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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
(Mark One)

☒ | Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended June 30, 2022
or

☐ | Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
| For the transition period from ______________ to ______________

Commission File Number 1-3548
ALLETE, Inc.
(Exact name of registrant as specified in its charter)

Minnesota |  | 41-0418150
(State or other jurisdiction of incorporation or organization) |  | (IRS Employer Identification No.)

30 West Superior Street
Duluth, Minnesota 55802-2093
(Address of principal executive offices)
(Zip Code)
(218) 279-5000
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:

Title of each class | Trading symbol | Name of each exchange on which registered
Common Stock, without par value | ALE | New York Stock Exchange

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 during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). ☒ Yes ☐ No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer ☒ Accelerated Filer ☐
Non-Accelerated Filer ☐ Smaller Reporting Company ☐
Emerging Growth Company ☐
If an emerging growth company, 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. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes ☒ No
Common Stock, without par value,
57,071,967 shares outstanding
as of June 30, 2022

Index

Definitions | 3
Forward-Looking Statements | 5
Part I. | Financial Information |
| Item 1. | Consolidated Financial Statements - Unaudited | 6
|  | Consolidated Balance Sheet | 6
|  | Consolidated Statement of Income | 7
|  | Consolidated Statement of Comprehensive Income | 8
|  | Consolidated Statement of Cash Flows | 9
|  | Consolidated Statement of Equity | 10
|  | Notes to Consolidated Financial Statements | 11
|  | Note 1. Operations and Significant Accounting Policies | 11
|  | Note 2. Regulatory Matters | 14
|  | Note 3. Acquisitions | 16
|  | Note 4. Equity Investments | 17
|  | Note 5. Fair Value | 17
|  | Note 6. Short-Term and Long-Term Debt | 19
|  | Note 7. Commitments, Guarantees and Contingencies | 20
|  | Note 8. Earnings Per Share and Common Stock | 26
|  | Note 9. Income Tax Expense | 26
|  | Note 1 0. Pension and Other Postretirement Benefit Plans | 28
|  | Note 1 1. Business Segments | 28
| Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 30
|  | Comparison of the Quarters Ended | 32
|  | Comparison of the Six Months Ended | 36
|  | Critical Accounting Policies | 39
|  | Outlook | 40
|  | Liquidity and Capital Resources | 42
|  | Other | 44
| Item 3. | Quantitative and Qualitative Disclosures about Market Risk | 45
| Item 4. | Controls and Procedures | 45
Part II. | Other Information |
| Item 1. | Legal Proceedings | 46
| Item 1A. | Risk Factors | 46
| Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 46
| Item 3. | Defaults Upon Senior Securities | 46
| Item 4. | Mine Safety Disclosures | 46
| Item 5. | Other Information | 46
| Item 6. | Exhibits | 47
Signatures | 48

ALLETE, Inc. Second Quarter 2022 Form 10-Q
2

Definitions
The following abbreviations or acronyms are used in the text. References in this report to “we,” “us” and “our” are to ALLETE, Inc., and its subsidiaries, collectively.

Abbreviation or Acronym | Term
AFUDC | Allowance for Funds Used During Construction – the cost of both debt and equity funds used to finance regulated utility plant additions during construction periods
ALLETE | ALLETE, Inc.
ALLETE Clean Energy | ALLETE Clean Energy, Inc. and its subsidiaries
ALLETE Properties | ALLETE Properties, LLC and its subsidiaries
ALLETE South Wind | ALLETE South Wind, LLC
ALLETE Transmission Holdings | ALLETE Transmission Holdings, Inc.
ArcelorMittal | ArcelorMittal S.A.
ATC | American Transmission Company LLC
Bison | Bison Wind Energy Center
BNI Energy | BNI Energy, Inc. and its subsidiary
Boswell | Boswell Energy Center
Cliffs | Cleveland-Cliffs Inc.
Company | ALLETE, Inc. and its subsidiaries
COVID-19 | 2019 novel coronavirus
CSAPR | Cross-State Air Pollution Rule
DC | Direct Current
EPA | United States Environmental Protection Agency
ESOP | Employee Stock Ownership Plan
FERC | Federal Energy Regulatory Commission
Form 10-K | ALLETE Annual Report on Form 10-K
Form 10-Q | ALLETE Quarterly Report on Form 10-Q
GAAP | Generally Accepted Accounting Principles in the United States of America
GHG | Greenhouse Gases
Hibbing Taconite | Hibbing Taconite Co.
Invest Direct | ALLETE’s Direct Stock Purchase and Dividend Reinvestment Plan
IRP | Integrated Resource Plan
Item ___ | Item ___ of this Form 10-Q
kW / kWh | Kilowatt(s) / Kilowatt-hour(s)
Laskin | Laskin Energy Center
Lampert Capital Markets | Lampert Capital Markets, Inc.
Minnesota Power | An operating division of ALLETE, Inc.
Minnkota Power | Minnkota Power Cooperative, Inc.
MISO | Midcontinent Independent System Operator, Inc.
MMTP | Manitoba-Minnesota Transmission Project
Moody’s | Moody’s Investors Service, Inc.
MPCA | Minnesota Pollution Control Agency
MPUC | Minnesota Public Utilities Commission
MW / MWh | Megawatt(s) / Megawatt-hour(s)
NAAQS | National Ambient Air Quality Standards
New Energy | New Energy Equity LLC
Nobles 2 | Nobles 2 Power Partners, LLC
NOL | Net Operating Loss

ALLETE, Inc. Second Quarter 2022 Form 10-Q
3

Abbreviation or Acronym | Term
NO X | Nitrogen Oxides
Northshore Mining | Northshore Mining Company, a wholly-owned subsidiary of Cleveland-Cliffs Inc.
Note ___ | Note ___ to the Consolidated Financial Statements in this Form 10-Q
NPDES | National Pollutant Discharge Elimination System
NTEC | Nemadji Trail Energy Center
PPA / PSA | Power Purchase Agreement / Power Sales Agreement
PPACA | Patient Protection and Affordable Care Act of 2010
PSCW | Public Service Commission of Wisconsin
SEC | Securities and Exchange Commission
Silver Bay Power | Silver Bay Power Company, a wholly-owned subsidiary of Cleveland-Cliffs Inc.
SO 2 | Sulfur Dioxide
Square Butte | Square Butte Electric Cooperative, a North Dakota cooperative corporation
South Shore Energy | South Shore Energy, LLC
ST Paper | ST Paper LLC
SWL&P | Superior Water, Light and Power Company
Taconite Harbor | Taconite Harbor Energy Center
U.S. | United States of America
USS Corporation | United States Steel Corporation

ALLETE, Inc. Second Quarter 2022 Form 10-Q
4

Forward-Looking Statements
Statements in this report that are not statements of historical facts are considered “forward-looking” and, accordingly, involve risks and uncertainties that could cause actual results to differ materially from those discussed. Although such forward-looking statements have been made in good faith and are based on reasonable assumptions, there can be no assurance that the expected results will be achieved. Any statements that express, or involve discussions as to, future expectations, risks, beliefs, plans, objectives, assumptions, events, uncertainties, financial performance, or growth strategies (often, but not always, through the use of words or phrases such as “anticipates,” “believes,” “estimates,” “expects,” “intends,” “plans,” “projects,” “likely,” “will continue,” “could,” “may,” “potential,” “target,” “outlook” or words of similar meaning) are not statements of historical facts and may be forward-looking.
In connection with the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, we are providing this cautionary statement to identify important factors that could cause our actual results to differ materially from those indicated in forward-looking statements made by or on behalf of ALLETE in this Form 10-Q, in presentations, on our website, in response to questions or otherwise. These statements are qualified in their entirety by reference to, and are accompanied by, the following important factors, in addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements that could cause our actual results to differ materially from those indicated in the forward-looking statements:
•our ability to successfully implement our strategic objectives;
•global and domestic economic conditions affecting us or our customers;
•changes in and compliance with laws and regulations or changes in tax rates or policies;
•changes in rates of inflation or availability of key materials and supplies;
•the outcome of legal and administrative proceedings (whether civil or criminal) and settlements;
•weather conditions, natural disasters and pandemic diseases, including the ongoing COVID-19 pandemic;
•our ability to access capital markets, bank financing and other financing sources;
•changes in interest rates and the performance of the financial markets;
•project delays or changes in project costs;
•changes in operating expenses and capital expenditures and our ability to raise revenues from our customers;
•the impacts of commodity prices on ALLETE and our customers;
•our ability to attract and retain qualified, skilled and experienced personnel;
•effects of emerging technology;
•war, acts of terrorism and cybersecurity attacks;
•our ability to manage expansion and integrate acquisitions;
•population growth rates and demographic patterns;
•wholesale power market conditions;
•federal and state regulatory and legislative actions that impact regulated utility economics, including our allowed rates of return, capital structure, ability to secure financing, industry and rate structure, acquisition and disposal of assets and facilities, operation and construction of plant facilities and utility infrastructure, recovery of purchased power, capital investments and other expenses, including present or prospective environmental matters;
•effects of competition, including competition for retail and wholesale customers;
•effects of restructuring initiatives in the electric industry;
•the impacts on our businesses of climate change and future regulation to restrict the emissions of GHG;
•effects of increased deployment of distributed low-carbon electricity generation resources;
•the impacts of laws and regulations related to renewable and distributed generation;
•pricing, availability and transportation of fuel and other commodities and the ability to recover the costs of such commodities;
•our current and potential industrial and municipal customers’ ability to execute announced expansion plans;
•real estate market conditions where our legacy Florida real estate investment is located may deteriorate; and
•the success of efforts to realize value from, invest in, and develop new opportunities.
Additional disclosures regarding factors that could cause our results or performance to differ from those anticipated by this report are discussed in Part I, Item 1A. Risk Factors of our 2021 Form 10-K and Part II, Item 1A. Risk Factors of this Form 10-Q. Any forward-looking statement speaks only as of the date on which such statement is made, and we undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which that statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time, and it is not possible for management to predict all of these factors, nor can it assess the impact of each of these factors on the businesses of ALLETE or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement. Readers are urged to carefully review and consider the various disclosures made by ALLETE in this Form 10-Q and in other reports filed with the SEC that attempt to identify the risks and uncertainties that may affect ALLETE’s business.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
5

PART I. FINANCIAL INFORMATION
ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS
ALLETE
CONSOLIDATED BALANCE SHEET
Unaudited

| June 30, 2022 |  | December 31, 2021
Millions |  |  |
Assets |  |  |
Current Assets |  |  |
Cash and Cash Equivalents | $74.6 |  |  | $45.1 |
Accounts Receivable (Less Allowance of $1.8 and $1.8) | 116.2 |  |  | 123.7 |
Inventories – Net | 355.8 |  |  | 97.7 |
Prepayments and Other | 113.4 |  |  | 24.8 |
Total Current Assets | 660.0 |  |  | 291.3 |
Property, Plant and Equipment – Net | 5,027.1 |  |  | 5,100.2 |
Regulatory Assets | 470.9 |  |  | 511.8 |
Equity Investments | 322.0 |  |  | 318.0 |
Goodwill and Intangible Assets – Net | 151.1 |  |  | 0.8 |
Other Non-Current Assets | 207.9 |  |  | 212.9 |
Total Assets | $6,839.0 |  |  | $6,435.0 |
Liabilities and Equity |  |  |
Liabilities |  |  |
Current Liabilities |  |  |
Accounts Payable | $134.8 |  |  | $111.0 |
Accrued Taxes | 52.7 |  |  | 65.1 |
Accrued Interest | 20.3 |  |  | 20.1 |
Long-Term Debt Due Within One Year | 390.5 |  |  | 214.2 |
Other | 110.7 |  |  | 133.0 |
Total Current Liabilities | 709.0 |  |  | 543.4 |
Long-Term Debt | 1,595.6 |  |  | 1,763.2 |
Deferred Income Taxes | 181.8 |  |  | 185.7 |
Regulatory Liabilities | 532.6 |  |  | 536.1 |
Defined Benefit Pension and Other Postretirement Benefit Plans | 174.6 |  |  | 179.5 |
Other Non-Current Liabilities | 286.5 |  |  | 280.8 |
Total Liabilities | 3,480.1 |  |  | 3,488.7 |
Commitments, Guarantees and Contingencies (Note 7) |  |  |
Equity |  |  |
ALLETE Equity |  |  |
Common Stock Without Par Value, 80.0 Shares Authorized, 57.1 and 53.2 Shares Issued and Outstanding | 1,771.7 |  |  | 1,536.7 |
Accumulated Other Comprehensive Loss | (23.9) |  |  | (23.8) |
Retained Earnings | 932.6 |  |  | 900.2 |
Total ALLETE Equity | 2,680.4 |  |  | 2,413.1 |
Non-Controlling Interest in Subsidiaries | 678.5 |  |  | 533.2 |
Total Equity | 3,358.9 |  |  | 2,946.3 |
Total Liabilities and Equity | $6,839.0 |  |  | $6,435.0 |

The accompanying notes are an integral part of these statements.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
6

ALLETE
CONSOLIDATED STATEMENT OF INCOME
Unaudited

| Quarter Ended |  | Six Months Ended
| June 30, |  | June 30,
| 2022 | 2021 |  | 2022 | 2021
Millions Except Per Share Amounts |  |  |  |  |
Operating Revenue |  |  |  |  |
Contracts with Customers – Utility | $308.7 |  | $290.4 |  |  | $637.7 |  | $583.4 |
Contracts with Customers – Non-utility | 62.1 |  | 42.3 |  |  | 113.8 |  | 85.7 |
Other – Non-utility | 2.3 |  | 2.9 |  |  | 5.1 |  | 5.7 |
Total Operating Revenue | 373.1 |  | 335.6 |  |  | 756.6 |  | 674.8 |
Operating Expenses |  |  |  |  |
Fuel, Purchased Power and Gas – Utility | 143.2 |  | 128.9 |  |  | 280.6 |  | 249.3 |
Transmission Services – Utility | 18.3 |  | 19.2 |  |  | 38.2 |  | 36.9 |
Cost of Sales – Non-utility | 41.5 |  | 15.8 |  |  | 58.5 |  | 32.6 |
Operating and Maintenance | 79.6 |  | 67.1 |  |  | 154.9 |  | 133.4 |
Depreciation and Amortization | 61.0 |  | 57.9 |  |  | 122.7 |  | 115.9 |
Taxes Other than Income Taxes | 15.8 |  | 18.5 |  |  | 34.6 |  | 36.5 |
Total Operating Expenses | 359.4 |  | 307.4 |  |  | 689.5 |  | 604.6 |
Operating Income | 13.7 |  | 28.2 |  |  | 67.1 |  | 70.2 |
Other Income (Expense) |  |  |  |  |
Interest Expense | (18.6) |  | (17.4) |  |  | (36.9) |  | (34.5) |
Equity Earnings | 5.3 |  | 5.1 |  |  | 10.8 |  | 9.9 |
Other | 12.1 |  | 1.8 |  |  | 14.1 |  | 5.1 |
Total Other Expense | (1.2) |  | (10.5) |  |  | (12.0) |  | (19.5) |
Income Before Income Taxes | 12.5 |  | 17.7 |  |  | 55.1 |  | 50.7 |
Income Tax Benefit | (8.3) |  | (4.0) |  |  | (12.2) |  | (14.4) |
Net Income | 20.8 |  | 21.7 |  |  | 67.3 |  | 65.1 |
Net Loss Attributable to Non-Controlling Interest | (16.8) |  | (6.2) |  |  | (36.6) |  | (14.6) |
Net Income Attributable to ALLETE | $37.6 |  | $27.9 |  |  | $103.9 |  | $79.7 |
Average Shares of Common Stock |  |  |  |  |
Basic | 56.1 |  | 52.2 |  |  | 54.9 |  | 52.2 |
Diluted | 56.1 |  | 52.3 |  |  | 54.9 |  | 52.2 |
Basic Earnings Per Share of Common Stock | $0.67 |  | $0.53 |  |  | $1.89 |  | $1.53 |
Diluted Earnings Per Share of Common Stock | $0.67 |  | $0.53 |  |  | $1.89 |  | $1.53 |

The accompanying notes are an integral part of these statements.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
7

ALLETE
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
Unaudited

| Quarter Ended |  | Six Months Ended
| June 30, |  | June 30,
| 2022 |  | 2021 |  | 2022 |  | 2021
Millions |  |  |  |  |  |  |
Net Income | $20.8 |  |  | $21.7 |  |  | $67.3 |  |  | $65.1 |
Other Comprehensive Income (Loss) |  |  |  |  |  |  |
Unrealized Loss on Securities |  |  |  |  |  |  |
Net of Income Tax Expense of $(0.2), $–, $(0.2) and $– | (0.1) |  |  | — |  |  | (0.4) |  |  | — |
Defined Benefit Pension and Other Postretirement Benefit Plans |  |  |  |  |  |  |
Net of Income Tax Expense of $–, $0.2, $0.1 and $0.3 | 0.2 |  |  | 0.4 |  |  | 0.3 |  |  | 0.8 |
Total Other Comprehensive Income (Loss) | 0.1 |  |  | 0.4 |  |  | (0.1) |  |  | 0.8 |
Total Comprehensive Income | 20.9 |  |  | 22.1 |  |  | 67.2 |  |  | 65.9 |
Net Loss Attributable to Non-Controlling Interest | (16.8) |  |  | (6.2) |  |  | (36.6) |  |  | (14.6) |
Total Comprehensive Income Attributable to ALLETE | $37.7 |  |  | $28.3 |  |  | $103.8 |  |  | $80.5 |

The accompanying notes are an integral part of these statements.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
8

ALLETE
CONSOLIDATED STATEMENT OF CASH FLOWS
Unaudited

| Six Months Ended
| June 30,
| 2022 |  | 2021
Millions |  |  |
Operating Activities |  |  |
Net Income | $67.3 |  |  | $65.1 |
Adjustments to Reconcile Net Income to Cash (used in) provided by Operating Activities: |  |  |
AFUDC – Equity | (1.7) |  |  | (1.1) |
Income from Equity Investments – Net of Dividends | 0.6 |  |  | 1.1 |
Loss (Gain) on Investments and Property, Plant and Equipment | 1.4 |  |  | (0.7) |
Depreciation Expense | 122.7 |  |  | 115.8 |
Amortization of PSAs | (5.1) |  |  | (5.7) |
Amortization of Other Intangible Assets and Other Assets | 4.3 |  |  | 5.1 |
Deferred Income Tax Benefit | (12.3) |  |  | (14.4) |
Share-Based and ESOP Compensation Expense | 2.7 |  |  | 3.1 |
Defined Benefit Pension and Postretirement Benefit Expense (Benefit) | (1.4) |  |  | 2.2 |
Bad Debt Expense | 0.8 |  |  | 0.6 |
Fuel Adjustment Clause | (18.8) |  |  | (18.3) |
Residential Interim Rate Adjustment | (3.8) |  |  | — |
Changes in Operating Assets and Liabilities |  |  |
Accounts Receivable | 8.2 |  |  | 5.7 |
Inventories | (168.2) |  |  | (13.9) |
Prepayments and Other | (8.7) |  |  | 1.7 |
Accounts Payable | 17.8 |  |  | (1.2) |
Other Current Liabilities | (27.7) |  |  | (13.0) |
Cash Contributions to Defined Benefit Pension Plans | — |  |  | (10.3) |
Changes in Regulatory and Other Non-Current Assets | 16.9 |  |  | (7.3) |
Changes in Regulatory and Other Non-Current Liabilities | (2.9) |  |  | (8.8) |
Cash (used in) provided by Operating Activities | (7.9) |  |  | 105.7 |
Investing Activities |  |  |
Proceeds from Sale of Available-for-sale Securities | 1.2 |  |  | 2.6 |
Payments for Purchase of Available-for-sale Securities | (1.2) |  |  | (2.0) |
Acquisition of Subsidiaries - Net of Cash & Restricted Cash Acquired | (155.0) |  |  | — |
Payments for Equity Method Investments | (3.9) |  |  | (17.1) |
Additions to Property, Plant and Equipment | (89.5) |  |  | (293.4) |
Other Investing Activities | 1.2 |  |  | 4.2 |
Cash used in Investing Activities | (247.2) |  |  | (305.7) |
Financing Activities |  |  |
Proceeds from Issuance of Common Stock | 240.4 |  |  | 10.1 |
Equity Issuance Costs | (8.1) |  |  | — |
Proceeds from Issuance of Short-Term and Long-Term Debt | 475.3 |  |  | 379.0 |
Repayments of Short-Term and Long-Term Debt | (501.6) |  |  | (149.3) |
Proceeds from Non-Controlling Interest in Subsidiaries - Net | 155.7 |  |  | 28.9 |
Dividends on Common Stock | (71.5) |  |  | (65.7) |
Other Financing Activities | (1.1) |  |  | (0.9) |
Cash provided by Financing Activities | 289.1 |  |  | 202.1 |
Change in Cash, Cash Equivalents and Restricted Cash | 34.0 |  |  | 2.1 |
Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 47.7 |  |  | 65.2 |
Cash, Cash Equivalents and Restricted Cash at End of Period | $81.7 |  |  | $67.3 |

The accompanying notes are an integral part of these statements.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
9

ALLETE
CONSOLIDATED STATEMENT OF EQUITY
Unaudited

| Quarter Ended |  | Six Months Ended
| June 30, |  | June 30,
| 2022 | 2021 |  | 2022 | 2021
Millions Except Per Share Amounts |  |  |  |  |
Common Stock |  |  |  |  |
Balance, Beginning of Period | $1,541.3 |  | $1,467.6 |  |  | $1,536.7 |  | $1,460.9 |
Common Stock Issued | 230.4 |  | 6.5 |  |  | 235.0 |  | 13.2 |
Balance, End of Period | 1,771.7 |  | 1,474.1 |  |  | 1,771.7 |  | 1,474.1 |
Accumulated Other Comprehensive Loss |  |  |  |  |
Balance, Beginning of Period | (24.0) |  | (30.7) |  |  | (23.8) |  | (31.1) |
Other Comprehensive Income - Net of Income Taxes |  |  |  |  |
Unrealized Loss on Debt Securities | (0.1) |  | — |  |  | (0.4) |  | — |
Defined Benefit Pension and Other Postretirement Plans | 0.2 |  | 0.4 |  |  | 0.3 |  | 0.8 |
Balance, End of Period | (23.9) |  | (30.3) |  |  | (23.9) |  | (30.3) |
Retained Earnings |  |  |  |  |
Balance, Beginning of Period | 932.0 |  | 883.8 |  |  | 900.2 |  | 864.8 |
Net Income Attributable to ALLETE | 37.6 |  | 27.9 |  |  | 103.9 |  | 79.7 |
Common Stock Dividends | (37.0) |  | (32.9) |  |  | (71.5) |  | (65.7) |
Balance, End of Period | 932.6 |  | 878.8 |  |  | 932.6 |  | 878.8 |
Non-Controlling Interest in Subsidiaries |  |  |  |  |
Balance, Beginning of Period | 694.2 |  | 525.7 |  |  | 533.2 | 505.6
Proceeds from Non-Controlling Interest in Subsidiaries - Net | 1.7 |  | — |  |  | 182.9 |  | 28.9 |
Net Loss Attributable to Non-Controlling Interest | (16.8) |  | (6.2) |  |  | (36.6) |  | (14.6) |
Distributions to Non-Controlling Interest | (0.6) |  | (0.2) |  |  | (1.0) |  | (0.6) |
Balance, End of Period | 678.5 |  | 519.3 |  |  | 678.5 |  | 519.3 |
Total Equity | $3,358.9 |  | $2,841.9 |  |  | $3,358.9 |  | $2,841.9 |
Dividends Per Share of Common Stock | $0.65 |  | $0.63 |  |  | $1.30 |  | $1.26 |

The accompanying notes are an integral part of these statements.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
10

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – UNAUDITED
The accompanying unaudited Consolidated Financial Statements have been prepared in accordance with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X, and do not include all of the information and notes required by GAAP for complete financial statements. Similarly, the December 31, 2021, Consolidated Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. The presentation of certain prior period amounts on the Consolidated Financial Statements have been adjusted for comparative purposes. In management’s opinion, these unaudited financial statements include all adjustments necessary for a fair statement of financial results. All adjustments are of a normal, recurring nature, except as otherwise disclosed. Operating results for the six months ended June 30, 2022, are not necessarily indicative of results that may be expected for any other interim period or for the year ending December 31, 2022. For further information, refer to the Consolidated Financial Statements and notes included in our 2021 Form 10-K.
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES
Cash, Cash Equivalents and Restricted Cash. We consider all investments purchased with original maturities of three months or less to be cash equivalents. As of June 30, 2022, restricted cash amounts included in Prepayments and Other on the Consolidated Balance Sheet include collateral deposits required under ALLETE Clean Energy loan and tax equity financing agreements. The restricted cash amounts included in Other Non-Current Assets represent collateral deposits required under an ALLETE Clean Energy loan agreement as well as PSAs. The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the Consolidated Balance Sheet that aggregate to the amounts presented in the Consolidated Statement of Cash Flows.

Cash, Cash Equivalents and Restricted Cash | June 30, 2022 |  | December 31, 2021 |  | June 30, 2021 |  | December 31, 2020
Millions |  |  |  |  |  |  |
Cash and Cash Equivalents | $74.6 |  |  | $45.1 |  |  | $62.5 |  |  | $44.3 |
Restricted Cash included in Prepayments and Other | 0.8 |  |  | 0.3 |  |  | 1.6 |  |  | 0.8 |
Restricted Cash included in Other Non-Current Assets | 6.3 |  |  | 2.3 |  |  | 3.2 |  |  | 20.1 |
Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows | $81.7 |  |  | $47.7 |  |  | $67.3 |  |  | $65.2 |

Inventories – Net. Inventories are stated at the lower of cost or net realizable value. Inventories in our Regulated Operations segment are carried at an average cost or first-in, first-out basis. Inventories in our ALLETE Clean Energy segment and Corporate and Other businesses are carried at an average cost, first-in, first-out or specific identification basis.

Inventories – Net | June 30, 2022 |  | December 31, 2021
Millions |  |  |
Fuel (a) | $35.5 |  |  | $18.7 |
Materials and Supplies | 67.6 |  |  | 56.1 |
Renewable Energy Facilities Under Development (b) | 252.7 |  |  | 22.9 |
Total Inventories – Net | $355.8 |  |  | $97.7 |

(a) Fuel consists primarily of coal inventory at Minnesota Power.
(b) Renewable Energy Facilities Under Development consists primarily of project costs related to ALLETE Clean Energy’s Northern Wind, Rock Aetna, and Red Barn wind projects which are expected to be sold in late 2022 and early 2023, respectively. (See Other Current Liabilities.)
ALLETE, Inc. Second Quarter 2022 Form 10-Q
11

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Other Non-Current Assets | June 30, 2022 |  | December 31, 2021
Millions |  |  |
Contract Assets (a) | $22.1 |  |  | $23.3 |
Operating Lease Right-of-use Assets | 15.1 |  |  | 16.4 |
ALLETE Properties | 18.1 |  |  | 19.4 |
Restricted Cash | 6.3 |  |  | 2.3 |
Other Postretirement Benefit Plans | 66.0 |  |  | 64.8 |
Other | 80.3 |  |  | 86.7 |
Total Other Non-Current Assets | $207.9 |  |  | $212.9 |

(a) Contract Assets consist of payments made to customers as an incentive to execute or extend service agreements. The contract payments are being amortized over the term of the respective agreements as a reduction to revenue.

Other Current Liabilities | June 30, 2022 |  | December 31, 2021
Millions |  |  |
Customer Deposits (a) | $28.5 |  |  | $27.2 |
PSAs | 6.1 |  |  | 12.6 |
Manufactured Gas Plant (b) | 1.9 |  |  | 12.8 |
Fuel Adjustment Clause | — |  |  | 5.0 |
Operating Lease Liabilities | 4.3 |  |  | 4.8 |
Redeemable Non-Controlling Interest (c) | — |  |  | 30.6 |
Other | 69.9 |  |  | 40.0 |
Total Other Current Liabilities | $110.7 |  |  | $133.0 |

(a) Primarily related to deposits received by ALLETE Clean Energy for the Northern Wind, Rock Aetna and Red Barn wind projects which are expected to be sold in late 2022 and early 2023, respectively. (See Inventories – Net.)
(b) The manufactured gas plant represents the current liability for remediation of a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P.
(c) Amount reclassified from Non-Controlling Interest in Subsidiaries resulting from the exercise of an option to buy out a non-controlling interest, which was paid in the first quarter of 2022.

Other Non-Current Liabilities | June 30, 2022 |  | December 31, 2021
Millions |  |  |
Asset Retirement Obligation (a) | $196.5 |  |  | $184.5 |
PSAs | 30.0 |  |  | 39.5 |
Manufactured Gas Plant (b) | 16.1 |  |  | 5.2 |
Operating Lease Liabilities | 10.7 |  |  | 11.6 |
Other | 33.2 |  |  | 40.0 |
Total Other Non-Current Liabilities | $286.5 |  |  | $280.8 |

(a)The asset retirement obligation is primarily related to our Regulated Operations and is funded through customer rates over the life of the related assets. Additionally, BNI Energy funds its obligation through its cost-plus coal supply agreements for which BNI Energy has recorded a receivable of $28.5 million in Other Non-Current Assets on the Consolidated Balance Sheet as of June 30, 2022, ($28.5 million as of December 31, 2021).
(b)The manufactured gas plant represents the non-current liability for remediation of a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
12

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Other Income |  |
Six Months Ended June 30, | 2022 | 2021
Millions |  |
Pension and Other Postretirement Benefit Plan Non-Service Credits (a) | $5.3 |  | $2.8 |
Interest and Investment Income (Loss) | (0.9) |  | 1.8 |
AFUDC - Equity | 1.7 |  | 1.1 |
PSA Liability (b) | 10.2 |  | — |
Other | (2.2) |  | (0.6) |
Total Other Income | $14.1 |  | $5.1 |

(a)These are components of net periodic pension and other postretirement benefit cost other than service cost. (See Note 10. Pension and Other Postretirement Benefit Plans.)
(b)The gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the legacy wind energy facility assets, which was fully offset by a reserve for an anticipated loss on the sale of the Northern Wind project.
Supplemental Statement of Cash Flows Information.

Six Months Ended June 30, | 2022 |  | 2021
Millions |  |  |
Cash Paid for Interest – Net of Amounts Capitalized | $35.6 |  | $33.8
Noncash Investing and Financing Activities |  |  |
Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment | $3.1 |  | $(8.8)
Reclassification of Property, Plant and Equipment to Inventory (a) | $78.6 |  | —
Capitalized Asset Retirement Costs | $8.8 |  | $3.5
AFUDC–Equity | $1.7 |  | $1.1

(a)The decommissioning of the existing Northern Wind assets resulted in a reclassification from Property, Plant and Equipment – Net to Inventories – Net in the second quarter of 2022 as they are being sold to a su bsidiary of Xcel Energy Inc.
Non-Controlling Interest in Subsidiaries. Non-controlling interest in subsidiaries on the Consolidated Balance Sheet and net loss attributable to non-controlling interest on the Consolidated Statement of Income represent the portion of equity ownership and earnings, respectively, of subsidiaries that are not attributable to equity holders of ALLETE. These amounts are primarily related to the tax equity financing structures for ALLETE Clean Energy’s 106 MW Glen Ullin, 80 MW South Peak, 303 MW Diamond Spring and 303 MW Caddo wind energy facilities as well as ALLETE’s equity investment in the 250 MW Nobles 2 wind energy facility.
Subsequent Events. The Company performed an evaluation of subsequent events for potential recognition and disclosure through the date of the financial statements issuance.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
13

NOTE 2. REGULATORY MATTERS
Regulatory matters are summarized in Note 4. Regulatory Matters to the Consolidated Financial Statements in our 2021 Form 10-K, with additional disclosure provided in the following paragraphs.
Electric Rates. Entities within our Regulated Operations segment file for periodic rate revisions with the MPUC, PSCW or FERC. As authorized by the MPUC, Minnesota Power also recognizes revenue under cost recovery riders for transmission, renewable, and environmental investments and expenditures. Revenue from cost recovery riders was $11.9 million for the six months ended June 30, 2022 ($22.1 million for the six months ended June 30, 2021).
2022 Minnesota General Rate Case. On November 1, 2021, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 18 percent for retail customers. The rate filing seeks a return on equity of 10.25 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would generate approximately $108 million in additional revenue. In orders dated December 30, 2021, the MPUC accepted the filing as complete and authorized an annual interim rate increase beginning January 1, 2022, with approximately $80 million expected to be collected in cash and approximately $8 million of interim rates for residential customers deferred with a final determination on recovery at the end of the rate case. We cannot predict the level of final rates that may be authorized by the MPUC.
2022 Wisconsin General Rate Case. On June 1, 2022, SWL&P refiled its rate increase request with the PSCW seeking an average increase of 3.6 percent for retail customers. The filing seeks an overall return on equity of 10.4 percent and a 55 percent equity ratio. On an annualized basis, the requested final rate increase would generate approximately $4.3 million in additional revenue.
Renewable Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for the costs of certain renewable investments and expenditures, including a return on the capital invested. Current customer billing rates for the renewable cost recovery rider were approved by the MPUC in a 2020 order. On February 2, 2022, Minnesota Power submitted its 2022 renewable factor filing, which included a request to recover a regulatory asset of $3.8 million related to the recognition of production tax credits due to a metering error at Bison. If the filing is approved, Minnesota Power would be authorized to include updated billing rates on customer bills; any portion disallowed would be charged to earnings.
Fuel Adjustment Clause. In 2020, Minnesota Power filed its fuel adjustment forecast for 2021, which was approved by the MPUC in a December 2020 order, subject to the annual prudence review and true-up filing in 2022. During 2021, Minnesota Power incurred higher fuel and purchased power costs than those forecasted in its May 2020 filing, which resulted in the recognition of an approximately $56 million regulatory asset through December 31, 2021. Minnesota Power submitted its annual true-up filing and a significant events filing in March 2022 requesting recovery of these under-collected fuel adjustment clause recoveries. No parties objected to the request; recovery of the regulatory asset began in April 2022 and will continue through mid-2023. The MPUC approved recovery of the regulatory asset in an order dated July 5, 2022.
Minnesota Power has also incurred higher fuel and purchased power costs in 2022 than those factored in its fuel adjustment forecast filed in May 2021 for 2022, which resulted in the recognition of an approximately $28 million regulatory asset as of June 30, 2022. Minnesota Power filed a significant events filing in June 2022 requesting recovery of the under-collected fuel adjustment clause recoveries that are expected for 2022 from August 2022 through December 2022. No parties objected to the request and higher rates were implemented in August 2022 to recover the expected under-collection of fuel adjustment clause recoveries, subject to final approval by the MPUC which is expected in 2023.
Conservation Improvement Program. On April 1, 2022, Minnesota Power submitted its 2021 consolidated filing detailing Minnesota Power’s CIP program results and requesting a CIP financial incentive of $1.9 million based upon MPUC procedures, which was recognized in the second quarter of 2022 upon approval by the MPUC at a hearing on June 30, 2022. In 2021, a CIP financial incentive of $2.4 million was recognized in the third quarter upon approval by the MPUC of Minnesota Power’s 2020 CIP consolidated filing. CIP financial incentives are recognized in the period in which the MPUC approves the filing.
2021 Integrated Resource Plan. On February 1, 2021, Minnesota Power filed its latest IRP with the MPUC, which outlines its clean-energy transition plans through 2035. These plans include expanding its renewable energy supply, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. As part of these plans, Minnesota Power anticipates adding approximately 400 MW of new wind and solar energy resources, retiring Boswell Unit 3 by 2030 and transforming Boswell Unit 4 to be coal-free by 2035. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably. A final decision on the IRP is expected in the second half of 2022.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
14

NOTE 2. REGULATORY MATTERS (Continued)
Regulatory Assets and Liabilities. Our regulated utility operations are subject to accounting guidance for the effect of certain types of regulation. Regulatory assets represent incurred costs that have been deferred as they are probable for recovery in customer rates. Regulatory liabilities represent obligations to make refunds to customers and amounts collected in rates for which the related costs have not yet been incurred. The Company assesses quarterly whether regulatory assets and liabilities meet the criteria for probability of future recovery or deferral. With the exception of the regulatory asset for Boswell Units 1 and 2 net plant and equipment, no other regulatory assets are currently earning a return. The recovery, refund or credit to rates for these regulatory assets and liabilities will occur over the periods either specified by the applicable regulatory authority or over the corresponding period related to the asset or liability.

Regulatory Assets and Liabilities | June 30, 2022 |  | December 31, 2021 |  |
Millions |  |  |  |  |
Current Regulatory Assets (a) |  |  |  |  |
Fuel Adjustment Clause | $39.8 |  |  | — |  |  |
Total Current Regulatory Assets | 39.8 |  |  | — |  |  |
Non-Current Regulatory Assets |  |  |  |  |
Defined Benefit Pension and Other Postretirement Benefit Plans | 220.1 |  |  | $226.4 |  |  |
Income Taxes | 100.7 |  |  | 104.7 |  |  |
Cost Recovery Riders | 49.9 |  |  | 63.2 |  |  |
Asset Retirement Obligations | 34.2 |  |  | 33.1 |  |  |
Fuel Adjustment Clause | 34.7 |  |  | 56.4 |  |  |
Manufactured Gas Plant | 17.6 |  |  | 17.0 |  |  |
PPACA Income Tax Deferral | 4.2 |  |  | 4.3 |  |  |
Residential Customer Interim Rate Adjustment | 3.8 |  |  | — |  |  |
Other | 5.7 |  |  | 6.7 |  |  |
Total Non-Current Regulatory Assets | 470.9 |  |  | 511.8 |  |  |
Total Regulatory Assets | $510.7 |  |  | $511.8 |  |  |
Current Regulatory Liabilities (b) |  |  |  |  |
Fuel Adjustment Clause | — |  |  | $5.0 |  |  |
Transmission Formula Rates Refund | $4.5 |  |  | 3.1 |  |  |
Other | 1.1 |  |  | 0.5 |  |  |
Total Current Regulatory Liabilities | 5.6 |  |  | 8.6 |  |  |
Non-Current Regulatory Liabilities |  |  |  |  |
Income Taxes | 341.7 |  |  | 353.4 |  |  |
Wholesale and Retail Contra AFUDC | 82.2 |  |  | 83.7 |  |  |
Plant Removal Obligations | 56.9 |  |  | 52.6 |  |  |
North Dakota Investment Tax Credits | 13.6 |  |  | 12.2 |  |  |
Defined Benefit Pension and Other Postretirement Benefit Plans | 25.0 |  |  | 28.1 |  |  |
Boswell Units 1 and 2 Net Plant and Equipment | 2.8 |  |  | 0.4 |  |  |
Other | 10.4 |  |  | 5.7 |  |  |
Total Non-Current Regulatory Liabilities | 532.6 |  |  | 536.1 |  |  |
Total Regulatory Liabilities | $538.2 |  |  | $544.7 |  |  |

(a)Current regulatory assets are presented within Prepayments and Other on the Consolidated Balance Sheet.
(b)Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
15

NOTE 3. ACQUISITIONS
2022 Activity
New Energy. On April 15, 2022, a wholly-owned subsidiary of ALLETE acquired 100 percent of the membership interests of New Energy for a purchase price of $165.5 million. Total consideration of approximately $158.8 million was paid in cash on the acquisition date, which is net of cash acquired and debt assumed. New Energy, which is headquartered in Annapolis, Maryland, is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. The acquisition of New Energy is consistent with ALLETE’s stated strategy of additional investment in renewable energy and related infrastructure across North America to support the Company’s sustainability-in-action strategy while providing potential long-term earnings growth.
The acquisition was accounted for as a business combination and the purchase price was allocated based on the preliminary estimated fair values of the assets acquired and the liabilities assumed at the date of acquisition, as shown in the following table. The allocation of the purchase price is subject to judgment and the preliminary estimated fair value of the assets acquired and the liabilities assumed may be adjusted when the valuation analysis is complete in subsequent periods. Preliminary estimates subject to adjustment in subsequent periods relate primarily to working capital; subsequent adjustments could impact the amount of goodwill recorded. Fair value measurements were valued primarily using the discounted cash flow method and replacement cost basis. The goodwill recorded is primarily attributable to the highly skilled workforce of New Energy and synergies expected to arise as a result of the acquisition.
Since the acquisition in April 2022, aggregate revenue was $16.8 million. The Company has not presented separate results of operations since closing or combined pro forma financial information of the Company and New Energy since the beginning of 2021, as the results of operations for New Energy are not material to the Company's consolidated financials.

Millions |  |  |  |
Assets Acquired |  |  |  |
Cash and Cash Equivalents |  |  |  | $3.9 |
Accounts Receivable |  |  |  | 1.4 |
Inventory |  |  |  | 23.2 |
Other Current Assets |  |  |  | 13.2 |
Property, Plant and Equipment - Net |  |  |  | 16.4 |
Goodwill (a) |  |  |  | 150.3 |
Other Non-Current Assets |  |  |  | 2.2 |
Total Assets Acquired |  |  |  | $210.6 |
Liabilities Assumed |  |  |  |
Current Liabilities |  |  |  | $17.4 |
Long-Term Debt Due Within One Year |  |  |  | 28.3 |
Long-Term Debt |  |  |  | 5.9 |
Other Non-Current Liabilities |  |  |  | 0.2 |
Total Liabilities Assumed |  |  |  | $51.8 |
Net Identifiable Assets Acquired |  |  |  | $158.8 |

(a)For tax purpose, the purchase price allocation resulted in $150.3 million of deductible goodwill.
Acquisition-related costs were approximately $3 million after-tax, expensed as incurred during 2022 and recorded in Operating and Maintenance on the Consolidated Statement of Income.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
16

NOTE 4. EQUITY INVESTMENTS
Investment in ATC. Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. We account for our investment in ATC under the equity method of accounting.

ALLETE’s Investment in ATC |
Millions |
Equity Investment Balance as of December 31, 2021 | $154.5 |
Cash Investments | 3.9 |
Equity in ATC Earnings | 10.7 |
Distributed ATC Earnings | (8.6) |
Amortization of the Remeasurement of Deferred Income Taxes | 0.7 |
Equity Investment Balance as of June 30, 2022 | $161.2 |

ATC’s authorized return on equity is 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization, based on a 2020 FERC order which is subject to various outstanding legal challenges related to the refund period ordered by the FERC. If these legal challenges are successful, ATC may be required to provide refunds to its customers of up to approximately $66 million of which our share would be approximately $5 million pre-tax. In addition, the FERC issued a Notice of Proposed Rulemaking in April 2021 proposing to limit the 50 basis point incentive adder for participation in a regional transmission organization to only the first three years of membership in such an organization. If this proposal is adopted, our equity in earnings from ATC would be reduced by approximately $1 million pre-tax annually.
Investment in Nobles 2. Our subsidiary, ALLETE South Wind, owns 49 percent of Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20-year PPA with Minnesota Power. We account for our investment in Nobles 2 under the equity method of accounting.

ALLETE’s Investment in Nobles 2 |
Millions |
Equity Investment Balance as of December 31, 2021 | $163.5 |
Equity in Nobles 2 Earnings (a) | 0.1 |
Distributed Nobles 2 Earnings | (2.8) |
Equity Investment Balance as of June 30, 2022 | $160.8 |

(a)The Company also recorded net loss attributable to non-controlling interest of $6.2 million related to its investment in Nobles 2.
NOTE 5. FAIR VALUE
Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the market approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. These inputs, which are used to measure fair value, are prioritized through the fair value hierarchy. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Descriptions of the three levels of the fair value hierarchy are discussed in Note 6. Fair Value to the Consolidated Financial Statements in our 2021 Form 10-K.
The following tables set forth, by level within the fair value hierarchy, our assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, 2022, and December 31, 2021. Each asset and liability is classified based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of these assets and liabilities and their placement within the fair value hierarchy levels. The estimated fair value of Cash and Cash Equivalents listed on the Consolidated Balance Sheet approximates the carrying amount and therefore is excluded from the recurring fair value measures in the following tables.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
17

NOTE 5. FAIR VALUE (Continued)

| Fair Value as of June 30, 2022
Recurring Fair Value Measures | Level 1 |  | Level 2 |  | Level 3 |  | Total
Millions |  |  |  |  |  |  |
Assets |  |  |  |  |  |  |
Investments (a) |  |  |  |  |  |  |
Available-for-sale – Equity Securities | $7.6 |  |  | — |  |  | — |  |  | $7.6 |
Available-for-sale – Corporate and Governmental Debt Securities (b) | — |  |  | $5.6 |  |  | — |  |  | 5.6 |
Cash Equivalents | 3.2 |  |  | — |  |  | — |  |  | 3.2 |
Total Fair Value of Assets | $10.8 |  |  | $5.6 |  |  | — |  |  | $16.4 |
Liabilities |  |  |  |  |  |  |
Deferred Compensation (c) | — |  |  | $15.8 |  |  | — |  |  | $15.8 |
Total Fair Value of Liabilities | — |  |  | $15.8 |  |  | — |  |  | $15.8 |
| Fair Value as of December 31, 2021
Recurring Fair Value Measures | Level 1 |  | Level 2 |  | Level 3 |  | Total
Millions |  |  |  |  |  |  |
Assets |  |  |  |  |  |  |
Investments (a) |  |  |  |  |  |  |
Available-for-sale – Equity Securities | $8.9 |  |  | — |  |  | — |  |  | $8.9 |
Available-for-sale – Corporate and Governmental Debt Securities | — |  |  | $6.2 |  |  | — |  |  | 6.2 |
Cash Equivalents | 2.5 |  |  | — |  |  | — |  |  | 2.5 |
Total Fair Value of Assets | $11.4 |  |  | $6.2 |  |  | — |  |  | $17.6 |
Liabilities |  |  |  |  |  |  |
Deferred Compensation (c) | — |  |  | $18.0 |  |  | — |  |  | $18.0 |
Total Fair Value of Liabilities | — |  |  | $18.0 |  |  | — |  |  | $18.0 |

(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.
(b)As of June 30, 2022, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $0.7 million, in one year to less than three years was $2.7 million, in three years to less than five years was $1.7 million and in five or more years was $0.5 million.
(c)Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.
Fair Value of Financial Instruments. With the exception of the item listed in the following table, the estimated fair value of all financial instruments approximates the carrying amount. The fair value of the item listed in the following table was based on quoted market prices for the same or similar instruments (Level 2).

Financial Instruments | Carrying Amount |  | Fair Value
Millions |  |  |
Short-Term and Long-Term Debt (a) |  |  |
June 30, 2022 | $1,994.4 |  | $1,923.3
December 31, 2021 | $1,986.4 |  | $2,192.6

(a)Excludes unamortized debt issuance costs.
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis. Non-financial assets such as equity method investments, land inventory, and property, plant and equipment are measured at fair value when there is an indicator of impairment and recorded at fair value only when an impairment is recognized. For the quarter and six months ended June 30, 2022, and the year ended December 31, 2021, there were no indicators of impairment for these non-financial assets.
We continue to monitor changes in the broader energy markets along with wind resource expectations that could indicate impairment at ALLETE Clean Energy wind energy facilities upon contract expirations. A continued decline in energy prices or lower wind resource expectations could result in a future impairment.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
18

NOTE 6. SHORT-TERM AND LONG-TERM DEBT
The following tables present the Company’s short-term and long-term debt as of June 30, 2022, and December 31, 2021:

June 30, 2022 | Principal |  | Unamortized Debt Issuance Costs |  | Total
Millions |  |  |  |  |
Short-Term Debt | $390.7 |  |  | $(0.2) |  | $390.5 |
Long-Term Debt | 1,603.7 |  |  | (8.1) |  | 1,595.6 |
Total Debt | $1,994.4 |  |  | $(8.3) |  | $1,986.1 |

December 31, 2021 | Principal |  | Unamortized Debt Issuance Costs |  | Total
Millions |  |  |  |  |
Short-Term Debt | $214.4 |  |  | $(0.2) |  | $214.2 |
Long-Term Debt | 1,772.0 |  |  | (8.8) |  | 1,763.2 |
Total Debt | $1,986.4 |  |  | $(9.0) |  | $1,977.4 |

We had $33.2 million outstanding in standby letters of credit and $108.9 million outstanding draws under our lines of credit as of June 30, 2022 ($31.5 million in standby letters of credit and $159.7 million outstanding draws as of December 31, 2021).
On February 28, 2022, ALLETE entered into an unsecured term loan agreement (February Term Loan) to borrow up to $175 million. No draws were made on the February Term Loan, which was subsequently terminated in April 2022.
On March 24, 2022, ALLETE entered into a $170 million unsecured term loan agreement (March Term Loan). The Term Loan is due March 23, 2023, and may be repaid at any time. Interest is payable monthly at a rate per annum equal to SOFR plus 0.75 percent. Proceeds from the Term Loan were used for general corporate purposes.
Financial Covenants. Our long-term debt arrangements contain customary covenants. In addition, our lines of credit and letters of credit supporting certain long-term debt arrangements contain financial covenants. Our compliance with financial covenants is not dependent on debt ratings. The most restrictive financial covenant requires ALLETE to maintain a ratio of indebtedness to total capitalization (as the amounts are calculated in accordance with the respective long-term debt arrangements) of less than or equal to 0.65 to 1.00, measured quarterly. As of June 30, 2022, our ratio was approximately 0.39 to 1.00. Failure to meet this covenant would give rise to an event of default if not cured after notice from the lender, in which event ALLETE may need to pursue alternative sources of funding. Some of ALLETE’s debt arrangements contain “cross-default” provisions that would result in an event of default if there is a failure under other financing arrangements to meet payment terms or to observe other covenants that would result in an acceleration of payments due. ALLETE has no significant restrictions on its ability to pay dividends from retained earnings or net income. As of June 30, 2022, ALLETE was in compliance with its financial covenants.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
19

NOTE 7. COMMITMENTS, GUARANTEES AND CONTINGENCIES
Power Purchase and Sale Agreements. Our long-term PPAs have been evaluated under the accounting guidance for variable interest entities. We have determined that either we have no variable interest in the PPAs or, where we do have variable interests, we are not the primary beneficiary; therefore, consolidation is not required. These conclusions are based on the fact that we do not have both control over activities that are most significant to the entity and an obligation to absorb losses or receive benefits from the entity’s performance. Our financial exposure relating to these PPAs is limited to our capacity and energy payments.
Our PPAs are summarized in Note 8. Commitments, Guarantees and Contingencies to the Consolidated Financial Statements in our 2021 Form 10-K, with additional disclosure provided in the following paragraphs.
Square Butte PPA. As of June 30, 2022, Square Butte had total debt outstanding of $197.2 million. Fuel expenses are recoverable through Minnesota Power’s fuel adjustment clause and include the cost of coal purchased from BNI Energy under a long-term contract. Minnesota Power’s cost of power purchased from Square Butte during the six months ended June 30, 2022, was $41.0 million ($39.8 million for the same period in 2021). This reflects Minnesota Power’s pro rata share of total Square Butte costs based on the 50 percent output entitlement. Included in this amount was Minnesota Power’s pro rata share of interest expense of $2.6 million ($2.9 million for the same period in 2021). Minnesota Power’s payments to Square Butte are approved as a purchased power expense for ratemaking purposes by both the MPUC and the FERC.
Minnkota Power PSA. Minnesota Power has a PSA with Minnkota Power, which commenced in 2014. Under the PSA, Minnesota Power is selling a portion of its entitlement from Square Butte to Minnkota Power, resulting in Minnkota Power’s net entitlement increasing and Minnesota Power’s net entitlement decreasing until Minnesota Power’s share is eliminated at the end of 2025. Of Minnesota Power’s 50 percent output entitlement, Minnesota Power sold to Minnkota Power approximately 32 percent in 2022 and 28 percent in 2021.
Coal, Rail and Shipping Contracts. Minnesota Power has coal supply agreements providing for the purchase of a significant portion of its coal requirements through December 2025. Minnesota Power also has coal transportation agreements in place for the delivery of a significant portion of its coal requirements through December 2024. The costs of fuel and related transportation costs for Minnesota Power’s generation are recoverable from Minnesota Power’s retail and municipal utility customers through the fuel adjustment clause.
Environmental Matters.
Our businesses are subject to regulation of environmental matters by various federal, state and local authorities. A number of regulatory changes to the Clean Air Act, the Clean Water Act and various waste management requirements have been promulgated by both the EPA and state authorities over the past several years. Minnesota Power’s facilities are subject to additional requirements under many of these regulations. Minnesota Power is reshaping its generation portfolio, over time, to reduce its reliance on coal, has installed cost-effective emission control technology, and advocates for sound science and policy during rulemaking implementation.
We consider our businesses to be in substantial compliance with currently applicable environmental regulations and believe all necessary permits have been obtained. We anticipate that with many state and federal environmental regulations and requirements finalized, or to be finalized in the near future, potential expenditures for future environmental matters may be material and require significant capital investments. Minnesota Power has evaluated various environmental compliance scenarios using possible outcomes of environmental regulations to project power supply trends and impacts on customers.
We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated based on current law and existing technologies. Accruals are adjusted as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the Consolidated Balance Sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are expensed unless recoverable in rates from customers.
Air. The electric utility industry is regulated both at the federal and state level to address air emissions. Minnesota Power’s thermal generating facilities mainly burn low-sulfur western sub-bituminous coal. All of Minnesota Power’s coal-fired generating facilities are equipped with pollution control equipment such as scrubbers, baghouses and low NO X technologies. Under currently applicable environmental regulations, these facilities are substantially compliant with emission requirements.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
20

NOTE 7. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Cross-State Air Pollution Rule (CSAPR). The CSAPR requires certain states in the eastern half of the U.S., including Minnesota, to reduce power plant emissions that contribute to ozone or fine particulate pollution in other states. The CSAPR does not require installation of controls but does require facilities have sufficient allowances to cover their emissions on an annual basis. These allowances are allocated to facilities from each state’s annual budget, and can be bought and sold. Based on our review of the NO X and SO 2 allowances issued and pending issuance, we currently expect generation levels and emission rates will result in continued compliance with the CSAPR. The EPA’s CSAPR Update Rule issued in March 2021 revising the 2016 CSAPR Update does not apply to the state of Minnesota and is therefore not currently projected to affect Minnesota Power’s CSAPR compliance. Minnesota Power will continue to monitor ongoing CSAPR rulemakings and compliance implementation, including the EPA’s Good Neighbor Rule proposed on April 6, 2022, to modify certain aspects of the CSAPR’s program scope and extent.
National Ambient Air Quality Standards (NAAQS). The EPA is required to review the NAAQS every five years. If the EPA determines that a state’s air quality is not in compliance with the NAAQS, the state is required to adopt plans describing how it will reduce emissions to attain the NAAQS. Minnesota Power actively monitors NAAQS developments and compliance costs for existing standards or proposed NAAQS revisions are not currently expected to be material. The EPA is currently reviewing the secondary NAAQS for NO x and SO 2, as well as particulate matter. In June 2021, the EPA announced it will reconsider the December 2020 final rule retaining the 2012 particulate matter NAAQS, with a proposed rulemaking anticipated in mid-2022. The EPA also announced in October 2021 that it was reconsidering the 2020 Ozone NAAQS rule finalized in December 2020, and issued a policy assessment on April 28, 2022, recommending retention of the current standard. A proposed rule is expected in the first half of 2023.
EPA Good Neighbor Plan for 2015 Ozone NAAQS. On April 6, 2022, the EPA published a proposed rule, the Good Neighbor Plan, to address regional ozone transport for the 2015 Ozone NAAQS by reducing NO x emissions during the period of May 1st through September 30th (ozone season). This rule is intended to address certain good neighbor or interstate transport provisions of the Clean Air Act relative to the 2015 Ozone NAAQS. In the justification for the proposed rule, the EPA asserted that 26 states, including Minnesota, are modeled as significant contributors to downwind states’ challenges in attaining or maintaining ozone NAAQS compliance within their state borders. The Good Neighbor Plan proposes to resolve this interstate transport issue by implementing a variety of NO x reduction strategies, including federal implementation plan requirements, NO x emission limitations, and ozone season allowance program requirements, beginning with the 2023 ozone season. The proposed rule would apply to fossil-fuel fired power plants in 25 states and certain other industrial sources in 23 states. Implementation of the rule would occur in part through changes to the existing CSAPR program.
Minnesota Power reviewed the proposed rule, assessed its potential impacts and submitted public comments to the EPA on June 21, 2022. Concerns noted by Minnesota Power and other entities included the technical accuracy of the EPA’s assumptions and methods used to identify Minnesota as a significant contributor state, as well as the proposed rule’s intended timeline. Anticipated compliance costs related to the Good Neighbor Plan cannot yet be estimated; however, the costs could be material, including costs of additional NO x controls, emission allowance program participation, or operational changes, if any are required. Minnesota Power would seek recovery of additional costs through a rate proceeding. The EPA intends to issue a final rule in early 2023.
EPA National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial and Institutional Boilers and Process Heaters (Industrial Boiler MACT) Rule. A final rule issued by the EPA for Industrial Boiler MACT became effective in 2012 with compliance required at major existing sources in 2016. Minnesota Power’s Hibbard Renewable Energy Center and Rapids Energy Center are subject to this rule. Compliance with the Industrial Boiler MACT Rule consisted largely of adjustments to fuels and operating practices and compliance costs were not material. Subsequent to this initial rulemaking, litigation from 2016 through 2018 resulted in court orders directing that the EPA reconsider certain aspects of the regulation including the basis for and numerical value of several different emission limits. On July 21, 2022, the EPA signed a final rule incorporating these changes. Minnesota Power is actively reviewing this new regulation to assess if changes are needed to attain compliance by the 2025 deadline. Compliance costs associated with the new Industrial Boiler MACT Rule cannot yet be estimated; however, the costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
21

NOTE 7. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Climate Change. The scientific community generally accepts that emissions of GHG are linked to global climate change which creates physical and financial risks. Physical risks could include, but are not limited to: increased or decreased precipitation and water levels in lakes and rivers; increased or other changes in temperatures; and changes in the intensity and frequency of extreme weather events. These all have the potential to affect the Company’s business and operations. We are addressing climate change by taking the following steps that also ensure reliable and environmentally compliant generation resources to meet our customers’ requirements:
•Expanding renewable power supply for both our operations and the operations of others;
•Providing energy conservation initiatives for our customers and engaging in other demand side management efforts;
•Improving efficiency of our generating facilities;
•Supporting research of technologies to reduce carbon emissions from generating facilities and carbon sequestration efforts;
•Evaluating and developing less carbon intensive future generating assets such as efficient and flexible natural gas-fired generating facilities;
•Managing vegetation on right-of-way corridors to reduce potential wildfire or storm damage risks; and
•Practicing sound forestry management in our service territories to create landscapes more resilient to disruption from climate-related changes, including planting and managing long-lived conifer species.
EPA Regulation of GHG Emissions. In 2019, the EPA finalized several separate rulemakings regarding regulating carbon emissions from electric utility generating units. These rulemakings included repealing the Clean Power Plan (CPP) and adopting the Affordable Clean Energy Rule under Section 111(d) of the Clean Air Act (CAA) to regulate CO2 emissions at existing coal-fired power plants. The CPP was first announced as a proposed rule under Section 111(d) of the CAA for existing power plants entitled “Carbon Pollution Emission Guidelines for Existing Stationary Sources: Electric Generating Units”. The Affordable Clean Energy Rule established emissions guidelines for states to use when developing plans to limit CO2 coal-fired power plants. The EPA also published regulations for the state implementation of the Affordable Clean Energy Rule and other Section 111(d) rules. Affected facilities for Minnesota Power included Boswell Units 3 and 4, and Taconite Harbor Units 1 and 2, which are currently economically idled.
On January 19, 2021, the D.C. Circuit issued an opinion vacating the Affordable Clean Energy Rule and remanded the Affordable Clean Energy Rule back to the EPA for further consideration, consistent with the D.C. Circuit’s finding that the EPA erred in interpreting the CAA, pending rehearing or appeal. Four petitions for review of the D.C. Circuit’s opinion were subsequently granted by the U.S. Supreme Court on October 29, 2021, consolidated under West Virginia v. EPA et al. On June 30, 2022, the U.S. Supreme Court released its opinion in favor of West Virginia and aligned parties. The Supreme Court found the EPA’s CPP structure of generation shifting to be disallowed under Section 111(d) of the CCA on grounds of the major questions doctrine. The court did not opine upon the regulatory approach the EPA proposed in the Affordable Clean Energy Rule. The petitions were remanded to the D.C. Circuit. The EPA has indicated that it intends to issue a proposed rule in early 2023 with a new set of emission guidelines for states to follow in submitting state plans to establish and implement standards of performance for GHG emissions from existing fossil fuel-fired electric generating units. Minnesota Power will continue to monitor any related guidelines and rulemakings issued by the EPA or state regulatory authorities.
On April 22, 2021, the Biden Administration announced a goal to reach 100 percent carbon pollution-free electricity by 2035 as part of the Nationally Determined Contributions pledge, which is part of an international effort to limit global warming. At this time, no specific regulatory pathway to achieve these reductions has been proposed. Minnesota Power will continue to monitor these developments.
Minnesota had already initiated several measures consistent with those called for under the now repealed CPP and vacated Affordable Clean Energy Rule. Minnesota Power continues implementing its EnergyForward strategic plan that provides for significant emission reductions and diversifying its electricity generation mix to include more renewable and natural gas energy. We are unable to predict the GHG emission compliance costs we might incur as a result of a replacement for the Affordable Clean Energy Rule or other future laws, regulations or administrative policies; however, the costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
22

NOTE 7. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Additionally on January 13, 2021, the EPA issued a rulemaking to apply CO 2 emission New Source Performance Standards (NSPS) to new, modified and reconstructed fossil fuel-fired electric generating units under Section 111(b) of the CAA. Currently, the EPA is a performing a comprehensive review of the Section 111(b) GHG NSPS for electric generating units, with a notice of proposed rulemaking expected in early 2023. Minnesota Power is monitoring the NSPS final rule and any further Section 111(b) developments including their potential impact to the Company. The proposed combined-cycle natural gas-fired generating facility, NTEC, is expected to meet these NSPS requirements.
Water. The Clean Water Act requires NPDES permits be obtained from the EPA (or, when delegated, from individual state pollution control agencies) for any wastewater discharged into navigable waters. We have obtained all necessary NPDES permits, including NPDES storm water permits for applicable facilities, to conduct our operations.
Steam Electric Power Generating Effluent Limitations Guidelines. In 2015, the EPA issued revised federal effluent limitation guidelines (ELG) for steam electric power generating stations under the Clean Water Act. It set effluent limits and prescribed BACT for several wastewater streams, including flue gas desulphurization (FGD) water, bottom ash transport water and coal combustion landfill leachate. In 2017, the EPA announced a two-year postponement of the ELG compliance date of November 1, 2018, to November 1, 2020, while the agency reconsidered the bottom ash transport water (BATW) and FGD wastewater provisions. On April 12, 2019, the U.S. Court of Appeals for the Fifth Circuit vacated and remanded back to the EPA portions of the ELG that allowed for continued discharge of legacy wastewater and leachate. On October 13, 2020, the EPA published a final ELG Rule allowing re-use of bottom ash transport water in FGD scrubber systems with limited discharges related to maintaining system water balance. The rule sets technology standards and numerical pollutant limits for discharges of bottom ash transport water and FGD wastewater. Compliance deadlines depend on subcategory, with compliance generally required as soon as possible, beginning after October 13, 2021, but no later than December 31, 2025, or December 31, 2028, in some specific cases. The rule also established new subcategories for retiring high-flow and low-utilization units, and established a voluntary incentives program for FGD wastewater. In accordance with the January 2021 Executive Order 13990, the EPA was mandated to conduct a review of actions and polices taken during the prior administration, including the 2020 ELG Rule. On September 14, 2021, the EPA published a notice of availability for preliminary effluent guidelines program plan. In the plan, the EPA confirmed the agency is initiating a rulemaking process to strengthen wastewater pollution limitations from FGD and bottom ash transport water discharges while the 2020 ELG Rule remains in effect. The EPA is expected to publish a proposed rule in November 2022.
The ELG's potential impact on Minnesota Power operations is primarily at Boswell. Boswell currently discharges bottom ash contact water through its NPDES permit, and also has a closed-loop FGD system that does not discharge to surface waters, but may do so in the future. With Boswell’s planned conversion to dry FGD handling and storage, ongoing FGD water generation will be reduced, and the majority of FGD waters will be legacy waters to be dewatered from existing impoundments. Re-use and onsite consumption for the majority of FGD waters is planned at Boswell.
Under the new ELG rule, most bottom ash transport water discharge to surface waters must cease no later than December 31, 2025, except for small discharges needed to retain water balance. The majority of bottom ash transport water will either need to be re-used in a closed-loop process or routed to a FGD scrubber. At Boswell, the bottom ash handling systems are planned to be converted to a dry process, which will eliminate the discharge of bottom ash transport water.
The EPA’s additional reconsideration of legacy wastewater discharge requirements has the potential to reduce timelines for dewatering Boswell’s existing ponds. In its spring 2022 Unified Agenda, the EPA announced it intends to consolidate consideration of legacy wastewater and leachate with the ELG/FGD and BATW proposed rulemaking expected in November 2022.
At this time, we estimate that the planned dry conversion of bottom ash handling and storage at Boswell in response to the CCR revisions requiring closure of clay-lined impoundments, as well as other water re-use practices, will reduce or eliminate the need for additional significant compliance costs for ELG bottom ash water and FGD requirements. Compliance costs we might incur related to other ELG waste streams (e.g., legacy leachate) or other potential future water discharge regulations cannot be estimated; however, the costs could be material, including costs associated with wastewater treatment and re-use. Minnesota Power would seek recovery of additional costs through a rate proceeding.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
23

NOTE 7. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Permitted Water Discharges – Sulfate. In 2017, the MPCA released a draft water quality standard in an attempt to update Minnesota’s existing 10 mg/L sulfate limit for waters used for the production of wild rice with the proposed rulemaking heard before an administrative law judge (ALJ). In 2018, the ALJ rejected significant portions of the proposed rulemaking and the MPCA subsequently withdrew the rulemaking. The existing 10 mg/L limit remains in place, but the MPCA is currently prohibited under state law from listing wild rice waters as impaired or requiring sulfate reduction technology.
In April 2021, the MPCA’s proposed list of impaired waters submitted pursuant to the Clean Water Act was partially rejected by the EPA due to the absence of wild rice waters listed for sulfate impairment. The EPA transmitted a final list of 32 EPA-added wild rice waters to the MPCA on November 5, 2021. This list could subsequently be used to set sulfate limits in discharge permits for power generation facilities and municipal and industrial customers, including paper and pulp facilities, and mining operations. At this time we are unable to determine the specific impacts these developments may have on Minnesota Power operations, if any. Minnesota Power would seek recovery of additional costs through a rate proceeding.
Solid and Hazardous Waste. The Resource Conservation and Recovery Act of 1976 regulates the management and disposal of solid and hazardous wastes. We are required to notify the EPA of hazardous waste activity and, consequently, routinely submit reports to the EPA.
Coal Ash Management Facilities. Minnesota Power produces the majority of its coal ash at Boswell, with small amounts of ash generated at Hibbard Renewable Energy Center. Ash storage and disposal methods include storing ash in clay-lined onsite impoundments (ash ponds), disposing of dry ash in a lined dry ash landfill, applying ash to land as an approved beneficial use, and trucking ash to state permitted landfills.
Coal Combustion Residuals from Electric Utilities (CCR). In 2015, the EPA published the final rule regulating CCR as nonhazardous waste under Subtitle D of the Resource Conservation and Recovery Act (RCRA) in the Federal Register. The rule includes additional requirements for new landfill and impoundment construction as well as closure activities related to certain existing impoundments. Costs of compliance for Boswell and Laskin are expected to be incurred primarily over the next 15 years and be between approximately $65 million and $120 million. Compliance costs for CCR at Taconite Harbor are not expected to be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.
Minnesota Power continues to work on minimizing costs through evaluation of beneficial re-use and recycling of CCR and CCR-related waters. In 2017, the EPA announced its intention to formally reconsider the CCR rule under Subtitle D of the RCRA. In March 2018, the EPA published the first phase of the proposed rule revisions in the Federal Register. In 2018, the EPA finalized revisions to elements of the CCR rule, including extending certain deadlines by two years, the establishment of alternative groundwater protection standards for certain constituents and the potential for risk-based management options at facilities based on site characteristics. In 2018, a U.S. District Court for the District of Columbia decision vacated specific provisions of the CCR rule. The court decision resulted in a change to the status of three existing clay-lined impoundments at Boswell that must now be considered unlined. The EPA proposed additional rule revisions in 2019 to address outstanding issues from litigation and closure timelines for unlined impoundments, respectively. The first of these rules, CCR Part A Rule, was finalized in September 2020. The Part A Rule revision requires unlined impoundments to cease disposal of waste as soon as technically feasible but no later than April 11, 2021. This deadline has tolled forward as the EPA did not make any variance application determinations by that date. Minnesota Power sought EPA approval to extend the closure date for the two active Boswell impoundments in November 2020 through a variance application, and continues to operate the impoundments pending a final determination by the EPA.
Additionally, the EPA released a proposed Part B rulemaking in February 2020 addressing options for beneficial reuse of CCR materials, alternative liner demonstrations, and other CCR regulatory revisions. Portions of the Part B Rule addressing alternative liner equivalency standards were finalized in November 2020. According to the EPA’s spring 2022 regulatory agenda, finalization of the remainder of the proposed Part B Rule is expected in early 2023. Expected compliance costs at Boswell due to the court decision and subsequent rule revisions are reflected in our estimate of compliance costs for the CCR rule noted previously. Minnesota Power would seek recovery of additional costs through a rate proceeding.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
24

NOTE 7. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Other Environmental Matters.
Manufactured Gas Plant Site. We are reviewing and addressing environmental conditions at a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. SWL&P has been working with the Wisconsin Department of Natural Resources (WDNR) in determining the extent and location of contamination at the site and surrounding properties. As of June 30, 2022, we have recorded a liability of approximately $18 million for remediation costs at this site after further refining the scope of work and cost estimates as well as incorporating detailed design components specific to the site in 2021 (approximately $18 million as of December 31, 2021). SWL&P has also recorded an associated regulatory asset as we expect recovery of these remediation costs to be allowed by the PSCW. Remediation costs are expected to be incurred through 2024.
Other Matters.
Letters of Credit and Surety Bonds.
We have multiple credit facility agreements in place that provide the ability to issue standby letters of credit to satisfy contractual security requirements across our businesses. As of June 30, 2022, we had $150.2 million of outstanding letters of credit issued, including those issued under our revolving credit facility.
Regulated Operations. As of June 30, 2022, we had $18.1 million outstanding in standby letters of credit at our Regulated Operations which are pledged as security to MISO and a state agency.
ALLETE Clean Energy. ALLETE Clean Energy’s wind energy facilities have PSAs in place for their entire output and expire in various years between 2022 and 2039. As of June 30, 2022, ALLETE Clean Energy has $96.4 million outstanding in standby letters of credit, the majority of which are pledged as security under these PSAs and PSAs for wind energy facilities under development. ALLETE Clean Energy does not believe it is likely that any of these outstanding letters of credit will be drawn upon.
Corporate and Other.
BNI Energy. As of June 30, 2022, BNI Energy had surety bonds outstanding of $82.4 million related to the reclamation liability for closing costs associated with its mine and mine facilities. Although its coal supply agreements obligate the customers to provide for the closing costs, additional assurance is required by federal and state regulations. BNI Energy’s total reclamation liability is currently estimated at $82.1 million. BNI Energy does not believe it is likely that any of these outstanding surety bonds will be drawn upon.
Investment in Nobles 2. The Nobles 2 wind energy facility requires standby letters of credit as security for certain contractual obligations. As of June 30, 2022, ALLETE South Wind has $11.8 million outstanding in standby letters of credit, related to its portion of the security requirements relative to its ownership in Nobles 2. We do not believe it is likely that any of these outstanding letters of credit will be drawn upon.
South Shore Energy. As of June 30, 2022, South Shore Energy had $23.9 million outstanding in standby letters of credit pledged as security in connection with the development of NTEC. South Shore Energy does not believe it is likely that any of these outstanding letters of credit will be drawn upon.
Legal Proceedings.
We are involved in litigation arising in the normal course of business. Also in the normal course of business, we are involved in tax, regulatory and other governmental audits, inspections, investigations and other proceedings that involve state and federal taxes, safety, and compliance with regulations, rate base and cost of service issues, among other things. We do not expect the outcome of these matters to have a material effect on our financial position, results of operations or cash flows.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
25

NOTE 7. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Legal Proceedings (Continued)
Minnesota Power was named in a lawsuit where a contractor performing work at one of its facilities experienced an injury and subsequently filed a lawsuit seeking compensatory damages. In the second quarter of 2022, Minnesota Power reached an agreement to settle the lawsuit with the plaintiff. The settlement is covered by the Company’s insurance coverage, subject to a deductible which has been previously expensed. The settlement, which was recorded in the financial statements for the quarter ended March 31, 2022, did not have a material impact on our financial position or results of operations.
NOTE 8. EARNINGS PER SHARE AND COMMON STOCK
We compute basic earnings per share using the weighted average number of shares of common stock outstanding during each period. The difference between basic and diluted earnings per share, if any, arises from non-vested restricted stock units and performance share awards granted under our Executive Long-Term Incentive Compensation Plan.

|  |  | 2022 |  |  |  |  |  | 2021 |  |
Reconciliation of Basic and Diluted |  |  | Dilutive |  |  |  |  |  | Dilutive |  |
Earnings Per Share | Basic |  | Securities |  | Diluted |  | Basic |  | Securities |  | Diluted
Millions Except Per Share Amounts |  |  |  |  |  |  |  |  |  |  |
Quarter ended June 30, |  |  |  |  |  |  |  |  |  |  |
Net Income Attributable to ALLETE | $37.6 |  |  |  |  | $37.6 |  |  | $27.9 |  |  |  |  | $27.9 |
Average Common Shares | 56.1 |  |  | — |  |  | 56.1 |  |  | 52.2 |  |  | 0.1 |  |  | 52.3 |
Earnings Per Share | $0.67 |  |  |  |  | $0.67 |  |  | $0.53 |  |  |  |  | $0.53 |
Six Months Ended June 30, |  |  |  |  |  |  |  |  |  |  |
Net Income Attributable to ALLETE | $103.9 |  |  |  |  | $103.9 |  |  | $79.7 |  |  |  |  | $79.7 |
Average Common Shares | 54.9 |  |  | — |  |  | 54.9 |  |  | 52.2 |  |  | — |  |  | 52.2 |
Earnings Per Share | $1.89 |  |  |  |  | $1.89 |  |  | $1.53 |  |  |  |  | $1.53 |

On April 5, 2022, ALLETE issued and sold approximately 3.7 million shares of ALLETE common stock. Net proceeds of approximately $224 million were received from the sale of shares. Proceeds were used primarily to fund the acquisition of New Energy and capital investments at ALLETE Clean Energy.
NOTE 9. INCOME TAX EXPENSE

|  | Quarter Ended |  | Six Months Ended
|  | June 30, |  | June 30,
|  | 2022 |  | 2021 |  | 2022 |  | 2021
Millions |  |  |  |  |  |  |  |
Current Income Tax Expense (a) |  |  |  |  |  |  |  |
Federal |  | — |  |  | — |  |  | — |  |  | — |
State |  | — |  |  | — |  |  | $0.1 |  |  | — |
Total Current Income Tax Expense |  | — |  |  | — |  |  | $0.1 |  |  | — |
Deferred Income Tax Expense (Benefit) |  |  |  |  |  |  |  |
Federal (b) |  | $(3.7) |  | $(6.4) |  | $(12.3) |  | $(20.5)
State (c) |  | (4.5) |  | 2.5 |  | 0.3 |  | 6.4
Investment Tax Credit Amortization |  | (0.1) |  | (0.1) |  | (0.3) |  | (0.3)
Total Deferred Income Tax Benefit |  | $(8.3) |  | $(4.0) |  | $(12.3) |  | $(14.4)
Total Income Tax Benefit |  | $(8.3) |  | $(4.0) |  | $(12.2) |  | $(14.4)

(a)For the three and six months ended June 30, 2022 and 2021, the federal and state current tax expense was minimal due to NOLs which resulted from the bonus depreciation provisions of certain tax legislation. Federal and state NOLs are being carried forward to offset current and future taxable income.
(b)For the three and six months ended June 30, 2022 and 2021, the federal income tax benefit is primarily due to production tax credits.
(c)For the three and six months ended June 30, 2022, the state benefit includes the impact of deferred repricing as a result of the New Energy acquisition.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
26

NOTE 9. INCOME TAX EXPENSE (Continued)
The Company's tax provision for interim periods is determined using an estimate of its annual effective tax rate, adjusted for discrete items arising in that quarter. In each quarter, the Company updates its estimate of the annual effective tax rate and if the estimated annual effective tax rate changes, the Company would make a cumulative adjustment in that quarter.

| Quarter Ended | Six Months Ended
Reconciliation of Taxes from Federal Statutory | June 30, | June 30,
Rate to Total Income Tax Expense | 2022 |  | 2021 | 2022 |  | 2021
Millions |  |  |  |  |  |
Income Before Income Taxes | $12.5 |  |  | $17.7 |  | $55.1 |  |  | $50.7 |
Statutory Federal Income Tax Rate | 21 | % |  | 21 | % | 21 | % |  | 21 | %
Income Taxes Computed at Statutory Federal Rate | $2.6 |  |  | $3.7 |  | $11.6 |  |  | $10.6 |
Increase (Decrease) in Income Tax Due to: |  |  |  |  |  |
State Income Taxes (Credit) – Net of Federal Income Tax Benefit | 1.6 |  |  | 2.0 |  | 5.5 |  |  | 5.1 |
Deferred Revaluation – Net of Federal Income Tax Benefit | (5.2) |  |  | — |  | (5.2) |  |  | — |
Production Tax Credits | (7.1) |  |  | (8.5) |  | (24.7) |  |  | (27.1) |
Regulatory Differences – Excess Deferred Tax | (1.4) |  |  | (1.4) |  | (5.2) |  |  | (4.6) |
Non-Controlling Interest in Subsidiaries | 3.2 |  |  | 1.3 |  | 7.0 |  |  | 3.1 |
Share-Based Compensation | — |  |  | — |  | 0.5 |  |  | 0.5 |
Other | (2.0) |  |  | (1.1) |  | (1.7) |  |  | (2.0) |
Total Income Tax Benefit | $(8.3) |  | $(4.0) | $(12.2) |  | $(14.4)

For the six months ended June 30, 2022, the effective tax rate was a benefit of 22.1 percent (benefit of 28.4 percent for the six months ended June 30, 2021). The effective tax rate for 2022 and 2021 was primarily impacted by production tax credits.
Uncertain Tax Positions. As of June 30, 2022, we had gross unrecognized tax benefits of $1.3 million ($1.3 million as of December 31, 2021). Of the total gross unrecognized tax benefits, $0.6 million represents the amount of unrecognized tax benefits included on the Consolidated Balance Sheet that, if recognized, would favorably impact the effective income tax rate. The unrecognized tax benefit amounts have been presented as reductions to the tax benefits associated with NOL and tax credit carryforwards on the Consolidated Balance Sheet.
ALLETE and its subsidiaries file a consolidated federal income tax return as well as combined and separate state income tax returns in various jurisdictions. ALLETE has no open federal or state audits, and is no longer subject to federal examination for years before 2018, or state examination for years before 2017. Additionally, the statute of limitations related to the federal tax credit carryforwards will remain open until those credits are utilized in subsequent returns.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
27

NOTE 10. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS

| Pension |  | Other Postretirement
Components of Net Periodic Benefit Cost (Credit) | 2022 |  | 2021 |  | 2022 |  | 2021
Millions |  |  |  |  |  |  |
Quarter Ended June 30, |  |  |  |  |  |  |
Service Cost | $2.4 |  |  | $2.8 |  |  | $0.7 |  |  | $0.9 |
Non-Service Cost Components (a) |  |  |  |  |  |  |
Interest Cost | 6.8 |  |  | 6.2 |  |  | 1.1 |  |  | 1.1 |
Expected Return on Plan Assets | (10.3) |  |  | (10.9) |  |  | (2.4) |  |  | (2.5) |
Amortization of Prior Service Credits | (0.1) |  |  | (0.1) |  |  | (1.9) |  |  | (1.9) |
Amortization of Net Loss | 2.6 |  |  | 4.7 |  |  | 0.1 |  |  | 0.8 |
Net Periodic Benefit Cost (Credit) | $1.4 |  |  | $2.7 |  |  | $(2.4) |  | $(1.6)
Six Months Ended June 30, |  |  |  |  |  |  |
Service Cost | $4.8 |  |  | $5.5 |  |  | $1.5 |  |  | $1.8 |
Non-Service Cost Components (a) |  |  |  |  |  |  |
Interest Cost | 13.5 |  |  | 12.3 |  |  | 2.2 |  |  | 2.2 |
Expected Return on Plan Assets | (20.7) |  |  | (21.7) |  |  | (4.8) |  |  | (4.9) |
Amortization of Prior Service Credits | (0.1) |  |  | (0.1) |  |  | (3.8) |  |  | (3.8) |
Amortization of Net Loss | 5.8 |  |  | 9.4 |  |  | 0.2 |  |  | 1.5 |
Net Periodic Benefit Cost (Credit) | $3.3 |  |  | $5.4 |  |  | $(4.7) |  | $(3.2)

(a)These components of net periodic benefit cost (credit) are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.
Employer Contributions. For the six months ended June 30, 2022, we made no contributions to the defined benefit pension plans ($10.3 million for the six months ended June 30, 2021); we do not expect to make any contributions to our defined benefit pension plans in 2022. For the six months ended June 30, 2022 and 2021, we made no contributions to our other postretirement benefit plans; we do not expect to make any contributions to our other postretirement benefit plans in 2022.
NOTE 11. BUSINESS SEGMENTS
We present two reportable segments: Regulated Operations and ALLETE Clean Energy. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.
Regulated Operations includes three operating segments which consist of our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC. ALLETE Clean Energy is our business focused on developing, acquiring and operating clean and renewable energy projects. We also present Corporate and Other which includes BNI Energy, our coal mining operations in North Dakota, New Energy, a renewable energy development company, ALLETE Properties, our legacy Florida real estate investment, along with our investment in Nobles 2, South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, land holdings in Minnesota, and earnings on cash and investments.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
28

NOTE 11. BUSINESS SEGMENTS (Continued)

| Quarter Ended |  | Six Months Ended
| June 30, |  | June 30,
| 2022 | 2021 |  | 2022 | 2021
Millions |  |  |  |  |
Operating Revenue |  |  |  |  |
Regulated Operations |  |  |  |  |
Residential | $40.6 |  | $35.4 |  |  | $96.6 |  | $81.0 |
Commercial | 44.4 |  | 40.7 |  |  | 92.7 |  | 80.4 |
Municipal | 10.0 |  | 11.5 |  |  | 22.1 |  | 24.1 |
Industrial | 150.6 |  | 139.1 |  |  | 298.4 |  | 268.1 |
Other Power Suppliers | 36.9 |  | 37.3 |  |  | 77.9 |  | 75.7 |
Other | 26.2 |  | 26.4 |  |  | 50.0 |  | 54.1 |
Total Regulated Operations | 308.7 |  | 290.4 |  |  | 637.7 |  | 583.4 |
ALLETE Clean Energy |  |  |  |  |
Long-term PSA | 18.9 |  | 18.7 |  |  | 44.3 |  | 36.8 |
Other | 2.3 |  | 2.9 |  |  | 5.1 |  | 5.7 |
Total ALLETE Clean Energy | 21.2 |  | 21.6 |  |  | 49.4 |  | 42.5 |
Corporate and Other |  |  |  |  |
Long-term Contract | 21.4 |  | 21.4 |  |  | 44.0 |  | 43.1 |
Sale of Renewable Development Projects | 14.5 |  | — |  |  | 14.5 |  | — |
Other | 7.3 |  | 2.2 |  |  | 11.0 |  | 5.8 |
Total Corporate and Other | 43.2 |  | 23.6 |  |  | 69.5 |  | 48.9 |
Total Operating Revenue | $373.1 |  | $335.6 |  |  | $756.6 |  | $674.8 |
Net Income Attributable to ALLETE |  |  |  |  |
Regulated Operations | $29.6 |  | $21.5 |  |  | $81.1 |  | $66.5 |
ALLETE Clean Energy | 5.8 |  | 5.1 |  |  | 22.3 |  | 12.5 |
Corporate and Other (a) | 2.2 |  | 1.3 |  |  | 0.5 |  | 0.7 |
Total Net Income Attributable to ALLETE | $37.6 |  | $27.9 |  |  | $103.9 |  | $79.7 |

(a)Net Income in 2022 includes $4.0 million after-tax of purchase price accounting adjustments and $3.0 million after-tax of transaction costs related to the acquisition of New Energy.

| June 30, 2022 | December 31, 2021
Millions |  |
Assets |  |
Regulated Operations | $4,370.9 |  | $4,289.4 |
ALLETE Clean Energy | 1,834.9 |  | 1,719.4 |
Corporate and Other | 633.2 |  | 426.2 |
Total Assets | $6,839.0 |  | $6,435.0 |

ALLETE, Inc. Second Quarter 2022 Form 10-Q
29

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
OVERVIEW
The following discussion should be read in conjunction with our Consolidated Financial Statements and notes to those statements, Management’s Discussion and Analysis of Financial Condition and Results of Operations from our 2021 Form 10-K, and the other financial information appearing elsewhere in this report. In addition to historical information, the following discussion and other parts of this Form 10-Q contain forward-looking information that involves risks and uncertainties. Readers are cautioned that forward-looking statements should be read in conjunction with our disclosures in this Form 10-Q, including Part II, Item 1A Risk Factors, and our 2021 Form 10-K under the headings: “Forward-Looking Statements” located on page 6 and “Risk Factors” located in Part I, Item 1A, beginning on page 24 of our 2021 Form 10-K. The risks and uncertainties described in this Form 10-Q and our 2021 Form 10-K are not the only risks facing our Company. Additional risks and uncertainties that we are not presently aware of, or that we currently consider immaterial, may also affect our business operations. Our business, financial condition or results of operations could suffer if the risks are realized.
Regulated Operations includes our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC, a Wisconsin-based regulated utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. Minnesota Power provides regulated utility electric service in northeastern Minnesota to approximately 150,000 retail customers. Minnesota Power also has 14 non-affiliated municipal customers in Minnesota. SWL&P is a Wisconsin utility and a wholesale customer of Minnesota Power. SWL&P provides regulated utility electric, natural gas and water service in northwestern Wisconsin to approximately 15,000 electric customers, 13,000 natural gas customers and 10,000 water customers. Our regulated utility operations include retail and wholesale activities under the jurisdiction of state and federal regulatory authorities. (See Note 2. Regulatory Matters.)
ALLETE Clean Energy focuses on developing, acquiring, and operating clean and renewable energy projects. ALLETE Clean Energy currently owns and operates, in seven states, more than 1,300 MW of nameplate capacity wind energy generation that is contracted under PSAs of various durations. In addition, ALLETE Clean Energy also engages in the development of wind energy facilities to operate under long-term PSAs or for sale to others upon completion. ALLETE Clean Energy currently has approximately 200 MW wind energy facilities under contract to be sold to others.
Corporate and Other is comprised of BNI Energy, our coal mining operations in North Dakota; New Energy, a renewable development company, our investment in Nobles 2, an entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota; South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility; ALLETE Properties, our legacy Florida real estate investment; other business development and corporate expenditures; unallocated interest expense; a small amount of non-rate base generation; land holdings in Minnesota, and earnings on cash and investments.
ALLETE is incorporated under the laws of Minnesota. Our corporate headquarters are in Duluth, Minnesota. Statistical information is presented as of June 30, 2022, unless otherwise indicated. All subsidiaries are wholly-owned unless otherwise specifically indicated. References in this report to “we,” “us” and “our” are to ALLETE and its subsidiaries, collectively.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
30

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS (Continued)
Financial Overview
The following net income discussion summarizes a comparison of the six months ended June 30, 2022, to the six months ended June 30, 2021.
Net income attributable to ALLETE for the six months ended June 30, 2022, was $103.9 million, or $1.89 per diluted share, compared to $79.7 million, or $1.53 per diluted share, for the same period in 2021. Net income in 2022 included purchase price accounting adjustments of $4.0 million after-tax, or $0.07 per share, and transaction costs of $3.0 million after-tax, or $0.06 per share, related to the acquisition of New Energy. Net income in 2021 included an approximately $5 million after-tax, or $0.10 per share, negative impact related to ALLETE Clean Energy’s Diamond Spring wind energy facility due to an extreme winter storm event in the southwest United States in February 2021. Earnings per share dilution in 2022 was $0.10 due to additional shares of common stock outstanding as of June 30, 2022.
Regulated Operations net income attributable to ALLETE was $81.1 million for the six months ended June 30, 2022, compared to $66.5 million for the same period in 2021. Net income at Minnesota Power was higher than 2021 primarily due to the implementation of interim rates on January 1, 2022. These increases were partially offset by higher costs under a PPA with Manitoba Hydro, higher operating and maintenance expense, and lower kWh sales to industrial customers.
ALLETE Clean Energy net income attributable to ALLETE was $22.3 million for the six months ended June 30, 2022, compared to $12.5 million for the same period in 2021. Net income in 2022 reflected higher wind resources compared to 2021, partially offset by losses incurred under the Caddo wind energy facility’s power sales agreements resulting from extreme market volatility and transmission congestion in the Southwest Power Pool. Net income in 2021 included an approximately $5 million after-tax negative impact related to ALLETE Clean Energy’s Diamond Spring wind energy facility due to an extreme winter storm event in the southwest United States in February 2021. This winter storm event caused volatility in power prices in the regional power market resulting in losses being incurred under the facility’s power sales agreements during portions of the winter storm event.
Corporate and Other net income attributable to ALLETE was $0.5 million for the six months ended June 30, 2022, compared to net income of $0.7 million for the same period in 2021. Net income in 2022 reflects higher earnings from our investment in Nobles 2 due to higher wind resources in 2022, higher land sales at ALLETE Properties and lower income taxes. These increases were partially offset by a net loss from New Energy of $1.1 million, which included purchase price accounting adjustments of $4.0 million after-tax, and transaction costs of $3.0 million after-tax related to the acquisition of New Energy, and higher other expenses compared to 2021.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
31

COMPARISON OF THE QUARTER ENDED JUNE 30, 2022 AND 2021
(See Note 11. Business Segments for financial results by segment.)
Regulated Operations

Quarter Ended June 30, | 2022 | 2021
Millions |  |
Operating Revenue – Utility | $308.7 |  | $290.4 |
Fuel, Purchased Power and Gas – Utility | 143.2 |  | 128.9 |
Transmission Services – Utility | 18.3 |  | 19.2 |
Operating and Maintenance | 57.1 |  | 55.3 |
Depreciation and Amortization | 43.6 |  | 42.6 |
Taxes Other than Income Taxes | 11.9 |  | 15.9 |
Operating Income | 34.6 |  | 28.5 |
Interest Expense | (14.4) |  | (14.4) |
Equity Earnings | 5.3 |  | 5.2 |
Other Income | 2.8 |  | 0.7 |
Income Before Income Taxes | 28.3 |  | 20.0 |
Income Tax Benefit | (1.3) |  | (1.5) |
Net Income Attributable to ALLETE | $29.6 |  | $21.5 |

Operating Revenue – Utility increased $18.3 million from 2021 primarily due to the implementation of interim rates at Minnesota Power on January 1, 2022, and higher fuel adjustment clause recoveries as well as timing of financial incentives and increased recoveries under the Minnesota conservation improvement program. These increases were partially offset by lower revenue from kWh sales, lower cost recovery rider revenue and lower transmission revenue.
Interim retail rates for Minnesota Power, subject to refund, were approved by the MPUC and became effective January 1, 2022, resulting in revenue of $21.4 million. (See Note 2. Regulatory Matters.)
Fuel adjustment clause revenue increased $7.3 million due to higher fuel and purchased power costs attributable to retail and municipal customers. (See Fuel, Purchased Power and Gas – Utility.)
Financial incentives under the Minnesota conservation improvement program were $1.9 million higher than 2021 due to the timing of MPUC approval. (See Note 2. Regulatory Matters.)
Conservation improvement program recoveries increased $1.7 million from 2021 primarily due to an increase in related expenditures. (See Operating Expenses - Operating and Maintenance.)
Revenue from kWh sales was down $7.3 million from 2021 reflecting lower sales to retail and municipal customers as well as other power suppliers. Sales to industrial customers decreased primarily due to lower sales to taconite customers resulting from less taconite production in 2022 compared to 2021, reflecting Cliffs’ Northshore mine being temporarily idled in 2022. (See Outlook - Customers - Northshore Mining.) Sales to residential, commercial and municipal customers decreased from 2021 primarily due to milder weather in the second quarter of 2022 compared to 2021. Sales to other power suppliers, which are sold at market-based prices into the MISO market on a daily basis or through PSAs of various durations, decreased in 2022 compared to 2021 primarily due to additional kWh sales made in 2021 to mitigate the uncertainty of customers’ energy needs and potential load loss due to the COVID-19 pandemic.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
32

COMPARISON OF THE QUARTER ENDED JUNE 30, 2022 AND 2021 (Continued)
Regulated Operations (Continued)

Kilowatt-hours Sold |  |  |  |  | Variance
Quarter Ended June 30, | 2022 |  | 2021 |  | Quantity |  | %
Millions |  |  |  |  |  |  |
Regulated Utility |  |  |  |  |  |  |
Retail and Municipal |  |  |  |  |  |  |
Residential | 245 |  |  | 247 |  |  | (2) |  |  | (0.8) | %
Commercial | 314 |  |  | 317 |  |  | (3) |  |  | (0.9) | %
Industrial | 1,616 |  |  | 1,775 |  |  | (159) |  |  | (9.0) | %
Municipal | 131 |  |  | 138 |  |  | (7) |  |  | (5.1) | %
Total Retail and Municipal | 2,306 |  |  | 2,477 |  |  | (171) |  |  | (6.9) | %
Other Power Suppliers | 794 |  |  | 1,194 |  |  | (400) |  |  | (33.5) | %
Total Regulated Utility Kilowatt-hours Sold | 3,100 |  |  | 3,671 |  |  | (571) |  |  | (15.6) | %

Revenue from electric sales to taconite customers accounted for 34 percent of regulated operating revenue in 2022 (34 percent in 2021). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 5 percent of regulated operating revenue in 2022 (5 percent in 2021). Revenue from electric sales to pipelines and other industrial customers accounted for 9 percent of regulated operating revenue in 2022 (9 percent in 2021).
Cost recovery rider revenue decreased $7.1 million primarily due to additional production tax credits recognized by Minnesota Power. If production tax credits are recognized at a level above those assumed in Minnesota Power’s retail rates, a decrease in cost recovery rider revenue is recognized to offset the impact of higher production tax credits on income tax expense.
Transmission revenue decreased $2.3 million primarily due to lower MISO-related revenue.
Operating Expenses increased $12.2 million, or 5 percent, from 2021.
Fuel, Purchased Power and Gas – Utility expense increased $14.3 million, or 11 percent, from 2021 primarily due to higher purchased power prices and fuel costs, partially offset by lower kWh sales. Fuel and purchased power expense related to our retail and municipal customers is recovered through the fuel adjustment clause.
Operating and Maintenance expense increased $1.8 million, or 3 percent, from 2021 primarily due to higher conservation improvement program expenses, materials purchased for generation facilities and labor expenses. This was partially offset by lower benefit expenses as compared to 2021. In addition, 2022 included rate case-related expenses for Minnesota Power’s ongoing rate case. (See Note 2. Regulatory Matters.)
Depreciation and Amortization expense increased $1.0 million, or 2 percent, from 2021 primarily due to additional property, plant and equipment in service.
Taxes Other than Income Taxes decreased $4.0 million, or 25 percent from 2021 primarily due to lower property tax expense resulting from an updated estimate of taxable market values and rates in 2022.
Income Tax Benefit was lower than 2021 primarily due to higher pre-tax income. We expect our annual effective tax rate in 2022 to be a lower income tax benefit than in 2021 primarily due to higher pre-tax income and lower production tax credits.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
33

COMPARISON OF THE QUARTER ENDED JUNE 30, 2022 AND 2021 (Continued)
ALLETE Clean Energy

Quarter Ended June 30, | 2022 | 2021
Millions |  |
Operating Revenue |  |
Contracts with Customers – Non-utility | $18.9 |  | $18.7 |
Other – Non-utility (a) | 2.3 |  | 2.9 |
Cost of Sales – Non-utility | 10.2 |  | — |
Operating and Maintenance | 12.5 |  | 9.2 |
Depreciation and Amortization | 14.5 |  | 12.2 |
Taxes Other than Income Taxes | 3.1 |  | 1.6 |
Operating Loss | (19.1) |  | (1.4) |
Interest Expense | (0.7) |  | (0.4) |
Other Income | 10.3 |  | 0.1 |
Loss Before Income Taxes | (9.5) |  | (1.7) |
Income Tax Benefit | (1.5) |  | (2.6) |
Net Income (Loss) | (8.0) |  | 0.9 |
Net Loss Attributable to Non-Controlling Interest | (13.8) |  | (4.2) |
Net Income Attributable to ALLETE | $5.8 | $5.1 |

(a)Represents non-cash amortization of differences between contract prices and estimated market prices on assumed PSAs.
Operating Revenue was similar to 2021. Operating revenue reflected higher kWh sales, mostly offset by losses incurred under the Caddo wind energy facility’s power sales agreements resulting from extreme market volatility and transmission congestion in the Southwest Power Pool.

| Quarter Ended June 30,
| 2022 | 2021
Production and Operating Revenue | kWh | Revenue | kWh | Revenue
Millions |  |  |  |
Wind Energy Regions |  |  |  |
East | 58.0 |  | $5.2 |  | 47.9 |  | $4.3 |
Midwest | 203.5 |  | 7.3 |  | 221.5 |  | 8.1 |
South | 574.8 |  | 3.9 |  | 237.4 |  | 4.2 |
West | 214.4 |  | 4.8 |  | 167.7 |  | 5.0 |
Total Production and Operating Revenue | 1,050.7 |  | $21.2 |  | 674.5 |  | $21.6 |

Cost of Sales – Non-utility increased $10.2 million from 2021 reflecting a reserve for an anticipated loss on sale of ALLETE Clean Energy’s project to repower and sell its Northern Wind project, which was fully offset by a gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the wind energy facility. (See Other Income and Outlook – ALLETE Clean Energy.)
Operating and Maintenance expense increased $3.3 million, or 36 percent, from 2021 primarily due to operating and maintenance expenses related to the Caddo wind energy facility, which commenced operations in December 2021.
Depreciation and Amortization expense increased $2.3 million, or 19 percent, from 2021 primarily due to additional property, plant and equipment in service related to the Caddo wind energy facility.
Taxes Other than Income Taxes increased $1.5 million from 2021 primarily due to higher property tax expense related to Caddo wind energy facility.
Other Income increased $10.2 million from 2021 primarily due to a gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the wind energy facility. (See Cost of Sales – Non-utility and Outlook – ALLETE Clean Energy.)
Income Tax Benefit decreased $1.1 million from 2021 primarily due to lower production tax credits and higher net loss attributable to non-controlling interest, partially offset by lower pre-tax income.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
34

COMPARISON OF THE QUARTER ENDED JUNE 30, 2022 AND 2021 (Continued)
ALLETE Clean Energy (Continued)
Net Loss Attributable to Non-Controlling Interest increased $9.6 million from 2021 reflecting net losses attributable to non-controlling interest for the Caddo wind energy facility as well as higher net losses attributable to non-controlling interests for the Glen Ullin, South Peak and Diamond Spring wind energy facilities resulting primarily from higher wind resources.
Corporate and Other
Operating Revenue increased $19.6 million from 2021 reflecting revenue from New Energy, which was acquired in April 2022, as well as higher land sales at ALLETE Properties compared to 2021.
Net Income Attributable to ALLETE of $2.2 million in 2022 compared to net income of $1.3 million in 2021. Net income in 2022 included higher earnings from our investment in Nobles 2 reflecting higher wind resources in 2022, higher land sales at ALLETE Properties and lower income taxes. These increases were partially offset by a net loss from New Energy of $1.1 million, which included purchase price accounting adjustments of $4.0 million after-tax, and transaction costs of $1.6 million after-tax related to the acquisition of New Energy, and higher other expenses compared to 2021.
Income Taxes – Consolidated
For the quarter ended June 30, 2022, the effective tax rate was a benefit of 66.4 percent (benefit of 22.6 percent for the quarter ended June 30, 2021). The effective tax rate for 2022 was a higher benefit primarily due to the impact of deferred repricing as a result of the New Energy acquisition.
We expect our annual effective tax rate in 2022 to be a lower income tax benefit than in 2021 primarily due to higher non-controlling interests in subsidiaries, higher pre-tax income, and lower production tax credits. The estimated annual effective tax rate can differ from what a quarterly effective tax rate would otherwise be on a standalone basis, and this may cause quarter to quarter differences in the timing of income taxes.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
35

COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2022 AND 2021
(See Note 11. Business Segments for financial results by segment.)
Regulated Operations

Six Months Ended June 30, | 2022 | 2021
Millions |  |
Operating Revenue – Utility | $637.7 |  | $583.4 |
Fuel, Purchased Power and Gas – Utility | 280.6 |  | 249.3 |
Transmission Services – Utility | 38.2 |  | 36.9 |
Operating and Maintenance | 115.5 |  | 105.7 |
Depreciation and Amortization | 87.0 |  | 85.6 |
Taxes Other than Income Taxes | 27.1 |  | 31.6 |
Operating Income | 89.3 |  | 74.3 |
Interest Expense | (28.3) |  | (28.6) |
Equity Earnings | 10.7 |  | 10.5 |
Other Income | 4.6 |  | 3.1 |
Income Before Income Taxes | 76.3 |  | 59.3 |
Income Tax Benefit | (4.8) |  | (7.2) |
Net Income Attributable to ALLETE | $81.1 |  | $66.5 |

Operating Revenue – Utility increased $54.3 million from 2021 primarily due to the implementation of interim rates at Minnesota Power on January 1, 2022, higher fuel adjustment clause recoveries, increased conservation improvement program recoveries, increased gas sales and timing of financial incentives under the Minnesota conservation improvement program. These increases were partially offset by lower cost recovery rider and transmission revenue.
Interim retail rates for Minnesota Power, subject to refund, were approved by the MPUC and became effective January 1, 2022, resulting in revenue of $45.7 million. (See Note 2. Regulatory Matters.)
Fuel adjustment clause revenue increased $9.9 million due to higher fuel and purchased power costs attributable to retail and municipal customers. (See Fuel, Purchased Power and Gas – Utility.)
Conservation improvement program recoveries increased $3.7 million from 2021 primarily due to an increase in related expenditures. (See Operating Expenses - Operating and Maintenance.)
Gas sales at SWL&P increased $3.1 million as a result of colder weather and higher gas prices in the first quarter of 2022 compared to 2021. (See Fuel, Purchased Power and Gas – Utility.)
Financial incentives under the Minnesota conservation improvement program were $1.9 million higher than 2021 due to the timing of MPUC approval. (See Note 2. Regulatory Matters.)
Cost recovery rider revenue decreased $10.2 million primarily due to additional production tax credits recognized by Minnesota Power. If production tax credits are recognized at a level above those assumed in Minnesota Power’s retail rates, a decrease in cost recovery rider revenue is recognized to offset the impact of higher production tax credits on income tax expense.
Transmission revenue decreased $2.1 million primarily due to lower MISO-related revenue.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
36

COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2022 AND 2021 (Continued)
Regulated Operations (Continued)
Revenue from kWh sales was similar to 2021 reflecting higher sales to residential and commercial customers as well as higher pricing on sales to other power suppliers, offset by lower sales to industrial customers and other power suppliers. Sales to residential and commercial customers increased from 2021 primarily due to colder weather in the first quarter of 2022 compared to 2021. Sales to industrial customers decreased primarily due to lower sales to taconite customers resulting from less taconite production in 2022 compared to 2021, reflecting Cliffs’ Northshore mine being temporarily idled in 2022. (See Outlook - Customers - Northshore Mining.) Sales to other power suppliers, which are sold at market-based prices into the MISO market on a daily basis or through PSAs of various durations, decreased in 2022 compared to 2021 primarily due to additional kWh sales made in 2021 to mitigate the uncertainty of customers’ energy needs and potential load loss due to the COVID-19 pandemic.

Kilowatt-hours Sold |  |  |  |  | Variance
Six Months Ended June 30, | 2022 |  | 2021 |  | Quantity |  | %
Millions |  |  |  |  |  |  |
Regulated Utility |  |  |  |  |  |  |
Retail and Municipal |  |  |  |  |  |  |
Residential | 600 |  |  | 578 |  |  | 22 |  |  | 3.8 | %
Commercial | 674 |  |  | 658 |  |  | 16 |  |  | 2.4 | %
Industrial | 3,382 |  |  | 3,573 |  |  | (191) |  |  | (5.3) | %
Municipal | 289 |  |  | 298 |  |  | (9) |  |  | (3.0) | %
Total Retail and Municipal | 4,945 |  |  | 5,107 |  |  | (162) |  |  | (3.2) | %
Other Power Suppliers | 1,775 |  |  | 2,442 |  |  | (667) |  |  | (27.3) | %
Total Regulated Utility Kilowatt-hours Sold | 6,720 |  |  | 7,549 |  |  | (829) |  |  | (11.0) | %

Revenue from electric sales to taconite customers accounted for 33 percent of regulated operating revenue in 2022 (32 percent in 2021). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 5 percent of regulated operating revenue in 2022 (4 percent in 2021). Revenue from electric sales to pipelines and other industrial customers accounted for 9 percent of regulated operating revenue in 2022 (9 percent in 2021).
Operating Expenses increased $39.3 million, or 8 percent, from 2021.
Fuel, Purchased Power and Gas – Utility expense increased $31.3 million, or 13 percent, from 2021 primarily due to higher purchased power prices and fuel costs as well as increased gas prices and sales, partially offset by lower kWh sales. Fuel and purchased power expense related to our retail and municipal customers is recovered through the fuel adjustment clause.
Transmission Services – Utility expense increased $1.3 million, or 4 percent, from 2021 primarily due to higher MISO-related expense.
Operating and Maintenance expense increased $9.8 million, or 9 percent, from 2021 primarily due to higher conservation improvement program expenses, materials purchased for generation facilities and labor expenses. In addition, 2022 included rate case-related expenses for Minnesota Power’s ongoing rate case. (See Note 2. Regulatory Matters.)
Depreciation and Amortization expense increased $1.4 million, or 2 percent, from 2021 primarily due to additional property, plant and equipment in service.
Taxes Other than Income Taxes decreased $4.5 million, or 14 percent, from 2021 primarily due to lower property tax expense resulting from an updated estimate of taxable market values and rates in 2022.
Income Tax Benefit decreased $2.4 million from 2021 primarily due to higher pre-tax income. We expect our annual effective tax rate in 2022 to be a lower income tax benefit than in 2021 primarily due to higher pre-tax income and lower production tax credits.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
37

COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2022 AND 2021 (Continued)
ALLETE Clean Energy

Six Months Ended June 30, | 2022 | 2021
Millions |  |
Operating Revenue |  |
Contracts with Customers – Non-utility | $44.3 | $36.8
Other – Non-utility (a) | 5.1 |  | 5.7 |
Cost of Sales – Non-utility | 10.2 |  | — |
Operating and Maintenance | 23.9 |  | 21.4 |
Depreciation and Amortization | 29.9 |  | 24.3 |
Taxes Other than Income Taxes | 6.1 |  | 3.5 |
Operating Loss | (20.7) |  | (6.7) |
Interest Expense | (1.8) |  | (0.8) |
Other Income | 10.4 |  | 0.3 |
Loss Before Income Taxes | (12.1) |  | (7.2) |
Income Tax Benefit | (4.0) |  | (8.5) |
Net Income (Loss) | (8.1) |  | 1.3 |
Net Loss Attributable to Non-Controlling Interest | (30.4) |  | (11.2) |
Net Income Attributable to ALLETE | $22.3 |  | $12.5 |

(a)Represents non-cash amortization of differences between contract prices and estimated market prices on assumed PSAs.
Operating Revenue increased $6.9 million, or 16 percent, from 2021 primarily due to the absence of the negative impact related to ALLETE Clean Energy’s Diamond Spring wind energy facility resulting from an extreme winter storm event in the southwest United States in February 2021 as well as higher wind resources at other wind energy facilities. Operating revenue in 2022 was also impacted by losses incurred under the Caddo wind energy facility’s power sales agreements resulting from extreme market volatility and transmission congestion in the Southwest Power Pool.

| Six Months Ended June 30,
| 2022 | 2021
Production and Operating Revenue | kWh | Revenue | kWh | Revenue
Millions |  |  |  |
Wind Energy Regions |  |  |  |
East | 145.3 |  | $13.2 |  | 127.3 |  | $11.5 |
Midwest | 491.1 |  | 16.9 |  | 461.6 |  | 16.5 |
South | 1,177.7 |  | 8.5 |  | 513.8 |  | 3.4 |
West | 472.7 |  | 10.8 |  | 389.5 |  | 11.1 |
Total Production and Operating Revenue | 2,286.8 |  | $49.4 |  | 1,492.2 |  | $42.5 |

Cost of Sales – Non-utility increased $10.2 million from 2021 reflecting a reserve for an anticipated loss on sale of ALLETE Clean Energy’s project to repower and sell its Northern Wind project, which was fully offset by a gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the wind energy facilities. (See Other Income and Outlook – ALLETE Clean Energy.)
Operating and Maintenance expense increased $2.5 million, or 12 percent, from 2021 primarily due to operating and maintenance expenses related to the Caddo wind energy facility, which commenced operations in December 2021.
Depreciation and Amortization expense increased $5.6 million, or 23 percent, from 2021 primarily due to additional property, plant and equipment in service related to the Caddo wind energy facility.
Taxes Other than Income Taxes increased $2.6 million from 2021 primarily due to higher property tax expense related to the Caddo wind energy facility.
Other Income increased $10.1 million from 2021 primarily due to a gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the wind energy facilities. (See Cost of Sales – Non-utility and Outlook – ALLETE Clean Energy.)
ALLETE, Inc. Second Quarter 2022 Form 10-Q
38

COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2022 AND 2021 (Continued)
ALLETE Clean Energy (Continued)
Income Tax Benefit decreased $4.5 million from 2021 primarily due to higher net loss attributable to non-controlling interest.
Net Loss Attributable to Non-Controlling Interest increased $19.2 million from 2021 reflecting net losses attributable to non-controlling interest for the Caddo wind energy facility as well as higher net losses attributable to non-controlling interests for the Glen Ullin, South Peak and Diamond Spring wind energy facilities resulting from higher wind resources.
Corporate and Other
Operating Revenue increased $20.6 million, or 42 percent, from 2021 reflecting revenue from New Energy, which was acquired in April 2022, as well as higher land sales at ALLETE Properties compared to 2021.
Net Income Attributable to ALLETE was $0.5 million in 2022 compared to $0.7 million in 2021. Net income in 2022 reflects higher earnings from our investment in Nobles 2 due to higher wind resources in 2022, higher land sales at ALLETE Properties and lower income taxes. These increases were partially offset by a net loss from New Energy of $1.1 million, which included purchase price accounting adjustments of $4.0 million after-tax, and transaction costs of $3.0 million after-tax related to the acquisition of New Energy, and higher other expenses compared to 2021.
Income Taxes – Consolidated
For the six months ended June 30, 2022, the effective tax rate was a benefit of 22.1 percent (benefit of 28.4 percent for the six months ended June 30, 2021). The effective tax rate for 2022 was a lower benefit primarily due to higher pre-tax income and higher net losses attributable to non-controlling interests in subsidiaries.
We expect our annual effective tax rate in 2022 to be a lower income tax benefit than in 2021 primarily due to higher net losses attributable to non-controlling interests in subsidiaries, higher pre-tax income and lower production tax credits. The estimated annual effective tax rate can differ from what a quarterly effective tax rate would otherwise be on a standalone basis, and this may cause quarter to quarter differences in the timing of income taxes. (See Note 9. Income Tax Expense.)
CRITICAL ACCOUNTING POLICIES
Certain accounting measurements under GAAP involve management’s judgment about subjective factors and estimates, the effects of which are inherently uncertain. Accounting measurements that we believe are most critical to our reported results of operations and financial condition include: regulatory accounting, pension and postretirement health and life actuarial assumptions, valuation of business combinations and resulting goodwill, impairment of long-lived assets, and taxation. These policies are reviewed with the Audit Committee of our Board of Directors on a regular basis and summarized in Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations of our 2021 Form 10-K. As a result of our acquisition of New Energy on April 15, 2022, the valuation of business combination and resulting goodwill is considered a critical accounting policy.
Valuation of Business Combinations and Resulting Goodwill. When we acquire a business, the assets acquired and liabilities assumed are recorded at their respective fair values as of the acquisition date. Determining the fair value of intangible assets acquired as part of a business combination requires us to make significant estimates. These estimates may include the amount and timing of projected future cash flows, the discount rate used to discount those cash flows to present value, the assessment of the asset’s life cycle, and the consideration of legal, technical, regulatory, economic and competitive risks.
Goodwill. Goodwill is the excess of the purchase price (consideration transferred) over the estimated fair value of net assets of acquired businesses. In accordance with GAAP, goodwill is not amortized. The Company assesses whether there has been an impairment of goodwill annually in the fourth quarter and whenever an event occurs or circumstances change that would indicate the carrying amount may be impaired. Impairment testing for goodwill is done at the reporting unit level. An impairment loss is recognized when the carrying amount of the reporting unit’s net assets exceeds the estimated fair value of the reporting unit. The test for impairment requires us to make several estimates about fair value, most of which are based on projected future cash flows. Our estimates associated with the goodwill impairment test are considered critical due to the amount of goodwill recorded on our Consolidated Balance Sheet and the judgment required in determining fair value, including projected future cash flows.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
39

OUTLOOK
For additional information see our 2021 Form 10-K.
ALLETE is an energy company committed to earning a financial return that rewards our shareholders, allows for reinvestment in our businesses, and sustains growth. The Company has a long-term objective of achieving consolidated average annual earnings per share growth within a range of 5 percent to 7 percent.
ALLETE is predominately a regulated utility through Minnesota Power, SWL&P, and an investment in ATC. ALLETE’s strategy is to remain predominately a regulated utility while investing in ALLETE Clean Energy and New Energy and its Corporate and Other businesses to complement its regulated businesses, balance exposure to the utility’s industrial customers, and provide potential long-term earnings growth. ALLETE expects net income from Regulated Operations to be approximately 80 percent of total consolidated net income in 2022. Over the next several years, ALLETE expects increased contributions to net income from ALLETE Clean Energy, New Energy, and its Corporate and Other businesses as ALLETE grows these operations. ALLETE expects its businesses to provide regulated, contracted or recurring revenues, and to support sustained growth in net income and cash flow.
Regulated Operations. Minnesota Power’s long-term strategy is to be the leading electric energy provider in northeastern Minnesota by providing safe, reliable and cost-competitive electric energy, while complying with environmental permit conditions and renewable energy requirements. Keeping the cost of energy production competitive enables Minnesota Power to effectively compete in the wholesale power markets and minimizes retail rate increases to help maintain customer viability. As part of maintaining cost competitiveness, Minnesota Power intends to reduce its exposure to possible future carbon and GHG legislation by reshaping its generation portfolio, over time, to reduce its reliance on coal. Minnesota Power has a goal of delivering 100 percent carbon-free energy by 2050. (See EnergyForward.) We will monitor and review proposed environmental regulations and may challenge those that add considerable cost with limited environmental benefit. Minnesota Power will continue to pursue customer growth opportunities and cost recovery rider approvals for transmission, renewable and environmental investments, as well as work with regulators to earn a fair rate of return.
2022 Wisconsin General Rate Case. On June 1, 2022, SWL&P refiled its rate increase request with the PSCW seeking an average increase of 3.6 percent for retail customers. The filing seeks an overall return on equity of 10.4 percent and a 55 percent equity ratio. On an annualized basis, the requested final rate increase would generate approximately $4.3 million in additional revenue.
Industrial and Municipal Customers and Prospective Additional Load.
Industrial Customers. Electric power is one of several key inputs in the taconite mining, paper, pulp and secondary wood products, pipeline and other industries. Approximately 50 percent of our regulated utility kWh sales in the six months ended June 30, 2022, were made to our industrial customers (47 percent in the six months ended June 30, 2021).
Cliffs. In 2020, Cliffs announced that it had completed the previously announced acquisition of substantially all of the operations of ArcelorMittal USA LLC and its subsidiaries. Cliffs had stated that upon closure of the acquisition Cliffs would be the largest flat-rolled steel producer and the largest iron ore pellet producer in North America. The acquisition included ArcelorMittal’s Minorca mine in Virginia, Minnesota, and its ownership share of Hibbing Taconite in Hibbing, Minnesota, which are both large industrial customers of Minnesota Power. Cliffs is Minnesota Power’s largest customer. The acquisition has increased customer concentration risk for the Company and could lead to further capacity consolidation for both steel blast furnaces and related Minnesota iron ore production.
Cliffs completed construction of a hot briquetted iron production plant in Toledo, Ohio, in 2020, which has utilized direct reduced-grade pellets from Northshore Mining. In October 2021, Cliffs indicated it plans to move direct reduced-grade pellet production to its Minorca mine and that Northshore Mining would become a “swing facility” due to the higher royalty rates at that mine. (See Northshore Mining.).
Northshore Mining. On February 11, 2022, Cliffs announced that with the use of additional scrap in its basic oxygen furnaces, its iron ore needs are not as high as before. In determining where to adjust production, Cliffs decided to idle all production at its Northshore mine until at least April 2023. Cliffs has also indicated that going forward it will be limiting the tonnage of iron ore pellets sold to third parties. Northshore Mining has the capability to produce approximately 6 million tons annually. Minnesota Power has a PSA through 2031 with Silver Bay Power, which provides the majority of the electric service requirements for Northshore Mining. (See Cliffs.)
ALLETE, Inc. Second Quarter 2022 Form 10-Q
40

OUTLOOK (Continued)
Industrial and Municipal Customers and Prospective Additional Load (Continued)
USS Corporation. On June 28, 2022, USS Corporation announced plans to invest approximately $150 million and to begin to construct a system in the fall of 2022 dedicated to producing direct reduced-grade (DR-grade) pellets. On July 28, 2022, USS Corporation subsequently announced the system will be constructed at its Keetac plant and is expected to be completed in 2024. This will enable the existing pelletizing plant to not only create DR-grade pellets for use as a feedstock for a direct reduced iron (DRI) or hot briquetted iron (HBI) process that ultimately supplies electric arc furnace steelmaking but also maintains the optionality to continue producing blast furnace-grade pellets. USS Corporation’s Minntac and Keetac plants are large power industrial customers of Minnesota Power. USS Corporation has the capability to produce approximately 15 million and 5 million tons annually at its Minntac and Keetac plants, respectively.
ST Paper. In May 2021, ST Paper announced it had completed the purchase of the Duluth Mill from Verso Corporation. ST Paper has stated it plans to convert the Duluth Mill to produce tissue. In January 2022, Minnesota Power entered into an electric service agreement with ST Paper that would begin Large Power customer service with a minimum term of six years upon start-up of operations, which is anticipated in 2023. A petition for approval of the electric service agreement was approved by the MPUC in February 2022. Upon start-up of operations, ST Paper will become a Large Power customer as we expect to serve requirements of at least 10 MW of customer load.
Hibbing Public Utilities. In April 2022, Minnesota Power entered into a new long-term Power Purchase and Market Energy Service Agreement with Hibbing Public Utilities for the period of June 1, 2022 through May 31, 2027. The agreement replaces the 2015 Electric Services Agreement between Hibbing Public Utilities and Minnesota Power that was under FERC jurisdiction.
Transmission.
MISO Long Range Transmission Plan. Minnesota Power and Great River Energy announced on July 25, 2022, their intent to build a 150-mile, 345-kV transmission line, connecting northern Minnesota to central Minnesota to support continued reliability in the Upper Midwest. Great River Energy, a wholesale electric power cooperative, and Minnesota Power filed a Notice of Intent to Construct, Own and Maintain the transmission line with the MPUC on August 1, 2022. This joint project is part of a portfolio of transmission projects approved on July 25, 2022, by MISO, as part of the first phase of its Long Range Transmission Plan. Planning for the $970 million transmission line is in its early stages with the route anticipated to generally follow existing rights of way in an established power line corridor. The two utilities expect to seek a combined Certificate of Need and Route Permit from the MPUC. The MPUC will determine the final route as well as cost recovery for Minnesota Power’s approximately 50 percent estimated share of the project. Subject to regulatory approvals, the transmission line is expected to be in service in 2030.
ALLETE Clean Energy.
ALLETE Clean Energy will pursue growth through acquisitions or project development. ALLETE Clean Energy is targeting acquisitions of existing operating portfolios which have a mix of long-term PSAs in place and/or available for repowering and recontracting. Further, ALLETE Clean Energy will evaluate actions that will lead to the addition of complimentary clean energy products and services. At this time, ALLETE Clean Energy is focused on actions that will optimize its clean energy project portfolio of operating and development projects, which may include recontracting, repowering, entering into partnerships and divestitures along with continued acquisitions or development of new projects including wind, solar, energy storage or storage ready facilities across North America. ALLETE Clean Energy is also targeting the development of new facilities up to 300 MW each, which will have long-term PSAs in place for the output or may be sold upon completion.
In July 2022, ALLETE Clean Energy entered into amended purchase and sale agreements with a subsidiary of Xcel Energy Inc. to sell two separate wind energy facilities for a combined total sales price of approximately $215 million. As part of the transaction, ALLETE Clean Energy will repower its Northern Wind project, consisting of its 98 MW Chanarambie and Viking wind energy facilities as well as develop and construct a new 22 MW facility, both of which are located in southwest Minnesota. Construction commenced in the second quarter of 2022 and is expected to be completed in late 2022. The amended purchase and sale agreements are subject to MPUC approval, and are expected to close in late 2022 and early 2023, respectively.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
41

OUTLOOK (Continued)
ALLETE Clean Energy (Continued)
In May 2021, ALLETE Clean Energy announced that it acquired the rights to the approximately 92 MW Red Barn wind development project and the approximately 68 MW Whitetail renewable development project in southwestern Wisconsin. ALLETE Clean Energy also signed an asset sale agreement for the completed Red Barn wind project with Wisconsin Public Service Corporation and Madison Gas and Electric Company. At a hearing in January 2022, the PSCW approved the sale of the Red Barn wind project, which is expected to close in 2023, subject to completion of construction.
Corporate and Other.
Corporate and Other includes BNI Energy, our coal mining operations in North Dakota, New Energy, a renewable energy development company, and ALLETE Properties, our legacy Florida real estate investment, along with our investment in Nobles 2, South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, land in Minnesota, and earnings on cash and investments.
New Energy. On April 15, 2022, a wholly-owned subsidiary of ALLETE acquired 100 percent of the membership interests of New Energy for a purchase price of $165.5 million. New Energy, which is headquartered in Annapolis, Maryland, is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. New Energy is a leading developer of community, commercial and industrial, and small utility-scale renewable energy projects that has completed more than 250 projects across the nation totaling more than 330 MW. New Energy currently has a robust project pipeline with greater than 2,000 MW of renewable projects in development across 26 different states. New Energy adds value through cost effective development and economies of scale on project implementation, bringing national capabilities to regional co-development partners. New Energy is involved in greenfield development as well as acquiring and completing mid-stage and late-stage renewable energy projects. The acquisition of New Energy is consistent with ALLETE’s stated strategy of additional investment in renewable energy and related infrastructure across North America to support the Company’s sustainability-in-action strategy while providing potential long-term earnings growth. New Energy will continue its current strategy of developing and operating renewable energy projects.
LIQUIDITY AND CAPITAL RESOURCES
Liquidity Position. ALLETE is well-positioned to meet the Company’s liquidity needs. As of June 30, 2022, we had cash and cash equivalents of $74.6 million, $377.3 million in available consolidated lines of credit, 2.1 million original issue shares of common stock available for issuance through a distribution agreement with Lampert Capital Markets and a debt-to-capital ratio of 37 percent. (See Working Capital.)
Capital Structure. ALLETE’s capital structure is as follows:

| June 30, 2022 |  | % |  | December 31, 2021 |  | %
Millions |  |  |  |  |  |  |
ALLETE Equity | $2,680.4 |  |  | 50 |  |  | $2,413.1 |  |  | 49 |
Non-Controlling Interest in Subsidiaries | 678.5 |  |  | 13 |  |  | 533.2 |  |  | 11 |
Short-Term and Long-Term Debt (a) | 1,994.4 |  |  | 37 |  |  | 1,986.4 |  |  | 40 |
| $5,353.3 |  |  | 100 |  |  | $4,932.7 |  |  | 100 |

(a)Excludes unamortized debt issuance costs.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
42

LIQUIDITY AND CAPITAL RESOURCES (Continued)
Cash Flows. Selected information from the Consolidated Statement of Cash Flows is as follows:

For the Six Months Ended June 30, | 2022 |  | 2021
Millions |  |  |
Cash, Cash Equivalents and Restricted Cash at Beginning of Period | $47.7 |  |  | $65.2 |
Cash Flows provided by (used in) |  |  |
Operating Activities | (7.9) |  |  | 105.7 |
Investing Activities | (247.2) |  |  | (305.7) |
Financing Activities | 289.1 |  |  | 202.1 |
Change in Cash, Cash Equivalents and Restricted Cash | 34.0 |  |  | 2.1 |
Cash, Cash Equivalents and Restricted Cash at End of Period | $81.7 |  |  | $67.3 |

Operating Activities. Cash used in operating activities was lower in 2022 compared to 2021. Cash used in operating activities in 2022 reflected higher payments for inventories compared to 2021 primarily related to ALLETE Clean Energy’s Northern Wind and Red Barn projects which will be sold to third parties in late 2022 and early 2023, respectively.
Investing Activities. Cash used in investing activities was lower in 2022 compared to 2021. Cash used in investing activities in 2022 reflected lower cash payments for additions to property, plant and equipment compared to 2021, partially offset by cash payments for the acquisition of New Energy.
Financing Activities. Cash provided by financing activities was higher in 2022 compared to 2021. 2022 reflected higher proceeds from the issuance of common stock and proceeds from non-controlling interest in subsidiaries compared to 2021. These were partially offset by higher repayments of short-term and long-term debt.
Working Capital. Additional working capital, if and when needed, generally is provided by consolidated bank lines of credit and the issuance of securities, including long-term debt, common stock and commercial paper. As of June 30, 2022, we had consolidated bank lines of credit aggregating $519.4 million ($432.0 million as of December 31, 2021), the majority of which expire in January 2025. We had $33.2 million outstanding in standby letters of credit and $108.9 million outstanding draws under our lines of credit as of June 30, 2022 ($31.5 million in standby letters of credit and $159.7 million outstanding draws as of December 31, 2021). We also have other credit facility agreements in place that provide the ability to issue up to $120.0 million in standby letters of credit. As of June 30, 2022, we had $105.0 million outstanding in standby letters of credit under these agreements.
In addition, as of June 30, 2022, we had 3.0 million original issue shares of our common stock available for issuance through Invest Direct, our direct stock purchase and dividend reinvestment plan, and 2.1 million original issue shares of common stock available for issuance through a distribution agreement with Lampert Capital Markets. (See Securities.) The amount and timing of future sales of our securities will depend upon market conditions and our specific needs.
Securities. During the six months ended June 30, 2022, we issued 0.2 million shares of common stock through Invest Direct, the Employee Stock Purchase Plan, and the Retirement Savings and Stock Ownership Plan, resulting in net proceeds of $8.3 million (0.2 million shares were issued for the six months ended June 30, 2021, resulting in net proceeds of $10.1 million).
On April 5, 2022, ALLETE issued and sold approximately 3.7 million shares of ALLETE common stock. Net proceeds of approximately $224 million were received from the sale of shares. Proceeds were used primarily to fund the acquisition of New Energy and capital investments at ALLETE Clean Energy.
Financial Covenants. See Note 6. Short-Term and Long-Term Debt for information regarding our financial covenants.
Pension and Other Postretirement Benefit Plans. Management considers various factors when making funding decisions, such as regulatory requirements, actuarially determined minimum contribution requirements and contributions required to avoid benefit restrictions for the defined benefit pension plans. (See Note 10. Pension and Other Postretirement Benefit Plans.)
Off-Balance Sheet Arrangements. Off-balance sheet arrangements are summarized in our 2021 Form 10-K, with additional disclosure in Note 7. Commitments, Guarantees and Contingencies.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
43

LIQUIDITY AND CAPITAL RESOURCES (Continued)
Credit Ratings. Access to reasonably priced capital markets is dependent in part on credit and ratings. Our securities have been rated by S&P Global Ratings and by Moody’s. Rating agencies use both quantitative and qualitative measures in determining a company’s credit rating. These measures include business risk, liquidity risk, competitive position, capital mix, financial condition, predictability of cash flows, management strength and future direction. Some of the quantitative measures can be analyzed through a few key financial ratios, while the qualitative ones are more subjective. Our current credit ratings are listed in the following table:

Credit Ratings | S&P Global Ratings | Moody’s
Issuer Credit Rating | BBB | Baa1
Commercial Paper | A-2 | P-2
First Mortgage Bonds | (a) | A2

(a) Not rated by S&P Global Ratings.
The disclosure of these credit ratings is not a recommendation to buy, sell or hold our securities. Ratings are subject to revision or withdrawal at any time by the assigning rating organization. Each rating should be evaluated independently of any other rating.
Capital Requirements. Our capital expenditures for 2022 are expected to be approximately $210 million. For the six months ended June 30, 2022, capital expenditures totaled $94.0 million ($288.3 million for the six months ended June 30, 2021). The expenditures were primarily made in the Regulated Operations segment. Minnesota Power and Great River Energy announced on July 25, 2022, their intent to build a 150-mile, 345-kV transmission line from Itasca County in northern Minnesota to Benton County in central Minnesota, which is expected to be in service in 2030. As a result, Minnesota Power expects capital expenditures related to the project for its approximately 50 percent estimated share of the approximately $970 million project through 2030. (See Outlook – Regulated Operations – Transmission.)
OTHER
Environmental Matters.
Our businesses are subject to regulation of environmental matters by various federal, state and local authorities. A number of regulatory changes to the Clean Air Act, the Clean Water Act and various waste management requirements have been promulgated by both the EPA and state authorities over the past several years. Minnesota Power’s facilities are subject to additional requirements under many of these regulations. Minnesota Power is reshaping its generation portfolio, over time, to reduce its reliance on coal, has installed cost-effective emission control technology, and advocates for sound science and policy during rulemaking implementation. (See Note 7. Commitments, Guarantees and Contingencies.)
Employees.
As of June 30, 2022, ALLETE had 1,466 employees, of which 1,428 were full-time.
Minnesota Power and SWL&P have an aggregate of 483 employees covered under collective bargaining agreements, of which most are members of International Brotherhood of Electrical Workers (IBEW) Local 31. The current labor agreements with IBEW Local 31 expire on April 30, 2023, for Minnesota Power and on January 31, 2024, for SWL&P.
BNI Energy has 175 employees, of which 127 are subject to a labor agreement with IBEW Local 1593. The current labor agreement with IBEW Local 1593 expires on March 31, 2023.
NEW ACCOUNTING PRONOUNCEMENTS
New accounting pronouncements are discussed in Note 1. Operations and Significant Accounting Policies.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
44

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
SECURITIES INVESTMENTS
Available-for-Sale Securities. As of June 30, 2022, our available-for-sale securities portfolio consisted primarily of securities held in other postretirement plans to fund employee benefits.
COMMODITY PRICE RISK
Our regulated utility operations incur costs for power and fuel (primarily coal and related transportation) in Minnesota, and power and natural gas purchased for resale in our regulated service territory in Wisconsin. Minnesota Power’s exposure to price risk for these commodities is significantly mitigated by the current ratemaking process and regulatory framework, which allows recovery of fuel costs in excess of those included in base rates or distribution of savings in fuel costs to ratepayers. SWL&P’s exposure to price risk for natural gas is significantly mitigated by the current ratemaking process and regulatory framework, which allows the commodity cost to be passed through to customers. We seek to prudently manage our customers’ exposure to price risk by entering into contracts of various durations and terms for the purchase of power and coal and related transportation costs (Minnesota Power), and natural gas (SWL&P).
POWER MARKETING
Minnesota Power’s power marketing activities consist of: (1) purchasing energy in the wholesale market to serve its regulated service territory when energy requirements exceed generation output; and (2) selling excess available energy and purchased power. From time to time, Minnesota Power may have excess energy that is temporarily not required by retail and municipal customers in our regulated service territory. Minnesota Power actively sells any excess energy to the wholesale market to optimize the value of its generating facilities.
We are exposed to credit risk primarily through our power marketing activities. We use credit policies to manage credit risk, which includes utilizing an established credit approval process and monitoring counterparty limits.
INTEREST RATE RISK
We are exposed to risks resulting from changes in interest rates as a result of our issuance of variable rate debt. We manage our interest rate risk by varying the issuance and maturity dates of our fixed rate debt, limiting the amount of variable rate debt, and continually monitoring the effects of market changes in interest rates. We may also enter into derivative financial instruments, such as interest rate swaps, to mitigate interest rate exposure. Interest rates on variable rate long-term debt are reset on a periodic basis reflecting prevailing market conditions. Based on the variable rate debt outstanding as of June 30, 2022, an increase of 100 basis points in interest rates would impact the amount of pre-tax interest expense by $3.0 million. This amount was determined by considering the impact of a hypothetical 100 basis point increase to the average variable interest rate on the variable rate debt outstanding as of June 30, 2022.
ITEM 4. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures. As of June 30, 2022, evaluations were performed, under the supervision and with the participation of management, including our principal executive officer and principal financial officer, on the effectiveness of the design and operation of ALLETE’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934 (Exchange Act)). Based upon those evaluations, our principal executive officer and principal financial officer have concluded that such disclosure controls and procedures are effective to provide assurance that information required to be disclosed in ALLETE’s reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.
Changes in Internal Controls. There has been no change in our internal control over financial reporting that occurred during our most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
45

PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
For information regarding material legal and regulatory proceedings, see Note 4. Regulatory Matters and Note 8. Commitments, Guarantees and Contingencies to the Consolidated Financial Statements in our 2021 Form 10-K and Note 2. Regulatory Matters and Note 7. Commitments, Guarantees and Contingencies herein. Such information is incorporated herein by reference.
ITEM 1A. RISK FACTORS
Our 2021 Form 10-K includes a detailed discussion of our risk factors. The information presented below updates, and should be read in conjunction with, the risk factors disclosed in Part I, Item 1A. Risk Factors of our 2021 Form 10-K.
The price of electricity may be volatile, which may impact results of operations at ALLETE Clean Energy wind energy facilities under certain contracts with commercial and industrial (C&I) customers.
Unusual, adverse weather conditions or other natural events and different settlement prices between hub and node can cause volatility in market prices for electricity and adversely affect our financial position, results of operations and cash flows. ALLETE Clean Energy’s power sales agreements with C&I customers at its Diamond Spring and Caddo wind energy facilities are contracts for differences where power is delivered to the market, and a fixed price is paid by the customers to ALLETE Clean Energy, and differences between the market price and the fixed price are paid to or received from the customers. Certain contracts also settle with the market at the hub price where as ALLETE Clean Energy settles with the customer at the node price which can vary significantly based on multiple factors. These settlement provisions can result in an adverse impact on our financial position, results of operations and cash flows when market prices are volatile.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
None.
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
None.
ITEM 4. MINE SAFETY DISCLOSURES
The Dodd-Frank Wall Street Reform and Consumer Protection Act (Dodd-Frank Act) requires issuers to include in periodic reports filed with the SEC certain information relating to citations or orders for violations of standards under the Federal Mine Safety and Health Act of 1977 (Mine Safety Act). Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Act and this Item are included in Exhibit 95 to this Form 10-Q.
ITEM 5. OTHER INFORMATION
None.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
46

ITEM 6. EXHIBITS

Exhibit Number |
10 |  | ALLETE Non-Employee Director Stock Plan (As Amended and Restated Effective May 10, 2022) (filed as Exhibit 99, File No. 333-265211). |
31(a) |  | Rule 13a-14(a)/15d-14(a) Certification by the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
31(b) |  | Rule 13a-14(a)/15d-14(a) Certification by the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
32 |  | Section 1350 Certification of Periodic Report by the Chief Executive Officer and the Chief Financial Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. |
95 |  | Mine Safety. |
99 |  | ALLETE News Release dated August 3, 2022, announcing 2022 second quarter earnings. (This exhibit has been furnished and shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, nor shall it be deemed incorporated by reference in any filing under the Securities Act of 1933, except as shall be expressly set forth by specific reference in such filing.) |
101.INS |  | XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document. |
101.SCH |  | XBRL Schema |
101.CAL |  | XBRL Calculation |
101.DEF |  | XBRL Definition |
101.LAB |  | XBRL Label |
101.PRE |  | XBRL Presentation |
104 |  | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101) |

ALLETE agrees to furnish to the SEC upon request any instrument with respect to long-term debt that ALLETE has not filed as an exhibit pursuant to the exemption provided by Item 601(b)(4)(iii)(A) of Regulation S-K.
ALLETE, Inc. Second Quarter 2022 Form 10-Q
47

SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

|  | ALLETE, INC.
August 3, 2022 |  | /s/ Steven W. Morris
|  | Steven W. Morris
|  | Senior Vice President and Chief Financial Officer
|  | (Principal Financial Officer and Principal Accounting Officer)

ALLETE, Inc. Second Quarter 2022 Form 10-Q
48