-denominated debt. In 2019, our electricity purchases from Itaipu amounted to R$1,316 million;

| · | Our distribution business is required to purchase a large portion of its energy needs from the regulated market. For more information, see “Item 4. Information on the Company—The Brazilian Electric Power—Industry—Auctions in the Regulated Market”.

Under current legislation, the amount that our distribution business charges Final Customers is composed of two fees: a fee for the actual energy consumed and a fee for the use of our distribution grid. Since the regulated rates at which our distribution business sells energy to final customers are substantially the same as the rates at which it purchases energy (after accounting for deductions and the cost of energy purchased for resale), our distribution business does not generate operating profit from the sale of electricity to final customers. Rather, our distribution business generates operating profit principally by collecting tariffs for the use of our distribution grid.

Impact of the CRC Account

One of our most significant assets consists of the obligations of the State of Paraná under an agreement that was last amended in October 2017. These obligations derive from amounts we were entitled to recover

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under a prior regulatory regime, and as a result they are referred to as the recoverable rate deficit account or “CRC Account” (Conta de Resultados a Compensar). The balance is adjusted for IGP-DI, plus interest at 6.65% per year, and is payable in monthly installments until April 2025. If the State of Paraná fails to make payments on a timely basis, we may apply dividends we owe to the State of Paraná in its capacity as our shareholder against amounts it owes us under the CRC Account agreement.

In June 2016, as per the request of the Paraná State Government, our Board of Directors approved an amendment to the CRC Agreement, contingent upon the approval of the Brazilian Department of Treasury, comprising: (i) a grace period from April 2016 to December 2016, in which no principal and interest amounts were paid under the CRC Agreement; and (ii) a grace period from January 2017 to December 2017, in which amounts corresponding exclusively to the interest were paid monthly, but no principal amounts were paid. All other provisions of the CRC Agreement were maintained as they were, including the maintenance of the current correction and interest rates, thus not affecting the global net present value of such agreement.

The Company and the State of Paraná formalized the above-mentioned amendment on October 31, 2017, after the consent from the Brazilian Department of Treasury. The State of Paraná complied with the agreed terms of such amendment and made monthly interest payments until December 2018. As of December 31, 2019, the outstanding balance of the CRC Account was R$1,350.7 million.

As of January 1, 2020, there were 64 monthly installments left. For additional information, see Note 8 to our audited consolidated financial statements.

Special Obligations

The contributions received from the federal government and our customers exclusively for investment in our generation assets, transmission and distribution grid are named as special obligations. We record the amount of these contributions on our statement of financial position as a reduction of our intangible and financial assets, under the caption “special obligations”, and, upon the conclusion or termination of the operating concession granted to us, the amount of these contributions is offset against intangible and financial assets. The amount we recorded as special obligations as of December 31, 2019 was R$2,783.6 million as a reduction of intangible assets and R$31.1 million as a reduction of contract assets.

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CRITICAL ACCOUNTING POLICIES

In preparing our financial statements, we make estimates concerning a variety of matters as referred to in Note 3.4 to our audited consolidated financial statements. Some of these matters are highly uncertain, and our estimates involve judgments we make based on the information available to us. We have discussed in “Overview” above certain accounting policies relating to regulatory matters. In the discussion below, we have identified several other matters for which our financial information would be materially affected if either (i) we reasonably used different estimates or (ii) in the future we change our estimates in response to changes that are reasonably likely to occur.

The discussion below 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. Please see Note 3.4 to our audited consolidated financial statements included herein for a more detailed discussion of the application of these and other accounting policies.

Property, Plant and Equipment

We have adopted the deemed cost methodology to determine the fair value of Copel Geração e Transmissão’s property, plant and equipment, specifically for the generation business as of the date of transition of our financial statements to IFRS (January 1, 2009). These assets are depreciated according to the linear method based on annual rates set forth and reviewed periodically by ANEEL, which are used and accepted by the market as representative of the economic useful life of the assets related to concession’s infrastructure, limited to the term of said concession, when applicable. The estimated useful life, the residual amounts, and depreciation are reviewed as of each reporting date, and the effect of any changes in estimates is recorded prospectively.

Accounting for Concession Arrangements

We account for our concession contracts segregated in: Financial Assets (Accounts receivable - concession), Contract Assets and Intangible Assets, as presented below:

Concession of electric power distribution

The portion that we recognize as a financial asset refers to the indemnification provided for in the concession agreement for public electricity distribution services that guarantees the unconditional right to receive cash at the end of the concession, to be paid by the granting authority. This indemnification aims to reimburse the Company for investments made in infrastructure, without recovery, through the tariff. We calculate the cash flows linked to these assets considering the value of the tariff base called the Regulatory Remuneration Base - BRR, defined by the granting authority, using the methodology of replacement cost of the assets that are part of the distribution infrastructure linked to the concession.

The portion that we recognize as contract asset represents the contractual right of the concessionaire related to the works under construction to meet the needs of the distribution concession, accounted for at cost plus financial charges, when applicable. When these assets are put into operation, we transfer to the intangible asset the amount equivalent to what will be remunerated by the user through payment of the fee for the use of the services, and for the receivables linked to the concession, the amount equivalent to the residual portion of the assets not amortized which will be reverted to the granting authority through indemnification at the end of the concession.

The portion that we recognize as an intangible asset comprises the right to exploit the infrastructure, built or acquired under the concession regime for the public electric power service, and to charge users for the public service rendered. We record at acquisition cost, including borrowing costs, less accumulated amortization and impairment losses, when applicable. The amortization of this intangible asset reflects the pattern in which

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we expect the future economic benefits of the asset to be consumed, with amortization expected during the concession term.

Concession of electric power transmission

The portion that we recognize as a financial asset refers to the right to indemnification of Concession Agreement No. 060/2001 arising from the Annual Revenue Allowed - RAP not received in the period from January 2013 to June 2017 for the assets of the Basic Network of the Existing System - RBSE. On the balance, we recorded monetary restatement and interest.

The portion that we recognize as a contract asset represents the balance of the public electricity transmission service contracts signed with the granting authority to build, operate and maintain the high voltage lines and substations of the generation centers up to the distribution points. During the term of the agreement, we receive, subject to performance, a remuneration denominated Annual Revenue Allowance (RAP) that amortizes the investments made in the construction of the infrastructure and covers the costs of operation and maintenance incurred. After the start of the commercial operation and to the extent that the operation and maintenance service is provided, we recognize this revenue on a monthly basis in the result and invoice together with the part of the revenue recognized in the construction phase related to the remuneration of the constructed assets. The assets arising from the construction of the transmission infrastructure are formed by the recognition of the construction revenue and its financial remuneration. Upon expiration of the concession, if there is a remaining balance not yet received related to the construction of the infrastructure, it will be received directly from the granting authority, as provided in the concession agreement, as compensation for the investments made and not recovered through RAP.

We have not recognized intangible assets for energy transmission concession contracts.

Concession of electric power generation

We recognize as a financial asset the concession agreement for quota generation that provides for the payment of a bonus for the grant, considering that this bonus represents an unconditional right to receive cash, guaranteed by the granting authority during the term of the concession and without risk of demand. The remuneration of this financial asset is based on the weighted average cost of capital (WACC).

We also recognize as financial assets the electricity generation concession contracts that contain clauses for indemnification of the infrastructure not depreciated, amortized and / or received during the term of the concession. At the end of each reporting period, we evaluate the recoverability of the asset, remeasuring its cash flow based on our best estimate.

In intangible assets, we record the onerous concession contract for the generation of electric energy, which corresponds to the acquisition of the right to exploit the hydroelectric power generation potential whose contract provides for payments to the Federal Government as Use of Public Property - UBP. During the construction of the project, we recognize the amount at the present value of the future cash outflows during the period of validity of the concession agreement. On the date of commencement of the commercial operation of the enterprise, the amount presented is fixed and amortized during the concession period.

We also recognize as an intangible asset the asset constituted by the Generation Scaling Factor (GSF), derived from the excess amount between the amount recovered from the cost and the MRE (GSF) adjustment factor, subtracted from the total cost of the risk premium to be amortized over the period of energy supply in the regulated environment. The amount was transformed by ANEEL into an extension of the grant period, which we amortized on a straight-line basis as from January 1, 2016 until the end of the new concession term.

We did not recognize a contract asset for the power generation concession contracts

Distribution of piped gas

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The portion that we recognize as a financial asset is the one that will be indemnified by the granting authority corresponding to the investments made in the ten years prior to the end of the concession provided for in the agreement and which, in Management's opinion, guarantees the unconditional right to receive cash at the end of the concession. We use the indemnification premise based on the replacement cost of the concession assets.

The portion that we recognize as a contract asset comprises the works in progress for the distribution of piped gas which will be transferred to the intangible asset upon its entry into operation and to the extent that the right (authorization) to receive the users is received.

The portion that we recognize as an intangible asset corresponds to the users' right to charge for the gas supply. We initially valued this asset at acquisition cost, including interest and other capitalized financial charges. We apply the linear depreciation method based on the estimated useful life of each asset, considering the standard of economic benefit generated by the intangible assets.

In addition to our financial assets, contract assets and intangible assets, under IFRS we also recognize construction revenues and construction costs for construction activities we perform in connection with our distribution and transmission concessions. Our distribution business outsources power distribution infrastructure construction. As a result, under IFRS we recognize construction costs and revenues in roughly the same amounts. In contrast, since our transmission business performs much of our transmission infrastructure construction, we recognize construction revenue in amounts that exceed construction costs. The resulting margin for our transmission business’ construction revenue was 1.65% in 2019, and is calculated based on a methodology that takes into account business risk.

The determination of the amortization term of our intangible assets and the fair value of our financial assets in connection with our concession contracts is subject to assumptions and estimates, and the use of different assumptions could affect the amounts we recognize. The estimated useful lives of the underlying assets, as well as the rate of return of the financial assets also require significant assumptions and estimates. Different assumptions and estimates and changes in future circumstances could have a significant impact on our results of operations.

Additional information on the accounting for intangible, contract and financial assets arising from concession agreements is contained in Notes 4.4, 4.5 and 4.9 to our audited consolidated financial statements.

Revenue Recognition

Revenue from contracts with customers is measured based on the consideration that the Company expects to receive in a contract with the customer, net of any variable consideration. The Company recognizes revenues when it transfers control of the product or service to the customer and when it is probable to receive the consideration considering the client's ability and intention to pay the consideration when due. The Company records unbilled revenue, by estimate, when there is no information on the effective revenue incurred.

Interest income is recognized on a straight-line basis and based on time and the effective interest rate on outstanding principal amounts, when it is probable that future economic benefits will flow to the Company and its amount can be reliably measured.

Revenue related to construction services for infrastructure in the power transmission and distribution services, and gas distribution, are recognized using the percentage of completion method at each reporting period and measured on the basis of the proportion of costs incurred in relation to the total estimated costs of the contracts.

Additional information is contained in Notes 4.12 and 4.13 to our audited consolidated financial statements.

Net Sectorial Financial Assets and Liabilities

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Until 2009, the Brazilian accounting standards allowed distribution concessionaires to book the difference, if any, between the amounts that concessionaires were entitled to collect under their respective concession contracts and the amounts they actually collected, which are referred to as sectorial assets and liabilities. The positive or negative variations in these amounts were included in the tariffs in the following annual tariff adjustment. With the adoption of IFRS in 2010, these assets and liabilities were no longer recorded in the financial statements of distribution concessionaires.

As a result of an amendment to our distribution concession agreement executed on December 10, 2014, we recognized on December 31, 2019, a financial asset of R$474.0 (R$678.8 million in 2018) and a financial liability in the amount of R$102.3 million (R$96.5 million in 2018). This amendment added a guarantee that, if the concession is extinguished for any reason, the residual amounts of items of Parcel A costs and other financial components that have not been recovered or returned via tariff shall be incorporated in the calculation of the indemnification amount by the granting authority. For more information, see Note 9 to the audited consolidated financial statements.

Impairment of Long-Lived Assets

Long-lived assets, primarily property, plants and equipment and intangible assets, comprise a significant amount of our total assets. We evaluate our long-lived assets and make judgments and estimates concerning the carrying value of these assets, including the amounts to be capitalized, the depreciation/ amortization rates and useful lives of these long-lived assets. The carrying values of these assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable. An impairment loss is recorded in the period in which it is determined that the carrying amount is not recoverable. This requires us to make long-term forecasts of future revenues and costs related to the assets subject to review. These forecasts require assumptions about the demand for our products and services, future market conditions and regulatory developments. Significant and unanticipated changes to these assumptions could require a provision for impairment in a future period. Our evaluation as of December 31, 2019, resulted in an impairment of our in service and in progress property, plant and equipment in the amounts of R$1,042.5 million and R$127.6 million, respectively (see Notes 17.1 of our consolidated financial statements).

Provision for Risks (Labor, Civil, Tax and Environmental Claims)

Our subsidiaries and we are party to certain legal proceedings in Brazil arising in the normal course of business regarding tax, labor, civil and environmental claims.

Provisions are recognized when, and only when: (i) the Company has a present obligation (legal or constructive) resulting from a past event, (ii) it is probable (i.e., more likely than not) that an outflow of resources embodying economic benefits will be required to settle the obligation, and (iii) a reliable estimate can be made of the amount to settle the obligation. By their nature, risks will only be resolved when a future event or events occur or fail to occur. Typically such events will occur a number of years in the future. The evaluation of these risks is performed by our internal and external legal counsel. Accounting for risks requires significant judgment by management concerning the estimated probabilities, including classification as probable or possible losses and ranges of exposure to potential liability. Management’s assessment of our exposure to risks could change as new developments occur or more information becomes available. The outcome of the risks could vary significantly and could materially impact our consolidated results of operations, cash flows and financial position. The provision classified as probable losses, as of December 31, 2019 amounted to R$1,606.7 million, of which R$175.8 million was related to tax proceedings, R$591.8 million was related to civil claims, R$673.1 million was related to labor claims, R$86.2 million was related to employee benefits and R$79.8 million was related to regulatory proceedings.

As of December 31, 2019, we estimate that the total amount of claims against us, excluding disputes involving non-monetary claims or claims that cannot be evaluated in the current stage of proceedings, classified as possible losses, was approximately R$3,485.1 million, of which R$419.9 million correspond to labor claims; R$21.3 million to employee benefits; R$1,141,4 million to regulatory claims; R$1,273.9 million to civil claims; and R$628.6 million to tax claims. For more information, see Note 29 to our audited consolidated financial statements.

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Employee Retirement and Health Benefits

We sponsor a (i) defined-benefit pension plan and a (ii) variable contribution pension plan covering substantially all of our employees. We have also established a health care plan for current and retired employees. We determine our obligations for these plans based on calculations performed by independent actuaries using assumptions that we provide about interest rates, investment returns, rates of inflation, mortality rates and future employment levels (see the assumptions in Note 23.5.1 and the sensitivity analysis in Note 23.5.8 of our consolidated financial statements). These assumptions directly affect our post-employment benefits liability.

In 2019, we recorded expenses in the amount of R$238.3 million for our pension and health care plans. We estimate that we will incur expenses in the amount of R$94.3 million in 2020 for our health care plans (according to actuarial calculations).

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Deferred Taxes

We recognize deferred tax assets and liabilities based on the differences between the financial statement carrying amounts and the tax basis of assets and liabilities using prevailing rates. We regularly review our deferred tax assets for recoverability 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 derecognize 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. The taxes balances subject to the federal taxing department inspection are those constituted over the last five years. As of December 31, 2019, we have recognized deferred tax assets totaling R$2,069.0 million and deferred tax liabilities in the amount of R$1,350.8 million. We have not considered any reduction for risk of recovery of such assets (see Note 13.1.2 to the consolidated financial statements).

Expected credit losses

We recorded the expected credit losses in amounts deemed sufficient to cover potential losses on the realization of customer receivables and others whose recovery is considered unlikely. We account for the balance of expected credit losses based on the credit risk analysis, taking into account specific payment history criteria, recovery actions for credit recovery and the relevance of the amount due in the receivables portfolio. As of December 31, 2019, we recorded expected credit losses in the amount of R$376.8 million (see Note 7.3 to our consolidated financial statements for further details including provisions and reversals).

Derivative Financial Instruments

We negotiate energy purchase and sale operations and part of our contracts are classified as derivative financial instruments measured at fair value through profit or loss. We recognize in the income for the period unrealized net gains or losses arising from the mark-to-market of these contracts, based on the difference between contracted and market prices.

In addition, we enter into Non-Deliverable Forward (“NDF”) contracts, which aim exclusively at providing hedge against exchange rate risks associated with cash flows from capital contributions to subsidiaries, when they reflect foreign-currency denominated purchases of projected equipment. They are measured at their fair value, with changes recorded in the statement of income for the year. The fair value is calculated based on the information of each contracted operation and the respective market information on the closing dates of the financial statements.

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ANALYSIS OF ELECTRICITY SALES AND COST OF ELECTRICITY PURCHASED

The following table sets forth the volume and average rate components of electricity sales and purchases for the years ended December 31, 2019, 2018 and 2017:

| Year ended December 31,
| 2019 | 2018 | 2017
Electricity Sales |  |  |
Sales to Final Customers |  |  |
Average price (R$/MWh):(1) |  |  |
Industrial customers(2) | 284.03 | 292.71 | 307.24
Residential customers | 789.75 | 745.77 | 670.21
Commercial customers | 743.25 | 711.64 | 657.14
Rural customers | 465.30 | 408.71 | 377.97
Other customers(3) | 582.91 | 551.84 | 499.25
All customers(2) | 561.27 | 537.51 | 508.83
Volume (GWh): |  |  |
Industrial customers(2) | 9,000 | 8,641 | 7,689
Residential customers | 7,499 | 7,238 | 7,126
Commercial customers | 5,238 | 4,979 | 4,847
Rural customers | 2,361 | 2,288 | 2,257
Other customers(3) | 2,546 | 2,481 | 2,455
All customers(2) | 26,644 | 25,627 | 24,374
Total revenues from sales to final customers (millions of R$) | 14,954 | 13,775 | 12,402
Sales to distributors(4) |  |  |
Average price (R$/MWh)(1) | 213,57 | 241,62 | 204,48
Volume (GWh) (5) | 15,456 | 12,979 | 17,263
Total revenues (millions of R$) | 3,301 | 3,136 | 3,530
Electricity Purchases |  |  |
Purchases from Itaipu |  |  |
Average cost (R$/MWh)(6) | 237.4 | 222.18 | 188.41
Volume (GWh) | 5,533 | 5,726 | 5,934
Percentage of total Itaipu production purchased | 8.7 | 7.1 | 7.2
Total cost (millions of R$)(7) | 1,316.5 | 1,272.2 | 1,118.0
Purchases from Angra |  |  |
Average cost (R$/MWh) | 253,58 | 248.07 | 226.49
Volume (GWh) | 0,978 | 1,009 | 1,023
Total cost (millions of R$)(7) | 248.0 | 250.3 | 231.7
Purchases from CCGF |  |  |
Average cost (R$/MWh) | 102.28 | 90.92 | 61.55
Volume (GWh) | 6,274 | 6,520 | 7,271
Total cost (millions of R$)(7) | 641.7 | 592.8 | 447.5
Purchases from others(4) |  |  |
Average cost (R$/MWh) | 185.27 | 237.41 | 342.37
Volume (GWh) | 21,045 | 17,884 | 12,758
Total cost (millions of R$)(7) | 3,899 | 4,246 | 4,368

(1) | Average prices or costs have been computed by dividing (i) the corresponding revenues or expenses by (ii) MWh of electricity sold or purchased.

(2) | Includes Free Customers outside Paraná.

(3) | Includes public services such as street lighting, as well as the supply of electricity to government agencies, and our own consumption.

(4) | Energy traded between Copel’s subsidiaries not included.

(5) | Energy Reallocation Mechanism not included.

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(6) | Our purchases of electricity generated by Itaipu are stated in reais and paid for on the basis of a capacity charge expressed in U.S. dollars per kW plus a “wheeling” (or transportation) charge expressed in reais per kWh.

(7) | See “Item 4. Information on the Company—Business—Generation” and “Item 4. Information on the Company—Business— Purchases for the captive market” for an explanation of our expenses relating to electricity purchases.

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RESULTS OF OPERATIONS FOR THE YEARS ENDED DECEMBER 31, 2019, 2018 AND 2017

The following table summarizes our results of operations for the years ended December 31, 2019, 2018 and 2017.

Our consolidated financial statements present our operating costs of sales and services provided by function. However, in accordance with IFRS, Note 32 of our audited consolidated financial statements presents this information according to the nature of the operating cost or expense. For ease of understanding, the analysis below reflects the information presented by nature.

| Year ended December 31,
| 2019 | 2018 | 2017
| (R$million)
Operating Revenues: |  |  |
Electricity sales to Final Customers: | 10,481.7 | 10,104.0 | 8,689.5
Residential | 3,336.4 | 3,175.3 | 2,750.5
Industrial | 1,276.1 | 1,419.2 | 1,337.9
Commercial, services and other activities | 2,179.5 | 2,136.1 | 1,880.9
Rural | 631.5 | 572.3 | 511.1
Other classes | 3,058.2 | 2,801.1 | 2,209.1
Electricity sales to distributors | 3,301.3 | 3,136.2 | 3,529.8
Use of main distribution and transmission grid | 8,271.0 | 6,867.3 | 6,442.8
Residential | 2,585.9 | 2,222.6 | 2,025.4
Industrial | 1,280.2 | 1,110.1 | 1,024.4
Commercial, services and other activities | 1,713.6 | 1,407.2 | 1,304.3
Rural | 467.0 | 362.8 | 341.9
Other classes | 597.9 | 511.5 | 469.1
Interest income | 413.2 | 319.1 | 440.6
Other distribution and transmission revenue | 1,213.2 | 934.0 | 837.1
Construction revenues | 1,132.9 | 1,097.3 | 868.0
Revenues from telecommunications | 532.9 | 512.5 | 426.8
Distribution of piped gas | 1,003.8 | 753.2 | 622.0
Sectorial financial assets and liabilities result | 25.1 | 985.3 | 767.0
Other operating revenues | 442.4 | 222.3 | 171.3
Fair value of assets from the indemnity for the concession | 36.6 | 47.5 | 57.1
| 25,227.7 | 23,725.6 | 21,574.3
Cost of sales and services provided: |  |  |
Electricity purchased for resale | (6,105.3) | (6,361.2) | (6,165.5)
Charge of main distribution and transmission grid | (1,249.3) | (1,176.8) | (712.0)
Personnel and management | (1,325.4) | (1,357.8) | (1,343.3)
Pension and healthcare plans | (238.3) | (243.8) | (237.6)
Material and supplies | (82.2) | (81.8) | (83.1)
Materials and supplies for power electricity | (49.4) | (19.7) | (97.4)
Natural gas and supplies for gas business | (585.2) | (412.6) | (309.5)
Third-party services | (613.1) | (572.2) | (521.5)
Depreciation and amortization | (1,093.8) | (749.2) | (731.6)
Accruals and provisions | (374.8) | (306.7) | (365.5)

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Construction cost | (1,091.4) | (1,052.2) | (1,003.9)
Other costs and expenses | (352.2) | (342.7) | (414.0)
| (13,160.3) | (12,676.6) | (11,984.9)
Equity in earnings of associates and joint ventures | 106.8 | 135.9 | 101.7
Financial results | (488.5) | (438.1) | (748.4)
Profit before income tax and social contribution | 2,702.2 | 1,956.0 | 1,392.9
Income tax and social contribution on profit | (639.3) | (512.0) | (274.7)
Net income for the year | 2,062.9 | 1,444.0 | 1,118.3
Net income attributable to controlling shareholders | 1,989.9 | 1,407.1 | 1,033.6
Net income attributable to non-controlling interest | 72.9 | 36.9 | 84.7
Other comprehensive income | 123.2 | 38.5 | 31.3
Comprehensive income | 1,939.7 | 1,405.6 | 1,086.9
Comprehensive income attributable to controlling shareholders | 1,862.5 | 1,368.5 | 1,002.4
Comprehensive income attributable to non-controlling interest | 77.2 | 37 | 84.5

Results of Operations for 2019 Compared with 2018

Operating Revenues

Our consolidated operating revenues increased by 6.3% or R$1,502.1 million in 2019 compared to 2018. This result reflected an increase of R$377.7 million in electricity sales to Final Customers; an increase of R$35.6 million in construction revenues; an increase of R$250.6 million in the distribution of piped gas; an increase of R$ 20.4 million in telecommunications revenues; and an increase of R$220 million in other operating revenues; an increase of R$165.1 million in electricity sales to distributors; and an increase of R$1,403.7 million in the use of our main transmission grid. These increases were partially offset by a reduction of R$960.2 million in sectorial financial assets and liabilities and a reduction of R$10.9 million in fair value of the indemnity for the concession assets.

Electricity Sales to Final Customers. Our revenues from electricity sales to Final Customers increased by 3.7%, or R$377.7 million, to R$10,481.7 million in 2019 compared to R$10,104.0 million in 2018, mainly due to an increase of 3.96% of total power consumption of our Final Customers, from 25,627 GWh in 2018 to 26,644 GWh in 2019, as follows:

| · | The volume of electricity sold to residential customers increased by 3.6% in 2019 compared to 2018, while there was an increase in the number of customers by 1.9%.

| · | The volume of electricity sold to industrial customers, including both Captive Customers and Free Customers, increased by 3.9% in 2019 compared to 2018, mainly due to the growth of energy consumption of industrial customers in the Free Market, partially offset by the reduction of 1.5% in the number industrial customers in the captive market.

| · | The volume of electricity sold to commercial customers, including both Captive Customers and Free Customers, increased by 5.2% in 2019 compared to 2018. The number of Captive customers increase by 1.6%, in 2019 compared to 2018.

| · | The volume of electricity sold to rural customers increased by 3.2% in 2019 compared to 2018. This increase is mainly due to the performance of agribusiness in the State of Paraná.

Electricity Sales to Distributors. Our revenues from electricity sales to distributors increased by 5.3%, or R$165.1 million, to R$3,301.3 million in 2019 compared to R$3,136.2 million in 2018. This increase was mainly due to the increase in our revenues from electricity sold in regulated contracts, which increased by 121.8%, or R$469.1 million, to R$854.2 million in 2019 compared to R$385.1 million in 2018.

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Use of main distribution and transmission grid. Our revenues from the use of main distribution and transmission grid increased by 20.4%, or R$1,403.8 million, to R$8,271.0 million in 2019 compared to R$6,867.2 million in 2018. This increase was mainly due the 3.3% growth in the grid market and the tariff readjustment of Copel Distribuição (with an increase of 16.42% and 11.63% in TUSD as of June 24, 2018 and June 24, 2019, respectively), and the entry into operation of new transmission assets that increased.

Construction revenues. Our revenues construction increased by 3.2%, or R$35.6 million, to R$1,132.9 million in 2019, compared to R$1,097.3 million in 2018. This increase was mainly due to the intensification of construction efforts in 2019 with the objective of improving our distribution and transmission infrastructure.

Fair value of assets from the indemnity for the concession. The fair value of the assets from the indemnity for the concession decreased by 22.9%, or R$10.9 million, to R$36.6 million in 2019, compared to R$47.5 million in 2018. The decrease was mainly due to lower variation in the distribution concession agreement’s assets.

Revenues from Telecommunications. Revenues from our telecommunications segment increased by 4.0%, or R$20.4 million, to R$532.9 million in 2019 compared to R$512.5 million in 2018, as a result of an increase in the number of customers in the retail market, notably in the internet broadband segment

Distribution of Piped Gas. Revenues from the distribution of piped gas increased by 33.2%, or R$250.6 million, to R$1,003.8 million in 2019, compared to R$753.2 million in 2018, due to the tariff adjustment and improvement in the gas market.

Sectorial Financial Assets and Liabilities. Sectoral financial assets and liabilities decreased by 97.4%, or R$960.2 million, to R$25.1 million in 2019, compared to R$985.3 million in 2018. This variation was mainly due to the amortization of the amounts considered in the electricity sales to final customers after the tariff adjustment in June 2018 and the lower variation of balances created for the adjustment applied as of June 2019.

Other Operating Revenues. Other operating revenues increased by 98.9%, or R$220 million, to R$442.4 million in 2019, compared to R$222.4 million in 2018, mainly due to fair value in the purchases and sale of power revenues, and higher revenues from leases and rents.

Cost of sales and services provided

Our consolidated costs of sales and services provided increased by 3.8% or R$483.7 million, to R$13,160.3 million in 2019 compared to R$12,676.6 million in 2018. The main factors leading to such increase in our cost of sales and services provided are as follows:

| · | Electricity Purchased for Resale. Our purchased energy costs for resale decreased by 4%, or R$255.9 million, to R$6,105.3 million in 2019, compared to R$6,361.2 million in 2018. This was mainly due to a decrease in the cost of "electricity purchased for resale", due to the higher GSF applicable.

| · | Charge of Main Distribution and Transmission Grid. Expenses we incurred for our use of the main distribution and transmission grid increased 6.2%, or R$72.5 million, to R$1,249.3 million in 2019, compared to R$1,176.8 million in 2018, mainly as a result of the increase in tariffs and charges for transmission infrastructure made available for new generation projects from 2019, in addition to the effect of the variation in costs related to dispatching thermal plants, with an impact on system service fees - ESS.

| · | Personnel and Management. Personnel and administrative expenses decreased by 2.4%, or R$32.4 million, to R$1,325.4 million in 2019, compared to R$ 1,357.8 million in 2018. Despite the increase in the provision for profit sharing (PLR) due to the improvement in the Company’s results, the decrease in costs reflects on employee reduction occurred in 2019.

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| · | Pension and Healthcare Plans. Pension and Healthcare expenses decreased 2.25%, or R$5.5 million, to R$238.3 million in 2019, compared to R$243.8 million in 2018, due to the readjustment of the monthly care plans.

| · | Material and Supplies. Material expenses increased 0.5%, or R$0.4 million, to R$82.2 million in 2019 compared to R$81.8 million in 2018.

| · | Material and Supplies for Power Electricity. These expenses increased 150.7% or R$29.7 million, totaling R$49.4 million in 2019, compared to R$19.7 million in 2018, mainly as a result of the completion of Araucária TPP in 2019.

| · | Natural Gas and Supplies for Gas Business. Expenses related to natural gas purchases increased 41.8%, or R$172.6 million, to R$585.2 million in 2019, compared to R$412.6 million in 2018, mainly due to growth in the market of Compagás and exchange variation.

| · | Third-Party Services. Third-party service expenses increased by 7.1%, or R$40.9 million, to R$613.1 million in 2019, compared to R$572.2 million in 2018, mainly due to the higher maintenance value of the electric system, communication, data processing and transmission and advisory and auditing services.

| · | Depreciation and Amortization. Depreciation and amortization increased by 46%, or R$344.6 million, to R$1,093.8 million in 2019, compared to R$749.2 in 2018, due to an increase by 81.2% in the costs with depreciation and amortization resulting from the start of commercial operation in 2019 at the Colíder, Cutia and Baixo Iguaçu plants.

| · | Accruals and Provisions. Provisions and reversals expenses increased by 22.2%, or R$68.1 million, to R$374.8 million in 2019, compared to R$306.7 million in 2018, mainly due to (i) increase by 17.4% related to provisions for litigations, and (ii) increase by 59.7% in expected credit losses (or bad debt).

| · | Construction Cost. Construction costs increased by 3.7%, or R$39.2 million, to R$1,091.4 million in 2019, compared to R$1,052.2 million in 2018, mainly reflecting investments in transmission, distribution and Compagas assets.

| · | Other Costs and Expenses. Other costs and expenses increased 2.8%, or R$9.5 million, to R$352.2 million in 2019, compared to R$342.7 million in 2018.

Equity earnings of associates and joint ventures

Equity earnings of associates and joint ventures was R$106.8 million in 2019, a decrease of 21.4%, compared to R$135.9 million in 2018, mainly due to a decrease in the profits of our associate entities and joint ventures.

Namely, our equity accounting income for 2019 was: (i) loss of R$3.4 million from Voltalia, compared to loss of R$4.0 million in 2018; (ii) R$4.8 million from Caiuá, compared to R$5.0 million in 2018; (iii) R$11.3 million from the Integração Maranhense compared to R$9.2 million in 2018; (iv) R$48.6 million from Matrinchã compared to R$50.4 million in 2018; (v) R$18.3 million from Guaraciaba, compared to R$35.3 million in 2018; (vi) R$16.4 million from Paranaíba, compared to a loss of R$16.5 million in 2018; (vii) loss of R$41.7 million from the Mata de Santa Genebra, compared to a loss of R$2.5 million in 2018; (viii) R$28.0 million from Cantareira compared to R$24.6 million in 2018; (ix) R$9.8 million from Dona Francisca compared to R$10.0 million in 2018; and (x) R$13.9 million from Foz do Chopim versus R$13.2 million from 2018.

Financial Results

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We recognized an increase of financial losses of 11.5%, or R$10.4 million, to R$488.5 million in 2019. This result is due to: (i) a decrease by 7.8% in financial revenues, mainly due to other financial income, monetary variation on CRC onlendings and the recognition of tax credits; and, (ii) a reduction of 1.06% in financial expenses, other financial expenses.

Income Tax and Social Contribution Expenses

In 2019, our income tax and social contribution expenses increased to R$639.3 million, reflecting an effective tax rate of 23.7% in our pretax income, compared to R$512.0 million and an effective tax rate of 26.2% in our pretax profit in 2018. The decrease in our effective tax rate was mainly due to (i) our enrollment in a special tax benefit program of the Brazilian Federal Tax Authority (Programa Especial de Regularização Tributária – PERT da Secretaria da Receita Federal). For more information on this special tax benefit program, see Note 13.2.2 to our Consolidated Financial Statements; and (ii) an increase of R$123.9 million in paid Capital in 2019.

Results of Operations for 2018 Compared with 2017

Operating Revenues

Our consolidated operating revenues increased by 10.0% or R$2,151.3.2 million in 2018 compared to 2017. This result reflected an increase of R$1,414.5 million in electricity sales to Final Customers; an increase of R$229.3 million in construction revenues; an increase of R$218.3 million in sectorial financial assets and liabilities; an increase of R$131.2 million in the distribution of piped gas; an increase of R$85.7 million in telecommunications revenues; an increase of R$424.4 million in the use of our main transmission grid; and an increase of R$51 million in other operating revenues. These increases were partially offset by a reduction of R$393.6 million in electricity sales to distributors; and a reduction of R$9.6 million in fair value of the Indemnifiable Concession Assets.

Electricity Sales to Final Customers. Our revenues from electricity sales to Final Customers increased by 16.3%, or R$1,414.5 million, to R$10,104.0 million in 2018 compared to R$8,689.5 million in 2017, mainly due to an increase of 5.1% of total power consumption of our Final Customers, from 24,374 GWh in 2017 to 25,627 GWh in 2018, and the average readjustment of 15.99% in June 2018 in tariffs paid by consumers in the captive market, as follows:

| · | The volume of electricity sold to residential customers increased by 1.6% in 2018 compared to 2017. While there was an increase in the number of customers by 2.0%, the average consumption remained stable in 2018 compared to 2017.

| · | The volume of electricity sold to industrial customers, including both Captive Customers and Free Customers, increased by 12.4% in 2018 compared to 2017, mainly due to the growth of Copel's commercial customers in the Free Market, partially offset by the reduction of industrial customers in the captive market. The number of industrial customers decreased by 4.1% and average consumption grew by 17.2% in 2018 compared to 2017.

| · | The volume of electricity sold to commercial customers, including both Captive Customers and Free Customers, increased by 2.7% in 2018 compared to 2017. Despite the increase in number of customers by 2.7%, the average consumption remained practically stable in 2018 compared to 2017.

| · | The volume of electricity sold to rural customers increased by 1.4% in 2018 compared to 2017. This increase is mainly due to the performance of agribusiness in the State of Paraná and an increase of 2.2% in the average consumption.

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Electricity Sales to Distributors. Our revenues from electricity sales to distributors revenues decreased by 11.1%, or R$393.6 million, to R$3,136.2 million in 2018 compared to R$3,529.8 million in 2017. This reduction was mainly due to the decrease in our revenues from electricity sold in the Spot Market (CCEE), which decreased by 38.1%, or R$387.0 million, to R$628.1 million in 2018 compared to R$1,015.1 million in 2017. This reduction in CCEE's revenues is a result of (i) the non-activation of the Araucária Thermoelectric Plant; and (ii) lower prices in the Spot Market.

Use of main distribution and transmission grid. Our revenues from the use of main distribution and transmission grid increased by 6.6%, or R$424.4 million, to R$6,867.2 million in 2018 compared to R$6,442.8 million in 2017. This decrease was mainly due to the remeasurement of assets related to tRBSE, which registered a revenue of R$82.6 million in 2018 compared to R$361.2 million in 2017, as disclosed in Note 10.5 of our consolidated audited financial statements. This decrease in our revenues from the use of main distribution and transmission grid was partially offset by the 1.9% growth in Copel Distribuição's grid market.

Construction revenues. Our revenues construction increased by 26.4%, or R$229.3 million, to R$1,097.3 million in 2018, compared to R$868.0 million in 2017. This increase was mainly due to the intensification of construction efforts in 2018 with the objective of improving our distribution and transmission infrastructure.

Fair value of assets from the indemnity for the concession. The fair value of the assets from the indemnity for the concession decreased by 16.8%, or R$9.6 million, to R$47.5 million in 2018, compared to R$57.1 million in 2017. The decrease was mainly due to lower variation in the distribution concession agreement’s assets.

Revenues from Telecommunications. Revenues from our telecommunications segment increased by 20.1%, or R$85.7 million, to R$512.5 million in 2018 compared to R$426.8 million in 2017, as a result of an increase in the number of customers in the retail market, notably in the internet broadband segment

Distribution of Piped Gas. Revenues from the distribution of piped gas increased by 21.1%, or R$131.2 million, to R$753.2 million in 2018, compared to R$622.0 million in 2017, due to the tariff adjustment and improvement of 2.9% in the gas market.

Sectorial Financial Assets and Liabilities. Sectoral financial assets and liabilities increased by 28.4%, or R$218.3 million, to R$985.3 million in 2018, compared to R$767.0 million in 2017. This variation was mainly due to the recognition of receivables resulting from the positive difference between the average price of electricity purchased from Itaipu, Angra, CCGF and the Availability Contracts and the average price of the hedging rate. In relation to Itaipu's electricity, the higher cost is due to the exchange variation, while in relation to other contracts the higher cost originates from the hydrological scenario (variations in GSF and PLD). For more information on this variation, see Note 9.2 to our consolidated audited financial statements.

Other Operating Revenues. Other operating revenues increased by 29.7%, or R$51.0 million, to R$222.4 million in 2018, compared to R$171.4 million in 2017, mainly due to revenues from services rendered of the engineering contract of owner of the HPP Baixo Iguaçu, and higher revenues from leases and rents.

Cost of sales and services provided

Our consolidated costs of sales and services provided increased by 5.8% or R$691.7 million, to R$12,676.6 million in 2018 compared to R$11,984.9 million in 2017. The main factors leading to such increase in our cost of sales and services provided are as follows:

| · | Electricity Purchased for Resale. Our purchased energy costs for resale increased by 3.2%, or R$195.8 million, to R$6,361.2 million in 2018, compared to R$6,165.4 million in 2017. This increase was mainly due to: (i) an increase by 21.1% in the cost of electricity purchased through bilateral contracts, explained in particular by the higher volume of electricity purchased by Copel Comercialização (4,101 GWh in 2018 compared to 2,644 GWh in 2017), and (ii) an increase by 13.8% in the costs of purchasing electricity from Itaipu, due to the exchange variation.

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| · | Charge of Main Distribution and Transmission Grid. Expenses we incurred for our use of the main distribution and transmission grid increased 65.3%, or R$464.8 million, to R$1,176.8 million in 2018, compared to R$712.0 million in 2017, mainly as a result of (i) the adjustment in TUST in June 2018 and June 2017 (when the indemnity related to RBSE assets began to incorporate Permitted Annual Revenue - APR, and in 2018 the impact was on the whole year), and (ii) cost of System Services Charges (ESS), reflecting the greater amount of resources received from the reserve electric energy (Coner) in 2017, due to the effects of the indemnities to the transmission of energy.

| · | Personnel and Management. Personnel and administrative expenses increased by 1.1%, or R$14.5 million, to R$1,357.8 million in 2018, compared to R$1,343.3 million in 2017, as a result of (i) salary readjustment of 3.97% as of October 2018 and 1.63% as of October 2017, (ii) provision for indemnification for retirement incentive program (PDI), and (iii) an increase of R$22.7 million in the amount allocated to Profit Sharing - PLR, partially offset by a reduction in the number of employees.

| · | Pension and Healthcare Plans. Pension and Healthcare expenses increased 2.6%, or R$6.2 million, to R$243.8 million in 2018, compared to R$237.6 million in 2017, due to the readjustment of the monthly care plans.

| · | Material and Supplies. Material expenses decreased 1.6%, or R$1.3 million, to R$81.8 million in 2018 compared to R$83.1 million in 2017.

| · | Material and Supplies for Power Electricity. These expenses decreased 79.8% or R$77.7 million, totaling R$19.7 million in 2018, compared to R$97.4 million in 2017, mainly as a result of the activation of Araucária TPP in 2017, and the corresponding increase in purchases of natural gas, while in 2018 the plant was not activated.

| · | Natural Gas and Supplies for Gas Business. Expenses related to natural gas purchases increased 33.3%, or R$103.1 million, to R$412.6 million in 2018, compared to R$309.5 million in 2017, mainly due to growth in the market of Compagas and exchange variation.

| · | Third-Party Services. Third-party service expenses increased by 9.7%, or R$50.7 million, to R$572.2 million in 2018, compared to R$521.5 million in 2017, mainly due to the higher maintenance value of the electric system, communication, data processing and transmission and advisory services and auditing services.

| · | Depreciation and Amortization. Depreciation and amortization increased by 2.4%, or R$17.6 million, to R$749.2 million in 2018, compared to R$731.6 in 2017, mainly due to an increase in our non-current assets.

| · | Accruals and Provisions. Provisions and reversals expenses decreased by 16.1%, or R$58.8 million, to R$306.7 million in 2018, compared to R$365.5 million in 2017, due in particular to the reversal of the provision for R$92.7 million related to an indemnification action against third parties.

| · | Construction Cost. Construction costs increased by 4.8%, or R$48.3 million, to R$1,052.2 million in 2018, compared to R$1,003.9 million in 2017, mainly reflecting investments in transmission, distribution and Compagas assets.

| · | Other Costs and Expenses. Other costs and expenses decreased 17.2%, or R$71.3 million, to R$342.7 million in 2018, compared to R$414.0 million in 2017. This reduction is mainly due to reimbursement from suppliers of wind farm assets of the Brisa Potiguar Complex in the amount of R$72.1 million.

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Equity earnings of associates and joint ventures

Equity earnings of associates and joint ventures was R$135.9 million in 2018, an increase of 33.5%, compared to R$101.8 million in 2017, mainly due to a growth in the profits of our associate entities and joint ventures.

Namely, our equity accounting income for 2018 was: (i) loss of R$4.0 million from Voltalia, compared to loss of R$0.6 million in 2017; (ii) R$3.0 million from Costa Oeste, compared to loss of R$2.6 million in 2017; (iii) R$7.0 million from Marumbi compared to loss of R$9.5 million in 2017; (iv) R$1.2 million from Transmissora Sul Brasileira, compared to loss of R$5.0 million in 2017; (v) R$5.0 million from Caiuá, compared to loss of R$4.0 million in 2017; (vi) R$9.2 million from the Integração Maranhense compared to loss of R$8.9 million in 2017; (vii) R$50.4 million from Matrinchã compared to R$57.4 million in 2017; (viii) R$35.3 million from Guaraciaba, compared to R$25.4 million in 2017; (ix) loss of R$16.5 million from Paranaíba, compared to R$17.0 million in 2017; (x) loss of R$2.5 million from the Mata de Santa Genebra, compared to R$19.5 million in 2017; (xi) R$24.6 million from Cantareira compared to R$3.9 million in 2017; (xii) R$10.0 million from Dona Francisca compared to R$8.9 million in 2017; and (xiii) R$13.2 million from Foz do Chopim versus R$6.6 million from 2017.

Financial Results

We recognized a reduction of financial losses of 41.5%, or R$310.3 million, to R$438.1 million of net financial losses in 2018, compared to a net financial loss of R$748.4 million in 2017. This result is due to: (i) an increase by 16.4% in financial revenues, mainly due to the increase in interest and monetary variation on CRC onlendings and the recognition of tax credits, and (ii) a reduction of 13.5% in financial expenses, due to lower monetary, exchange rate and debt charges, mainly influenced by the reduction of the SELIC rate.

Income Tax and Social Contribution Expenses

In 2018, our income tax and social contribution expenses increased to R$512.0 million, reflecting an effective tax rate of 26.2% in our pretax income, compared to R$274.7 million and an effective 19.7% in our pretax profit in 2017. The increase in our effective tax rate in 2018 compared to 2017 was primarily due to our enrollment in a special tax benefit program of the Brazilian Federal Tax Authority (Programa Especial de Regularização Tributária – PERT da Secretaria da Receita Federal). For more information on this special tax benefit program, see Note 13.3.1 to our consolidated audited financial statements.

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LIQUIDITY AND CAPITAL RESOURCES

Our principal liquidity and capital requirements are to finance the expansion and improvement of our distribution and transmission infrastructure and to finance the expansion of our generation facilities.

We believe our working capital is sufficient for our present requirements and the next 12 months. However, the expectation of the economic impacts resulting from the shutdown caused by the outbreak of the coronavirus (COVID-19), with subsequent effects on Copel's operations, may affect Company's financial results. In December 2019, our Current Liquidity, an index ratio that measures our current assets over our current liabilities reached 1.5x (1.0x in 2018) with a cash balance, equivalent to cash and marketable securities of R$3,223.8 million (R$2,292.7 million in 2018).

The Company monitors its financial liquidity continuously and, for that that purpose, it considers (i) on the external side, the possibility of raising funds and the prospect of preserving cash through the assistance of structural measures by the Federal Government and other Sectoral Institutions, and (b) on the internal side, taking the necessary actions in our operations by reducing expenses or postponing investments in order to guarantee the timely fulfillment of financial obligations. Accordingly, our estimates are to preserve the working capital required for our operations throughout the period.

In addition to working capital, our other principal uses of cash are to dividends payments and debt servicing. Capital expenditures were R$2,055.6 million in 2019 and R$2,590.8 million in 2018. The following table sets forth a breakdown of our capital expenditures for the periods indicated. Our capital expenditures are focused on projects located in Brazil.

As in previous years, our capital requirement will be financed by cash from our operations and/or by external financing, which may serve to offset commitments arising from the maturity of previous external financing.

| Year ended December 31,
| 2019 | 2018 | 2017
| (R$million)
Generation and transmission¹ | 691.9 | 1,423.1 | 1,389.1
Distribution | 919.9 | 696.0 | 630.4
Telecom | 146.3 | 309.4 | 241.1
Investment of associates and joint ventures | 267.5 | 87.5 | 248.2
Araucária Thermoelectric Plant | 0.4 | 2.8 | 0.7
Compagas | 17.6 | 15.6 | 13.7
Elejor | 0.2 | 2.7 | 1.5
Others | 11.8 | 53 | -
Total | 2,055.6 | 2,590.8 | 2,524.7

¹ Considers investment in projects held 100% by Copel GeT.

Our total budgeted capital expenditures for our wholly-owned subsidiaries for 2020 is R$2,087.2 million, of which:

| · | R$792.3 million are for generation and transmission, R$80.5 million are for the construction of the Colíder Hydroelectric Plant, and R$25.8 million are for the construction of the Baixo Iguaçu Hydroelectric Plant;

| · | R$1,073.8 million are for our distribution business;

| · | R$123.9 million are for our telecommunication business;

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| · | R$13.0 million for the construction of the Cutia Wind Farm Complex; and

| · | R$84.2 million are for other investments.

Our following subsidiaries also budgeted their own capital expenditures for 2019, as described as follows:

| · | Compagas: R$27.3 million;

| · | Araucária: R$1.5 million; and

| · | Elejor: R$13.9 million.

Historically, we have financed our liquidity and capital requirements primarily with cash provided by our operations and through external financing. Our principal source of funds in 2019 was our operating activities. Net cash used by financing activities was R$288.0 million in 2019, compared with R$1,286.5 million in 2018. Net cash provided by operating activities was R$2,945.0 million in 2019, compared with R$1,771.0 million in 2018. In 2020, we expect to finance our liquidity and capital requirements primarily with cash provided by our operations and through debt financing from BNDES and the Brazilian capital markets.

As in prior years, we plan to make significant investments in future periods to expand and upgrade our generation, transmission and distribution businesses. In addition, we may seek to invest in other existing electric utilities, in communications services or in other areas, each of which may require additional domestic and international financing. Our ability to generate cash sufficient to meet our planned expenditures is dependent upon a variety of factors, including our ability to maintain adequate tariff levels, to obtain the required regulatory and environmental authorizations, to access domestic and international capital markets, and a variety of operating and other contingencies. We anticipate that our cash provided by operations may be insufficient to meet these planned capital expenditures, and that we may require additional financing from sources such as BNDES and the Brazilian and international capital markets.

ANEEL’s regulations require prior approval from ANEEL for any transfer of funds from our subsidiaries to us in the form of loans or advances. ANEEL approval is not required for cash dividends, as long as cash dividends do not exceed a dividend threshold (“Dividend Threshold”) equal to the greater of adjusted net income or income reserves available for distribution. The Dividend Threshold is established by Brazilian Corporate Law.

The cash dividends we have received from our subsidiaries have been historically sufficient to meet our cash flow requirements without exceeding the Dividend Threshold. As a result, we have not sought approval from ANEEL to receive either loans or advances from our subsidiaries or cash dividends from our subsidiaries in excess of the Dividend Threshold. We do not expect these restrictions on loans and advances and on cash dividends exceeding the Dividend Threshold to impact our ability to meet our cash obligations, since we expect cash dividends below the Dividend Threshold to be sufficient in the future.

Like other state-owned companies, we are subject to certain CMN restrictions on our ability to obtain financing from domestic and international financial institutions. CMN restrictions could limit our ability to obtain bank financing but do not affect our ability to access the Brazilian and international capital markets, and do not restrict our access to banking financing for the purpose of repaying or refinancing debt.

Our total outstanding loans and financing (including debentures) as of December 31, 2019 totaled R$11,572 million. Approximately R$109 million of the total debt outstanding as of December 31, 2019 was denominated in U.S. dollars. For more information on the terms of these loans and financings, including reference to their specific maturity dates and interest rate structure, see Notes 22 and 23 to our audited consolidated financial statements. We are not subject to seasonality with respect to our borrowing requirements. Our major loans and financing arrangements are:

Banco do Brasil:

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| · | We have R$789 million of outstanding debt with Banco do Brasil (not including the debentures listed below), consisting of financings we contracted to increase our working capital.

Debentures:

| · | In May 2015, Copel GeT issued R$1,000.0 million in simple, in five-year non-convertible debentures, with an interest rate of 113% of the CDI index per year and payment of interest on an annual basis. As of December 31, 2019, we had an aggregate balance of R$347 million of outstanding debt under these debentures;

| · | In October 2015, Copel Telecom issued R$160.0 million in simple, in nine-year non-convertible debentures. These debentures have an interest rate equal to IPCA index + 7.9633% per year, a five-year maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate balance of R$195.4 million of outstanding debt under these debentures;

| · | In March 2016, Nova Asa Branca I, Nova Asa Branca II, Nova Asa Branca III, Nova Eurus IV and Ventos de Santo Uriel Wind Farms issued R$300.8 million in non-convertible debentures, with sixteen-year maturity and payment of interest on monthly basis. The interest rate of TJLP index + 2.02% per year is applicable to R$147.6 million and IPCA index + 9.87% per year is applicable to R$153.2 million. As of December 31, 2019, we had an aggregate balance of R$254.8 million of outstanding debt under these debentures. As of December 31, 2019, all the conditions agreed had been fulfilled. For more information, see Note 23.3 to our audited consolidated financial statements;

| · | In April 2016, Compagas privately issued R$33.6 million in simple non-convertible debentures, single series, with floating charge, with an interest rate equal to TJLP index + 2.17% per year, with a five-year maturity and payment of interest on a quartely basis. As of December 31, 2019, we had an aggregate balance of R$11.8 million of outstanding debt under these debentures;

| · | In July 2017, Copel Telecom issued R$220.0 million in five-year simple, non-convertible debentures. These debentures have an interest rate equal to IPCA index + 5.4329% per year, a five-year maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$246.3 million under these debentures;

| · | In October 2017, Copel Distribuição issued R$500.0 million in simple, non-convertible debentures, with an interest rate of 126% of the CDI index per year, with a five years maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$505.8 million under these debentures;

| · | In October 2017, Copel GeT issued R$1.0 billion in simple non-convertible debentures, with an interest rate of 126% of the CDI index per year, with a five years maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$1,011.7 million under these debentures;

| · | In January 2018, Copel Holding issued R$600.0 million in simple, non-convertible debentures, with an interest rate of 119% of the CDI index per year, with a three-year maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$617.4 million under these debentures;

| · | In July 2018, Copel GeT issued R$1.0 billion in simple, non-convertible debentures, with an interest rate of 126% of the CDI index per year, with a five-year maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$1,030.1 million under these debentures;

| · | In September 2018, Copel GeT issued R$290.0 million in simple, non-convertible debentures. These debentures have an interest rate equal to IPCA index + 7.6475% per year, with a seven-year maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$308.5 million under these debentures;

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| · | In September 2018, Copel Distribuição issued R$1.0 billion in simple, non-convertible debentures with an interest rate of CDI index + 2.70% per year, with a five-year maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$1,019.6 million under these debentures;

| · | In March 2019, Cutia Empreendimentos issued R$360.0 million in simple, non-convertible debentures. These debentures have an interest rate equal to IPCA index + 5.8813% per year, with a thirteen-year maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$352.9 million under these debentures;

| · | In May 2019, Copel Telecom issued R$210 million in simple, non-convertible debentures, with an interest rate of 117% of the CDI index per year, with a five-year maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$211,3 million under these debentures;

| · | In June 2019, Copel Holding issued R$500 million in simple, non-convertible debentures, with an interest rate of 106% of the CDI index per year, with a three-year maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$501 million under these debentures;

| · | In July 2019, Copel GeT issued R$1 billion in simple, non-convertible debentures, in two series, with an interest rate of 109% of the CDI index per year and IPCA index + 3.90% with a five-years and six-years maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$1.024,1 million under these debentures;

| · | In November 2019, Copel Distribuição issued R$850 million in simple, non-convertible debentures, in two series, with an interest rate of IPCA index + 4.20% per year and CDI index + 1,45% per year with an eight-years and three-years maturity and payment of interest on a semester basis. As of December 31, 2019, we had an aggregate outstanding balance of R$858,1 million under these debentures; and

| · | In December 2019, Compagas privately issued R$43 million in simple non-convertible debentures, single series, with an interest rate equal to CDI index + 0.88% per year, with a two-year maturity and payment of interest on a monthly basis. As of December 31, 2019, we had an aggregate balance of R$44,7 million of outstanding debt under these debentures.

BNDES

| · | In December 2013, we received approval for the BNDES financing of HPP Colíder in an aggregate amount of R$1,041.2 million. As of December 31, 2013, we had received R$840.1 million of this amount, with the remaining disbursements to be made in accordance with the construction schedule of HPP Colíder. Additionally, BNDES approved the finance of the Cerquilho III transmission substation in the amount of R$17.6 million, which was disbursed in a single installment. As of December 31, 2019, the aggregate outstanding balance of these two contracts totaled R$828.7 million;

| · | BNDES has provided a loan to Copel of R$339.0 million to finance the construction of the Mauá Hydroelectric Plant. Mauá is owned by Consórcio Energético Cruzeiro do Sul, in which Copel has a 51.0% interest and Eletrosul has a 49.0% interest. BNDES is providing 50.0% of the loan amount, and Banco do Brasil S.A. is providing the remaining 50.0%. All the receivables arising from this plant were pledged in favor of BNDES and Banco do Brasil until full repayment of the loan. As of December 31, 2019, we had an aggregate of R$191.6 million in outstanding debt with BNDES and Banco do Brasil under this facility;

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| · | In December 2011, we entered into a financing contract with BNDES in the total value of R$44.7 million for the construction of Transmission Line Foz do Iguacu - Cascavel Oeste, with maturity in 14 years. As of December 31, 2019, we had an aggregate of R$21.1 million in outstanding debt under this financing contract;

| · | In March 2012, we entered into a financing contract with BNDES in the total value of R$282.1 million for the construction of GE Farol, Ge Boa Vista, GE São Bento do Norte and GE Olho D’Água Wind Farms with maturity in 16 years. As of December 31, 2019, we had an aggregate of R$215.5 million in outstanding debt under this financing contract;

| · | In September 2012, we entered into a financing contract with BNDES in the total value of R$73.1 million for the construction of SHP Cavernoso II, with maturity in 16 years. As of December 31, 2019, we had an aggregate balance of R$46.2 million of outstanding debt under this financing contract;

| · | In December 2014, we entered into a financing contract with BNDES to finance the improvement of the distribution system of the greater Curitiba area, with maturity in 9.4 years. We have obtained a R$139.1 million funding on December 2014 and as of December 31, 2019, we had an aggregate outstanding balance of R$51.2 million under this financing contract;

| · | In June 2015, we entered into a financing contract with BNDES in the total value of R$124.0 million for the construction Santa Helena and Santa Maria Wind Farm, with maturity in 16 years. As of December 31, 2019, we had an aggregate balance of R$95.1 million of outstanding debt under this financing contract;

| · | In December 2015, we entered into a financing contract with BNDES in the total value of R$55.8 million for the construction of Transmission Line Assis - Paraguaçu Paulista II and Londrina - Figueira e Salto Osório - Foz do Chopim C2, with maturity in 15 years. As of December 31, 2019, we had an aggregate balance of R$35.9 million of outstanding debt under this financing contract;

| · | In October 2018, we entered into a financing contract with BNDES in the total value of R$194.0 million for the implementing Baixo Iguaçu Hydroelectric Power Plant as well as its associated transmission system, with maturity in 17 years. As of December 31, 2019, we had an aggregate balance of R$196.8 million of outstanding debt under this financing contract;

| · | In October 2018, we entered into a financing contract with BNDES in the total value of R$619.4 million for the construction and implementing Cutia Empreendimentos Eólicos Wind Farms, with maturity in 17 years. As of December 31, 2019, we had an aggregate balance of R$611.5 million of outstanding debt under this financing contract.

| · | In August 2018, Copel GeT signed a share exchange agreement with Eletrosul in the controlled ventures Costa Oeste Transmissora de Energia S.A. (51% Copel GeT and 49% Eletrosul), Marumbi Transmissora de Energia S.A. (80% Copel GeT and 20% Eletrosul) and Transmissora Sul Brasileira de Energia S.A. (20% Copel GeT and 80% Eletrosul). With this contract, Copel GeT starts to hold 100% interest in the Costa Oeste and Marumbi undertakings and Eletrosul now holds 100% stake in Transmissora Sul Brasileira.

| · | Marumbi has an agreement signed with BNDES in 2014, in the amount of R$55 million, for the Implementation of the 525 kV Transmission Line between SE Curitiba and SE Curitiba Leste and the implementation of SE Curitiba. It has a balance on December 31, 2019 of R$34.4 million.

| · | Costa Oeste, has an agreement signed with BNDES in 2013, in the amount of R$36.7 million, for the implementation of the 230 kV Transmission Line between SE Cascavel Oeste and SE Umuarama Sul and the implementation of the SE. It has a balance on December 31, 2019 of R $22.2 million

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CAIXA ECONÔMICA FEDERAL (CEF)

| · | We have R$13.4 million in outstanding debt related to government programs to finance distribution projects; and

| · | Copel Distribuição entered into an agreement in 2016, in the amount of R$1.2 million, for the purchase of machinery and/or equipment and also computer and automation goods. It has a balance on December 31, 2019 of R$0.3 million.

ELETROBRAS

| · | We have R$10.9 million in outstanding debt with Eletrobras under government programs to finance distribution projects;

FINEP

In July 2012, a loan agreement in the amount of R$52.2 million was signed by Copel Telecomunicações S.A. with FINEP to partially finance the BEL – Extra Broadband project. As of December 31, 2019, we had an aggregate outstanding balance of R$4.8 million under this loan agreement.

We are party to several legal proceedings that could have a material adverse impact on our liquidity if the rulings are unfavorable to us. These contingencies are described in “Item 8. Financial Information—Legal Proceedings”.

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CONTRACTUAL OBLIGATIONS

In the table below, we set forth certain of our contractual obligations as of December 31, 2019, and the period in which such contractual obligations come due.

| Payments due by period
| Total | Less than1 year | 1-3 years | 3-5 years | More than 5 years
| (R$million)
Contractual obligations: |  |  |  |  |
Loans and financing(1) | 4,185.8 | 455.9 | 1,343.8 | 719.6 | 1,666.5
Debentures(2) | 10,413.5 | 1,501.9 | 4,967.7 | 2,288.6 | 1,655.3
Suppliers(3) | 1,873.2 | 1,732.6 | 128.0 | 12.6 | -
Purchase obligations(4) | 130,075.9 | 4,390.5 | 10,101.5 | 11,411.1 | 104,172.8
Concession payments(5) | 1,799.9 | 74.5 | 161.9 | 174.2 | 1,389.3
Eletrobras ‒ Itaipu(6) | 6,723.5 | 1,667.0 | 3,475.4 | 1,581.1 | -
Installment due to the Federal Revenue of Brazil(7) | 623.8 | 68.4 | 105.4 | 114.3 | 335.7
Post-employment benefits(8) | 10,322.2 | 670.5 | 1,301.0 | 1,231.3 | 7,119.4
Sectoral Financial liabilities(9) | 108.4 | - | 108.4 | - | -
Lease liability(10) | 126,999.2 | 42,258.2 | 57,399.4 | 16,115.9 | 11,225.7
Total | 293,125.4 | 52,819.5 | 79,092.5 | 33,648.7 | 127,564.7

(1) | Includes interest as agreed under agreements in the amount of R$1, 016.1. For more details, see Note 21 to our audited consolidated financial statements.

(2) | Includes interest as agreed under relevant agreements in the amount of R$1, 647.0. For more details, see Note 22 to our audited consolidated financial statements.

(3) | Mainly consists of Electricity purchased from auctions on the CCEAR with balances falling due in less than 30 days and gas supplied by Petrobras to the Araucária Thermoelectric Plant.

(4) | Consists of binding power purchase commitments. Includes monetary restatements as agreed under relevant agreements.

(5) | Payments to the federal government arising from Elejor, Mauá, Colíder, Rio Jordão and Baixo Iguaçu facilities concession agreement. Includes interest and applicable monetary restatements.

(6) | Includes expected exchange variation.

(7) | Income Tax and Social Contribution due by Copel Geração e Transmissão in 2014 and joining the Special Tax Regularization Program (Programa Especial de Regularização Tributária – Pert) in August 2017 by Copel Distribuição. Includes interest and applicable monetary restatement.

(8) | For more details, see Note 23 to our audited consolidated financial statements.

(9) | For more details, see Note 9 to our audited consolidated financial statements.

(10) | For more details, see Note 27 to our audited consolidated financial statements.

We are also subject to risks with respect to tax, labor and civil claims and have provisioned R$1,606.7 million for accrued liabilities under legal proceedings related to these claims as of December 31, 2019. For more information, see “Item 8. Financial Information—Legal Proceedings” and Notes 15 and 29] to our audited consolidated financial statements.

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OFF-BALANCE SHEET ARRANGEMENTS

We have not engaged in any off-balance sheet arrangements that have, or are reasonably likely to have a current or future effect on the registrant’s financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to investors.

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Item 6. Directors, Senior Management and Employees

We are managed by:

| · | a Board of Directors, which may be composed of up to nine (9) members and is currently composed of nine (9) members; and

| · | a Board of Executive Officers, which is currently composed of seven (7) members.

BOARD OF DIRECTORS

The Board of Directors ordinarily meets monthly. A majority of the members of the Board of Directors is required for the meeting to be held, and decisions are taken by a majority vote of those present at the meeting. For additional information, see “Item 10. Additional Information—Memorandum and Articles of Association”. The members of the Board of Directors are elected to serve for two-year terms and may be reelected. Among the current nine members of the Board of Directors:

| · | six were elected by the controlling shareholders;

| · | one was elected by minority shareholders (holding voting shares);

| · | one was elected by minority shareholders (holding outstanding non-voting shares); and

| · | one was elected by our employees.

According to Brazilian Corporate Law, minority shareholders are entitled to appoint and remove at least one member of the Board of Directors, in a separate election, without the participation of the controlling shareholder, if such minority shareholders hold (i) at least 15% of the company’s voting shares or (ii) at least 10% of the company’s outstanding non-voting shares.

Also according to Brazilian Coroporate law, members of our Board of Directors who are elected by the non-controlling shareholders have the right to veto (provided it is duly justified) the appointment of the independent accountant made by the majority of the members of our Board of Directors.

The terms of the current members of the Board of Directors expire in April 2021. The current members of our Board of Directors are:

Name | Position | Since
Marcel Martins Malczewski | Chairman | 2019
Leila Abraham Loria | Director | 2017
Olga Stankevicius Colpo | Director | 2017
Carlos Biedermann | Director | 2019
Adriana Angela Antoniolli | Director | 2017
Marco Antônio Barbosa Cândido | Director | 2018
Gustavo Bonini Guedes | Director | 2019
Luiz Claudio Maia Vieira | Director | 2019
Daniel Pimentel Slaviero | Director | 2019

The following are brief biographies of the current members of our Board of Directors:

Marcel Martins Malczewski. Mr. Malczewski was born on December 8, 1964. He holds a Master's degree in Industrial Sciences and Computing from Universidade Tecnológica Federal do Paraná (2001); and a Bachelor's degree in Electrical Engineering from Universidade Federal do Paraná (1992). Mr. Malczewski also attended the Owner/President Management Program at Harvard Business School (2004). He is currently Chairman of the Board of Directors of Companhia Paranaense de Energia - Copel. Additionally, Mr.

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Malczewski is a partner at M3 Investimentos Ltda. and at Trivella M3 Investimentos S.A. Previously, he was co-founder (1990), CEO (2001-2009), Chairman (2010-2011) and member of the Board of Directors (2012-2015) at Bematech S.A. He was also a Professor (1989-1994) and coordinator (1991-1994) of the Computer Engineering undergraduate course at Pontifícia Universidade Católica do Paraná.

Leila Abraham Loria. Ms. Loria was born on January 26, 1954. Ms. Loria took an advanced Governance, Risk and Compliance training course at Risk University - KPMG (2018) and a Corporate Governance and Innovation course at Nova School of Business and Economics, in Lisbon, Portugal (2016). She holds a Post-MBA in Corporate Governance and Capital Markets for executives from B.I. International (2015) and an International Executive MBA from APG-Amana (1994). Ms. Loria also has a Taught Master’s Degree in Business Administration from COPPEAD-UFRJ Business School (1978) and a Bachelor’s Degree in Business Administration from Fundação Getúlio Vargas (1976). Ms. Loria is currently a member of the Board of Directors and of the Statutory Audit Committee of Companhia Paranaense de Energia - Copel. Additionally, she sits on the Board of the Brazilian Institute of Corporate Governance - IBGC, and of the Board of Directors of Madeira Energia - MESA. She is also a member of the Advisory Board on Casas Pernambucanas, INPLAC Indústria de Plástico and Costão do Santinho Resort. Previously, she was an Executive Officer at Telefonica Brasil and Member of the Board of Directors of Telefonica Vivo (2010-2015); Chairman and General Officer at TVA (Abril Group) and Member of the Board of Directors at Tevecap (1997-2006) and Canbras, a joint venture between Abril and Bell Canada (1998-2002); General Officer and Member of the Board of Directors at Direct TV (1997-1999); Chief Business Officer at Walmart (1994-1997); and Chief Officer for Marketing, Sales, Business, Acquisitions and Human Resources at Mesbla (1978-1994).

Olga Stankevicius Colpo. Ms. Colpo was born on May 26, 1952. Ms. Colpo received a post-graduate degree from the Executive Program of Singularity University (2018) and, an international executive MBA degree from FIA/USP (2000); she took a specialization course in International Business at Harvard University (1996), a specialization course in Managing Managers at Michigan University (1986); a Continued Education Program in Human Resources Management from Fundação Getúlio Vargas (1984); Ms. Colpo has a Bachelor’s degree in Psychology from Universidade de Mogi das Cruzes - UMC (1975). Ms. Colpo is currently a member of the Board of Directors and of the Statutory Audit Committee of Companhia Paranaense de Energia - Copel. She is also a member of the Board of Directors of Solvi S.A., member of the Board of Directors, Audit Committee and People Committee at Banco BMG S.A.; member of the Consulting Board of the International Executive MBA at FIA; counselor and member of the Executive Board at Childhood Brasil; Visiting Professor at the International Executive MBA program at FIA/USP; and instructor of the Board of Directors Training Course at IBGC. Previously, she was Chief Executive Officer at Participações Morro Vermelho S.A. (2009-2016); a partner at PwC - PricewaterhouseCoopers (1999-2009); and partner at Coopers & Lybrand (1974-1999).

Adriana Angela Antoniolli. Ms. Antoniolli was born on November 19, 1966. Ms. Antoniolli received a post-graduate degree in Applied Law from Escola da Magistratura do Paraná (2011) and a post-graduate degree in Marketing and Advertising from Instituto Superior de Pós-graduação - ISPG (2000). Ms. Antoniolli holds a degree in Law from Universidade Tuiuti do Paraná (2008) and a degree in Accounting from Faculdade de Educação, Ciências e Letras de Cascavel (1988). She is currently a Regulatory Analyst at Copel. Previously, she acted as Services Department Manager at Copel (2013-2015); East Revenue Department Manager at Copel (2009-2013); and Business Procedures Department Manager at Copel (2008). Ms. Antoniolli was appointed as a member of our Board of Directors as a representative of our employees.

Marco Antônio Barbosa Cândido. Mr. Cândido was born on March 6, 1969. Mr. Cândido holds a Ph.D. degree in Production Engineering from Universidade Federal de Santa Catarina - UFSC (1997), a Master’s degree in Production Engineering from Universidade Federal de Santa Catarina - UFSC (1994) and a degree in Aeronautical Mechanics Engineering from Instituto Tecnológico de Aeronáutica - ITA (1991). Mr. Cândido is currently a member of the Board of Directors and of the Statutory Audit Committee of Companhia Paranaense de Energia - Copel , Chief Executive Officer and Founding Partner at MBC Consultoria, member of the Board of Directors of Hospital Santa Rita and Santa Rita Saúde health care provider in the city of Maringá – PR, and member of the Board of Directors at the hotel group Rafain, in the city of Foz do Iguaçu - PR. Previously, he was a professor and researcher at Pontifícia Universidade Católica do Paraná - PUCPR (1995-2013); Chief Executive Officer at Associação Paranaense de Cultura - APC, a parent company of Pontifícia Universidade Católica do Paraná - PUCPR (2005-2012); Chief Executive Officer at Grupo Marista (2012-2013); Chief Executive Officer at Grupo Paysage (2013-2015); member of the Board of Directors at Sistema de

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Saúde Mãe de Deus, health care provider in the state of Rio Grande do Sul (2014-2015); and member of the Board of Directors at Grupo Positivo (2014-2016).

Carlos Biedermann. Mr. Biedermann was born on August 18, 1953. Mr. Biedermann attended the Executive Program of the Singularity University (2019) and the International Business Programme at INSEAD in France (1995). He holds a post-graduate degree in Financial Markets from Fundação Getúlio Vargas - FGV (1979) and Bachelors’ degrees in Accounting, from Unisinos (1977), and in Business Management and Public Management, from Universidade Federal do Rio Grande do Sul (1975). He is currently a member of the Board of Directors and of the Statutory Audit Committee of Companhia Paranaense de Energia - Copel. Mr. Biedermann has considerable experience as a board member in several sectors, including organizations such as Amcham/RS and the Association of Marketing and Sales Directors of Brazil - ADVB/RS. At present, he also has seats in the Board of Directors of Lojas Lebes and Maiojama Empreendimentos Imobiliários; in the Audit Committee of Suzano Papel e Celulose, Grupo Algar, Grupo Solar and Grupo Cornélio Brennand; and as Chairman of the Deliberative Council of Grêmio Foot-Ball Porto Alegrense. Additionally, he is an instructor at the Brazilian Institute of Corporate Governance - IBGC and a partner at Biedermann Consulting. Previously, he was senior partner for the southern region and senior partner of Capital and Infrastructure Projects (CP&I) for Brazil at PricewaterhouseCoopers (2002 - 2015); Chairman of the Audit Committee of IBGC (2009 - 2014), Chairman (2013 - 2014) and member (2009 - 2017) of the Board of the Young Presidents Organization - YPO, and a guest lecturer in the Post-MBA Corporate Governance Program at Unisinos (2017 - 2019).

Gustavo Bonini Guedes. Mr. Guedes was born on April 10, 1982. He holds a post-graduate degree in Election Law from Centro Universitário Curitiba (2009) and a Bachelor's degree in Law from Centro Universitário Autônomo do Brasil (2005). Mr. Guedes is currently a member of the Board of Directors of Companhia Paranaense de Energia - Copel. Additionally, he is a member of the Brazilian Academy of Election and Political Law - Abradep and a founding partner at Bonini Guedes Advocacia. Previously, he was President of the Election Law Institute of Paraná; a Professor at Escola Superior de Advocacia - ESA/PR; advisory member of the Election Law Commission of the Federal Council of the Brazilian Bar Association - OAB; and coordinator of the Election Law Department of Vernalha Guimarães e Pereira Advogados.

Luiz Claudio Maia Vieira. Mr. Vieira was born on October 7, 1969. Mr. Vieira attended an Advanced Management Program at Fundação Dom Cabral/INSEAD Fontainebleau (2013) and an Advanced Management Program at IESE Business School in Barcelona (2009). He holds an MBA in Finance from Columbia University (1998) and a Bachelor’s degree in Business Management from Fundação Getúlio Vargas - FGV (1992). Mr. Vieira is currently a member of the Board of Directors and of the Statutory Audit Committee of Companhia Paranaense de Energia - Copel. Additionally, he is a member of the Board of Directors of Grupo Aviva (Rio Quente and Costa do Sauípe Resorts) and a Partner at Partilha Empreendiemtos. Previously, he was Chief Consumer Goods Officer and Chief Financial Officer of Nutrimental Indústria e Comércio de Alimentos S.A. (2017 - 2018); Executive Director of Planning and Finance at Infoglobo Comunicação e Participações S.A. (2011 - 2014); CEO of Rede Paranaense de Comunicação - RPCTV (2001 - 2011); and Vice President of Corporate Finance at BNP Paribas Bank (1998 - 2001).

Daniel Pimentel Slaviero. Mr. Slaviero was born on November 22, 1980. Mr. Slaviero attended the Owner/President Management - OPM program (2015) and the YPO Harvard President Seminar (2010), both from Harvard Business School. Mr. Slaviero also completed the Executive Business Program (STC) from Kellog School of Management/Fundação Dom Cabral (2009); and holds a degree in Business Administration from Universidade Positivo - UP (2001). He is currently Copel’s Chief Executive Officer and Chairman of the Board of Directors of Copel Geração e Transmissão S.A., Copel Distribuição S.A., Copel Comercialização S.A., Copel Telecomunicações S.A. and Copel Renováveis S.A.. Previously he acted as the Chief Executive Officer at Sistema Brasileiro de Televisão - SBT (2017-2018); Chief Business Officer at Sistema Brasileiro de Televisão - SBT (2017-2018); Chief Institutional Officer at Grupo Silvio Santos (2010-2017); General Director at Sistema Brasileiro de Televisão - SBT Brasília (2010-2017); Chairman at the Brazilian Association of Radio and Television Broadcasters - ABERT (2006-2016); Executive Officer at Grupo Paulo Pimentel (2001-2010); and Programming and Production Manager at Grupo Paulo Pimentel (2000-2001).

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BOARD OF EXECUTIVE OFFICERS

Our Board of Executive Officers meets every two weeks and is responsible for the daily management of the Company. Each Executive Officer also has individual responsibilities established by the Board’s rules of procedure.

According to our bylaws, our Board of Executive Officers consists of seven (7) members. The Executive Officers are elected by the Board of Directors for two-year terms but may be removed by the Board of Directors at any time. The terms of the current members of the Board of Executive Officers expire in December 2021. The current members are as follows:

Name | Position | Since
Daniel Pimentel Slaviero | Chief Executive Officer | 2019
Ana Letícia Feller | Chief Business Management Officer | 2018
Adriano Rudek de Moura | Chief Financial and Investor Relations Officer | 2017
Cassio Santana da Silva | Chief Business Development Officer | 2019
Eduardo Vieira de Souza Barbosa | Chief Legal and Institutional Relations Officer | 2019
Vicente Loiácono Neto | Chief Governance, Risk and Compliance Officer | 2018
David Campos | Chief Assistant Officer. | 2019

The following are brief biographies of the current members of our Board of Executive Officers:

Daniel Pimentel Slaviero. Mr. Slaviero has been our Chief Executive Officer since January 8, 2019. For biographical information regarding Mr. Slaviero, see “Board of Directors”.

Ana Letícia Feller. Ms. Feller was born on October 15, 1977. She received an MBA degree in Leadership with emphasis in Management, from Estação Business School (2015); a Post-graduate degree in Management with emphasis in Strategic People Management, from FAE Centro Universitário (2009); and a Post-graduate degree in Labor Law, from Unibrasil (2005). She holds a Bachelor’s degree in Law from Pontifícia Universidade Católica do Paraná (2000). Ms. Feller has been a Lawyer at Companhia Paranaense de Energia - Copel since 2000, where she also served as Assistant to the Chief Corporate Management Officer (2017-2018); Chair of the Permanent Compensation Committee (2017-2018); Chair of the Management Committee (2017-2018); Human Resources Chief Official (2007-2010 e 2013-2017); and member of the Ethical Guidance Council (2006-2008 and 2010-2012). Additionally, she was an alternate member of the Deliberative Council of Fundação Copel de Previdência e Assistência Social (2014-2018). She is currently Copel’s Chief Corporate Management Officer, as well as a member of the Board of Directors of Copel Distribuição S.A., Copel Comercialização S.A., Copel Telecomunicações S.A. and Copel Renováveis S.A.

Adriano Rudek de Moura. Mr. Moura was born on September 25, 1962. Mr. Moura took a professional development course at Fundação Dom Cabral (2019), at Instituto Brasileiro de Governança Corporativa - IBGC (2018), at Duke’s Fuqua School of Business (2010) and at Harvard Business School (2007). He received a post-graduate degree in Finance and Controllership from Fundação Instituto de Pesquisas Contábeis, Atuariais e Financeiras - FIPECAFI/USP (1997). Mr. Moura holds a degree in Accounting from Centro Universitário Ítalo Brasileiro – Unítalo (1985). Mr. Moura is currently Copel’s Chief Financial and Investor Relations Officer. He is also Chief Financial and Investor Relations Officer of Copel Geração e Transmissão S.A.; Chief Financial Officer of Copel Distribuição S.A.; Chief Financial Officer of Copel Comercialização S.A.; and Chief Financial Officer of Copel Renováveis S.A.. Previously, he was Vice-president and Chief Management, Financial and Investor Relations Officer at Elecrolux for Latin America (2003-2017); Chief Management, Financial and Investor Relations Officer at Electrolux do Brasil (1999-2003); Controller at Electrolux do Brasil (1997-1999); Vice-president at Associação Nacional de Fabricantes de Produtos Eletroeletrônicos (National Association of Home Appliance Manufacturers)(2013-2015); member of the Board of Directors at CTI (2011-2017); at Eletros (2013-2015); member of the Supervisory Board at Gafisa (2009-2014); member of the Supervisory Board at Tenda (2009-2014); at Alphaville (2012-2013); graduate school Professor at Fundação Armando Alvares

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Penteado - FAAP (1999); Professor at Faculdade de Administração de Empresas e Economia do Paraná – FAE (1995); and auditor and consultant at Arthur Andersen (1982-1997).

Cassio Santana da Silva. Mr. da Silva was born on August 14, 1978. He holds a Bachelor’s degree in Business Administration from Universidade Federal do Paraná - UFPR (2002); and an Executive MBA from Fundação Getúlio Vargas - Rio de Janeiro (2003). He is currently Copel’s Chief Business Development Officer. Previously, he held leading positions in many multinational companies, such as Business Unit Manager at Telefônica Brasil S.A. (2014-2019); Senior Brand and Trade Manager at Kimberly Clark (2011-2013); Marketing and Trade Marketing Manager at Danone Northeastern Business Unit (2009-2011); National Trade Marketing Manager at Danone (2008-2009); Trade Marketing Manager at Philip Morris (2007-2008); Regional Sales Manager at Ambev in the Dominican Republic (2006-2007); Trade Marketing Manager (2005-2006) and Sales Manager (2002-2005) at AmBev.

Eduardo Vieira de Souza Barbosa. Mr. Barbosa was born on October 3, 1982. Mr. Barbosa holds a post-graduate degree in Constitutional Law from Academia Brasileira de Direito Constitucional - ABDConst. Mr. Barbosa holds a Bachelor’s degree in Law from Universidade Tuiuti do Paraná - UTP. He is currently Copel’s Chief Legal and Institutional Relations Officer, as well as the Chief Legal and Institutional Relations Officer of Copel Geração e Transmissão S.A., Copel Distribuição S.A., Copel Comercialização S.A. and Copel Renováveis S.A.. Previously he acted as Chief Legal Officer of the Conselho de Jovens Empresários - CJE (Young Entrepreneurs Committee) at the State of Paraná Trade Association (2011-2016); Member of the Political Council of the State of Paraná Trade Association (2013-2016); Strategic Consultant of Companhia Paranaense de Saneamento do Paraná - Sanepar, Assistant to the Chief Legal Officer for CS Bioenergia S.A. (2015); Chief Prosecutor of the Commercial Registry of the State of Paraná (2011-2015); and Legal adviser and referee to legal and individual entities directly and indirectly connected to the Public Administration.

Vicente Loiácono Neto. Mr. Loiácono was born on June 4, 1983. He received a post-graduate degree in Civil Procedure Law from Universidade do Sul de Santa Catarina (2010). He holds a Bachelor’s degree in Law from Faculdades Integradas Curitiba (2007). He is currently attending the Master’s program on Business Law and Citizenship from Centro Universitário Curitiba (2019-2021). Mr. Loiácono is currently Copel’s Chief Governance, Risk and Compliance Officer. Mr. Loiácono has been a lawyer at the company since 2011, where he also served as Advisor to the CEO (2017-2018);; member of the Supervisory Board of Fundação Copel de Previdência e Assistência Social (2015); and member of the Ethical Guidance Council (2014). Previously, Mr. Loiácono had served as deputy coordinator of the Conselho de Jovens Empresários - CJE (Young Entrepreneurs Committee) at the State of Paraná Trade Association.

David Campos. Mr. Campos was born on November 05, 1969. Mr. Campos received a Bachelor’s degree in Social Communication - Journalism from Universidade Estadual de Ponta Grossa - UEPG (1990). He is currently Chief Assistant Officer at Companhia Paranaense de Energia - Copel. Previously he acted as Chief Communication Official at Itaipu Binacional (2017); Municipal Secretary of Social Communication at Curitiba Municipality (2011-2012); Head of the Mayor’s Office in Curitiba (2010); Chief Journalist at the State of Paraná Legislative Assembly (2001-2009); Secretary of Social Communication for the State of Paraná (1999-2000); and Municipal Secretary of Social Communication at Curitiba Municipality (1997-1998).

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SUPERVISORY BOARD

We have a permanent Supervisory Board (Conselho Fiscal), which generally meets monthly. The Supervisory Board consists of five (5) members and five (5) alternates elected for two-year terms by the shareholders at the annual meeting. The Supervisory Board, which is independent of our management and of our external auditors, has the responsibilities provided in Federal Law No. 6,404/1976 and Federal Law No. 13,303/2016, which include, among others:

| · | reviewing our financial statements and reporting on them to our shareholders;

| · | issuing reports on proposed changes in capitalization, corporate budgets and proposed dividend distributions and any corporate reorganization to be submitted to the shareholders; and

| · | in general, supervising the activities of management and reporting on them to our shareholders.

The following table lists the current and alternate members of the Supervisory Board, who were appointed at the 63rd annual shareholders’ meeting held on April 29, 2019 and at the 200th extraordinary shareholders’ meeting held on December 2, 2019. The term of all members of the Supervisory Board indicated below will expire in April 2021.

Name | Since
Demetrius Nichele Macei | 2019
Harry Françóia Júnior | 2019
José Paulo da Silva Filho | 2019
Roberto Lamb | 2017
Letícia Pedercini Issa Maia(1) | 2017
Alternates |
Emir Calluf Filho | 2019
João Luiz Giona Junior | 2018
Otamir Cesar Martins | 2018
Estevão de Almeida Accioly | 2019
Gilberto Pereira Issa(1) | 2018

(1) | Letícia Pedercini Issa Maia, member of our Supervisory Board, is the daughter of Gilberto Pereira Issa, an alternate member of our Supervisory Board.

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AUDIT COMMITTEE

Pursuant to Rule 10A-3 under the Securities Exchange Act and our bylaws, our Audit Committee is composed of five members of our Board of Directors, each of whom serves a term of two years, and may be re-elected up to three consecutive times. Pursuant to the rules of procedure of the Audit Committee, the members of this committee are appointed by, and may be replaced by, a resolution taken by our Board of Directors. The members of the Audit Committee are Mr. Marco Antônio Barbosa Cândido (chairman), Ms. Leila Abraham Loria, Ms. Olga Stankevicius Colpo, Mr. Luiz Claudio Maia Vieira and Mr. Carlos Biedermann. The Audit Committee is responsible for auditing, supervising and fiscalizing the processes related to the preparation of our financial statements, ensuring that we are in compliance with all legal requirements related to our reporting obligations, monitoring the work of the independent auditors and our staff who are responsible for internal auditing of the Company and reviewing the effectiveness of our internal control and risk management procedures and staff.

Under Brazilian Corporate Law, the function of hiring independent auditors is reserved for the board of directors of a company. As a result, our Board of Directors acts as our Audit Committee, as specified in Section 3(a)(58) of the Securities Exchange Act, for the purposes of approving, on a case-by-case basis, any engagement of our independent auditors for audit and non-audit services provided to us or our subsidiaries. Except in these respects, our Audit Committee is comparable to and performs the functions of audit committees of U.S. companies.

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APPOINTMENT AND EVALUATION COMMITTEE (“CIA”)

The CIA is a permanent statutory body of Copel which provides support to Copel’s shareholders. The CIA’s purpose is to verify the compliance of the process of appointment and evaluation of statutory body members of Copel (i.e. Board of Directors, Fiscal Council, Executive Board and relevant statutory committees), in each case in accordance with (i) the Appointment Policy; (ii) the Internal Rules of Appointment of Statutory Bodies Members; (iii) other internal rules; and (iv) applicable law. The CIA works closely with Copel (Holding) and its wholly-owned subsidiaries and its scope may be extended to controlled companies, affiliates and other companies in which Copel and its wholly-owned subsidiaries hold equity interests.

Member | Position | Date of Appointment
Marcos Leandro Pereira | President | 12.02.2019
Robson Augusto Pascoalini | Member | 12.02.2019
Claudio Nogas | Member | 04.29.2019
Ana Silvia Corso Matte | Member | 04.29.2019
Durval Jose Soledade Santos | Member | 04.29.2019

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COMPENSATION OF DIRECTORS, OFFICERS, SUPERVISORY BOARD MEMBERS AND AUDIT COMMITTEE MEMBERS

Under Brazilian Corporate law, the total compensation of the Board of Directors, Executive Board and Supervisory Board is established annually by our general shareholders meeting. Under parapraph 3 of section162 of the Brazilian Corporate Law, the compensation of the members of our Supervisory Board must be equal to, or greater than, 10% of the average compensation paid to the members of our Executive Board (excluding benefits, representation funds and profit-sharing plans, if applicable). The members of our Supervisory Board received in 2018 15% of the monthly compensation of the Chief Executive Officer. Finally, the members of our Audit Committee (who are also members of our Board of Directors) received the monthly compensation paid to the members of the Supervisory Board plus R$5,000.

For the year ended December 31, 2019, the aggregate amount of compensation paid by us to the members of our Board of Directors, Board of Executive Officers and Supervisory Board was R$12,549.0 million, of which 78.6% was for our Board of Executive Officers, 14.9% was for our Board of Directors, and 6.4% was for our Supervisory Board, as approved by our 64rd annual shareholders’ meeting held on April 29, 2019.

The following table shows additional details about the compensation paid to the members of our Board of Directors, Executive Board and Supervisory Board for the periods indicated.

| Compensation (R$’000) in the years ended December 31,
| Board of Directors | Executive Officers | Supervisory Board
Area | 2019 | 2018 | 2017 | 2019 | 2018 | 2017 | 2019 | 2018 | 2017
Number of members(1) | 8.33 | 8.58 | 8.75 | 7.00 | 7.00 | 6.00 | 5.00 | 5.00 | 5.00
Total Salary | 514.7 | 854.4 | 987.2 | 4,976.8 | 6,562.1 | 6,652.7 | 659.2 | 628.2 | 557.2
Largest Salary | 230.3 | 268.8 | 153.3 | 1,731.4 | 1,404.2 | 1,431.4 | 171.4 | 169.8 | 162.9
Smallest Salary | 158.3 | 156.0 | 134.2 | 805,6 | 867.2 | 868.4 | 158.3 | 90.2 | 162.9
Average Salary | 224.6 | 206.3 | 148.3 | 1,409.7 | 1,375.1 | 1,346.4 | 161.8 | 159.2 | 162.9
Compensation for attending committees(2) | 1,005.2 | 508.5 | 62.8 | - | - | - | - | - | -
Others(3) | 340.0 | 322.3 | 247.2 | 2,059.5 | 2,719.6 | 2,771.9 | 147.5 | 154.9 | 153.0
Total | 1,871.9 | 1,685.2 | 1,297.2 | 9,868.0 | 9,281.7 | 9,424.6 | 809.1 | 783.1 | 710.2

(1) | This figure corresponds to the average number of members per year.

(2) | Refers to Statutory Audit Committee.

(3) | Refers to Private Pension Contribution, Assistance Plan for all members and Representation Grant for Executive Officers.

We have no service contracts with our directors providing for benefits upon termination of employment. We do not have a stock option plan for our directors, officers or employees.

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EMPLOYEES

On December 31, 2019, we had 7,095 employees, compared to 7,611 employees on December 31, 2018 and 8,245 employees on December 31, 2017. Including employees at Compagas, Elejor and UEG Araucária Ltda. (companies in which we have a majority stake) we had 7,266 employees as of December 31, 2019.

The following table sets forth the number of our employees and a breakdown of employees by area of activity as of the dates indicated in each area of our operations.

| As of December 31,
Area | 2019 | 2018 | 2017
Generation and transmission | 1,620 | 1,660 | 1,734
Distribution | 4,964 | 5,364 | 5,746
Telecommunications | 412 | 478 | 649
Corporation staff and research and development | 61 | 75 | 78
Other employees | 38 | 34 | 38
Total employees of Copel wholly-owned subsidiaries | 7,095 | 7,611 | 8,245
Compagas | 148 | 159 | 163
Elejor | 7 | 7 | 7
Araucária | 16 | 17 | 17
Total | 7,266 | 7,794 | 8,432

All of our employees are covered by collective bargaining agreements that we renegotiate annually with the unions that represent the various employee groups. In 2019, we negotiated and signed labor agreements with the unions representing our employees. These new bargaining agreements became effective in October and will be in place for a one-year term. We agreed to salary increases of 2,92% in 2019 compared to 2018 salaries.

We provide a number of benefits to our employees. The most significant is our sponsorship of Fundação Copel de Previdência e Assistência Social (“Fundação Copel”), which supplements the Brazilian government retirement and health benefits available to our employees. As of December 31, 2019, approximately 99% of our employees had elected to participate in a defined contribution plan.

In accordance with federal law and our compensation policy, our employees participate in a profit-sharing plan. The Board of Directors and the shareholders must approve the amount of such compensation, which is determined in accordance with an agreement between an employee committee and us. An employee’s receipt of compensation is conditioned on the company meeting certain benchmarks described in the above-mentioned agreement, as confirmed in our published year-end financial statements. The amount of profit-sharing distributions reserved and approved for the 2019 fiscal year (including Compagas) was R$155.5 million. The amount of profit-sharing distributions accrued and approved for the 2018 fiscal year (including Compagas) was R$91.5 million. The terms of the profit-sharing agreement are currently being revised and negotiated for future years. On November 1, 2019, we launched a new retirement incentive program (“PDI”), which was divided into two phases: (i) from November 1 to November 15, 2019, only employees who met the following requirements were entitled to took advantage of the PDI: (a) having worked at Copel for 25 years or more and (b) being 55 years old or older; and (ii) from November 16 to November 30, 2019, any employee could apply to the program. All employees who joined the program were to leave the company prior to December 15, 2019.

Thus, by December 15, 2019, three hundred and ninety-seven (397) employees took advantage of the program, totaling R$43.5 million in benefits paid and expenses related to this program.

On February 12, 2020 the Board of Directors approved the implementation, within Copel and its wholly-owned subsidiaries, of a short-term incentive program called Performance Incentive Program (Prêmio Por Desempenho “PPD”) directed at aligning efforts throughout different organizational levels to the company's strategic objectives.

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The program prizes technical consistency and takes the best market practices into account. It was developed with the support of Fundação Instituto de Administração - FIA, a consultancy that specializes in people management modernization projects for the private sector as well as state-owned companies.

As a result, Copel improves its target-based management strategy and enhances its merit-based culture, thus aligning with the achievement of its strategic plan. Upholding the company's values, the implementation of the program reflects the commitment of Copel's management to the improvement of the group's operational efficiency, and to the highest corporate governance standards, strengthening the pillars that support the business' sustainable growth and longevity.

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SHARE OWNERSHIP

As of March 31, 2020, board members and executive officers held, collectively, directly or indirectly, less than 0,01% of any class of our shares.

The following table indicates the board members, executive officers and members of the Supervisory Board who held shares as of March 31, 2020, and their respective share ownership as of such date. No other board member, executive officer, members or alternate members of the Supervisory Board held shares issued by the Company on March 31, 2020.

| Number of shares
Common | Class A | Class B
Board of Directors
Marcel Martins Malczewski |  |  |
Leila Abraham Loria | - | - | -
Olga Stankevicius Colpo | - | - | -
Adriana Angela Antoniolli |  |  |
Executive Officers
Daniel Pimentel Slaviero | - | - | -
Ana Letícia Feller | - | - | -
Adriano Rudek de Moura | - | - | -
Cassio Santana da Silva | - | - | -
Eduardo Vieira de Souza Barbosa | - | - | -
Vicente Loiácono Neto | - | - | -
Supervisory Board – Members
Demetrius Nichele Macei | - |  | -
Harry Françóia Júnior | - | - | -
José Paulo da Silva Filho | - | - | -
Roberto Lamb | - | - | -
Letícia Pedercini Issa Maia | 2 | - | 2
Supervisory Board – Alternates
Emir Calluf Filho |  |  |
João Luiz Giona Junior | - | - | -
Otamir Cesar Martins | - | - | -
Estevão de Almeida Accioly | - | - | -
Gilberto Pereira Issa | - | - | -

We have no share-based incentive plan for employees.

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Item 7. Major Shareholders and Related Party Transactions.

MAJOR SHAREHOLDERS

Since 1954, the State of Paraná has owned the majority of our Common Shares and has exercised control over us. On December 31, 2019, the State of Paraná directly owned 58.63% of the Common Shares. The State of Paraná does not have any different voting rights, but as long as it holds a majority of our Common Shares, it will have the right to elect a majority of our directors.

On December 31, 2019, BNDESPAR owned directly 26.41% of our Common Shares. The shareholders’ agreement entered into by and between the State of Paraná and BNDESPAR on December 22, 1998, and amended on March 29, 2001, was terminated on December 21, 2018.

The following table sets forth certain information regarding the ownership of our Common Shares on December 31, 2019:

Shareholder | Common shares
| (thousands) | (% of total)
State of Paraná | 85,029 | 58.6
BNDESPAR | 38,299 | 26.4
Eletrobras | 1,531 | 1.1
Public Float – ADRs | 109 | 0.1
Public Float – B3 (Brasil, Bolsa, Balcão) | 19,728 | 13.6
Other | 335 | 0.2
All directors and officers as a group(1) | - | -
Total | 145,031 | 100.0

(1) | On December 31, 2019, our directors and officers held an aggregate of 2 Common Shares.

The following table sets forth certain information regarding the ownership of our Class B Shares on December 31, 2019:

Shareholder | Class B Shares
| (thousand) | (% of total)
State of Paraná | – | –
BNDESPAR | 27,282 | 21.3
Eletrobras | – | –
Traded as ADSs | 27,181 ] | 21.2
Traded in the B3 (Brasil, Bolsa, Balcão) | 73,613 | 57.4
Other | 221 | 0.1
All directors and officers as a group | – | –
Total | 128,297 | 100.0

As of March 31, 2020, 1.19% of the Common Shares and 39.79% of the Class B Shares were held by 239 holders that reside in the United States and have registered with the B3 (Brasil, Bolsa, Balcão) market. At the same date, the ADSs represented 0.07% of the Common Shares and 18.18% of the Class B Shares, and together, approximately 8.56% of our total share capital. Until December 31,2019, there were conversions of 1,485 Class A Shares into Class B shares. For the last three fiscal years, we had no changes in the amount of our issued corporate capital, in the number of our shares or in the voting rights of our shares.

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Related Party Transactions

We engage in transactions, including the sale of electric energy, with our principal shareholders and with our affiliates. The tariffs we charge on electric energy sold to our related parties are approved by ANEEL, and the amounts are not material. We also provide guarantees in the context of financing transactions and power purchase agreements entered into by our subsidiaries in the ordinary course of business. For more information, see Note 36 to our audited consolidated financial statements.

Transactions with Shareholders

The following summarizes the most significant transactions with our principal shareholders:

Government of the State of Paraná

The Company's management and the Paraná State Government formalized on October 31, 2017 the fifth amendment to the agreement for renegotiation of the Account for Compensation of Income and Losses - CRC. The State of Paraná complied with the agreed terms and made the payments of the monthly interest until December 2017. With the end of the grace period, the State of Paraná has complied with the payments under the agreed terms, with 64 monthly installments remaining to be paid. The contract balance is updated by the IGP-DI variation and interest of 6.65% p.a.

BNDES and BNDESPAR

BNDESPAR, a wholly-owned subsidiary of BNDES, owns 26.4% of our Common Shares. BNDES has granted us loans to finance the construction of generation and transmission facilities and both BNDES and BNDESPAR have purchased debentures issued by Compagás and all debentures issued by Nova Asa Branca I, Nova Asa Branca II, Nova Asa Branca III, Nova Eurus IV and Ventos de Santo Uriel Wind Farms, which are our subsidiaries.

As of December 31, 2019, we had an aggregate of R$2,521 million in outstanding debt with BNDES and BNDESPAR under these financing transactions. For additional information, please see Notes 21 and 22 to our audited consolidated financial statements, as well as “Item 5. Operating and Financial Review and Prospects—Liquidity and Capital Resources.”

Fundação Copel

Fundação Copel is a closed pension fund sponsored by Copel, Compagas and other entities that runs and operates benefit plans, welfare and social assistance. In 2019, Copel made payments to Fundação Copel consisting of: (i) rental in the amount of R$2.5 million and (ii) R$238.3 million for expenditure on pension and welfare plans. For more information, see Notes 32 and 36 to our audited consolidated financial statements.

Transactions with Affiliates

Dona Francisca Energética S.A.

We own 23.0% of the total issued and outstanding share capital of Dona Francisca Energética S.A. - DFESA.

Until March 2015, we had a power purchase agreement with DFESA, valued at R$81.3 million annually, under which Copel Geração e Transmissão purchased 100% of DFESA’s assured energy. In April 2015, we signed a new ten-year power purchase agreement with DFESA, valued at R$17.0 million annually, under which Copel Geração e Transmissão purchases 23.03% of DFESA’s assured energy (proportional to Copel’s equity interest).

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As of December 31, 2019, we had accounts payable to DFESA in the amount of R$1.4 million under the above-mentioned agreements. For more information, see Note 36 to our audited consolidated financial statements.

Foz do Chopim Energética Ltda.

We own 35.8% of Foz do Chopim Energética Ltda., which operates a hydroelectric generation project. In 2018, we acquired from Foz do Chopim plant projects for which we recorded a liability of R$19.5 million. In 2019, this acquisition was settled through a matching of accounts with the dividend’s receivable from that supplier, which is part of the Company's consolidated investments as associate. For more information, see Note 39 to our audited consolidated financial statements.

We also had balances receivable from jointly controlled projects, mainly in the case of dividends. For additional information, please see Note 36 to our audited consolidated financial statements.

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Item 8. Financial Information

See pages F-1 through F-138.

A. Consolidated Financial Information

See “Item 3. Key Information—Selected Financial Data”, “Item 5. Operating and Financial Review and Prospects—Overview” and “Item 18. Financial Statements.”

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Legal Proceedings

We are currently subject to numerous proceedings relating to civil, administrative, labor and tax claims. Our audited consolidated financial statements only include provisions when the Company has a present obligation (legal or constructive) resulting from a past event; it is probable (i.e, more likely than not) that an outflow of resources embodying economic benefits will be required to settle the obligation; and a reliable estimate can be made of the amount necessary to settle the obligation. As of December 31, 2019, our provisions for such risks were R$1,606.7 million. However, it is possible that some amounts actually paid are different from the estimates made in recognizing these provisions because of determinations of final judgments and/or liquidations of the award.

As of December 31, 2019, we estimate that the total amount of claims against us, excluding disputes involving non-monetary claims or claims whose potential losses cannot be reasonably estimated due to the current early stages of proceedings, for which no provisions have been made, was approximately R$3,485.1 million, of which R$419.9 million correspond to labor claims; R$21.3 million to employee benefits; R$1,141.4 million to regulatory claims; R$1,273.9 million to civil claims; and R$628.6 million to tax claims. For more information, see Note 29 to our audited consolidated financial statements.

Tax and Social Contribution Claims

During the second half of 2010, two lawsuits were decided before the Federal Regional Court (Tribunal Regional Federal) in favor of the federal government, reversing the prior judgment that recognized our immunity regarding the payment of COFINS tax. As a result, the Federal Internal Revenue Service (Receita Federal) issued an infraction notice demanding the payment of COFINS tax from the period between August 1995 and December 1996. As of December 31, 2019, we had provisioned R$104.2 million to cover expected losses related to these lawsuits.

Additionally, we are party to administrative and judicial proceedings pursuant to which we are challenging claims of the Brazilian Social Security authorities to pay additional security contributions for the period between 2000 and 2006. In these proceedings, we estimate the amount of our expected loss to be R$30.7 million.

Labor-related Claims

We are the defendant in several lawsuits filed by either current or past employees of ours, related to overtime claims, dangerous work conditions, relocation, and other matters. As of December 31, 2019, we have provisions totaling R$673.0 million reflecting the expected losses related to these lawsuits.

Regulatory

We are disputing certain regulatory and legal proceedings in connection with ANEEL’s allegations that we violated regulatory standards. As of December 31, 2019, we have provisions totaling R$79.8 million reflecting the expected losses related to these proceedings.

Additional Claims

We are party to several lawsuits related to accidents involving equipment used in our electricity transmission and distribution grids and vehicle accidents (for more information see Note 29.1.2(e) to our audited consolidated financial statements). As of December 31, 2019, we have provisions totaling R$337.0 million reflecting the expected losses related to these lawsuits.

We are also party to several lawsuits brought by landowners whose land has been affected by our transmission and distributions lines. As of December 31, 2019, we have provisions totaling R$245.8 million reflecting the expected losses related to these lawsuits.

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Dividend Payments

In accordance with our bylaws and Brazilian Corporate Law, we regularly pay annual dividends for each fiscal year within sixty days of the declaration of the dividends at the annual shareholders’ meeting. To the extent amounts are available for distribution, we are required to distribute as a mandatory dividend an aggregate amount equal to at least 25.0% of our adjusted net profit. Dividends are allocated pursuant to the formula described in “Dividend Priority of Class A Shares and Class B Shares” below. Under Brazilian Corporate Law, we are not permitted to suspend the mandatory dividend payable with respect to the Common Shares, Class A Shares and Class B Shares for any year. Brazilian Corporate Law permits, however, a company to suspend the payment of all dividends if the Board of Directors, with the approval of the Supervisory Board, reports at the shareholders’ meeting that the distribution would be detrimental to the Company given its financial circumstances. In such a case, companies with publicly traded securities must submit a report to the CVM providing the reasons for the suspension of dividend payments. Notwithstanding the above, Brazilian Corporate Law and our bylaws provide that Class A Shares and Class B Shares shall acquire voting rights if we suspend the mandatory dividend payments for more than three consecutive fiscal years, and such voting rights will continue until all dividend payments, including back payments, have been made. We are not subject to any contractual limitations on our ability to pay dividends.

On March 30, 2020, and in the context of the coronavirus (COVID-19) pandemic, the Brazilian Government issued Provisional Measure No. 931 which is applicable to us and allows for (i) annual shareholders meetings for the fiscal year of 2020 to take place on a date up to seven months from the end of the respective 2019 fiscal year and (ii) board of directors of Brazilian companies to declare dividends pending the 2020 annual shareholders meeting.

Calculation of Adjusted Net Profit

Annual dividends are payable from our adjusted net profit for such period. Brazilian Corporate Law defines “net profit” for any fiscal year as the result of a fiscal year after the deduction of income and social contribution taxes for that fiscal year and after the deduction of any amounts allocated to employees’ and management’s participation in our results in such fiscal year. The “net profit” for a relevant fiscal year is subject to adjustment by the addition or subtraction of amounts allocated to legal and other reserves, the result of which is known as our adjusted net profit.

In accordance with Brazilian Corporate Law, we must maintain a legal reserve, to which we must allocate a minimum of 5% of our net profits for each fiscal year until such reserve reaches an amount equal to 20.0% of our capital stock (calculated in accordance with Brazilian Corporate Law). However, we are not required to make any allocations to our legal reserve in a fiscal year in which the legal reserve, when added to our other established capital reserves, exceeds 30.0% of our total capital stock. The amounts to be allocated to such reserve must be approved by our shareholders in a shareholders’ meeting and may be used only for the increase of our capital stock or compensation of losses.

On December 31, 2019, our legal reserve was R$1,014.2 million, or approximately 9.4% of our capital stock at that date.

In addition to deducting amounts for the legal reserve, under Brazilian Corporate Law net profit may also be adjusted by deducting amounts allocated to:

| · | the contingency reserve: under Brazilian Corporate Law, our shareholders’ meeting, upon a justified proposal of our Board of Directors or Board of Executive Officers, may decide to allocate a percentage of our net profits to a contingency reserve for anticipated losses that are deemed probable in future years, which amount may be estimated;

| · | the tax incentives reserve: under Brazilian Corporate Law, our shareholders’ meeting, upon a justified proposal of our Board of Directors or Board of Executive Officers, may decide to allocate a percentage of our net profits resulting from government donations or subsidies for investment purposes.

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On the other hand, net profits may also be increased by:

| · | the reversal of any amounts previously allocated to a contingency reserve in the fiscal year in which the loss that had been anticipated does not occur as projected or in which the anticipated loss occurs but is lower than the contingency allocated to it; and

| · | any amounts included in the unrealized profits reserve that have been realized in the relevant fiscal year and have not been used to offset losses, as approved by our shareholders’ meeting, upon the proposal of our Board of Directors or Board of Executive Officers.

Moreover, our net profits are also adjusted by adding the realization of amounts registered under “Equity Value Adjustments”. The account “Equity Value Adjustments” was created as a result of the first-time adoption of IFRS by Copel in 2010, which caused a fair value revaluation of certain fixed assets and the adoption of the fair value as its “deemed cost” at that date. The increase of the deemed cost of fixed assets led to an increase in depreciation costs. Thus, our management has decided to add to the adjusted net profits the realization of the “Equity Value Adjustments” in order to compensate for effects of the increased depreciation costs. This procedure is authorized by ICPC 10 (“Interpretação do Comitê de Pronunciamento Contábil”). In 2019, our adjusted net profits used to calculate our dividends was increased by R$66.2 million as a result of said realization.

The amounts available for distribution are determined on the basis of the Statutory Financial Statements prepared using the method required by Brazilian Corporate Law, which differ from our audited consolidated financial statements included herein.

Dividend Priority of Class A Shares and Class B Shares

According to our bylaws, Class A Shares and Class B Shares are entitled to receive annual, non-cumulative minimum dividends, which dividend per share shall be at least 10% higher than the dividends per share paid to the holders of the Common Shares. Class A Shares have a dividend priority over the Class B Shares, and Class B Shares have a dividend priority over the Common Shares. To the extent that dividends are paid, they are to be paid in the following order:

| · | first, the holders of Class A Shares have the right to receive a minimum dividend equal to 10% of the total share capital represented by the Class A Shares outstanding at the end of the fiscal year in respect of which the dividends have been declared;

| · | second, to the extent there are additional amounts to be distributed after all amounts allocated to the Class A Shares have been paid, the holders of Class B Shares have the right to receive a minimum dividend per share equal to (i) the mandatory dividend divided by (ii) the total number of Class B Shares outstanding at the end of the fiscal year in respect of which the dividends have been declared; and

| · | third, to the extent that there are additional amounts to be distributed after all amounts allocated to the Class A Shares and the Class B Shares have been paid, the holders of Common Shares have the right to receive an amount per share equal to (i) the mandatory dividend divided by (ii) the total number of Common Shares outstanding at the end of the fiscal year in respect of which dividends have been declared, provided that the Class A Shares and Class B Shares receive dividends per share at least 10% higher than the dividends per share paid to the Common Shares.

To the extent that there are additional amounts to be distributed after all amounts described in the preceding items have been paid and in the form therein described, any such additional amount will be divided equally among all our shareholders.

Payment of Dividends

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We are required to hold an annual shareholders’ meeting by April 30th of each year at which, among other things, an annual dividend may be declared by decision of the shareholders on the recommendation of the management, as approved by the Board of Directors. The payment of annual dividends is based on the financial statements prepared for the fiscal year ending December 31. Under Brazilian Corporate Law, we must pay dividends to shareholders of record within 60 days of the date of the shareholders meeting that declared the dividends. A shareholders’ resolution may set forth another date of payment, which must occur prior to the end of the fiscal year in which such dividend was declared. We are not required to adjust the amount of paid-in capital for inflation for the period from the end of the last fiscal year to the date of declaration or to adjust the amount of the dividend for inflation for the period from the end of the relevant fiscal year to the payment date. Consequently, the amount of dividends paid to holders of Class B Shares may be substantially reduced due to inflation.

Pursuant to our bylaws, our management may declare interim dividends to be paid from profits in our semi-annual financial statements, in accordance with the Company's dividend policy and subject to further endorsement by the Shareholders’ Meeting. Any payment of interim dividends counts towards the mandatory dividend for the year in which the interim dividends were paid.

Pursuant to Brazilian Corporate Law, we may pay interest on equity in lieu of dividends as an alternative form of making distributions to shareholders. We may treat a payment of interest on equity as a deductible expense for tax purposes, provided that it does not exceed the lesser of:

| · | the total amount resulting from (i) Long-Term Interest Rate (Taxa de Juros a Longo Prazo, or “TJLP”) multiplied by (ii) the total shareholders’ equity (determined in accordance with Brazilian Corporate Law), less certain deductions prescribed by Brazilian Corporate Law; and

| · | the greater of (i) 50.0% of current net income (after the deduction of social contribution on profits (CSLL ‒ Contribuição Social sobre o Lucro Líquido) and before taking such distributions and any deductions for corporate income tax) for the year in respect of which the payment is made or (ii) 50.0% of retained earnings and profit reserves for the year prior to the year in respect of which the payment is made.

In order to be eligible to receive amounts remitted in foreign currency outside of Brazil, shareholders who are not residents of Brazil must register with the Central Bank in order to receive dividends, sales proceeds or other amounts with respect to their shares. The Class B Shares underlying the ADSs are held in Brazil by the Custodian, as agent for the Depositary, which is the registered owner of our shares.

Payments of cash dividends and distributions, if any, will be made in Brazilian currency to the Custodian on behalf of the Depositary, which will then convert such proceeds into U.S. dollars and will cause such U.S. dollars to be delivered to the Depositary for distribution to holders of ADSs. In the event that the Custodian is unable to immediately convert the Brazilian currency received as dividends into U.S. dollars, the amount of U.S. dollars payable to holders of ADSs may be adversely affected by devaluations of the Brazilian currency that occur before such dividends are converted and remitted. In the event the holder of an ADS fails to collect its dividends from the Custodian within three (3) years, counted as of the date when such dividend was made available, Brazilian corporate law states that such dividends may be returned to us. In this case, the ADS holder shall lose its right to receive the dividends.

The table below sets forth the cash distributions we paid/will pay as dividends and as interest on equity for the periods indicated.

Year | Payment date | Distribution (R$ thousands) | Payment per share (R$)
|  |  | Common | Preferred A | Preferred B
2014 | June 2015 | 622,523 | 2.17236 | 2.52507 | 2.39000

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2015 | June 2016 | 326,795 | 1.13716 | 2.52507 | 1.25473
2016 | June 2017 | 282,947 | 0.98539 | 2.89050 | 1.08410
2016 | December 2017 | 223,266 | 0.77927 | - | 0.85932
2017 | August 2018 | 266,000 | 0.92624 | 2.89050 | 1.01887
2017 | August 2018 | 23,401 | 0.08177 | - | 0.08996
2018 | December 2018 | 280,000 | 0.97515 | 2.89050 | 1.07270
2018 | April 2019 | 98.54 | 0.34435 | - | 0.37881
2019 | December 2019 | 643,000 | 2.24235 | 3.94657 | 2.46692

The table below sets forth the cash distributions we paid/will pay as dividends and as interest on equity, translated into US$ based on the exchange rate at year-end, for the periods indicated.

Year | Payment date | Distribution (US$ thousands) | Payment per thousand shares (US$)
|  |  | Common | Preferred A | Preferred B
2014 | June 2015 | 234,366 | 0.81785 | 0.95063 | 0.89978
2015 | June 2016 | 83,691 | 0.29122 | 0.64666 | 0.32133
2016 | June 2017 | 86,818 | 0.30235 | 0.88690 | 0.33264
2016 | December 2017 | 68,505 | 0.23911 | - | 0.26367
2017 | August 2018 | 81,618 | 0.29237 | 0.91241 | 0.32161
2017 | August 2018 | 7,387 | 0.02581 | - | 0.02840
2018 | December 2018 | 72,262 | 0.25166 | 0.74597 | 0.27684
2018 | April 2019 | 25,431 | 0,08887 | - | 0.09776
2019 | December 2019 | 159,526 | 0.55632 | 0.97913 | 0.61203

Item 9. The Offer and Listing

The principal trading market for our shares (including our Class B Shares) is the B3 (Brasil, Bolsa, and Balcão) market. Our Common Shares trade on B3 under the symbol “CPLE3” and our Class B Shares trade under the symbol “CPLE6”. On March 31, 2020, approximately 15,878 shareholders owned our Class B Shares.

In the United States, our Class B Shares in the form of ADSs, each representing one Class B Share (as a result of the reverse stock split), issued by the Depositary pursuant to the Deposit Agreement by and between Copel, the Depositary and the registered holders and beneficial owners from time to time of the ADSs. The ADSs trade on the NYSE under the symbols “ELP” and “ELPVY”.

On June 19, 2002, our shares were listed on Latibex, an Euro-based market for Latin American securities. The shares trade under the symbol “XCOP”.

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Item 10. Additional Information

Memorandum and Articles of Association

Organization

We are a publicly traded company duly registered with the CVM under No. 1431-1. According to Article One of our bylaws, we are authorized to pursue, directly or through consortia or in partnership with private companies, the following objectives and purposes:

| · | researching and studying, technically and economically, all energy sources, providing solutions for a sustainable development;

| · | researching, studying, planning, constructing and developing the production, transformation, transportation, storage, distribution and trade of energy in any of its forms, chiefly electric power, as well as fuels and energy raw materials;

| · | studying, planning, designing, constructing and operating dams and their reservoirs, as well as other undertakings for multiple uses of water resources;

| · | providing services in energy trading, energy infrastructure, information and technical assistance concerning the rational use of energy to business undertakings with the aim of implementing and developing economic activities deemed relevant for the development of the State of Paraná, upon approval by the Board of Directors; and

| · | developing activities in the areas of energy generation, electronic data transmission, electronic communications and control, cellular telephone systems, and other endeavors that may be deemed relevant to the Company and the State of Paraná, being authorized, for such aims, upon approval by the Board of Directors, and for the aims set forth in the second and third sub-items above, to join, preferably holding major stakes or controlling interest, consortia or concerns with private companies, pension funds or other private entities, to participate in bidding processes of new concessions and/or already established special purpose companies to exploit already existing concessions, having taken into consideration, besides the projects' general features, their respective social and environmental impacts.

Except as described in this section, our bylaws do not contain provisions addressing the duties, authority, or liabilities of directors and management, which are instead established by Brazilian Corporate Law.

Qualification of Board of Directors

The appointed directors must comply with the legal requirements set forth in Federal Law No. 13,303/2016, particularly the ones mentioned in its article 17, and Federal Law No. 6,404/1976. Moreover, pursuant to Federal Law No. 13,303/2016 and to our bylaws, our Board of Directors will mandatorily comprise, at least, (i) three independent members, (ii) five members that meet the requirements for members of the Statutory Audit Committee, and (iii) one member appointed by the employees. Among the members described in item (ii) above, at least one shall compulsorily have recognized professional experience in matters of corporate accounting in order to sit on the Statutory Audit Committee.

Limitations on Directors’ Powers

Under Brazilian Corporate Law, if a director or an executive officer has a conflict of interest with the company in connection with any proposed transaction, the director or executive officer may not vote in any decision of the board of directors or of the board of executive officers related to that transaction, and must disclose the nature and extent of the conflict of interest for transcription in the minutes of the meeting. A director or an executive officer may not transact any business with a company, including accepting any loans, except on reasonable and fair terms for the Company and conditions that are identical to the terms and

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conditions prevailing in the market or offered by third parties. According to our bylaws, shareholders set the aggregate compensation payable to directors and executive officers. For more information, see “Item 6. Directors, Senior Management and Employees”. Our bylaws do not establish any mandatory retirement age limits.

Board of Directors and Board of Executive Officers

According to our bylaws, we are managed by a Board of Directors, composed of nine members and a Board of Executive Officers, composed of six members. -

Our Board of Directors ordinarily meets monthly and is responsible, among other things, for: (i) establishing our corporate strategy; (ii) defining the general orientation of our business; (iii) defining the responsibilities of members of our Board of Executive Officers; and (iv) electing the members of our Board of Executive Officers.

Our Board of Executive Officers meets every two weeks and is responsible for the daily management of the Company. Each Executive Officer also has individual responsibilities established by our bylaws.

The members of our Board of Directors, of our Board of Executive Officers, our Supervisory Board and of our statutory committees shall be liable for any loss or damages resulting from the performance of their duties, in compliance with the applicable law. Notwithstanding, we shall ensure, provided no conflict with our own interests arises, legal assistance for members or former members of statutory bodies in judicial and administrative proceedings brought by third parties, during or after their term of office, for the performance of the duties of their office, in accordance to the terms and provisions of our bylaws.

For further information, see Items 6 – “Directors, Senior Management and Employees - Board of Directors” and “Directors, Senior Management and Employees - Board of Executive Officers”.

Shareholders’ Meetings

The convening of our shareholders’ meeting is made through publication of a notice to shareholders in two newspapers, which are determined at the previous shareholders’ meeting. Generally, we make such notice in Diário Oficial do Estado – PR and the Folha de Londrina. As provided by Brazilian Corporate Law, publications have to be made in the official newspaper located in the state of our corporate headquarters, and in a newspaper with wide circulation in the same city as our corporate headquarters. The notice must be published no fewer than three times, beginning at least 30 calendar days prior to the scheduled meeting date.

In order for a shareholders’ meeting to be held on first call, shareholders representing at least one- quarter of the voting capital have to be present, except as otherwise provided for under Brazilian law. If no such quorum is verified, a second meeting may be called by notice given at least 8 calendar days prior to such meeting and in accordance with the same rules of publication previously described. The quorum requirements will not apply to a second meeting, subject to the minimum quorum and voting requirements for certain matters, as discussed as follows. A shareholder without a right to vote may attend a general shareholders’ meeting and take part in the discussion of matters submitted for consideration.

A shareholder may be represented at a general shareholders' meeting by a proxy appointed in accordance with applicable Brazilian law not more than one year before the meeting, who must be a shareholder, a company officer, a lawyer or a financial institution.

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Right of Withdrawal

Our common shares and preferred shares are not redeemable, with the exception that a dissenting shareholder has, under certain circunstances provided for in Brazilian Corporate Law, the right to withdraw its equity interest from a company and to receive a payment for the portion of shareholder’s equity attributable to his or her equity interest.

Preferred Shares Rights

Pursuant to Brazilian Corporate Law, each preferred share of a class that is admitted to trading on a Brazilian stock exchange must have the certain rights under the Company’s bylaws.

Our bylaws comply with the directives provided by Brazilian Corporate Law as follows: (i) our Class A Shares shall have priority in the distribution of minimum dividends of 10% per year, pro rata, calculated as a percentage of the paid-in capital stock represented by such shares on December 31 of the previous fiscal year; (ii) our Class B Shares shall have priority in the distribution of minimum dividends, pro rata, in the amount equivalent to 25.0% of our net profits, as adjusted in accordance with Section 202 of Law No. 6,404/76, calculated as a proportion of the paid-in capital stock represented by such shares on December 31st of the previous fiscal year; (iii) the dividends paid on Class B Shares pursuant to item (ii) above shall be paid only from any remaining profits after the payment of priority dividends to Class A Shares; and (iv) the dividends to be paid per preferred share, regardless of the class, shall be at least 10% higher than the dividends to be paid per Common Share; and (v) the preferred shares will 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. For more information on our dividend policy, see “Item 8. Financial Information.”

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.

Preemptive Rights

Our shareholders have a general preemptive right to subscribe for shares in any capital increase, in proportion to his or her ownership, as provided for in the Brazilian Corporate Law. A minimum period of 30 days following the publication of notice of a capital increase is assured for the exercise of the right, and the right is transferable. We may issue shares up to the limit of the authorized capital, excluding right of first refusal to the shareholders, as provided for in the Brazilian Corporate Law and in our bylaws.

Liquidation

In the event of liquidation of the Company, after all creditors have been paid, all shareholders will participate equally and ratably in any remaining residual assets.

Liability of the Shareholders for Further Capital Calls

Neither Brazilian Corporate Law nor our bylaws provide for capital calls. The shareholders’ liability is limited to the payment of the issue price of the shares subscribed or acquired.

Conversion Rights

Our bylaws provide that the only permitted conversion of shares is Class A Shares are convertible into Class B Shares. Our shares are not otherwise convertible.

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Form and Transfer

Our shares are maintained in book-entry form with a transfer agent (“Transfer Agent”). To make a transfer of shares, the Transfer Agent makes an entry in the register, debits the share account of the transferor and credits the share account of the transferee.

Transfers of shares by foreign investors are made in the manner described above and are executed by the investor’s local agent on the investor’s behalf. However, if the original investment was registered with the Central Bank pursuant to a foreign investment mechanism regulated by Resolution No. 4,373 of September 29, 2014 of the CMN (“Resolution No. 4,373”) as described under “Exchange Controls” as follows, the foreign investor must declare the transfer in its electronic registration.

A shareholder may choose, in its individual discretion, to hold its shares through B3. Shares are added to the B3 system through Brazilian institutions that have clearing accounts with the B3. Our shareholder registry indicates which shares are listed on the B3 system. Each participating shareholder is in turn registered in a register of beneficial shareholders maintained by the B3 and is treated in the same manner as the other registered shareholders.

Changes in rights of shareholders

A General Meeting of Shareholders must be held whenever the Company intends to change the rights of holders of our common shares or preferred shares. Under Brazilian Corporate Law the proposed changes must be approved by a majority of the class of shareholders that would be affected. Certain changes related to the rights of preferred shares, such as changes in preferences, advantages or conditions of redemption or amortization, may result in the exercise of rights to withdraw by the holders of the shares affected.

Regulation of and Restrictions on Foreign Investors

Foreign investors face no legal restrictions barring them from holding Common Shares, Class A Shares, Class B Shares or ADSs.

The ability to convert into foreign currency dividend payments and proceeds from the sale of Class B Shares or preemptive rights, and to remit such amounts outside Brazil is subject to restrictions under foreign investment legislation which generally requires, among other things, the registration of the relevant investment with the Central Bank. Any foreign investor who registers with the CVM in accordance with CMN Resolution No. 4,373 may buy and sell securities on Brazilian stock exchanges without obtaining a separate certificate of registration for each transaction.

Annex II to CMN Resolution No. 4,373 (“Annex II Regulations”) allows Brazilian companies to issue depositary receipts in foreign exchange markets. Our ADS program is duly registered with the Central Bank and the CVM.

Our bylaws do not impose any limitation on the rights of Brazilian residents or non-residents to hold our shares and exercise the rights in connection therewith.

Disclosure of Shareholder Ownership

Under Brazilian regulations any person or group of persons representing the same interest that carries out a relevant trading involving shares or securities issued by a publicly traded company must disclose its share ownership to the investor relations officer of such company, which, in turn, must disclose such information to the CVM and to any relevant stock exchange. A relevant trading is defined as a transaction by which the direct or indirect equity stake of the persons referred above reaches an equity interest corresponding to 5% or its multiples (10%, 15%, and so on), of a type or class of shares representing the company’s capital stock. Any subsequent increase or decrease of 5% or its multiples in ownership of any class of shares must be similarly disclosed. The same reporting obligation applies to the acquisition of any rights over the shares and other securities mentioned in applicable regulation and to the execution of any derivative financial instruments

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referenced in shares. If such increase results in change of corporate control or administrative structure, or if the increase imposes a public offering, in addition to informing the investor relations officer, a statement containing certain required information must be published in newspapers that are widely circulated in Brazil.

Arbitration

As provided for in our bylaws, we, our shareholders, directors, officers and members of the supervisory board shall resolve through arbitration any dispute or conflict that may arise between them, regarding, among others, the application, validity, effectiveness, interpretation, violation and corresponding effects of the provisions of our bylaws, of the current applicable law, of the rules applicable to the capital markets in general, as well as those of the regulation of the level 1 of corporate governance of B3 (Brasil, Bolsa, Balcão) (“Level 1”), of the Level 1 participation contract, and of the Sanctions and the Arbitration Regulations of the B3 Market Arbitration Chamber.

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Material Contracts

For information concerning our material contracts, see “Item 4. Information on the Company” and “Item 5. Operating and Financial Review and Prospects”.

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Exchange Controls

The ownership of Class A Shares, Class B Shares or Common Shares of the Company by individuals or legal entities domiciled outside Brazil is subject to certain conditions established under Brazilian law, as described below.

The right to convert dividend payments and proceeds from the sale of shares into foreign currency and to remit such amounts outside Brazil is subject to restrictions under Brazilian foreign investment legislation, which generally requires, among other things, that the relevant investments have been registered with the Central Bank. Such restrictions on the remittance of foreign capital abroad may hinder or prevent Itaú Unibanco S.A., as custodian for the Class B Shares represented by ADSs (“Custodian”), or holders who have exchanged ADSs for Class B Shares from converting dividends, distributions or the proceeds from any sale of such Class B Shares, as the case may be, into U.S. dollars and remitting such U.S. dollars abroad. Holders of ADSs could be adversely affected by delays in, or refusal to grant any, required government approval for conversions of Brazilian currency payments and remittances abroad of the Class B Shares underlying the ADSs.

Under Resolution No. 4,373/2014, 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. The definition of foreign investor includes individuals, legal entities, mutual funds and other collective investment entities, domiciled or headquartered abroad.

To be eligible to invest in the Brazilian financial and capital markets, foreign investors must:

| 1. | point at least one representative in Brazil with powers to perform actions relating to foreign investments;

| 2. | register as a foreign investor with the CVM;

| 3. | register the foreign investment with the Central Bank; and

| 4. | constitute at least one custodian institution authorized by CVM.

Securities and other financial assets held by foreign investors must be registered or maintained in deposit accounts or under the custody of an entity duly licensed by the Central Bank or the CVM. In addition, securities trading is restricted to transactions carried out in the stock exchanges or organized over-the-counter markets licensed by the CVM.

The Annex II Regulations provide for the issuance of depositary receipts in foreign markets in respect of shares of Brazilian issuers. Prior to the issuance of the ADSs, the ADS program was approved by the Central Bank and the CVM under the Annex V to CMN Resolution No. 2,689, which allowed Brazilian companies to issue depositary receipts in foreign exchange markets and was in force by the time the ADSs were issued. Depositary receipts are currently governed by Resolution No. 4,373. The proceeds from the sale of ADSs by ADS holders outside Brazil are free of Brazilian foreign investment controls and should not be subject to taxation in Brazil. The withdrawal and the disposal of Class B Shares upon cancellation of ADS will be subject to taxation in Brazil. For more information, see “Item 10. Additional Information—Taxation—Brazilian Tax Considerations—Taxation of Gains Outside Brazil”.

An electronic registration has been issued in the name of the Depositary with respect to the ADSs and is maintained by the Custodian on behalf of the Depositary. Pursuant to this electronic registration, the Custodian and the Depositary are able to convert dividends and other distributions with respect to the Class B Shares represented by ADSs into foreign currency and remit the proceeds outside Brazil. In the event that a holder of ADSs exchanges such ADSs for Class B Shares, such holder must seek to obtain its own electronic registration with the Central Bank.

Pursuant to Central Bank Resolution No. 4,373/2014, the withdrawal of Class B Shares upon cancellation of ADSs may require simultaneous exchange transactions in the event the investor decides not to

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dispose of those Class B Shares. The simultaneous exchange transactions may be required in order to obtain a certificate of registration of Class B Shares with the Central Bank. This transaction will be subject to tax in Brazil. For more information, see “Item 10. Additional Information—Taxation—Brazilian Tax Considerations—Other Brazilian Taxes”.

Thereafter, any holder of Class B Shares may not be able to convert into foreign currency and remit outside Brazil the proceeds from the disposition of, or distributions with respect to, such Class B Shares, unless such holder obtains his own electronic registration. A holder that obtains an electronic registration may be subject to less favorable Brazilian tax treatment than a holder of ADSs. For more information, see “Item 10. Additional Information—Taxation—Brazilian Tax Considerations”.

The federal government may impose temporary restrictions on remittances of foreign capital abroad in the event of a serious imbalance or an anticipated serious imbalance of Brazil’s balance of payments. For approximately six 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. There can be no assurance that the federal government will not impose similar restrictions on foreign repatriations in the future.

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Taxation

The following summary contains a description of the principal Brazilian and U.S. federal income tax consequences of the acquisition, ownership and disposition of Class B Shares or ADSs, 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 Class B Shares or ADSs. The summary is based upon the tax laws of Brazil and regulations thereunder and on the tax laws of the United States and regulations thereunder as in effect on the date hereof, which are subject to change. Prospective purchasers of Class B Shares or ADSs should consult their own tax advisors as to the tax consequences of the acquisition, ownership and disposition of Class B Shares or ADSs.

Although there is at present no income tax treaty between Brazil and the United States, the tax authorities of the two 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 Class B Shares or ADSs. Prospective holders of Class B Shares or ADSs should consult their own tax advisors as to the tax consequences of the acquisition, ownership and disposition of Class B Shares or ADSs in their particular circumstances.

Brazilian Tax Considerations

The following discussion summarizes the principal Brazilian tax consequences of the acquisition, ownership and disposition of Class B Shares or ADSs by an individual, entity, trust or organization resident or domiciled outside Brazil for purposes of Brazilian taxation (“Non-Brazilian Holder”). It is based on Brazilian law currently in effect, which is subject to differing interpretations and changes that may apply retroactively. This discussion does not address all the Brazilian tax considerations that may be applicable to any particular Non-Brazilian Holder, and each Non-Brazilian Holder should consult its own tax advisor about the Brazilian tax consequences of investing in Class B Shares or ADSs.

Taxation of Dividends

Dividends paid by the Company in cash or in kind from profits of periods beginning on or after January 1, 1996 (i) to the Depositary in respect of Class B Shares underlying ADSs or (ii) to a Non-Brazilian Holder in respect of Class B Shares generally will not be subject to Brazilian withholding income tax. Dividends paid from profits generated before January 1, 1996 may be subject to Brazilian withholding income tax at varying rates depending upon the year in which the profits have been obtained.

Distributions of Interest on Equity

In accordance with Law No. 9,249, dated December 26, 1995, as amended, Brazilian corporations may make payments to shareholders characterized as distributions of interest on the equity of the company as an alternative form of making dividend distributions. The rate of interest may not be higher than TJLP, as determined by the Central Bank from time to time. The total amount distributed as interest on equity may not exceed, for tax purposes, the greater of (i) 50.0% of net income (after the deduction of the social contribution on net profits and before taking into account the provision for corporate income tax and the amounts attributable to shareholders as net interest on equity) related to the period in respect of which the payment is made and (ii) 50.0% of the sum of retained profits and profit reserves as of the date of the beginning of the period in respect of which the payment is made.

Distributions of interest on equity paid to Brazilian and Non-Brazilian Holders of Class B Shares, including payments to the Depositary in respect of Class B Shares underlying ADSs, are deductible by the Company for Brazilian corporate income tax and social contribution on net profits purposes as far as the limits above described are observed. Such payments to shareholders are subject to Brazilian withholding income tax at the rate of 15.0%, except for payments to shareholders situated in tax haven jurisdictions (that is, a country or location 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 the beneficial owner of the income derived from transactions carried out and attributable to a Non-Brazilian Holder - “Tax Haven Holder”), which payments are subject to withholding income tax at a 25.0%

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rate. A regulation issued by the Brazilian tax authorities on November 28, 2014 (Ordinance 488, of 2014) decreased, from 20% to 17%, the minimum threshold for certain specific cases. The reduced 17% threshold applies only to countries and regimes aligned with international standards of fiscal transparency in accordance with rules to be established by the Brazilian tax authorities in Normative Ruling 1,530 dated December 19, 2014. The list of tax haven jurisdictions is currently provided in Normative Ruling No. 1,037. These payments may be included, at their net value, as part of any mandatory dividend. To the extent that payment of interest on net equity is so included, the corporation is required to distribute to shareholders an additional amount to ensure that the net amount received by them, after payment of the applicable withholding income tax, plus the amount of declared dividends, is at least equal to the mandatory dividend.

Taxation of Gains Outside Brazil

According to Law No. 10,833 of December 29, 2003 (“Law No. 10,833/03”), capital gains realized on the disposition of assets located in Brazil by a Non-Brazilian Holder, whether to another non-Brazilian resident or to Brazilian residents, are subject to taxation in Brazil. In this sense, if the Class B Shares are disposed of by a Non-Brazilian Holder, as they are defined as assets located in Brazil, such holder will be subject to income tax on the gains assessed, following the rules described below, whether the disposition is conducted in Brazil or abroad and with a Brazilian resident or not.

A disposition of Class B Shares can occur abroad if an investor decides to cancel its investment in ADSs and register the underlying Class B Shares as a direct foreign investment under Law No. 4,131. Any capital gain arising from sales or other dispositions of Class B Shares outside Brazil would be subject to Brazilian income tax at the rates that range from 15% to 22.5% depending on the amount of the gain, as follows: (i) 15% on gains not exceeding R$5,000,000.00; (ii) 17.5% on gains that exceed R$5,000,000.00 and do not exceed R$10,000,000.00; (iii) 20% on gains that exceed R$10,000,000.00 and do not exceed R$30,000,000.00; and (iv) 22.5% on gains exceeding R$30,000,000.00 or, if the investor is a Tax Haven Holder, 25.0%, which should be withheld by the purchaser of the Class B Shares outside Brazil or its attorney-in-fact in Brazil.

Regarding ADSs, although the matter is not free from doubt, the gains realized by a Non-Brazilian Holder on the disposition of ADSs to another Non-Brazilian Holder should not be taxed in Brazil, based on the theory that ADSs do not constitute assets located in Brazil for purposes of Law No. 10,833/03. However, we cannot assure you that Brazilian courts would adopt this theory. Thus, the gain on a disposition of ADSs by a Non-Brazilian Holder to a resident in Brazil (or possibly even to a Non-Brazilian Holder in the event that courts determine that ADSs would constitute assets located in Brazil) may be subject to income tax in Brazil.

Taxation of Gains in Brazil

For purposes of Brazilian taxation, the income tax rules on gains related to disposition of Class B Shares vary depending on the domicile of the Non-Brazilian Holder, the form by which such Non-Brazilian Holder has registered its investment before the Brazilian Central Bank and/or how the disposition is carried out, as described below.

Generally, gains are defined as the positive difference between the amount realized on the sale or exchange of a security and its acquisition cost. Gains assessed on the disposition of the Class B Shares carried out on the Brazilian stock exchange (which includes the transactions carried out on the organized over-the-counter market) are:

| 1. | exempt from income tax when assessed by a Non-Brazilian Holder registered under Resolution No. 4,373 of the CMN (“4,373 Holder”) that is not a Tax Haven Holder; or

| 2. | subject to income tax at a rate of 15.0% in any other case, including the gains assessed by a Non-Brazilian Holder that (i) is not a 4,373 Holder, or (ii) is a 4,373 Holder and is a Tax Haven Holder.

There can be no assurance that the current preferential treatment for 4,373 Holders will continue in the future.

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Any other gains assessed on a disposition of the Class B Shares that is not carried out on the Brazilian stock exchange is subject to income tax at the progressive rates ranging from 15% to 22.5%, except for gains assessed by Tax Haven Holders who are subject to an income tax rate of 25.0%.

If these gains are related to transactions conducted on the Brazilian non-organized, over-the-counter market, through an intermediary, the withholding income tax of 0.005% on the sale value shall also be applicable and can be offset with the eventual income tax due on the capital gain.

The deposit of Class B Shares in exchange for the ADSs may be subject to Brazilian income tax In this case, the difference between the acquisition cost and the market price of the Class B Shares would be subject to income tax at the progressive rates ranging from 15% to 22.5% or 25.0% in the case of investors that are Tax Haven Holders. There may be arguments to claim that this taxation is not applicable in the case of a Non-Brazilian Holder that is registered under Resolution 4,373 (other than Tax Haven Holders), which should not be subject to income tax in such a transaction.

The withdrawal of Class B Shares upon cancellation of ADSs should not be subject to Brazilian income tax, as long as the regulatory rules are appropriately observed with respect to the registration of the investment before the Central Bank.

In the case of redemption of the Class B Shares or ADSs or capital reduction by a Brazilian corporation, with subsequent withdrawal of the ADSs, such as our company, the positive difference between the amount effectively received by the Non-Brazilian Holder and the acquisition cost of the securities redeemed is treated as capital gain derived from the sale or exchange of shares not carried out on a Brazilian stock exchange market and is therefore subject to income tax at the progressive rates ranging from 15.0% to 22.5% or 25.0%, as the case may be.

Any exercise of preemptive rights relating to the Class B Shares or ADSs will not be subject to Brazilian taxation. Gains on the sale or assignment of preemptive rights will be subject to the same tax treatment applicable to disposition of Class B Shares.

Other Brazilian Taxes

There are no Brazilian inheritance, gift or succession taxes applicable to the ownership, transfer or disposition of Class B Shares or ADSs by a Non-Brazilian Holder except for gift and inheritance taxes levied by some states in Brazil on gifts made or inheritances bestowed by individuals or entities not resident or domiciled in Brazil or in the relevant State to individuals or entities that are resident or domiciled within such State in Brazil. There are no Brazilian stamp, issue, registration, or similar taxes or duties payable by holders of Class B Shares or ADSs.

Pursuant to Decree No. 6,306 of December 14, 2007 (“Decree No. 6,306/07”), a tax on foreign exchange transactions (“IOF/Exchange”) may be imposed on the conversion of Brazilian currency into foreign currency (e.g., for purposes of paying dividends and interest) or vice-versa. Currently, for most exchange transactions, the rate of IOF/Exchange is 0.38%, except for: (i) foreign exchange transactions for the inflow of funds related to investments in variable income effectuated by a Non-Brazilian Holder in the Brazilian financial and capital market, in which case the rate is 0%, and (ii) payment of dividends, and interest on shareholders’ equity related to the investment mentioned under item (i) above, in which case the rate is zero. Nonetheless, the Brazilian government may increase the rate to a maximum of 25.0%. Any such increase will be applicable only prospectively.

Pursuant to Decree No 6,306/07, the Tax on Bonds and Securities Transactions (“IOF/Bonds”) may be imposed on any transactions involving bonds and securities, including those carried out on Brazilian stock, futures and commodities exchanges. The rate of IOF/Bonds Tax applicable to transactions involving common shares is currently zero if the redemption, transfer or renegotiation occurs after 30 days of their acquisition. As from December 24, 2013, the IOF/Bonds levies at a rate of zero percent on the transfer (cessão) of shares traded in a Brazilian stock exchange environment with the specific purpose of enabling the issuance of depositary

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receipts to be traded outside Brazil. The Brazilian government is permitted to increase such rate at any time up to 1.5% per day, but only in respect of future transactions.

U.S. Federal Income Tax Considerations

The statements regarding U.S. tax law set forth below are based on U.S. law as in force on the date of this annual report, and changes to such law subsequent to the date of this annual report may affect the tax consequences described herein (possibly with retroactive effect). This summary describes the principal U.S. federal income tax consequences of the ownership and disposition of Class B Shares or ADSs, but it does not purport to be a comprehensive description of all of the U.S. tax consequences that may be relevant to a decision to hold or dispose of Class B Shares or ADSs. This summary applies only to purchasers of Class B Shares or ADSs who will hold the Class B Shares or ADSs as capital assets and does not apply to special classes of holders such as brokers or dealers in securities or currencies, holders whose functional currency is not the U.S. dollar, holders of 10% or more of our shares by vote or value (taking into account shares held directly or through depositary arrangements), tax-exempt organizations, financial institutions, holders liable for the alternative minimum tax, securities traders who elect to account for their investment in Class B Shares or ADSs on a mark-to-market basis, regulated investment companies, partnerships or other pass-through entities (or partners or members therein), insurance companies, U.S. expatriates, and persons holding Class B Shares or ADSs in a hedging transaction or as part of a straddle, conversion or other integrated transaction for U.S. federal income tax purposes. Moreover, this summary does not address the Medicare tax on net investment income or the tax consequences to U.S. holders of acquiring, owning or disposing of Class B Shares or ADSs under any U.S. federal estate or gift, state, local or foreign taxes.

Each holder is encouraged to consult such holder’s tax advisor concerning the overall tax consequences to it, including the consequences under laws other than U.S. federal income tax laws, of an investment in Class B Shares or ADSs.

In this discussion, references to a “U.S. holder” are to a beneficial holder of a Class B Share or an ADS that is (i) an individual citizen or resident of the United States of America, (ii) a corporation, or any other entity taxable as a corporation, organized under the laws of the United States of America, any state thereof, or the District of Columbia, or (iii) otherwise subject to U.S. federal income taxation on a net basis with respect to the Class B Share or ADS.

For purposes of the U.S. Internal Revenue Code of 1986, as amended, which we call the “Code”, holders of ADSs will generally be treated as owners of the Class B Shares represented by such ADSs.

Taxation of Distributions

A U.S. holder will recognize dividend income for U.S. federal income tax purposes in an amount equal to the amount of any cash and the value of any property distributed by us as a dividend to the extent that such distribution is paid out of our current or accumulated earnings and profits, as determined for U.S. federal income tax purposes, when such distribution is received by the custodian (or by the U.S. holder in the case of a holder of Class B Shares).

We do not expect to maintain calculations of our earnings and profits in accordance with U.S. federal income tax principles. U.S. holders therefore should expect that distributions generally will be treated as dividends for U.S. federal income tax purpose.

If you are a U.S. holder, the amount of any distribution will include the amount of Brazilian tax withheld on the amount distributed, and the amount of a distribution paid in reais will be measured by reference to the exchange rate for converting reais into U.S. dollars in effect on the date the distribution is received by the custodian (or by a U.S. holder in the case of a holder of Class B Shares). If the custodian (or U.S. holder in the case of a holder of Class B Shares) does not convert such reais into U.S. dollars on the date it receives them, it is possible that the U.S. holder will recognize foreign currency loss or gain, which would be ordinary loss or gain, when the reais are converted into U.S. dollars. Dividends paid by us will not be eligible for the dividends received deduction allowed to corporations under the Code.

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Subject to certain exceptions for short-term and hedged positions, the U.S. dollar amount of dividends received by an individual, with respect to the ADSs, will be subject to taxation at preferential rates if the dividends are “qualified dividends”. Dividends paid on the ADSs will be treated as qualified dividends if (i) the ADSs are readily tradable on an established securities market in the United States and (ii) we were not, in the year prior to the year in which the dividend was paid, and are not, in the year in which the dividend is paid, a passive foreign investment company (“PFIC”). The ADSs are listed on the New York Stock Exchange, and will qualify as readily tradable on an established securities market in the United States so long as they are so listed. Based on our audited consolidated financial statements and relevant market and shareholder data, we believe that we were not treated as a PFIC for U.S. federal income tax purposes with respect to our 2018 and 2019 taxable years. In addition, based on our audited consolidated financial statements and our current expectations regarding the value and nature of our assets, the sources and nature of our income, and relevant market and shareholder data, we do not anticipate becoming a PFIC for the 2020 taxable year. Based on existing guidance, it is not clear whether dividends received with respect to the Class B Shares will be treated as qualified dividends, because the Class B Shares themselves are not listed on a U.S. exchange.Holders of ADSs and Class B Shares should consult their own tax advisers regarding the availability of the reduced dividend tax rate in the light of the considerations discussed above and their own particular circumstances.

Distributions with respect to the Class B Shares or ADSs generally will be treated as dividend income from sources outside of the United States and generally will be treated separately along with other items of “passive” income for purposes of determining the credit for foreign income taxes allowed under the Code. Subject to certain limitations, Brazilian income tax withheld in connection with any distribution, with respect to the Class B Shares or ADSs may be claimed as a credit against the U.S. federal income tax liability of a U.S. holder if such U.S. holder elects for that year to credit all foreign income taxes. Alternatively such Brazilian withholding tax may be taken as a deduction against taxable income. Foreign tax credits will not be allowed for withholding taxes imposed in respect of certain short-term or hedged positions and may not be allowed in respect of arrangements in which a U.S. holder’s expected economic profit, after non-U.S. taxes, is insubstantial. U.S. holders should consult their own tax advisors concerning the implications of these rules in light of their particular circumstances.

Distributions of additional shares to holders with respect to their Class B Shares or ADSs that are made as part of a pro rata distribution to all our shareholders generally will not be subject to U.S. federal income tax.

Holders of Class B Shares or ADSs that are foreign corporations or nonresident alien individuals, which we call “Non-U.S. Holders”, generally will not be subject to U.S. federal income tax or withholding tax on distributions with respect to Class B Shares or ADSs that are treated as dividend income for U.S. federal income tax purposes unless such dividends are effectively connected with the conduct by the holder of a trade or business in the United States.

Taxation of Capital Gains

Upon the sale or other disposition of a Class B Share or ADS, a U.S. holder will recognize gain or loss for U.S. federal income tax purposes. The amount of the gain or loss will be equal to the difference between the amount realized in consideration for the disposition of the Class B Share or ADS (including the gross amount of the proceeds before the deduction of any Brazilian tax) and the U.S. holder’s tax basis in the Class B Share or ADS. Such gain or loss generally will be subject to U.S. federal income tax as capital gain or loss and will be long-term capital gain or loss if the Class B Share or ADS has been held for more than one year on the date of the disposition. The net amount of long-term capital gain recognized by an individual holder generally is subject to taxation at preferential rates. Capital losses may be deducted from taxable income, subject to certain limitations. Gain realized by a U.S. holder on a sale or disposition of Class B Shares or ADSs generally will be treated as U.S. source income for U.S. foreign tax credit purposes. Consequently, if Brazilian tax is imposed on such gain, the U.S. holder will not be able to use the corresponding foreign tax credit, unless the holder has other foreign source income of the appropriate type in respect of which the credit may be used. Alternatively, such Brazilian tax may be taken as a deduction against taxable income if the U.S. holder does not take a credit for any foreign income tax during the taxable year.

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A Non-U.S. Holder will not be subject to U.S. federal income tax or withholding tax on gain realized on the sale or other disposition of a Class B Share or ADS unless (i) such gain is effectively connected with the conduct by the holder of a trade or business in the United States, or (ii) such holder is an individual who is present in the United States of America for 183 days or more in the taxable year of the sale and certain other conditions are met.

Foreign Financial Asset Reporting

Certain U.S. Holders that own “specified foreign financial assets” with an aggregate value in excess of US$50,000 on the last day of the taxable year or US$75,000 at any time during the taxable year are generally required to file an information statement along with their tax returns, currently on Form 8938, with respect to such assets. “Specified foreign financial assets” include any financial accounts held at a non-U.S. financial institution, as well as securities issued by a non-U.S. issuer that are not held in accounts maintained by financial institutions. The understatement of income attributable to “specified foreign financial assets” in excess of US$5,000 extends the statute of limitations with respect to the tax return to six years after the return was filed. U.S. Holders who fail to report the required information could be subject to substantial penalties. Prospective investors are encouraged to consult with their own tax advisors regarding the possible application of these rules, including the application of the rules to their particular circumstances.

Backup Withholding and Information Reporting

Dividends paid on, and proceeds from the sale or other disposition of, the ADSs or Class B Shares to a U.S. holder generally may be subject to the information reporting requirements of the Code and may be subject to backup withholding unless the U.S. holder (i) is a corporation or other exempt recipient or (ii) provides an accurate taxpayer identification number and certifies that no loss of exemption from backup withholding has occurred. The amount of any backup withholding collected from a payment to a U.S. holder will be allowed as a credit against the U.S. holder’s U.S. federal income tax liability and may entitle the U.S. holder to a refund, provided that certain required information is furnished to the Internal Revenue Service.

A Non-U.S. Holder generally will be exempt from these information reporting requirements and backup withholding tax, but may be required to comply with certain certification and identification procedures in order to establish its eligibility for such exemption in connection with payments received within the United States or through certain U.S.-related intermediaries.

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Dividends and Paying Agents

Not applicable.

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statement by experts

Not applicable.

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SUBSIDIARY INFORMATION

Not applicable.

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Documents on Display

We file reports, including annual reports on Form 20-F and other information with the SEC pursuant to the rules and regulations of the SEC that apply to foreign private issuers. We are required to make filings with the SEC by electronic means. Any filings we make electronically will be available to the public over the Internet at the SEC’s website.

For more information about our securities, see Exhibit 2.4 to this annual report.

Item 11. Quantitative and Qualitative Disclosures about Market Risk

See Note 36.2 to our audited consolidated financial statements for disclosure about market risk.

Item 12. Description of Securities Other than Equity Securities

Not applicable.

Item 12A. Debt Securities

Not applicable.

Item 12B. Warrants and Rights

Not applicable.

Item 12C. Other Securities

Not applicable.

Item 12D. American Depositary Shares

In the United States, the Class B Shares trade in the form of ADSs, each representing one Class B Share (as a result of the reverse stock split), issued by The Bank of New York Mellon (or the Depositary) pursuant to the Deposit Agreement. The ADSs trade under the symbols ELP and ELPVY. ADS holders are required to pay various fees to the Depositary, and the Depositary may refuse to provide any service for which a fee is assessed until the applicable fee has been paid. The Depositary is located at 240 Greenwich Street, New York, NY 10286.

ADS holders are required to pay the Depositary: (i) an annual fee of up to US$0.02 per ADS (or portion thereof) for administering the ADS program, and (ii) amounts in respect of expenses incurred by the Depositary or its agents on behalf of ADS holders, including expenses arising from compliance with applicable law, taxes or other governmental charges, facsimile transmission, or conversion of foreign currency into U.S. dollars. In both cases, the Depositary may decide in its sole discretion to seek payment by either billing holders or by deducting the fee from one or more cash dividends or other cash distributions.

ADS holders are also required to pay additional fees for certain services provided by the Depositary, as set forth in the table below.

Depositary service | Fee payable by ADS holders
Issuance of ADSs, including issuances resulting from a distribution of shares or rights or other property | US$5.00 or less per 100 ADSs (or portion thereof)
Cancellation of ADSs for the purpose of withdrawal, including if the deposit agreement terminates | US$5.00 or less per 100 ADSs (or portion thereof)
Distribution of cash dividends | US$0.02 or less per ADS

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Distribution of securities distributed to holders of deposited securities which are distributed by the depositary to ADS registered holders | A fee equivalent to the fee that would be payable if securities distributed to the holder had been shares and the shares had been deposited for issuance of ADSs
Depositary services | US$0.02 (or less) per ADSs per calendar year
Transfer and registration of shares on the Depositary’s share register to or from the name of the depositary or its agent when the holder deposits or withdraws shares | Registration or transfer fees
Cable, telex and facsimile transmissions (when expressly provided in the deposit agreement) | Expenses of the Depositary
Converting foreign currency to U.S. dollars | Expenses of the Depositary
Taxes and other governmental charges the Depositary or the custodian are required to pay on any ADS or share underlying an ADS (e.g., stock transfer taxes, stamp duty or withholding taxes) | As necessary
Any charges incurred by the Depositary or its agents for servicing the deposited securities | As necessary

Payments by the Depositary

The Depositary pays us an agreed amount, which includes reimbursements for certain expenses we incur in connection with the ADS program. These reimbursable expenses currently include legal and accounting fees, listing fees, investor relations expenses and fees payable to service providers for the distribution of material to ADR holders. For the year ended December 31, 2019, this amount was US$781,639.97 thousand.

Item 13. Defaults, Dividend Arrearages and Delinquencies

Not applicable.

Item 14. Material Modifications to the Rights of Security Holders and Use of Proceeds

None.

Item 15. Control and Procedures

2019 Fiscal Year

Disclosure Controls and Procedures, and Report on Internal Control over Financial Reporting

(a) Disclosure Control and Procedures

We evaluated the effectiveness of our disclosure controls and procedures as of December 31, 2019 with the participation of our Chief Executive Officer and Chief Financial Officer. Based on our assessment, we concluded that, as of December 31, 2019, because of the material weakness in our internal control over financial reporting discussed below, our disclosure controls and procedures were not effective in providing reasonable assurance that the information that we are required to disclose in the reports we present or submit under the Exchange Act is recorded, processed, summarized and reported, within the deadlines specified in the applicable rules and forms, and are accumulated and reported to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow for timely decisions regarding any required disclosure.

(b) Management Annual Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting and for evaluating the effectiveness of internal control over financial reporting. The process of internal controls over financial reporting is designed by our Chief Executive Officer and our Chief Financial Officer, under the supervision of our Board of Directors, and is carried out by our management and other employees as a means to provide reasonable assurance regarding the reliability of financial reporting and the preparation of consolidated financial statements for external purposes in accordance with IFRS, issued by the IASB.

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Rules 13a-15 (f) and 15d-15 (f) under the Exchange Act define internal control over financial reporting as a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for purposes external in accordance with generally accepted accounting principles, and includes policies and procedures that (1) refer to record keeping that, in reasonable detail, accurately and reasonably reflect the transactions and dispositions of the Company's assets; (2) provide reasonable assurance that transactions are recorded as necessary to enable the preparation of financial statements in accordance with generally accepted accounting principles, and that Company's receipts and expenses are being made only with authorization from Company's management and directors; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of Company's assets that could have a material effect on the audited consolidated financial statements.

Due to its inherent limitations, internal control over financial reporting may not prevent or detect distortions. In addition, projections of any assessment of effectiveness for future periods are subject to numerous risks, including that controls may become inadequate due to changes in conditions.

Our management’s assessment of the effectiveness of our internal controls over financial reporting as of December 31, 2019 was based on the criteria established in the Internal Control - Integrated Structure (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on such criteria, our management concluded that there is a material weakness in our internal control as of December 31, 2019.

A material weakness is a deficiency, or a combination of deficiencies, in the internal control over financial reporting, in such that there is a reasonable possibility that a material misstatement of Company's consolidated annual or interim financial statements will not be avoided or detected in a timely manner.

Our management concluded that our internal control over financial reporting was not effective as of December 31, 2019, because of the following material weakness identified and assessed by our management as of December 31, 2019:

Ineffective control related to the review of the assumptions and the calculation of impairment of fixed assets of Copel Telecomunicações, a wholly-owned subsidiary of the Company, and of UEGA, a non-wholly-owned subsidiary of the Company.

Company's management identified a failure in the operating effectiveness of the control related to the review of the assumptions and the calculation of impairment of fixed assets of Copel Telecomunicações and of UEGA.

Our independent registered public accounting firm has examined the effectiveness of our internal control of financial disclosure, as indicated in the report included in this document.

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(c) Attestation Report of the Registered Public Accounting Firm

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(d) Changes in Internal Control on Financial Reporting

Company's management did not identify any change in the internal control over financial reporting during the fiscal year ended December 31, 2019 that significantly affected or had a reasonable possibility to significantly affect the internal controls over financial reporting, except for the matter related to the material weakness mentioned above and with respect to the remediation plans related to the material weakness described below.

Remediation Plan for Material Weakness Identified as of December 31, 2019

Company's management is committed to remediating the material weakness referred to above. The remediation plan described herein is in the process of being implemented and is designed to directly address the identified material weakness.

As a preliminary measure, Company's management decided to implement a performance indicator to monitor remediation actions related to the identified material weakness including periodic reports to the Audit Committee, the Fiscal Council and the Board of Directors of the Company.

Ineffective control related to the review of the assumptions and the calculation of impairment of fixed assets of Copel Telecomunicações, a wholly-owned subsidiary of the Company, and of UEGA, a non-wholly-owned subsidiary of the Company.

This material weakness arises from dificiencies in the operating effectiveness of the control related to the review of the assumptions and the calculation of impairment of fixed assets of Copel Telecomunicações and UEGA.

The Company has established the following procedures:

| · | Additional training and communication to the employees involved in the processes, including internal control concepts, as well as operational aspects of impairment calculation;

| · | Implementation of procedures and controls so that all impairment tests are duly reviewed by another qualified employee of the Company, through a checklist created strictly for this purpose;

| · | Improvement of the controls and processes to carry out prior internal evaluation of all potential impacts of impairment indicators.

| · | Implementation of procedures and control so that all assumptions related to telecommunications assets and UEGA assets will be formally approved by the executive board of Copel Telecomunicações and UEGA.

Material Weakness identified as of 2018 Fiscal Year

Ineffective Controls on the Revenues of Copel Geração e Transmissão and Copel Telecomunicações, wholly-owned subsidiaries of the Company.

As of December 31, 2018, we reported a material weakness related to the result of the aggregation of deficiencies in internal controls on revenues in our wholly owned subsidiaries Copel Geração e Transmissão and Copel Telecomunicações. We identified deficiencies in the design and in the operating effectiveness of controls related to (1) the review of unbilled revenues, by professionals with adequate levels of authority and competence; (2) absence of controls to verify the accuracy of customer registration information, including with respect to invoiced prices; and (3) absence of controls verifying the completeness of the revenue invoicing of Copel Telecomunicações.

In response to this material weakness, the Company adopted measures to mitigate the risks associated with such material weaknesses that included a set of actions involving changes in procedures and controls that were implemented throughout 2019:

| • | Establishment of criteria for calculating the provision for unbilled revenues, including with respect to recalculations at Copel Geração e Transmissão and Copel Telecomunicações;

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| • | Intensification of training initiatives and internal communication procedures to reinforce operational aspects of activities related to the accounting of revenue balances in Copel Geração e Transmissão and Copel Telecomunicações;

| • | Improvement of controls in order to ensure that prices and quantities of contracted energy are duly invoiced at Copel Geração e Transmissão;

| • | Improvement of customer registration, prices and flow registration processes with the implementation of controls and procedures at Copel Telecomunicações;

| • | Improvement of internal system to control and certify the integration of information related to Copel Telecomunicações, so as to ensure that Company's revenue is appropriately reported in relation to all of its customers.

Remediation of Material Weaknesses Reported as of December 31, 2018

As a means to remedy material deficiencies identified as of December 31, 2018, Company's management incorporated a committee comprised of Company Directors, with the support of specialists representing each management department. The aim of the committee was to analyze and establish immediate actions to remedy the identified deficiencies and its measures were periodically reported to the Statutory Audit Committee, the Fiscal Council and the Board of Directors CAD throughout 2019.

The Company has continuously been working to improve its internal controls environment. With the support of a consultancy company specifically engaged to provide internal controls consultancy, Company’s management has successfully established action plans to mitigate risks, carrying out periodic communication with governance bodies.

As a result of the work carried out by Company’s management, all material weaknesses identified as of December 31, 2018 have now been remedied.

Item 16A. Audit Committee Financial Expert

In May 3, 2019, our Board of Directors reviewed the qualifications and backgrounds of the members of the Audit Committee and determined that Mr. Carlos Biedermann an “audit committee financial expert” within the meaning of Item 16A of Form 20-F and satisfied the requirements of independence of Rule 10A-3 under the Securities Exchange Act.. For more information regarding our Audit Committee, see “Item 6. Directors, Senior Management and Employees—Audit Committee”.

Item 16B. Code of Ethics

Our code of ethics, named as “Code of Conduct”, was first adopted in 2003, applicable to our chief executive officer, our executive financial officer and the main executives of our accounting department.

In 2015, our code was revised after an open consultation process that involved our internal staff and inputs from stakeholders. In this process, after the proposals were consolidated, the code was approved by our Management and by our Board of Officers. In 2017, an amendment to this code was approved by our Management and our Board of Directors to reflect new Brazilian regulation on conflict of interests and periodical training. In 2018, the Code of Ethics was revised and a new version was approved by the Board of Directors on March 13, 2018. In 2019, we began a new process of revising our Code of Ethics, through public consultation, with completion scheduled for the second half of 2020.

This code applies to all of our employees, board members, officers (including our Chief Executive Officer, our Chief Financial Officer and our officer in charge of our accounting department) and outsourced, as well as those of our wholly-owned subsidiaries. Our code is available on our website (ir.copel.com) and copies can also be delivered by mail upon a written request sent to the address provided on the cover page of this 20-F.

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As from the adoption of our code of ethics, we have not granted any implicit or explicit waivers to any sections of our code of ethics to the above-mentioned employees, board members, officers and outsourced.

Item 16C. Principal Accountant Fees and Services

Audit and Non-Audit Fees

Deloitte Touche Tohmatsu Auditores Independentes acted as our independent registered public accounting firm for the fiscal years ended December 31, 2019, 2018 and 2017.

The table next sets forth the total amount billed to Deloitte Touche Tohmatsu Auditores Independentes for services performed in 2019, 2018 and 2017, and breaks down these amounts by category of service.

| Year ended December 31,
Billed | 2019 | 2018 | 2017
| (R$million)
Audit fees | 3.0 | 3.9 | 3.9
Audit-related fees | - | - | -
Tax fees | 0.2 | 0.2 | 0.2
All other fees | - | 1.0 | -
Total | 3.2 | 5.1 | 4.1

Audit Fees

Audit fees are fees billed for the audit of our annual financial statements and for the reviews of our quarterly financial information in connection with statutory and regulatory filings or engagements.

Tax Fees

Tax fees are fees billed for the review of fiscal and tax procedures, including the examination of the procedures in force for the calculation, retention, registration, control, collection, recovery and accounting of taxes, including ancillary obligations.

All Other Fees

The services comprising the fees disclosed under “All Other Fees” refer to (i) the rendering of independent technical assistance and issuance of opinions in connection with the dispute with the Colíder Consortium, with respect to the “Agreement for the Supply of Goods and Services” for the Implementation of the Colíder HPP, and (ii) the analysis and issuance of an opinion in connection with the legal procedure aimed at reestablishing the economic and financial balance of said Agreement.

Audit Committee Pre-Approval Policies and Procedures

When hiring other services from its external auditors, the Company's practice provides for prior analysis by the Audit Committee of the Board of Directors, which must consider in this assessment whether a relationship or service provided by an independent auditor: (i) creates conflicting interests with your audit client; (ii) puts them in a position to audit their own work; (iii) results in acting as a manager or as an employee of the audit client; or (iv) puts them in a position of attorney for the audit client.

The Audit Committee also considers, in this type of assessment, whether any service provided by the independent auditing company may impair, in fact or apparently, the firm's independence. Whenever necessary, the Audit Committee can count on the technical support of the Internal Audit, or of an independent consultancy, for technical evaluation that may be required in each specific case, with discussions on the contracting of other services being recorded in the minutes of this collegiate meeting independent auditor.

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For more information regarding our Board of Directors and Audit Committee, see “Item 6. Directors, Senior Management and Employees”.

Item 16D. Exemption from the Listing Standards for Audit Committees

Under the listed company audit committee rules of the NYSE and the SEC, we must comply with Securities Exchange Act Rule 10A-3, which requires that we establish an audit committee composed of members of the board of directors that meets specified requirements. All five members of our Audit Committee rely on the exemption in Rule 10A-3(b)(iv)(E): (i) Mr. Carlos Biedermann, Mr. Marco Antônio Barbosa Cândido and Luiz Claudio Maia Vieira, who are designees of the State of Paraná, and (ii) Ms. Leila Abraham Loria and Ms. Olga Stankevicius Colpo, who are designees of minority shareholders. In our assessment, each of these members acts independently in performing the responsibilities of an audit committee member under the Sarbanes-Oxley Act and satisfies the other requirements of Securities Exchange Act Rule 10A-3. For more information regarding our Audit Committee, see “Item 6. Directors, Senior Management and Employees—Audit Committee”.

Item 16E. Purchases of Equity Securities by the Issuer and Affiliated Purchasers

None.

Item 16F. Changes in Registrant’s Certifying Accountant

Not applicable.

Item 16G. Corporate Governance

Section | New York Stock Exchange Corporate Governance Rules for U.S. Domestic Issuers | Copel’s Approach
Director Independence
303A.01 | A company listed on the New York Stock Exchange (a “listed company”) must have a majority of independent directors on its Board of Directors. “Controlled companies” are not required to comply with this requirement. | Copel fits the definition of a “controlled company” since the majority of its voting shares are held by the State of Paraná. As such, Copel would not be required to comply with the majority of independent directors requirement. However, Brazilian Law 13,303/2016 requires that at least 25% of our board members be independent members and according to Copel’s bylaws, meeting the requirements of B3's State-Owned Enterprises Governance Program, we are required to have a minimum of 30% of independent directors on Board of Directors.
303A.03 | The non-management directors of a listed company must meet at regularly scheduled executive sessions without management. | Copel's non-managing directors regularly hold executive sessions without management, which are usually scheduled to occur at the end of board meetings.. Our Chief Executive Officer is also a member of our board of directors. Pursuant to the internal regulations of our board of directors, in the event a conflict of interest or particular interest of any board member is identified in relation to a matter to be decided to be decided by the board, such board member must recuse himself from the meeting, which will continue without his presence.
Nominating/Corporate Governance Committee

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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, Copel would not be required to comply with the nominating/ corporate governance committee requirements. However, Brazilian Law 13,303 / 2016 requires Copel to keep a permanent statutory committee, advisory to the shareholders, and responsible for monitoring the nomination and evaluation processes applicable to our management, members of our board of directors, Supervisory Board and board committees. This committee is composed of members nominated by the shareholders.

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Compensation Committee
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. | Copel fits the definition of “controlled company”, as the majority of its voting shares are held by the State of Paraná. As a controlled company, Copel would not be required to comply with the compensation committee requirements if it were a U.S. domestic issuer.
Audit Committee
303A.06 303A.07 | A listed company must have an audit committee with a minimum of three (3) independent directors who satisfy the independence requirements of Rule 10A-3 under the Securities Exchange Act, with a written charter that covers certain minimum specified duties. | COPEL has a statutory Audit Committee composed of five board members (of whom three must satisfy the requirements set forth in Rule 10A-3 under the Securities Exchange Act and one must have professional experience in corporate accounting), each of whom serves a term of two years, and may be re-elected up to three consecutive times. One of the positions in our Audit Committee is currently vacant. Pursuant to the Audit Committee internal rules, the Audit Committee members are appointed by, and may be replaced by, the Board of Directors. All of the members of the Audit Committee are members of our Board of Directors. The Audit Committee is an advisory committee responsible for assisting our Board of Directors and giving its opinion on matters related to our financial and accounting management, risks, internal controls and audit, including, but not limited to, the quality, transparency and integrity of our financial statements, effectiveness of our internal controls with respect to the preparation of financial reports, as well as the activities, independence and quality of the work of our external and internal auditors.
Equity Compensation Plans
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 pre-approval is required for the adoption of any equity compensation plans and material revisions thereto.
Corporate Governance Guidelines
303A.09 | A listed company must adopt and disclose corporate governance guidelines that cover certain minimum specified subjects. | Although the corporate governance practices adopted by Copel do not comply with all the terms specified in the rules of the NYSE, they fulfill the requirements established for companies listed on level 1 of corporate governance of B3 (Brasil, Bolsa, Balcão). The Company also adopts the Code of Better Corporate Governance Practices of the Brazilian Institute for Corporate Governance (”IBGC”) and was granted with a certification under the State-Owned Enterprise Governance Program of B3 (Brasil, Bolsa, Balcão) with the maximum score, being the only company in Brazil to obtain this result.
Code of Ethics for Directors, Officers and Employees

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303A.10 | A listed company must adopt and disclose a code of business conduct and ethics for its directors, officers and employees, and must promptly disclose any waivers of the code for directors or executive officers. | Copel has adopted a code of ethics that applies to all members of the board of directors, the Supervisory Board, the executive board and employees.
Certification Requirements
303A.12 | A CEO of a listed company must promptly notify the NYSE in writing after any executive officer of the listed company becomes aware of any material non-compliance with any applicable provisions of Section 303A and certify he or she is not aware of any violation by the listed company of NYSE corporate governance listing standards, qualifying the certification to the extent necessary. Each listed company must submit an executed Written Affirmation annually to the NYSE. In addition, each listed company must submit an interim Written Affirmation as and when required by the interim Written Affirmation form specified by the NYSE. | Copel’s CEO will promptly notify the NYSE in writing after any executive officer of Copel becomes aware of any material non-compliance with any applicable provisions of the NYSE corporate governance rules and will also certify if he is not aware of any violation by the listed company of NYSE corporate governance listing standards. Copel submits every year an Annual Written Affirmation to the NYSE and will submit an interim Written Affirmation when required.

Item 17. Financial Statements

Not applicable.

Item 18. Financial Statements

Reference is made to pages F-1 through F-143.

Item 19. Exhibits

1.1 | Corporate Bylaws approved and consolidated by the 187th Extraordinary Shareholders Meeting, of October 10, 2013, and amended by the 190th Extraordinary Shareholders meeting, of April 23, 2015, and by the 193rd Extraordinary Shareholders meeting of December 22, 2016, and by the 195th Extraordinary Shareholders meeting of June 7, 2017, and by the 197th Extraordinary Shareholders meeting of June 28, 2018 , and by the 199th Extraordinary Shareholders meeting of April 29, 2019, and by the 200th Extraordinary Shareholders meeting of December 02, 2019, incorporated by reference to Exhibit 1.1 to Copel’s annual report on Form 20-F dated April 27, 2020 (File Nos. 001-14668, Accession No. 0001292814-20-001451).
2.1 | Deposit Agreement (preferred shares) dated as of March 21, 1996, as amended and restated as of November 21, 2007, filed with the SEC on February 12, 2009 as an exhibit to our Registration Statement on Form F-6 and incorporated herein by reference (File No. 333-157278).

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2.4 | Description of Securities registered under Section 12 of the Exchange Act, incorporated by reference to Exhibit 2.4 to Copel’s annual report on Form 20-F dated April 27, 2020 (File Nos. 001-14668, Accession No. 0001292814-20-001451).
4.1 | The Adjustment Agreement of August 4, 1994 between the State of Paraná and Companhia Paranaense de Energia ‒ Copel (“Adjustment Agreement”) (incorporated by reference to our Form F-1 333-7148, filed with the SEC on June 30, 1997), the Deed of Amendment to the Adjustment Agreement (Quarto Termo Aditivo ao Termo de Ajuste celebrado em 21 de janeiro de 2005) (English translation) (incorporated by reference to our annual report on Form 20-F for the year ended December 31, 2005, filed with the SEC on June 30, 2006) (File No. 001-14668), and the Deed of Amendment to the Adjustment Agreement (Quinto Termo Aditivo ao Termo de Ajuste celebrado em 31 de outubro de 2017) (English translation).
8.1 | List of subsidiaries, incorporated by reference to Exhibit 8.1 to Copel’s annual report on Form 20-F dated April 27, 2020 (File Nos. 001-14668, Accession No. 0001292814-20-001451).
12.1 | Certification of the Chief Executive Officer of Copel, pursuant to Rules 13a-14 and 15d-14 under the Securities Exchange Act of 1934.
12.2 | Certification of the Chief Financial Officer of Copel, pursuant to Rules 13a-14 and 15d-14 under the Securities Exchange Act of 1934.
13.1 | Certification of Chief Executive Officer of Copel, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
13.2 | Certification of the Chief Financial Officer of Copel, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS | XBRL Instance Document.
101.SCH | XBRL Taxonomy Extension Schema Document.
101. CAL | XBRL Taxonomy Extension Calculation Linkbase Document.
101. DEF | XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB | XBRL Taxonomy Extension Label Linkbase Document.
101.PRE | XBRL Taxonomy Extension Presentation Linkbase Document.

We omitted from the exhibits filed with or incorporated by reference into this annual report certain promissory notes and other instruments and agreements with respect to our long-term debt, none of which authorizes securities in a total amount that exceeds 10% of our total assets. We hereby agree to furnish to the Securities and Exchange Commission copies of any such omitted promissory notes or other instruments or agreements as the Commission requests.

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technical GLOSSARY

2013 Concession Renewal Law: Brazilian Law No. 12,783 enacted on January 11, 2013, under which most generation, transmission and distribution concessionaires may be renewed at the request of the concessionaire for an additional period of 30 years, but only if the concessionaire agrees to amend the terms of the concession contract to reflect a new tariff regime to be established by ANEEL.

A-3 Auctions: The denomination of electricity auctions for new generation projects being held in the regulated Brazilian market in the third year before the initial delivery date.

A-5 Auctions: The denomination of electricity auctions for new generation projects being held in the regulated Brazilian market in the fifth year before the initial delivery date.

ADRs: American Depositary Receipts.

ADSs: American Depositary Shares, each representing one Class B Share.

ANATEL: The Brazilian National Telecommunication Agency, or the Agência Nacional de Telecomunicações.

ANEEL: The Brazilian Electricity Regulatory Agency, or the Agência Nacional de Energia Elétrica.

Annual Permitted Revenues: The annual revenue established by ANEEL to be charged by a transmission concessionaire for the use of its transmission lines by third parties, which include Free Customers, generators and distributors, or Receita Anual Permitida - RAP.

Assured Energy: Determined amount assigned to each hydroelectric plant according to the energy supply risk criteria defined by MME. The assured energy also represents the maximum energy that can be sold by the generator, which is set forth in each concession agreement, irrespective of the volume of electricity actually generated by the facility.

Availability Agreement: Agreement under which a generator commits to making a certain amount of electrical capacity available to the Regulated Market. In such case, the generator’s revenue is guaranteed and the distributors must bear the risk of a supply shortage.

Average Tariff or Rate: Total sales revenue divided by total megawatt hours (MWh) sold for each relevant period, including in the case of the Company, unbilled electricity, or electricity which has been delivered to a customer, but for which the utility has yet to deliver a bill. Total sales revenue, for the purpose of computing average tariff or rate, includes both gross billings before deducting value-added tax and unbilled electricity sales upon which such taxes have not yet accrued.

Bilateral Agreement: Legal instrument that formalizes the purchase and sale of electric energy between Agents of the Chamber of Commercialization of Electric Energy - CCEE, with the purpose of establishing prices, terms and amounts of supply at determined time intervals.

B3 (Brasil, Bolsa, Balcão): B3 S.A. - Brasil, Bolsa, Balcão, the securities, commodities and futures exchange, headquartered in São Paulo, Brazil, incoporated as a resulto f the merger of BM&FBOVESPA S.A. – Bolsa de Valores, Mercadorias e Futuros and CETIP S.A. – Mercados Organizados.

Captive Customers: customers whose energy is supplied by the distributor in which the consumer unit is connected, such as that the amount paid already includes the energy cost and service cost for use of transmission and distribution - wire service. The consumer is not free to negotiate the conditions and the flexibility of energy supplied to meet the needs of its business, instead having to follow the determinations set forth by the distributor. The consumer is subject to the unpredictability of the annual variation of the value of the distributors’ tariffs.

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CBLC: The Companhia Brasileira de Liquidação e Custódia.

CER: Reserve Energy Contract (Contrato de Energia Reserva).

Central Bank: The Brazilian Central Bank, or Banco Central do Brasil.

Class A Shares: The Company’s class A preferred shares.

Class B Shares: The Company’s class B preferred shares.

CMN: The National Monetary Council of Brazil, or Conselho Monetário Nacional.

Code: The U.S. Internal Revenue Code of 1986, as amended.

Common Shares: The Company’s common shares.

Copel Distribuição S.A.: The Company’s entity engaged in the distribution business.

Copel Geração e Transmissão S.A. or Copel GeT: The Company’s entity engaged in the generation and transmission business.

CRC Account: The recoverable rate deficit account, or Conta de Resultados a Compensar.

Custodian: Itaú Unibanco S.A., as custodian for the Class B Shares represented by ADSs.

Decree No. 6,306/07: Brazilian tax Decree No. 6,306 dated December 14, 2007, which regulates tax on credit, exchange and insurance, or relating to securities - IOF.

Deloitte: Deloitte Touche Tohmatsu Auditores Independentes.

Deposit Agreement: A Deposit Agreement between Copel, the Depositary and the registered holders and beneficial owners from time to time of the ADSs.

Depositary: The Bank of New York Mellon, as depositary.

Distribution: The transfer of electricity from the transmission lines at grid supply points and its delivery to customers through distribution lines at voltages between 13.8 kV and 44 kV.

Distributor: An entity supplying electrical energy to a group of customers by means of a distribution network.

Elejor: Centrais Elétricas do Rio Jordão S.A.

Eletrosul: Eletrosul Centrais Elétricas S.A.

Energy Agreement: Agreement under which a generator commits to supply a certain amount of electricity and assumes the risk that its electricity supply could be adversely affected by hydrological conditions and low reservoir levels, which could interrupt the supply of electricity. In such case, the generator would be required to purchase electricity elsewhere in order to comply with its supply commitments.

Final Customer: A party that uses electricity for its own needs.

FINEP: The Brazilian Studies and Projects Funding Agency or Financiadora de Estudos e Projetos.

Free Customers: Electricity customers that are able to choose their own power suppliers since they meet the following requirements: (i) demand of at least 3 MW at any voltage for new customers (those connected to the distribution grid after July 1995); (ii) demand of at least 3 MW and supplied at voltage levels

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equal to or greater than 69 kV for existing customers (those connected to the distribution grid before July 1995); and (iii) demand of at least 500 kW and that opt to be supplied energy by means of alternative sources, such as wind power projects, small hydroelectric power plants or biomass projects (also known as Special Customers).

Free Market: Market segment that permits a certain degree of competition. The Free Market specifically contemplates purchase of electricity by non-regulated entities such as Free Customers and energy traders.

Furnas: Furnas Centrais Elétricas S.A

Generating Unit: An electric generator together with the turbine or other device that drives it.

Gigawatt (GW): One billion watts.

Gigawatt hour (GWh): One gigawatt of power supplied or demanded for one hour, or one billion watt hours.

GPON: Gigabit-Capable Passive Optical Networks - A passive optical network (PON) is a system that brings optical fiber cabling and signals all or most of the way to the end user. Depending on where the PON terminates, the system can be described as fiber-to-the-curb (FTTC), fiber-to-the-building (FTTB), or fiber-to-the-home (FTTH). Passive Optical Network: A point-to-multipoint, passive fiber network architecture in which a single fiber utilizes optical splitters to serve multiple premises. Gigabit PON: Based on the previous PON types, GPON supports higher data rates and increased security, and has been deployed around the world by major telecom operators.

Group A Customers: A group of customers that uses electricity at 2.3 kV or higher. Tariffs applied to this group are based on the actual voltage level at which energy is supplied and the time of day and year the energy is supplied.

Group B Customers: A group of customers that uses electricity at less than 2.3 kV. Tariffs applied to this group are comprised solely of an energy charge and are based on the classification of the customer.

High Voltage: A class of nominal system voltages equal to or greater than 69,000 volts and less than 230,000 volts.

HPP – Hydroelectric Power Plant: A generating unit that uses water power to drive the electric generator.

IASB: International Accounting Standards Board.

IFRS: International Financial Reporting Standards.

IGP-DI: The Índice Geral de Preços—Disponibilidade Interna inflation index.

IGP-M Index: The Brazilian General Market Price inflation index, or the Índice Geral de Preços do Mercado.

Installed Capacity: The level of electricity that can be delivered from a particular generating unit on a full-load continuous basis under specified conditions as designated by the manufacturer.

Interconnected Transmission System: Systems or networks for the transmission of energy, connected together by means of one or more lines and transformers.

IPCA: Índice Nacional de Preços ao Consumidor Amplo - IPCA inflation index.

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IPP: Independent Power Producer, a legal entity or consortium holding a concession or authorization for power generation for sale for its own account to public Utility concessionaires or Free Customers.

Itaipu: Itaipu Binacional, a hydroelectric facility equally owned by Brazil and Paraguay, with an installed capacity of 14,000 MW.

Kilovolt (kV): One thousand volts.

Kilowatt (kW): One thousand watts.

Kilowatt hour (kWh): One kilowatt of power supplied or demanded for one hour, or one thousand watt hours.

Latibex: A Euro-based market for Latin American securities, which is part of the Madrid Stock Exchange.

Low-income Residential Customers: A group of customers that consumes less than 220 kWh per month and has filed an application to receive benefits under any of the federal government’s social programs. Low-income residential customers are considered a subgroup of residential customers and are not subject to payment of emergency capacity and emergency acquisition charges or any extraordinary tariff approved by ANEEL.

Main Transmission Concession: transmission concession contract No. 060/2001 comprised of different transmission assets that were in operation in the year of 2001 (date of execution of the concession agreement).

MCSD: The Mechanism for Compensation of Surpluses and Deficits (Mecanismo de Compensação de Sobras e Déficits), which corresponds to the p rocess of reallocation of energy surpluses and deficits undertaken in accordance with the Regulated Contracting Environment – ACR among the distribution agents that participate in CCEE.

MCSD-EN: The Mechanism for Compensation of Surpluses and Deficits of New Energy (Mecanismo de Compensação de Sobras e Déficits de Energia Nova), which allows distribution agents to offset amounts of electric energy and power acquired in auctions of new generation projects, and allows the reduction of amounts contracted with generating agents bound to new generation ventures.

Megawatt (MW): One million watts.

Megawatt hour (MWh): One megawatt of power supplied or demanded for one hour, or one million watt hours.

MME: The Brazilian Ministry of Mines and Energy, or the Ministério de Minas e Energia.

MRE: The Energy Reallocation Mechanism is a mechanism which attempts to mitigate the risks borne by hydroelectric generators due to variations in river flows (hydrological risk).

MVE: The Mechanism of Surplus Sales (Mecanismo de Venda de Excedentes), which allows distribution companies to sell energy surpluses and, in the case of sales related to amounts within the regulatory limits or involuntary overcontracting, allows distribution companies to revert the acquired benefit to consumers through tariff adjustments.

Non-Brazilian Holder: An individual, entity, trust or organization resident or domiciled outside Brazil for purposes of Brazilian taxation that acquires, owns and disposes of Class B Shares or ADSs.

ONS: The National Electric System Operator, or the Operador Nacional do Sistema Elétrico.

RAP or APR: Annual Permitted Revenues (or Receita Anual Permitida).

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Rationing Program: A program instituted by the Brazilian government to reduce electricity consumption, in effect from June 1, 2001 to February 28, 2002, given it was a period of low rainfall in Brazil.

Real, Reais or R$: Brazilian reais (plural) and the Brazilian real (singular).

Regulated Market: Market segment in which distribution companies purchase all the electricity needed to supply customers through public auctions. The auction process is administered by ANEEL, either directly or through CCEE, under certain guidelines provided by the MME. The regulated market is generally considered to be more stable in terms of supply of electricity.

Regulatory Remuneration Base: The aggregate amount of investments made by the distribution companies in connection with the services compensated by tariffs charged to consumers (Base de Remuneração Regulatória).

Reserve Energy Auction: mechanism for the contracting of reserve energy created to increase the security in the supplied of energy by the National Interconnected System (SIN). The reserve auction acts as an insurance contracted by distributors to be used when there is a mismatch between forecasted demand and supply. This modality of contracting is formalized through the conclusion of the CER between the selling agents in the auctions and the CCEE.

Retail Tariff: Revenue charged by distribution companies to its customers. Each customer falls within a certain tariff level defined by law and based on the customer’s classification, although some flexibility is available according to the nature of each customer’s demand. Retails tariffs are subject to annual revision by ANEEL.

RGR Fund: A reserve fund designed to provide compensatory payments to energy companies for certain assets used in connection with a concession if the concession is revoked or is not renewed.

Sanepar: Companhia de Saneamento do Paraná – Sanepar.

Securities Act: The United States Securities Act of 1933, as amended.

Securities Exchange Act: The United States Securities Exchange Act of 1934, as amended.

Sercomtel Telecomunicações: Sercomtel Telecomunicações S.A.

SHP ‒ Small Hydroelectric Plant: Hydroelectric plants with generating capacity between 1,000 kW and 30,000 kW with a reservoir covering an area equal to or less than 3.0 km2.

Special Customers: A group of customers that uses at least 500 kV. A Special Customer may choose its energy supplier if that supplier derives its energy from alternative sources, such as small hydroelectric plants, wind plants or biomass plants.

Spot Market: Deregulated market segment in which electricity is bought or sold for immediate delivery. In general, prices of spot market energy purchases tend to be substantially higher than the price of energy under long-term energy purchase agreements.

Substation: An assemblage of equipment, which switches and/or changes or regulates the voltage of electricity in a transmission and distribution system.

Tax Haven Holder: A shareholder situated in tax haven jurisdictions (that is, a country or location that does not impose income tax or where the maximum income tax rate is lower than 20% (or 17%, as the case may be) or where the local legislation imposes restrictions on disclosing the shareholding composition or the ownership of the investment or the beneficial owner of the income derived from transactions carried out and attributable to a Non-Brazilian Holder). The list of tax haven jurisdictions is currently provided in Normative Ruling No. 1,037.

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Thermoelectric Power Plant or TPP: A generating unit which uses combustible fuel, such as coal, oil, diesel natural gas or other hydrocarbon as the source of energy to drive the electric generator.

TJLP: The Long-Term Interest Rate, or the Taxa de Juros a Longo Prazo, the Brazilian federal government’s long-term interest rate.

Transmission: The bulk transfer of electricity from generating facilities to the distribution grid at load center station by means of the transmission grid (in lines with capacity between 69 kV and 525 kV).

Transmission Tariff: Revenue charged by a transmission concessionaire based on the transmission network it owns and operates. Transmission tariffs are subject to periodic revisions by ANEEL.

TUST: The tariff established by ANEEL for the use of the transmission system, which is the Interconnected Transmission System and its ancillary facilities.

U.S. Dollars, dollars, or US$: United States dollars.

U.S. Holder: A beneficial holder of a Class B Share or an ADS that is (i) an individual citizen or resident of the United States of America, (ii) a corporation, or any other entity taxable as a corporation, organized under the laws of the United States of America, any state thereof, or the District of Columbia, or (iii) otherwise subject to U.S. federal income taxation on a net basis with respect to the Class B Share or ADS.

Utility: An entity that is the holder of a concession or authorization to engage in the generation, transmission or distribution of electric energy in Brazil.

Volt: The basic unit of electric force analogous to water pressure in pounds per square inch.

Watt: The basic unit of electrical power.

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Signatures

The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F/A and that it has duly caused and authorized the undersigned to sign this annual report on its behalf.

Companhia Paranaense De Energia – Copel

By:/s/ Daniel Pimentel Slaviero

Name: Daniel Pimentel Slaviero

Title: Chief Executive Officer

By: /s/ Adriano Rudek de Moura

Name: Adriano Rudek de Moura

Title: Chief Financial and Investor Relations Officer

Date: November 18, 2020

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