10-Q

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, 2020

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,

51,880,664 shares outstanding

as of June 30, 2020

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	13
		Note 3. Equity Investments	16
		Note 4. Fair Value	17
		Note 5. Short-Term and Long-Term Debt	19
		Note 6. Commitments, Guarantees and Contingencies	20
		Note 7. Earnings Per Share and Common Stock	25
		Note 8. Income Tax Expense	25
		Note 9. Pension and Other Postretirement Benefit Plans	27
		Note 10. Business Segments	27
	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	29
		Comparison of the Quarters Ended	31
		Comparison of the Six Months Ended	34
		Critical Accounting Policies	37
		Outlook	37
		Liquidity and Capital Resources	45
		Other	47
	Item 3.	Quantitative and Qualitative Disclosures about Market Risk	47
	Item 4.	Controls and Procedures	48
Part II.	Other Information
	Item 1.	Legal Proceedings	49
	Item 1A.	Risk Factors	49
	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	50
	Item 3.	Defaults Upon Senior Securities	50
	Item 4.	Mine Safety Disclosures	50
	Item 5.	Other Information	50
	Item 6.	Exhibits	51
Signatures			52

ALLETE, Inc. Second Quarter 2020 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 Transmission Holdings	ALLETE Transmission Holdings, Inc.
ArcelorMittal	ArcelorMittal S.A.
ATC	American Transmission Company LLC
Basin	Basin Electric Power Cooperative
Bison	Bison Wind Energy Center
BNI Energy	BNI Energy, Inc. and its subsidiary
Boswell	Boswell Energy Center
Camp Ripley	Camp Ripley Solar Array
Cliffs	Cleveland-Cliffs Inc.
Company	ALLETE, Inc. and its subsidiaries
COVID-19	2019 novel coronavirus
CSAPR	Cross-State Air Pollution Rule
DC	Direct Current
EIS	Environmental Impact Statement
EPA	United States Environmental Protection Agency
ESOP	Employee Stock Ownership Plan
FASB	Financial Accounting Standards Board
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
GNTL	Great Northern Transmission Line
Hibbing Taconite	Hibbing Taconite Co.
Husky Energy	Husky Energy Inc.
Invest Direct	ALLETE’s Direct Stock Purchase and Dividend Reinvestment Plan
IRP	Integrated Resource Plan
Item ___	Item ___ of this Form 10-Q
kV	Kilovolt(s)
kW / kWh	Kilowatt(s) / Kilowatt-hour(s)
Laskin	Laskin Energy Center
Lampert Capital Markets	Lampert Capital Markets, Inc.
Manitoba Hydro	Manitoba Hydro-Electric Board
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.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

3

Abbreviation or Acronym	Term
MPCA	Minnesota Pollution Control Agency
MPUC	Minnesota Public Utilities Commission
MW / MWh	Megawatt(s) / Megawatt-hour(s)
NAAQS	National Ambient Air Quality Standards
NDPSC	North Dakota Public Service Commission
Nobles 2	Nobles 2 Power Partners, LLC
NOL	Net Operating Loss
NOX	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
Oliver Wind I	Oliver Wind I Energy Center
Oliver Wind II	Oliver Wind II Energy Center
PolyMet	PolyMet Mining Corp.
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.
SO2	Sulfur Dioxide
Square Butte	Square Butte Electric Cooperative, a North Dakota cooperative corporation
SWL&P	Superior Water, Light and Power Company
Taconite Harbor	Taconite Harbor Energy Center
Town Center District	Town Center at Palm Coast Community Development District in Florida
U.S.	United States of America
U.S. Water Services	U.S. Water Services Holding Company and its subsidiaries
USS Corporation	United States Steel Corporation
WTG	Wind Turbine Generator

ALLETE, Inc. Second Quarter 2020 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;

•changes in tax rates or policies or in rates of inflation;

•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 not improve; 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 ALLETE’s 2019 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 2020 Form 10-Q

5

PART I.  FINANCIAL INFORMATION

ITEM 1.  CONSOLIDATED FINANCIAL STATEMENTS

ALLETE

CONSOLIDATED BALANCE SHEET

Unaudited

	June 30, 2020	December 31, 2019
Millions
Assets
Current Assets
Cash and Cash Equivalents	$25.7	$69.3
Accounts Receivable (Less Allowance of $1.3 and $0.9)	85.8	96.4
Inventories – Net	82.0	72.8
Prepayments and Other	29.5	31.0
Total Current Assets	223.0	269.5
Property, Plant and Equipment – Net	4,644.5	4,377.0
Regulatory Assets	424.7	420.5
Equity Investments	267.1	197.6
Other Non-Current Assets	201.1	218.2
Total Assets	$5,760.4	$5,482.8
Liabilities and Equity
Liabilities
Current Liabilities
Accounts Payable	$86.1	$165.2
Accrued Taxes	48.5	50.8
Accrued Interest	18.0	18.1
Long-Term Debt Due Within One Year	509.7	212.9
Other	65.4	60.4
Total Current Liabilities	727.7	507.4
Long-Term Debt	1,381.0	1,400.9
Deferred Income Taxes	202.3	212.8
Regulatory Liabilities	569.6	560.3
Defined Benefit Pension and Other Postretirement Benefit Plans	159.5	172.8
Other Non-Current Liabilities	288.1	293.0
Total Liabilities	3,328.2	3,147.2
Commitments, Guarantees and Contingencies (Note 6)
Equity
ALLETE Equity
Common Stock Without Par Value, 80.0 Shares Authorized, 51.9 and 51.7 Shares Issued and Outstanding	1,447.7	1,436.7
Accumulated Other Comprehensive Loss	(23.3)	(23.6)
Retained Earnings	841.3	818.8
Total ALLETE Equity	2,265.7	2,231.9
Non-Controlling Interest in Subsidiaries	166.5	103.7
Total Equity	2,432.2	2,335.6
Total Liabilities and Equity	$5,760.4	$5,482.8

The accompanying notes are an integral part of these statements.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

6

ALLETE

CONSOLIDATED STATEMENT OF INCOME

Unaudited

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Millions Except Per Share Amounts
Operating Revenue
Contracts with Customers – Utility	$200.8	$249.8	$466.1	$532.0
Contracts with Customers – Non-utility	39.6	37.7	83.1	109.8
Other – Non-utility	2.8	2.9	5.6	5.8
Total Operating Revenue	243.2	290.4	554.8	647.6
Operating Expenses
Fuel, Purchased Power and Gas – Utility	69.3	87.9	158.3	197.7
Transmission Services – Utility	16.4	19.2	34.9	37.5
Cost of Sales – Non-utility	16.3	16.5	33.2	47.1
Operating and Maintenance	59.0	66.7	120.0	142.9
Depreciation and Amortization	54.5	50.2	107.9	102.1
Taxes Other than Income Taxes	15.0	13.7	27.6	27.3
Total Operating Expenses	230.5	254.2	481.9	554.6
Operating Income	12.7	36.2	72.9	93.0
Other Income (Expense)
Interest Expense	(15.9)	(16.3)	(31.6)	(32.8)
Equity Earnings	6.4	4.8	11.6	10.4
Gain on Sale of U.S. Water Services	—	0.5	—	20.6
Other	5.2	4.2	6.2	11.6
Total Other Income (Expense)	(4.3)	(6.8)	(13.8)	9.8
Income Before Income Taxes	8.4	29.4	59.1	102.8
Income Tax Expense (Benefit)	(8.5)	(4.8)	(22.3)	(1.9)
Net Income	16.9	34.2	81.4	104.7
Net Loss Attributable to Non-Controlling Interest	(3.2)	—	(5.0)	—
Net Income Attributable to ALLETE	$20.1	$34.2	$86.4	$104.7
Average Shares of Common Stock
Basic	51.8	51.6	51.8	51.6
Diluted	51.9	51.7	51.8	51.7
Basic Earnings Per Share of Common Stock	$0.39	$0.66	$1.67	$2.03
Diluted Earnings Per Share of Common Stock	$0.39	$0.66	$1.67	$2.02

The accompanying notes are an integral part of these statements.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

7

ALLETE

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

Unaudited

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Millions
Net Income	$16.9	$34.2	$81.4	$104.7
Other Comprehensive Income
Unrealized Gain on Securities
Net of Income Tax Expense of $0.1, $0.1, $– and $0.1	0.4	0.1	—	0.2
Defined Benefit Pension and Other Postretirement Benefit Plans
Net of Income Tax Expense of $–, $–, $0.1 and $0.1	0.1	0.2	0.3	0.2
Total Other Comprehensive Income	0.5	0.3	0.3	0.4
Total Comprehensive Income	17.4	34.5	81.7	105.1
Net Loss Attributable to Non-Controlling Interest	(3.2)	—	(5.0)	—
Total Comprehensive Income Attributable to ALLETE	$20.6	$34.5	$86.7	$105.1

The accompanying notes are an integral part of these statements.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

8

ALLETE

CONSOLIDATED STATEMENT OF CASH FLOWS

Unaudited

	Six Months Ended
	June 30,
	2020	2019
Millions
Operating Activities
Net Income	$81.4	$104.7
AFUDC – Equity	(1.4)	(1.3)
Income from Equity Investments – Net of Dividends	(2.2)	(2.2)
Realized and Unrealized (Gain) Loss on Investments and Property, Plant and Equipment	1.1	(2.6)
Depreciation Expense	107.9	100.8
Amortization of PSAs	(5.6)	(5.8)
Amortization of Other Intangible Assets and Other Assets	5.2	7.0
Deferred Income Tax Benefit	(22.3)	(2.1)
Share-Based and ESOP Compensation Expense	3.1	3.3
Defined Benefit Pension and Postretirement Benefit Expense	—	2.1
Provision (Payments) for Interim Rate Refund	11.7	(40.0)
Payments for Tax Reform Refund	(0.1)	(10.3)
Bad Debt Expense	1.1	(0.6)
Gain on Sale of U.S. Water Services	—	(20.6)
Changes in Operating Assets and Liabilities
Accounts Receivable	9.5	34.0
Inventories	(9.3)	(9.5)
Prepayments and Other	3.3	3.4
Accounts Payable	(11.6)	(11.2)
Other Current Liabilities	(8.5)	(24.2)
Cash Contributions to Defined Benefit Pension Plans	(10.7)	(10.4)
Changes in Regulatory and Other Non-Current Assets	(16.8)	(8.5)
Changes in Regulatory and Other Non-Current Liabilities	8.7	(10.8)
Cash from Operating Activities	144.5	95.2
Investing Activities
Proceeds from Sale of Available-for-sale Securities	2.1	6.0
Payments for Purchase of Available-for-sale Securities	(2.3)	(5.9)
Payments for Equity Investments	(66.6)	(4.6)
Return of Capital from Equity Investments	—	8.3
Proceeds from Sale of U.S. Water Services – Net of Transaction Costs and Cash Retained	—	264.2
Additions to Property, Plant and Equipment	(419.9)	(236.0)
Other Investing Activities	(0.7)	14.0
Cash from (for) Investing Activities	(487.4)	46.0
Financing Activities
Proceeds from Issuance of Common Stock	7.9	1.5
Proceeds from Issuance of Long-Term Debt	297.4	100.0
Repayments of Long-Term Debt	(20.9)	(49.8)
Proceeds from Non-Controlling Interest in Subsidiaries – Net of Issuance Costs	67.8	—
Acquisition-Related Contingent Consideration Payments	—	(3.8)
Dividends on Common Stock	(63.9)	(60.7)
Other Financing Activities	(0.5)	(0.8)
Cash from (for) Financing Activities	287.8	(13.6)
Change in Cash, Cash Equivalents and Restricted Cash	(55.1)	127.6
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	92.5	79.0
Cash, Cash Equivalents and Restricted Cash at End of Period	$37.4	$206.6

The accompanying notes are an integral part of these statements.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

9

ALLETE

CONSOLIDATED STATEMENT OF EQUITY

Unaudited

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Millions Except Per Share Amounts
Common Stock
Balance, Beginning of Period	$1,441.7	$1,431.1	$1,436.7	$1,428.5
Common Stock Issued	6.0	2.2	11.0	4.8
Balance, End of Period	1,447.7	1,433.3	1,447.7	1,433.3
Accumulated Other Comprehensive Loss
Balance, Beginning of Period	(23.8)	(27.2)	(23.6)	(27.3)
Other Comprehensive Income - Net of Income Taxes
Unrealized Gain on Debt Securities	0.4	0.1	—	0.2
Defined Benefit Pension and Other Postretirement Plans	0.1	0.2	0.3	0.2
Balance, End of Period	(23.3)	(26.9)	(23.3)	(26.9)
Retained Earnings
Balance, Beginning of Period	853.2	794.8	818.8	754.6
Net Income Attributable to ALLETE	20.1	34.2	86.4	104.7
Common Stock Dividends	(32.0)	(30.4)	(63.9)	(60.7)
Balance, End of Period	841.3	798.6	841.3	798.6
Non-Controlling Interest in Subsidiaries
Balance, Beginning of Period	101.9	—	103.7	—
Proceeds from Non-Controlling Interest in Subsidiaries – Net of Issuance Costs	67.8	—	67.8	—
Net Loss Attributable to Non-Controlling Interest	(3.2)	—	(5.0)	—
Balance, End of Period	166.5	—	166.5	—
Total Equity	$2,432.2	$2,205.0	$2,432.2	$2,205.0
Dividends Per Share of Common Stock	$0.6175	$0.5875	$1.235	$1.175

The accompanying notes are an integral part of these statements.

ALLETE, Inc. Second Quarter 2020 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, 2019, Consolidated Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. 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 quarter and six months ended June 30, 2020, are not necessarily indicative of results that may be expected for any other interim period or for the year ending December 31, 2020. For further information, refer to the Consolidated Financial Statements and notes included in our 2019 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, 2020, 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 ALLETE Clean Energy PSAs and construction projects. In December 31, 2018 balance presented, the amount also includes deposits from a SWL&P customer in aid of future capital expenditures. 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, 2020	December 31, 2019	June 30, 2019	December 31, 2018
Millions
Cash and Cash Equivalents	$25.7	$69.3	$203.1	$69.1
Restricted Cash included in Prepayments and Other	7.3	2.8	0.9	1.3
Restricted Cash included in Other Non-Current Assets	4.4	20.4	2.6	8.6
Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows	$37.4	$92.5	$206.6	$79.0

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, 2020	December 31, 2019
Millions
Fuel (a)	$33.5	$25.9
Materials and Supplies	48.5	46.9
Total Inventories – Net	$82.0	$72.8

(a) Fuel consists primarily of coal inventory at Minnesota Power.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

11

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Other Non-Current Assets	June 30, 2020	December 31, 2019
Millions
Contract Assets (a)	$26.7	$28.0
Operating Lease Right-of-use Assets	25.4	28.6
ALLETE Properties	21.5	21.9
Restricted Cash	4.4	20.4
Other Postretirement Benefit Plans	38.4	37.5
Other	84.7	81.8
Total Other Non-Current Assets	$201.1	$218.2

(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, 2020	December 31, 2019
Millions
PSAs	$12.4	$12.3
Provision for Interim Rate Refund (a)	11.7	—
Operating Lease Liabilities	6.6	6.9
Other	34.7	41.2
Total Other Current Liabilities	$65.4	$60.4

(a)Provision for Interim Rate Refund represents reserves for interim rates resulting from the MPUC’s approval of Minnesota Power’s petition and proposal to resolve and withdraw its rate case. (See Note 2. Regulatory Matters.)

Other Non-Current Liabilities	June 30, 2020	December 31, 2019
Millions
Asset Retirement Obligation	$164.8	$160.3
PSAs	58.3	64.6
Operating Lease Liabilities	18.8	21.8
Other	46.2	46.3
Total Other Non-Current Liabilities	$288.1	$293.0

Other Income
Six Months Ended June 30,	2020	2019
Millions
Pension and Other Postretirement Benefit Plan Non-Service Credits (a)	$4.8	$3.6
Interest and Investment Income (Loss)	(0.5)	2.5
AFUDC - Equity	1.4	1.3
Gain on Land Sales	0.1	2.0
Other	0.4	2.2
Total Other Income	$6.2	$11.6

(a)These are components of net periodic pension and other postretirement benefit cost other than service cost. (See Note 9. Pension and Other Postretirement Benefit Plans.)

ALLETE, Inc. Second Quarter 2020 Form 10-Q

12

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Supplemental Statement of Cash Flows Information.

Six Months Ended June 30,	2020	2019
Millions
Cash Paid for Interest – Net of Amounts Capitalized	$30.9	$33.8
Recognition of Right-of-use Assets and Lease Liabilities	—	$31.2
Noncash Investing and Financing Activities
Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment	$(67.5)	$21.1
Capitalized Asset Retirement Costs	$2.1	$1.4
AFUDC–Equity	$1.4	$1.3

Sale of U.S. Water Services. In February 2019, the Company entered into a stock purchase agreement providing for the sale of U.S. Water Services to a subsidiary of Kurita Water Industries Ltd. In March 2019, ALLETE completed the sale and received approximately $270 million in cash, net of transaction costs and cash retained. The gain on sale of U.S. Water Services in 2019 was $13.2 million after-tax.

ALLETE Clean Energy Asset Acquisition. On March 10, 2020, ALLETE Clean Energy acquired the rights to the approximately 300 MW Caddo wind project in Oklahoma from Apex Clean Energy for approximately $8 million with additional payments required to be made at defined milestones. The full development of this wind project will involve the sale of energy to corporate customers under long-term power sales agreements.

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 as of and during the quarter and six months ended June 30, 2020, related to the tax equity financing structure for ALLETE Clean Energy’s 106 MW Glen Ullin and 80 MW South Peak wind energy facilities.

On April 16, 2020, ALLETE Clean Energy commenced operations of South Peak, an 80 MW wind energy facility in Montana, and on April 29, 2020, received $67.8 million in cash, net of issuance costs, from a third-party investor as part of a tax equity financing for this 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.

New Accounting Pronouncements.

Credit Losses. In 2016, the FASB issued an accounting standard update that requires entities to recognize an allowance for expected credit losses for financial instruments within its scope. Examples of financial instruments within the scope include trade receivables, certain financial guarantees, and held-to-maturity debt securities. The allowance for expected credit losses should be based on historical information, current conditions and reasonable and supportable forecasts. The new standard also revises the other-than-temporary impairment model for available-for-sale debt securities. The new guidance became effective January 1, 2020, and was adopted by the Company in the first quarter of 2020. Adoption of this standard did not have a material impact on our Consolidated Financial Statements.

NOTE 2. REGULATORY MATTERS

Regulatory matters are summarized in Note 4. Regulatory Matters to the Consolidated Financial Statements in our 2019 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 $14.9 million for the six months ended June 30, 2020 ($17.4 million for six months ended June 30, 2019).

ALLETE, Inc. Second Quarter 2020 Form 10-Q

13

NOTE 2. REGULATORY MATTERS (Continued)

Electric Rates (Continued)

2020 Minnesota General Rate Case. In November 2019, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 10.6 percent for retail customers. The rate filing sought a return on equity of 10.05 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would have generated approximately $66 million in additional revenue. In orders dated December 23, 2019, the MPUC accepted the filing as complete and authorized an annual interim rate increase of $36.1 million that began January 1, 2020.

On April 23, 2020, Minnesota Power filed a request with the MPUC that proposed a resolution of Minnesota Power’s 2020 general rate case. Key components of our proposal included removing the power marketing margin credit in base rates and reflecting actual power marketing margins in the fuel adjustment clause effective May 1, 2020; refunding to customers interim rates collected through April 2020; increasing customer rates 4.1 percent compared to the 5.8 percent increase reflected in interim rates; and a provision that Minnesota Power would not file another rate case until at least November 1, 2021, unless certain events occur. In an order dated June 30, 2020, the MPUC approved Minnesota Power’s petition and proposal to resolve and withdraw the general rate case. Effective May 1, 2020, customer rates were set at an increase of 4.1 percent with the removal of the power marketing margin credit from base rates. Actual power marketing margins will be reflected in the fuel adjustment clause on an ongoing basis. As of June 30, 2020, reserves for interim rates of $11.7 million were recorded, which are expected to be refunded to customers in the third quarter of 2020.

Transmission Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place for certain transmission investments and expenditures. In a 2016 order, the MPUC approved Minnesota Power’s updated customer billing rates allowing Minnesota Power to charge retail customers on a current basis for the costs of constructing certain transmission facilities plus a return on the capital invested. On July 9, 2019, Minnesota Power filed a petition seeking MPUC approval to update the customer billing factor to include investments made for the GNTL, which was approved at a hearing on May 14, 2020. (See Note 6. Commitments, Guarantees and Contingencies.)

Renewable Cost Recovery Rider. Minnesota Power has an approved cost recovery rider for certain renewable investments and expenditures. The cost recovery rider allows Minnesota Power to charge retail customers on a current basis for the costs of certain renewable investments plus a return on the capital invested. Current customer billing rates for the renewable cost recovery rider were approved by the MPUC in a November 2018 order. On August 15, 2019, Minnesota Power filed a petition seeking MPUC approval to update the customer billing factor.

On June 30, 2020, Minnesota Power filed a petition seeking MPUC approval of a customer billing rate for solar costs related to investments and expenditures for meeting the state of Minnesota’s solar energy standard.

Fuel Adjustment Clause Reform. In a 2017 order, the MPUC adopted a program to implement certain procedural reforms to Minnesota utilities’ automatic fuel adjustment clause (FAC) for fuel and purchased power. With this order, the method of accounting for all Minnesota electric utilities changed to a monthly budgeted, forward-looking FAC with annual prudence review and true-up to actual allowed costs. On May 1, 2019, Minnesota Power filed its fuel adjustment forecast for 2020, which was accepted by the MPUC in an order dated November 14, 2019, for purposes of setting fuel adjustment clause rates for 2020, subject to a true-up filing in 2021. On May 1, 2020, Minnesota Power filed its fuel adjustment forecast for 2021, subject to MPUC approval.

COVID-19 Related Costs. In an order dated March 24, 2020, the PSCW authorized public utilities, which includes SWL&P, to defer expenditures incurred by the utility resulting from its compliance with state government or regulator orders, and as otherwise required to ensure the provision of safe, reliable and affordable access to utility services during Wisconsin’s declared public health emergency for COVID-19. On April 20, 2020, Minnesota Power along with other regulated electric and natural gas service providers in Minnesota filed a joint petition to request MPUC authorization to track incremental costs and expenses incurred as a result of the COVID-19 pandemic, and to defer and record such costs as a regulatory asset, subject to recovery in a future proceeding. In an order dated May 22, 2020, the MPUC approved the joint petition requiring the joint petitioners to track cost and revenue impacts resulting from the COVID-19 pandemic with review for recovery in a future rate proceeding.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

14

NOTE 2. REGULATORY MATTERS (Continued)

Integrated Resource Plan. In a 2016 order, the MPUC approved Minnesota Power’s 2015 IRP with modifications. The order accepted Minnesota Power’s plans for the economic idling of Taconite Harbor Units 1 and 2 and the ceasing of coal-fired operations at Taconite Harbor in 2020, directed Minnesota Power to retire Boswell Units 1 and 2 no later than 2022, required an analysis of generation and demand response alternatives to be filed with a natural gas resource proposal, and required Minnesota Power to conduct requests for proposal for additional wind, solar and demand response resource additions. Minnesota Power retired Boswell Units 1 and 2 in the fourth quarter of 2018. The MPUC also has required a baseload retirement evaluation in Minnesota Power’s next IRP filing analyzing its existing fleet, including potential early retirement scenarios of Boswell Units 3 and 4, as well as a securitization plan. Minnesota Power’s next IRP filing was due October 1, 2020; however, on May 29, 2020, Minnesota Power filed a request to extend the deadline for submitting its next IRP filing citing the COVID-19 pandemic. On July 30, 2020, the MPUC granted an extension of the deadline for submission until February 1, 2021, with interim reports due in the fourth quarter of 2020.

Nemadji Trail Energy Center. In 2017, Minnesota Power submitted a resource package to the MPUC which included requesting approval of a 250 MW natural gas capacity dedication agreement. The natural gas capacity dedication agreement was subject to MPUC approval of the construction of NTEC, a 525 MW to 550 MW combined-cycle natural gas-fired generating facility which will be jointly owned by Dairyland Power Cooperative and a subsidiary of ALLETE. Minnesota Power would purchase approximately 50 percent of the facility's output starting in 2025. In an order dated January 24, 2019, the MPUC approved Minnesota Power’s request for approval of the NTEC natural gas capacity dedication agreement. On December 23, 2019, the Minnesota Court of Appeals reversed and remanded the MPUC’s decision to approve certain affiliated-interest agreements. The MPUC was ordered to determine whether NTEC may have the potential for significant environmental effects and, if so, to prepare an environmental assessment worksheet before reassessing the agreements. On January 22, 2020, Minnesota Power filed a petition for further review with the Minnesota Supreme Court requesting that it review and overturn the Minnesota Court of Appeals decision, which petition was accepted for review by the Minnesota Supreme Court on March 18, 2020. On January 8, 2019, an application for a certificate of public convenience and necessity for NTEC was submitted to the PSCW, which was approved by the PSCW at a hearing on January 16, 2020. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $700 million, of which ALLETE’s portion is expected to be approximately $350 million. ALLETE’s portion of NTEC project costs incurred through June 30, 2020, is approximately $14 million.

Conservation Improvement Program. On July 1, 2020, Minnesota Power submitted its CIP triennial filing for 2021 through 2023 to the MPUC, which outlines Minnesota Power’s CIP spending and energy-saving goals for those years. Minnesota Power’s CIP investment goals are $10.5 million for 2021, $10.7 million for 2022 and $10.9 million for 2023, subject to MPUC approval.

MISO Return on Equity Complaint. MISO transmission owners, including ALLETE and ATC, have an authorized return on equity of 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization, based on a May 21, 2020, FERC order that granted rehearing of a November 2019 FERC order, which had reduced the base return on equity for regional transmission organizations to 9.88 percent, or 10.38 percent including an incentive adder.

Minnesota Solar Energy Standard. On May 20, 2020, the MPUC issued a notice requesting all regulated gas and electric utilities provide a list of all ongoing, planned, or possible investments that support Minnesota’s energy policy objectives and aid economic recovery in Minnesota, among other items. On June 17, 2020, Minnesota Power filed a response which included outlining a proposal to accelerate its plans for solar energy with an estimated $40 million investment in approximately 20 MW of solar energy projects in Minnesota.

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.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

15

NOTE 2. REGULATORY MATTERS (Continued)

Regulatory Assets and Liabilities (Continued)

Regulatory Assets and Liabilities	June 30, 2020	December 31, 2019
Millions
Non-Current Regulatory Assets
Defined Benefit Pension and Other Postretirement Benefit Plans	$208.0	$212.9
Income Taxes	122.1	123.4
Cost Recovery Riders	39.3	24.7
Asset Retirement Obligations	31.7	32.0
Manufactured Gas Plant	8.3	8.2
Boswell Units 1 and 2 Net Plant and Equipment	7.8	10.7
PPACA Income Tax Deferral	4.7	4.8
Other	2.8	3.8
Total Non-Current Regulatory Assets	$424.7	$420.5
Current Regulatory Liabilities (a)
Provision for Interim Rate Refund (b)	$11.7	—
Transmission Formula Rates Refund	0.8	$1.7
Other	1.7	0.2
Total Current Regulatory Liabilities	14.2	1.9
Non-Current Regulatory Liabilities
Income Taxes	395.5	407.2
Wholesale and Retail Contra AFUDC	87.4	79.3
Plant Removal Obligations	39.3	35.5
Defined Benefit Pension and Other Postretirement Benefit Plans	14.1	17.0
North Dakota Investment Tax Credits	12.2	12.3
Fuel Adjustment Clause (c)	12.2	—
Conservation Improvement Program	5.4	5.4
Other	3.5	3.6
Total Non-Current Regulatory Liabilities	569.6	560.3
Total Regulatory Liabilities	$583.8	$562.2

(a)Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.

(b)Provision for Interim Rate Refund represents reserves for interim rates resulting from the MPUC’s approval of Minnesota Power’s petition and proposal to resolve and withdraw its rate case. This amount is expected to be refunded to Minnesota Power regulated retail customers in the third quarter of 2020. (See 2020 Minnesota General Rate Case.)

(c)Fuel adjustment clause regulatory liability represents the amount expected to be refunded to customers for the over-collection of fuel adjustment clause recoveries. (See Fuel Adjustment Clause Reform.)

NOTE 3. 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. In the six months ended June 30, 2020, we invested $1.1 million in ATC, and on July 31, 2020, we invested an additional $0.8 million. We expect to make additional investments of $0.8 million in 2020.

ALLETE’s Investment in ATC
Millions
Equity Investment Balance as of December 31, 2019	$141.6
Cash Investments	1.1
Equity in ATC Earnings (a)	11.6
Distributed ATC Earnings	(9.4)
Amortization of the Remeasurement of Deferred Income Taxes	0.7
Equity Investment Balance as of June 30, 2020	$145.6

(a)Equity in ATC Earnings includes $1.2 million of additional earnings resulting from the FERC’s May 21, 2020, order increasing ATC’s authorized return on equity to 10.52 percent including an incentive adder for participation in a regional transmission organization.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

16

NOTE 3. EQUITY INVESTMENTS (Continued)

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 May 21, 2020, FERC order that granted rehearing of a November 2019 FERC order. (See Note 2. Regulatory Matters.)

Investment in Nobles 2. Our wholly-owned subsidiary, ALLETE South Wind, owns 49 percent of Nobles 2, the entity that will own and operate 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. As of June 30, 2020, our equity investment in Nobles 2 was $121.5 million ($56.0 million at December 31, 2019). In the six months ended June 30, 2020, we invested $65.5 million in Nobles 2, and in July 2020 we invested an additional $15.0 million. We expect to make approximately $35 million in additional investments in 2020.

NOTE 4. 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 7. Fair Value to the Consolidated Financial Statements in our 2019 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, 2020, and December 31, 2019. 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 2020 Form 10-Q

17

NOTE 4. FAIR VALUE (Continued)

	Fair Value as of June 30, 2020
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities	$10.1	—	—	$10.1
Available-for-sale – Corporate and Governmental Debt Securities (b)	—	$9.8	—	9.8
Cash Equivalents	0.8	—	—	0.8
Total Fair Value of Assets	$10.9	$9.8	—	$20.7
Liabilities
Deferred Compensation (c)	—	$20.0	—	$20.0
Total Fair Value of Liabilities	—	$20.0	—	$20.0
Total Net Fair Value of Assets (Liabilities)	$10.9	$(10.2)	—	$0.7
	Fair Value as of December 31, 2019
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities	$11.1	—	—	$11.1
Available-for-sale – Corporate and Governmental Debt Securities	—	$9.7	—	9.7
Cash Equivalents	0.9	—	—	0.9
Total Fair Value of Assets	$12.0	$9.7	—	$21.7
Liabilities
Deferred Compensation (c)	—	$21.2	—	$21.2
Total Fair Value of Liabilities	—	$21.2	—	$21.2
Total Net Fair Value of Assets (Liabilities)	$12.0	$(11.5)	—	$0.5

(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.

(b)As of June 30, 2020, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $3.8 million, in one year to less than three years was $5.0 million, in three years to less than five years was $1.0 million and in five or more years was zero.

(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
June 30, 2020	$1,899.0	$2,163.4
December 31, 2019	$1,622.6	$1,791.8

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, 2020, and the year ended December 31, 2019, there were no indicators of impairment for these non-financial assets.

We continue to monitor changes in the broader energy markets that could indicate impairment at an ALLETE Clean Energy wind energy facility which currently has undiscounted future cash flows that are marginally in excess of the asset carrying value of approximately $11 million. A continued decline in energy prices would likely result in a future impairment.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

18

NOTE 5. SHORT-TERM AND LONG-TERM DEBT

The following tables present the Company’s short-term and long-term debt as of June 30, 2020, and December 31, 2019:

June 30, 2020	Principal	Unamortized Debt Issuance Costs	Total
Millions
Short-Term Debt	$510.0	$(0.3)	$509.7
Long-Term Debt	1,389.0	(8.0)	1,381.0
Total Debt	$1,899.0	$(8.3)	$1,890.7

December 31, 2019	Principal	Unamortized Debt Issuance Costs	Total
Millions
Short-Term Debt	$213.3	$(0.4)	$212.9
Long-Term Debt	1,409.3	(8.4)	1,400.9
Total Debt	$1,622.6	$(8.8)	$1,613.8

We had $23.5 million outstanding in standby letters of credit and no outstanding draws under our lines of credit as of June 30, 2020 ($62.0 million in standby letters of credit and no outstanding draws as of December 31, 2019).

On January 10, 2020, ALLETE entered into a $200 million unsecured term loan agreement (Term Loan) of which we have borrowed the full amount as of June 30, 2020. The Term Loan is due on February 10, 2021, and may be repaid at any time. Interest is payable monthly at a rate per annum equal to LIBOR plus 0.55 percent. Proceeds from the Term Loan were used for construction-related expenditures.

On March 26, 2020, ALLETE agreed to sell first mortgage bonds (Bonds) to certain institutional buyers in the private placement market, which were issued on August 3, 2020, in two series as follows:

Maturity Date	Principal Amount	Interest Rate
August 1, 2030	$46 Million	2.50%
August 1, 2050	$94 Million	3.30%

ALLETE has the option to prepay all or a portion of the Bonds at its discretion, subject to a make-whole provision. The Bonds are subject to additional terms and conditions which are customary for these types of transactions. ALLETE plans to use the proceeds from the sale of the Bonds to fund utility capital investment and for general corporate purposes. The Bonds were sold in reliance on an exemption from registration under Section 4(a)(2) of the Securities Act of 1933, as amended, to institutional accredited investors.

On April 8, 2020, ALLETE entered into a $115 million unsecured term loan agreement (Term Loan) and borrowed $95 million upon execution. The additional draw of $20 million provided for under the Term Loan was made in July 2020. The Term Loan is due on April 7, 2021, and may be repaid at any time. Interest is payable monthly at a rate per annum equal to LIBOR plus 1.7 percent with a LIBOR floor of 0.75 percent. Proceeds from the Term Loan will be 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, 2020, our ratio was approximately 0.44 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, 2020, ALLETE was in compliance with its financial covenants.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

19

NOTE 6. 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 9. Commitments, Guarantees and Contingencies to the Consolidated Financial Statements in our 2019 Form 10-K, with additional disclosure provided in the following paragraphs.

Square Butte PPA. As of June 30, 2020, Square Butte had total debt outstanding of $272.9 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, 2020, was $40.8 million ($41.1 million for the same period in 2019). 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 $3.7 million ($4.2 million for the same period in 2019). 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, it sold to Minnkota Power approximately 28 percent in 2020 and in 2019.

Minnesota Power Short-term PSAs. Minnesota Power has entered into various short-term PSAs to sell 300 MW of energy in 2020 and 2021. These PSAs were entered into to proactively mitigate the uncertainty of customers’ energy needs and potential load loss due to the COVID-19 pandemic. Additional transactions, purchases or sales, could be entered into as the extent and duration of the COVID-19 pandemic becomes known.

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 2021. Minnesota Power also has coal transportation agreements in place for the delivery of a significant portion of its coal requirements through December 2021. 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.

Transmission. We continue to make investments in transmission opportunities that strengthen or enhance the transmission grid or take advantage of our geographical location between sources of renewable energy and end users. These include the GNTL, investments to enhance our own transmission facilities, investments in other transmission assets (individually or in combination with others) and our investment in ATC.

Great Northern Transmission Line. As a condition of the 250-MW long-term PPA entered into with Manitoba Hydro, construction of additional transmission capacity was required. As a result, Minnesota Power constructed the GNTL, an approximately 220-mile 500-kV transmission line between Manitoba and Minnesota’s Iron Range that was proposed by Minnesota Power and Manitoba Hydro in order to strengthen the electric grid, enhance regional reliability and promote a greater exchange of sustainable energy. On June 1, 2020, Minnesota Power placed the GNTL into service with project costs of $307.1 million incurred by Minnesota Power through June 30, 2020. Total project costs, including those costs contributed by a subsidiary of Manitoba Hydro, incurred through June 30, 2020 totaled $657.0 million. Also on June 1, 2020, Manitoba Hydro placed the MMTP into service.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

20

NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

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.

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 SO₂ allowances issued and pending issuance, we currently expect generation levels and emission rates will result in continued compliance with the CSAPR. The ongoing CSAPR “good neighbor” provision and interstate transport litigation is also not currently projected to affect Minnesota Power’s CSAPR compliance. The State of Minnesota has not been identified by the downwind litigant states as a culpable upwind source, and previous EPA air quality modeling has demonstrated that Minnesota is not a significant contributor to downwind air quality attainment challenges. Minnesota Power also does not currently anticipate being affected by the EPA’s expected upcoming rulemakings to address the remand of certain CSAPR rules. Minnesota Power will continue to monitor ongoing CSAPR litigation and associated rulemakings.

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 expected to be material.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

21

NOTE 6. 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; increases 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. On June 19, 2019, the EPA finalized several separate rulemakings regarding regulating carbon emissions from electric utility generating units.

The EPA repealed the Clean Power Plan (CPP), following a determination by the EPA that the CPP exceeded the EPA’s statutory authority under the Clean Air Act (CAA). The primary reason for the repeal was the CPP’s attempt to regulate electric generating unit’s carbon emissions through measures outside of the affected unit’s direct control. The CPP was first announced as a proposed rule under Section 111(d) of the Clean Air Act for existing power plants entitled “Carbon Pollution Emission Guidelines for Existing Stationary Sources: Electric Generating Units”.

With the repeal of the CPP, the Affordable Clean Energy Rule was finalized. The rule establishes emissions guidelines for states to use when developing plans to limit carbon dioxide at coal-fired power plants. The rule identifies heat rate improvements made at individual units as the best system of emission reduction. Affected facilities for Minnesota Power include Boswell Units 3 and 4. Based on our initial review of the rule, many of the candidate heat rate improvements are already installed on Boswell Units 3 and 4.

Additionally, the EPA finalized new regulations for the state implementation of the Affordable Clean Energy Rule and any future emission guidelines issued under CAA Section 111(d). States will have three years to submit State Implementation Plans (SIPs), and the EPA has 12 months to review and approve those plans. Since the Affordable Clean Energy Rule allows states considerable flexibility in how to best implement its requirements, Minnesota Power plans to work closely with the MPCA and the Minnesota Department of Commerce, who are currently co-reviewing the rule as the state develops its SIP. If a state does not submit a SIP or submits a SIP that is unacceptable to the EPA, the EPA will develop a Federal Implementation Plan. The MPCA currently plans to develop a SIP for the Affordable Clean Energy Rule and Minnesota Power is working with the MPCA to provide requested information for the SIP.

Minnesota had already initiated several measures consistent with those called for under the now repealed CPP and finalized 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 the Affordable Clean Energy Rule and the resulting SIP; however, the costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

22

NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

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 reconsiders the bottom ash transport water 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 November 22, 2019, the EPA published a draft rulemaking that proposes to allow re-use of bottom ash transport water in FGD scrubber systems with minor discharges related to maintaining system water balance. The proposed rulemaking would also allow future discharge of FGD wastewater discharge provided it meets new BACT standards. A final rulemaking is anticipated in late 2020.

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 if additional water treatment measures are implemented. Under the current ELG rule, bottom ash transport water discharge to surface waters must cease no later than December 31, 2023. Bottom ash contact water will either need to be re-used in a closed-loop process, routed to a FGD scrubber, or the bottom ash handling system will need to be converted to a dry process. The ELG rule provision regarding these two waste-streams are being reconsidered and may change prior to November 1, 2020. Efforts have been underway at Boswell to reduce the amount of water discharged and evaluate potential re-use options in its plant processes. The EPA’s additional reconsideration of legacy wastewater discharge requirements have the potential to reduce timelines for dewatering Boswell’s existing bottom ash pond. The timing of a draft rule addressing legacy wastewater and leachate is currently unknown.

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 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.

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 stores or disposes coal ash at four of its electric generating facilities by the following methods: 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 occur 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.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

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NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

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 and in March 2018, published the first phase of the proposed rule revisions in the Federal Register. In July 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 August 2018, a U.S. District Court for the District of Columbia decision vacated specific provisions of the CCR rule. The court decision changed the status of three existing impoundments at Boswell that must now be considered unlined. The EPA proposed additional rule revisions in August and December 2019 to address outstanding issues from litigation and closure timelines for unlined impoundments, respectively. These rules are anticipated to be finalized in 2020 and could impact the timing of closure activities for Boswell’s three impoundments. Additionally, the EPA recently released a proposed Part B rulemaking that addresses options for beneficial reuse of CCR materials, alternative liner demonstrations, and other CCR regulatory revisions. 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.

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. SWL&P has been working with the Wisconsin Department of Natural Resources (WDNR) in determining the extent of contamination at the site and surrounding properties. In December 2017, the WDNR authorized SWL&P to transition from site investigation into the remedial design process. As of June 30, 2020, we have recorded a liability of approximately $7 million for remediation costs at this site (approximately $7 million as of December 31, 2019). 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 2023.

Other Matters.

Letters of Credit.

We have multiple credit facility agreements in place that provide the ability to issue standby letters of credit to satisfy our contractual security requirements across our businesses. As of June 30, 2020, we had $84.0 million of outstanding letters of credit issued, including those issued under our revolving credit facility.

Minnesota Power. As of June 30, 2020, Minnesota Power had $6.4 million outstanding in standby letters of credit which are pledged as security for MISO and state agency agreements.

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, 2020, ALLETE Clean Energy has $63.6 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.

Investment in Nobles 2. Construction of the Nobles 2 wind energy facility requires standby letters of credit as security for certain contractual obligations. As of June 30, 2020, ALLETE South Wind has $14.0 million outstanding in standby letters of credit, related to our portion of the security requirements relative to our ownership in Nobles 2.

BNI Energy. As of June 30, 2020, BNI Energy had surety bonds outstanding of $67.7 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 $67.3 million. BNI Energy does not believe it is likely that any of these outstanding surety bonds will be drawn upon.

ALLETE Properties. As of June 30, 2020, ALLETE Properties had surety bonds outstanding and letters of credit to governmental entities totaling $2.3 million primarily related to development and maintenance obligations for various projects. The estimated cost of the remaining development work is $1.3 million. ALLETE Properties does not believe it is likely that any of these outstanding surety bonds or letters of credit will be drawn upon.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

24

NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Other Matters (Continued)

Community Development District Obligations. As of June 30, 2020, we owned 53 percent of the assessable land in the Town Center District (53 percent as of December 31, 2019). As of June 30, 2020, ownership levels, our annual assessments related to capital improvement and special assessment bonds for the ALLETE Properties project within the district is approximately $1.9 million. As we sell property at this project, the obligation to pay special assessments will pass to the new landowners. In accordance with accounting guidance, these bonds are not reflected as debt on our Consolidated Balance Sheet.

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.

NOTE 7. 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.

		2020			2019
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	$20.1		$20.1	$34.2		$34.2
Average Common Shares	51.8	0.1	51.9	51.6	0.1	51.7
Earnings Per Share	$0.39		$0.39	$0.66		$0.66
Six Months Ended June 30,
Net Income Attributable to ALLETE	$86.4		$86.4	$104.7		$104.7
Average Common Shares	51.8	—	51.8	51.6	0.1	51.7
Earnings Per Share	$1.67		$1.67	$2.03		$2.02

NOTE 8. INCOME TAX EXPENSE

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Millions
Current Income Tax Expense (a)
Federal	—	—	—	—
State	—	$(0.1)	—	$0.2
Total Current Income Tax Expense (Benefit)	—	$(0.1)	—	$0.2
Deferred Income Tax Expense (Benefit)
Federal (b)	$(8.6)	$(7.1)	$(26.2)	$(16.8)
State (c)	0.2	2.5	4.2	15.0
Investment Tax Credit Amortization	(0.1)	(0.1)	(0.3)	(0.3)
Total Deferred Income Tax Benefit	$(8.5)	$(4.7)	$(22.3)	$(2.1)
Total Income Tax Benefit	$(8.5)	$(4.8)	$(22.3)	$(1.9)

(a)For each of the six months ended June 30, 2020 and 2019, 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 each of the six months ended June 30, 2020 and 2019, the federal income tax benefit is primarily due to production tax credits.

(c)For the six months ended June 30, 2019, the state income tax expense is primarily related to the sale of U.S. Water Services.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

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NOTE 8. 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	2020		2019		2020		2019
Millions
Income Before Income Taxes	$8.4		$29.4		$59.1		$102.8
Statutory Federal Income Tax Rate	21	%	21	%	21	%	21	%
Income Taxes Computed at Statutory Federal Rate	$1.7		$6.2		$12.4		$21.6
Increase (Decrease) in Income Tax Due to:
State Income Taxes – Net of Federal Income Tax Benefit	0.1		1.9		3.3		12.0
Production Tax Credits	(9.6)		(9.8)		(33.4)		(26.1)
Regulatory Differences – Excess Deferred Tax	(0.9)		(1.6)		(5.3)		(4.8)
U.S. Water Services Sale of Stock Basis Difference	—		(0.7)		—		1.7
Share-Based Compensation	—		—		(0.1)		(0.9)
Other	0.2		(0.8)		0.8		(5.4)
Total Income Tax Benefit	$(8.5)		$(4.8)		$(22.3)		$(1.9)

For the six months ended June 30, 2020, the effective tax rate was a benefit of 37.8 percent (benefit of 1.8 percent for the six months ended June 30, 2019). The effective tax rate for 2020 was primarily impacted by production tax credits. The effective tax rate for 2019 was primarily impacted by production tax credits and the gain on sale of U.S. Water Services.

Uncertain Tax Positions. As of June 30, 2020, we had gross unrecognized tax benefits of $1.4 million ($1.4 million as of December 31, 2019). 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 2016, or state examination for years before 2015.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

26

NOTE 9. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS

	Pension		Other Postretirement
Components of Net Periodic Benefit Cost (Credit)	2020	2019	2020	2019
Millions
Quarter Ended June 30,
Service Cost	$2.7	$2.4	$0.9	$1.0
Non-Service Cost Components (a)
Interest Cost	7.0	8.0	1.2	1.9
Expected Return on Plan Assets	(10.7)	(11.1)	(2.4)	(2.7)
Amortization of Prior Service Credits	(0.1)	(0.1)	(2.0)	(0.4)
Amortization of Net Loss	3.2	1.9	0.2	0.1
Net Periodic Benefit Cost (Credit)	$2.1	$1.1	$(2.1)	$(0.1)
Six Months Ended June 30,
Service Cost	$5.3	$4.7	$1.7	$2.0
Non-Service Cost Components (a)
Interest Cost	14.0	16.0	2.5	3.8
Expected Return on Plan Assets	(21.4)	(22.1)	(4.9)	(5.3)
Amortization of Prior Service Credits	(0.1)	(0.1)	(4.0)	(0.8)
Amortization of Net Loss	6.4	3.7	0.5	0.2
Net Periodic Benefit Cost (Credit)	$4.2	$2.2	$(4.2)	$(0.1)

(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, 2020, we contributed $10.7 million in cash to the defined benefit pension plans ($10.4 million for the six months ended June 30, 2019); we do not expect to make additional contributions to our defined benefit pension plans in 2020. For the six months ended June 30, 2020, and 2019, 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 2020.

NOTE 10. BUSINESS SEGMENTS

We present three reportable segments: Regulated Operations, ALLETE Clean Energy and U.S. Water Services. 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. U.S. Water Services was our integrated water management company, which is reflected in operating results until it was sold in March 2019. We also present Corporate and Other which includes two operating segments, BNI Energy, our coal mining operations in North Dakota, and ALLETE Properties, our legacy Florida real estate investment, along with our investment in Nobles 2, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, approximately 4,000 acres of land in Minnesota, and earnings on cash and investments.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

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NOTE 10. BUSINESS SEGMENTS (Continued)

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Millions
Operating Revenue
Regulated Operations
Residential	$27.4	$29.2	$68.3	$74.4
Commercial	28.8	34.9	66.1	73.8
Municipal	9.0	12.2	19.3	27.6
Industrial	88.0	120.3	206.8	241.9
Other Power Suppliers	27.4	35.2	65.7	74.6
Other	20.2	18.0	39.9	39.7
Total Regulated Operations	200.8	249.8	466.1	532.0
ALLETE Clean Energy
Long-term PSA	14.8	12.5	32.1	27.1
Other	2.8	2.9	5.6	5.8
Total ALLETE Clean Energy	17.6	15.4	37.7	32.9
U.S. Water Services (a)
Point-in-Time	—	—	—	19.0
Contract	—	—	—	9.2
Capital Project	—	—	—	5.2
Total U.S. Water Services	—	—	—	33.4
Corporate and Other
Long-term Contract	22.5	21.2	44.9	41.4
Other	2.3	4.0	6.1	7.9
Total Corporate and Other	24.8	25.2	51.0	49.3
Total Operating Revenue	$243.2	$290.4	$554.8	$647.6
Net Income (Loss) Attributable to ALLETE
Regulated Operations	$11.1	$30.3	$68.6	$81.8
ALLETE Clean Energy	4.0	1.9	15.7	7.7
U.S. Water Services (a)	—	—	—	(1.1)
Corporate and Other (a)	5.0	2.0	2.1	16.3
Total Net Income Attributable to ALLETE	$20.1	$34.2	$86.4	$104.7

(a)  In March 2019, ALLETE sold U.S. Water Services. The Company recognized a gain on the sale of $11.1 million after-tax during the six months ended June 30, 2019, which is reflected in Corporate and Other.

	June 30, 2020	December 31, 2019
Millions
Assets
Regulated Operations	$4,139.8	$4,130.8
ALLETE Clean Energy	1,250.2	1,001.5
Corporate and Other	370.4	350.5
Total Assets	$5,760.4	$5,482.8

ALLETE, Inc. Second Quarter 2020 Form 10-Q

28

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 2019 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 2019 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 21 of our 2019 Form 10-K. The risks and uncertainties described in this Form 10-Q and our 2019 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.

The trends and results for the quarter and six months of 2020 may not be indicative of results that may be expected for the year ended December 31, 2020 due to uncertainty regarding the extent and duration of the COVID-19 pandemic. This pandemic has resulted in widespread impacts on the global economy and on our employees, customers, contractors, and suppliers. There is considerable uncertainty regarding the extent to which COVID-19 will spread and the extent and duration of measures to try to contain the virus, such as travel bans and restrictions, quarantines, shelter-in-place orders (including those in effect in areas our businesses operate), and business and government shutdowns. Additional disclosures in this Form 10-Q regarding the impacts of the ongoing COVID-19 pandemic are located in Outlook – Regulated Operations – Industrial Customers and Prospective Additional Load, Liquidity and Capital Resources – Liquidity Position and Part II, Item 1A. Risk Factors.

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 145,000 retail customers. Minnesota Power also has 15 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 six states, approximately 740 MW of nameplate capacity wind energy generation that is contracted under PSAs of various durations. In addition, ALLETE Clean Energy currently has approximately 600 MW of wind energy facilities under construction or development that it will own and operate with long-term PSAs in place. 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.

U.S. Water Services provided integrated water management for industry by combining chemical, equipment, engineering and service for customized solutions to reduce water and energy usage, and improve efficiency. In March 2019, the Company sold U.S. Water Services to a subsidiary of Kurita Water Industries Ltd. pursuant to a stock purchase agreement for approximately $270 million in cash, net of transaction costs and cash retained.

Corporate and Other is comprised of BNI Energy, our coal mining operations in North Dakota, our investment in Nobles 2, a 49 percent equity interest in the entity that will own and operate a 250 MW wind energy facility in southwestern Minnesota, 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, approximately 4,000 acres of land in Minnesota, and earnings on cash and investments.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

29

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL

CONDITION AND RESULTS OF OPERATIONS (Continued)

ALLETE is incorporated under the laws of Minnesota. Our corporate headquarters are in Duluth, Minnesota. Statistical information is presented as of June 30, 2020, 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.

Financial Overview

The following net income discussion summarizes a comparison of the six months ended June 30, 2020, to the six months ended June 30, 2019. The trends and results for the first six months of 2020 may not be indicative of full year results for 2020 due to uncertainty regarding the extent and duration of the COVID-19 pandemic. (See Overview.)

Net income attributable to ALLETE for the six months ended June 30, 2020, was $86.4 million, or $1.67 per diluted share, compared to $104.7 million, or $2.02 per diluted share, for the same period in 2019. Net income in 2020 included reserves for interim rates of $8.3 million after-tax, or $0.16 per share, for the refund of interim rates collected through April 30, 2020, resulting from the MPUC’s approval of the resolution of Minnesota Power’s 2020 general rate case. (See Note 2. Regulatory Matters.) Net income in 2019 included a gain on the sale of U.S. Water Services of $11.1 million after-tax, or $0.21 per share, and U.S. Water Services results of operations amounted to a loss of $1.1 million after-tax, or $0.02 per share, in 2019.

Regulated Operations net income attributable to ALLETE was $68.6 million for the six months ended June 30, 2020, compared to $81.8 million for the same period in 2019. Net income at Minnesota Power was lower than 2019 primarily due to: reserves for interim rates of $8.3 million after-tax for the refund of interim rates collected through April 30, 2020; lower kWh sales to retail and municipal customers; lower revenue from Other Power Suppliers resulting from the expiration of a PSA; and the timing of fuel adjustment clause recoveries in 2019 with the adoption of a new fuel adjustment clause methodology for Minnesota utilities beginning in 2020. Net income at SWL&P was similar to 2019. Our after-tax equity earnings in ATC were higher compared to 2019 primarily due to period over period changes in ATC’s estimate of a refund liability related to the FERC decision on MISO return on equity complaints.

ALLETE Clean Energy net income attributable to ALLETE was $15.7 million for the six months ended June 30, 2020, compared to $7.7 million for the same period in 2019. Net income in 2020 included $3.8 million of additional production tax credits generated compared to 2019 and earnings from the Glen Ullin and South Peak wind energy facilities which commenced operations in December 2019 and April 2020, respectively. These increases were partially offset by higher depreciation expense.

U.S. Water Services net loss attributable to ALLETE was $1.1 million for six months ended June 30, 2019. ALLETE completed the sale of U.S. Water Services in the first quarter of 2019.

Corporate and Other net income attributable to ALLETE was $2.1 million for the six months ended June 30, 2020, compared to net income of $16.3 million for the same period in 2019. Net income in 2019 included a gain on the sale of U.S. Water Services of $11.1 million after-tax. Net income in 2020 included lower earnings from marketable equity securities held in benefit trusts and additional income tax expense recorded in 2020 as GAAP requires the recognition of income taxes at the estimated annual effective tax rate.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

30

COMPARISON OF THE QUARTERS ENDED JUNE 30, 2020 AND 2019

(See Note 10. Business Segments for financial results by segment.)

Regulated Operations

Quarter Ended June 30,	2020	2019
Millions
Operating Revenue – Utility	$200.8	$249.8
Fuel, Purchased Power and Gas – Utility	69.3	87.9
Transmission Services – Utility	16.4	19.2
Operating and Maintenance	48.0	54.2
Depreciation and Amortization	41.9	40.2
Taxes Other than Income Taxes	13.3	12.5
Operating Income	11.9	35.8
Interest Expense	(14.7)	(14.4)
Equity Earnings	6.4	4.8
Other Income	3.3	2.8
Income Before Income Taxes	6.9	29.0
Income Tax Expense (Benefit)	(4.2)	(1.3)
Net Income	$11.1	$30.3

Operating Revenue – Utility decreased $49.0 million, or 20 percent, from 2019 primarily due to lower revenue from kWh sales, fuel adjustment clause recoveries, and cost recovery rider revenue as well as the regulatory outcome related to the resolution of Minnesota Power’s 2020 general rate case. (See Note 2. Regulatory Matters.)

Revenue from kWh sales decreased $27.0 million from 2019 reflecting lower sales to commercial, industrial and municipal customers as well as the expiration of a 100 MW PSA in April 2020, partially offset by higher sales to residential customers. Sales to commercial and industrial customers decreased primarily due to the adverse impact of the COVID-19 pandemic on customer operations. Many commercial and industrial customers operated at reduced levels or were temporarily closed or idled during the second quarter of 2020 as a result of the COVID-19 pandemic and related governmental responses. In addition, USS Corporation indefinitely idled its Keetac plant and Verso Corporation indefinitely idled its paper mill in Duluth, Minnesota. (See Outlook – Regulated Operations – Industrial Customers and Prospective Additional Load.) Sales to municipal customers decreased from 2019 as a result of the expiration of a contract with a municipal customer in June 2019. Sales to residential customers increased from 2019 primarily due to warmer weather in 2020.

Kilowatt-hours Sold			Variance
Quarter Ended June 30,	2020	2019	Quantity	%
Millions
Regulated Utility
Retail and Municipal
Residential	246	232	14	6.0	%
Commercial	286	317	(31)	(9.8)	%
Industrial	1,235	1,773	(538)	(30.3)	%
Municipal	131	170	(39)	(22.9)	%
Total Retail and Municipal	1,898	2,492	(594)	(23.8)	%
Other Power Suppliers	706	714	(8)	(1.1)	%
Total Regulated Utility Kilowatt-hours Sold	2,604	3,206	(602)	(18.8)	%

Revenue from electric sales to taconite customers accounted for 22 percent of consolidated operating revenue in 2020 (27 percent in 2019). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 5 percent of consolidated operating revenue in 2020 (6 percent in 2019). Revenue from electric sales to pipelines and other industrial customers accounted for 7 percent of consolidated operating revenue in 2020 (8 percent in 2019).

Fuel adjustment clause revenue decreased $10.7 million due to lower fuel and purchased power costs attributable to retail and municipal customers, partially offset by the timing of fuel adjustment clause recoveries in 2019. Beginning in 2020, Minnesota utilities adopted a new fuel adjustment clause methodology. (See Note 2. Regulatory Matters.)

ALLETE, Inc. Second Quarter 2020 Form 10-Q

31

COMPARISON OF THE QUARTERS ENDED JUNE 30, 2020 AND 2019 (Continued)

Regulated Operations (Continued)

Revenue decreased $5.5 million primarily due to reserves for interim rates of $11.7 million recorded for interim rates collected from January 2020 through April 2020 as a result of the regulatory outcome related to the resolution of Minnesota Power’s 2020 general rate case. This decrease was partially offset by higher rates resulting from Minnesota Power’s rate case. (See Note 2. Regulatory Matters.)

Cost recovery rider revenue decreased $4.6 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 base rates, a decrease in cost recovery rider revenue is recognized to offset the impact of higher production tax credits on income tax expense.

Operating Expenses decreased $25.1 million, or 12 percent, from 2019.

Fuel, Purchased Power and Gas – Utility expense decreased $18.6 million, or 21 percent, from 2019 primarily due to 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 decreased $2.8 million, or 15 percent, from 2019 primarily due to lower MISO-related expense.

Operating and Maintenance expense decreased $6.2 million, or 11 percent, from 2019 primarily due to lower expenses for planned maintenance outages at our generation facilities, benefit expenses and employee expenses as well as a decrease in conservation improvement program expenses. These decreases were partially offset by rate case-related expenses and higher bad debt expense.

Depreciation and Amortization expense increased $1.7 million, or 4 percent, from 2019 primarily due to additional property, plant and equipment in service.

Equity Earnings increased $1.6 million, or 33 percent, from 2019 primarily due to period over period changes in ATC’s estimate of a refund liability related to the FERC decision on MISO return on equity complaints. (See Outlook – Regulated Operations – Transmission – Investment in ATC.)

Income Tax Benefit increased $2.9 million from 2019 primarily due to lower pre-tax income. We expect our annual effective tax rate in 2020 to be a higher income tax benefit than in 2019 primarily due to lower pre-tax income.

ALLETE Clean Energy

Quarter Ended June 30,	2020	2019
Millions
Operating Revenue
Contracts with Customers – Non-utility	$14.8	$12.5
Other – Non-utility (a)	2.8	2.9
Operating and Maintenance	7.8	8.2
Depreciation and Amortization	8.9	6.6
Taxes and Other	0.9	0.5
Operating Income (Loss)	—	0.1
Interest Expense	(0.5)	(0.8)
Other Income	—	—
Loss Before Income Taxes	(0.5)	(0.7)
Income Tax Expense (Benefit)	(1.3)	(2.6)
Net Income	0.8	1.9
Net Loss Attributable to Non-Controlling Interest	(3.2)	—
Net Income Attributable to ALLETE	$4.0	$1.9

(a)Represents non-cash amortization of differences between contract prices and estimated market prices on assumed PSAs.

Operating Revenue increased $2.2 million, or 14 percent, from 2019 primarily due to revenue from the Glen Ullin and South Peak wind energy facilities which commenced operations in December 2019 and April 2020, respectively.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

32

COMPARISON OF THE QUARTERS ENDED JUNE 30, 2020 AND 2019 (Continued)

ALLETE Clean Energy (Continued)

	Quarter Ended June 30,
	2020		2019
Production and Operating Revenue	kWh	Revenue	kWh	Revenue
Millions
Wind Energy Regions
East	57.1	$5.1	64.0	$5.8
Midwest	207.4	7.7	191.5	7.8
West	202.5	4.8	22.7	1.8
Total Production and Operating Revenue	467.0	$17.6	278.2	$15.4

Depreciation and Amortization expense increased $2.3 million, or 35 percent, from 2019 primarily due to additional property, plant and equipment in service related to the Glen Ullin and South Peak wind energy facilities.

Income Tax Benefit decreased $1.3 million from 2019 primarily due to additional taxable income from the Glen Ullin and South Peak wind energy facilities and additional income tax expense recorded in 2020 as GAAP requires the recognition of income taxes at the estimated annual effective tax rate. These decreases were partially offset by additional production tax credits generated in 2020. The income tax benefit in 2020 reflected production tax credits generated of $3.8 million compared to $2.2 million in 2019.

Net Loss Attributable to Non-Controlling Interest increased $3.2 million from 2019 reflecting net losses attributable to non-controlling interest for the Glen Ullin and South Peak wind energy facilities.

Corporate and Other

Operating Revenue decreased $0.4 million, or 2 percent, from 2019 primarily due to the timing of land sales at ALLETE Properties, partially offset by higher revenue at BNI Energy, which operates under cost-plus fixed fee contracts, as a result of higher expenses in 2020 compared to 2019.

Net Income increased $3.0 million from 2019 primarily due to higher earnings from marketable equity securities held in benefit trusts in 2020 and additional income tax benefit as GAAP requires the recognition of income tax expense at the estimated annual effective tax rate. These increases were partially offset by additional gain on the sale of U.S. Water Services in 2019 resulting from the finalization of working capital. Net income at BNI Energy was $2.5 million in 2020 compared to $1.7 million in 2019 reflecting higher earnings from marketable equity securities held in benefit trusts in 2020. The net loss at ALLETE Properties was $0.5 million in 2020 and in 2019.

Income Taxes – Consolidated

For the quarter ended June 30, 2020, the effective tax rate was a benefit of 102.4 percent (benefit of 16.3 percent for the quarter ended June 30, 2019). The 2020 increase in tax benefit was primarily due to lower pre-tax income. 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 2020 Form 10-Q

33

COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2020 AND 2019

(See Note 10. Business Segments for financial results by segment.)

Regulated Operations

Six Months Ended June 30,	2020	2019
Millions
Operating Revenue – Utility	$466.1	$532.0
Fuel, Purchased Power and Gas – Utility	158.3	197.7
Transmission Services – Utility	34.9	37.5
Operating and Maintenance	97.3	101.9
Depreciation and Amortization	83.6	80.0
Taxes Other than Income Taxes	24.6	24.8
Operating Income	67.4	90.1
Interest Expense	(29.3)	(29.9)
Equity Earnings	11.6	10.4
Other Income	6.7	7.1
Income Before Income Taxes	56.4	77.7
Income Tax Expense (Benefit)	(12.2)	(4.1)
Net Income Attributable to ALLETE	$68.6	$81.8

Operating Revenue – Utility decreased $65.9 million from 2019 primarily due to lower revenue from kWh sales, fuel adjustment clause recoveries and conservation improvement program recoveries, partially offset by higher rates resulting from Minnesota Power’s rate case.

Revenue from kWh sales decreased $35.7 million from 2019 reflecting lower sales to residential commercial, industrial and municipal customers as well as the expiration of a 100 MW PSA in April 2020. Sales to residential customers decreased from 2019 primarily due to warmer weather in the first quarter of 2020. Sales to commercial and industrial customers decreased primarily due to the adverse impact of the COVID-19 pandemic on customer operations. Many commercial and industrial customers operated at reduced levels or were temporarily closed or idled during the second quarter of 2020 as a result of the COVID-19 pandemic and related governmental responses. In addition, USS Corporation indefinitely idled its Keetac plant and Verso Corporation indefinitely idled its paper mill in Duluth, Minnesota. (See Outlook – Regulated Operations – Industrial Customers and Prospective Additional Load.) Sales to municipal customers decreased from 2019 as a result of the expiration of a contract with a municipal customer in June 2019.

Kilowatt-hours Sold			Variance
Six Months Ended June 30,	2020	2019	Quantity	%
Millions
Regulated Utility
Retail and Municipal
Residential	567	581	(14)	(2.4)	%
Commercial	638	683	(45)	(6.6)	%
Industrial	3,137	3,587	(450)	(12.5)	%
Municipal	287	373	(86)	(23.1)	%
Total Retail and Municipal	4,629	5,224	(595)	(11.4)	%
Other Power Suppliers	1,528	1,536	(8)	(0.5)	%
Total Regulated Utility Kilowatt-hours Sold	6,157	6,760	(603)	(8.9)	%

Revenue from electric sales to taconite customers accounted for 24 percent of consolidated operating revenue in 2020 (24 percent in 2019). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 5 percent of consolidated operating revenue in 2020 (5 percent in 2019). Revenue from electric sales to pipelines and other industrial customers accounted for 7 percent of consolidated operating revenue in 2020 (8 percent in 2019).

Fuel adjustment clause revenue decreased $22.9 million due to lower fuel and purchased power costs attributable to retail and municipal customers, partially offset by the timing of fuel adjustment clause recoveries in 2019. Beginning in 2020, Minnesota utilities adopted a new fuel adjustment clause methodology. (See Note 2. Regulatory Matters.)

ALLETE, Inc. Second Quarter 2020 Form 10-Q

34

COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2020 AND 2019 (Continued)

Regulated Operations (Continued)

Conservation improvement program recoveries decreased $3.7 million from 2019 primarily due to a decrease in related expenditures. (See Operating Expenses - Operating and Maintenance.)

Revenue increased $3.5 million due to higher rates in May 2020 and June 2020 resulting from the resolution of Minnesota Power’s 2020 general rate case. As part of the resolution, interim rates collected from January 2020 through April 2020 were offset with reserves for interim rates which are expected to be refunded in the third quarter of 2020. (See Note 2. Regulatory Matters.)

Operating Expenses decreased $43.2 million, or 10 percent, from 2019.

Fuel, Purchased Power and Gas – Utility expense decreased $39.4 million, or 20 percent, from 2019 primarily due to lower kWh sales, purchased power prices and fuel costs. Fuel and purchased power expense related to our retail and municipal customers is recovered through the fuel adjustment clause.

Transmission Services – Utility expense decreased $2.6 million, or 7 percent, from 2019 primarily due to lower MISO-related expense.

Operating and Maintenance expense decreased $4.6 million, or 5 percent, from 2019 primarily due to a decrease in conservation improvement program expenses, lower expenses for planned maintenance outages at our generation facilities and lower salary, benefit and other employee-related expenses. These decreases were partially offset by rate case-related expenses and higher bad debt expense.

Depreciation and Amortization expense increased $3.6 million, or 5 percent, from 2019 primarily due to additional property, plant and equipment in service.

Equity Earnings increased $1.2 million, or 12 percent, from 2019 primarily due to period over period changes in ATC’s estimate of a refund liability related to the FERC decision on MISO return on equity complaints. (See Outlook – Regulated Operations – Transmission – Investment in ATC.)

Income Tax Benefit increased $8.1 million from 2019 primarily due to lower pre-tax income. We expect our annual effective tax rate in 2020 to be a higher income tax benefit than in 2019 primarily due to lower pre-tax income.

ALLETE Clean Energy

Six Months Ended June 30,	2020	2019
Millions
Operating Revenue
Contracts with Customers – Non-utility	$32.1	$27.1
Other – Non-utility (a)	5.6	5.8
Operating and Maintenance	16.0	15.4
Depreciation and Amortization	17.1	13.1
Taxes and Other	1.6	1.1
Operating Income	3.0	3.3
Interest Expense	(1.0)	(1.6)
Other Income	0.2	1.8
Income Before Income Taxes	2.2	3.5
Income Tax Expense (Benefit)	(8.5)	(4.2)
Net Income	10.7	7.7
Net Loss Attributable to Non-Controlling Interest	(5.0)	—
Net Income Attributable to ALLETE	$15.7	$7.7

(a)Represents non-cash amortization of differences between contract prices and estimated market prices on assumed PSAs.

Operating Revenue increased $4.8 million, or 15 percent, from 2019 primarily due to revenue from the Glen Ullin and South Peak wind energy facilities which commenced operations in December 2019 and April 2020, respectively.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

35

COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2020 AND 2019 (Continued)

ALLETE Clean Energy (Continued)

	Six Months Ended June 30,
	2020		2019
Production and Operating Revenue	kWh	Revenue	kWh	Revenue
Millions
Wind Energy Regions
East	135.7	$12.2	144.4	$13.2
Midwest	451.8	16.2	404.4	16.8
West	344.3	9.3	36.1	2.9
Total Production and Operating Revenue	931.8	$37.7	584.9	$32.9

Depreciation and Amortization expense increased $4.0 million, or 31 percent, from 2019 primarily due to additional property, plant and equipment in service related to the Glen Ullin and South Peak wind energy facilities.

Other Income decreased $1.6 million from 2019 reflecting various individually immaterial items.

Income Tax Benefit increased $4.3 million from 2019 primarily due to additional production tax credits generated in 2020 compared to 2019. The income tax benefit in 2020 reflected production tax credits generated of $8.0 million compared to $4.2 million in 2019.

Net Loss Attributable to Non-Controlling Interest increased $5.0 million from 2019 reflecting net losses attributable to non-controlling interest for the Glen Ullin and South Peak wind energy facilities.

U.S. Water Services

Six Months Ended June 30,	2020	2019
Millions
Operating Revenue	—	$33.4
Net Loss Attributable to ALLETE	—	$(1.1)

Operating Revenue was $33.4 million for the six months ended June 30, 2019. ALLETE completed the sale of U.S. Water Services in the first quarter of 2019.

Net Loss Attributable to ALLETE was $1.1 million for the six months ended June 30, 2019. ALLETE completed the sale of U.S. Water Services in the first quarter of 2019.

Corporate and Other

Operating Revenue increased $1.7 million, or 3 percent, from 2019 primarily due to higher revenue at BNI Energy, which operates under cost-plus fixed fee contracts, as a result of higher expenses in 2020 compared to 2019, partially offset by the timing of land sales at ALLETE Properties.

Net Income Attributable to ALLETE was $2.1 million in 2020 compared to net income of $16.3 million in 2019. Net income in 2019 included a gain on the sale of U.S. Water Services of $11.1 million after-tax. Net income in 2020 included lower earnings from marketable equity securities held in benefit trusts and additional income tax expense recorded in 2020 as GAAP requires the recognition of income taxes at the estimated annual effective tax rate. Net income at BNI Energy was $3.2 million in 2020 compared to $3.6 million in 2019, reflecting lower earnings from marketable equity securities held in benefit trusts in 2020. The net loss at ALLETE Properties was $1.0 million in 2020 compared to a net loss of $1.1 million in 2019.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

36

COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2020 AND 2019 (Continued)

Income Taxes – Consolidated

For the six months ended June 30, 2020, the effective tax rate was a benefit of 37.8 percent (benefit of 1.8 percent for the six months ended June 30, 2019). The effective tax rate for 2020 was a higher benefit primarily due to 2019 including a higher tax rate on and higher pre-tax income resulting from the gain on the sale of U.S. Water Services in 2019.

We expect our annual effective tax rate in 2020 to be a higher benefit as compared to 2019 primarily due to higher production tax credits generated by ALLETE Clean Energy in 2020 and lower pre-tax income. The effective rate deviated from the combined statutory rate of approximately 28 percent primarily due to production tax credits. (See Note 8. 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, 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 2019 Form 10-K.

OUTLOOK

For additional information see our 2019 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 long-term objectives of achieving average annual earnings per share growth of 5 percent to 7 percent, and providing a dividend payout competitive with our industry. Regulated Operations is projected to have average annual earnings growth of 4 percent to 5 percent over the long-term. ALLETE Clean Energy and our Corporate and Other businesses are projected to have average annual earnings growth of at least 15 percent over the long-term. Our annual earnings per share is expected to be negatively impacted in the short-term by the ongoing COVID-19 pandemic and related disruptions; however, the Company expects it will be able to maintain its stated financial objectives for average annual earnings per share growth over the long-term (next five years). (See Part II, Item 1A. Risk Factors.)

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 our 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 2020. Over the next several years, the contribution of ALLETE Clean Energy and our Corporate and Other businesses to net income is expected to increase 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. (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.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

37

OUTLOOK (Continued)

Regulatory Matters. Entities within our Regulated Operations segment are under the jurisdiction of the MPUC, FERC, PSCW and NDPSC. See Note 2. Regulatory Matters for discussion of regulatory matters within these jurisdictions.

2020 Minnesota General Rate Case. In November 2019, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 10.6 percent for retail customers. The rate filing sought a return on equity of 10.05 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would have generated approximately $66 million in additional revenue. In orders dated December 23, 2019, the MPUC accepted the filing as complete and authorized an annual interim rate increase of $36.1 million that began January 1, 2020.

On April 23, 2020, Minnesota Power filed a request with the MPUC that proposed a resolution of Minnesota Power’s 2020 general rate case. Key components of our proposal included removing the power marketing margin credit in base rates and reflecting actual power marketing margins in the fuel adjustment clause effective May 1, 2020; refunding to customers interim rates collected through April 2020; increasing customer rates 4.1 percent compared to the 5.8 percent increase reflected in interim rates; and a provision that Minnesota Power would not file another rate case until at least November 1, 2021, unless certain events occur. In an order dated June 30, 2020, the MPUC approved Minnesota Power’s petition and proposal to resolve and withdraw the general rate case. Effective May 1, 2020, customer rates were set at an increase of 4.1 percent with the removal of the power marketing margin credit from base rates. Actual power marketing margins will be reflected in the fuel adjustment clause on an ongoing basis. As of June 30, 2020, reserves for interim rates of $11.7 million were recorded, which are expected to be refunded to customers in the third quarter of 2020.

2018 Wisconsin General Rate Case. SWL&P’s current retail rates are based on a December 2018 PSCW order that allows for a return on equity of 10.4 percent and a 55.0 percent equity ratio. The PSCW has directed SWL&P to file a general rate case in 2020; however, on July 24, 2020, SWL&P filed a waiver and extension request with the PSCW to delay filing its next general rate case on or before December 20, 2022, primarily due to impacts of the COVID-19 pandemic.

Industrial 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 51 percent of our regulated utility kWh sales in the six months ended June 30, 2020, were made to our industrial customers (53 percent in the six months ended June 30, 2019). These customers and their markets have been impacted by the ongoing COVID-19 pandemic. (See Part II, Item 1A. Risk Factors.)

The ongoing COVID-19 pandemic and related governmental responses has led to a disruption of economic activity, and could result in an extended disruption of economic activity. This disruption has resulted in reduced sales and revenue from industrial customers as many industrial customers operated at reduced levels or were temporarily closed or idled during the second quarter of 2020. In addition, USS Corporation indefinitely idled its Keetac plant and Verso Corporation indefinitely idled its paper mill in Duluth, Minnesota. (See USS Corporation and Verso Corporation.) The current disruption of economic activity or an extended disruption of economic activity may lead to additional adverse impacts on our taconite and paper, pulp and secondary wood products, pipeline and other industrial customers’ operations including further reduced production or the temporary idling or indefinite shutdown of other facilities, which would result in lower sales and revenue from these customers.

Taconite. Minnesota Power’s taconite customers are capable of producing up to approximately 41 million tons of taconite pellets annually. Taconite pellets produced in Minnesota are primarily shipped to North American steel making facilities that are part of the integrated steel industry. Steel produced from these North American facilities is used primarily in the manufacture of automobiles, appliances, pipe and tube products for the gas and oil industry, and in the construction industry. Historically, less than 10 percent of Minnesota taconite production has been exported outside of North America.

There has been a general historical correlation between U.S. steel production and Minnesota taconite production. The American Iron and Steel Institute, an association of North American steel producers, reported that U.S. raw steel production operated at approximately 67 percent of capacity during the first six months of 2020 compared to 81 percent in the first six months of 2019; however, the American Iron and Steel Institute also reported that U.S. raw steel production in the last week of July 2020 was approximately 60 percent of capacity. The World Steel Association, an association of steel producers, national and regional steel industry associations, and steel research institutes representing approximately 85 percent of world steel production, projected in June 2020 that U.S. steel consumption in 2020 will decrease by approximately 23 percent compared to 2019.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

38

OUTLOOK (Continued)

Industrial Customers and Prospective Additional Load (Continued)

Minnesota Power’s taconite customers may experience annual variations in production levels due to such factors as economic conditions, short-term demand changes or maintenance outages. We estimate that a one million ton change in Minnesota Power’s taconite customers’ production would impact our annual earnings per share by approximately $0.04, net of expected power marketing sales at current prices. Changes in wholesale electric prices or customer contractual demand nominations could impact this estimate. Minnesota Power proactively sells power in the wholesale power markets that is temporarily not required by industrial customers to optimize the value of its generating facilities. (See Note 6. Commitments, Guarantees and Contingencies.) Long-term reductions in taconite production or a permanent shut down of a taconite customer may lead Minnesota Power to file a general rate case to recover lost revenue.

Northshore Mining. Cliffs is currently constructing a hot briquetted iron production plant in Toledo, Ohio, and had begun shipping direct reduced-grade pellets form Northshore Mining to the Toledo plant in anticipation of the planned start of operations in 2020. In March 2020, following guidelines from the office of the Governor of Ohio regarding the COVID-19 pandemic, Cliffs temporarily shut down construction activities at its hot briquetted iron project site. In April 2020, Cliffs announced that, based on market conditions, it would be temporarily idling production at two of its iron ore mining operations, Northshore Mining in Minnesota and Tilden Mine in Michigan. Cliffs idled production at Northshore Mining in April 2020 and is expected to restart the facility and be at full production in August 2020. In June 2020, Cliffs announced that it was resuming construction of its hot briquetted iron project in Toledo, Ohio, with construction expected to be completed in the fourth quarter of 2020. 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 Silver Bay Power.)

Silver Bay Power. In 2016, Minnesota Power and Silver Bay Power entered into a PSA through 2031. Silver Bay Power supplies approximately 90 MW of load to Northshore Mining, an affiliate of Silver Bay Power, which had previously been served predominately through self-generation by Silver Bay Power. Starting in 2016, Minnesota Power supplied Silver Bay Power with at least 50 MW of energy and Silver Bay Power had the option to purchase additional energy from Minnesota Power as it transitioned away from self-generation. In the third quarter of 2019, Silver Bay Power ceased self-generation and Minnesota Power began supplying the full energy requirements for Silver Bay Power.

USS Corporation. In April 2020, USS Corporation stated it would indefinitely idle its Keetac facility in Keewatin, Minnesota, in response to the sudden and dramatic decline in business conditions resulting from the COVID-19 pandemic. In addition, in May 2020, USS Corporation announced that production was expected to be temporarily reduced at its Minntac Plant in Mountain Iron, Minnesota. USS Corporation increased production at its Minntac Plant beginning in late July 2020. No update was provided regarding its Keetac facility. USS Corporation has the capability to produce approximately 20 million tons annually at its Minntac and Keetac plants.

Hibbing Taconite. In April 2020, ArcelorMittal announced that Hibbing Taconite in Hibbing, Minnesota, would idle production due to the COVID-19 pandemic. Hibbing Taconite is expected to resume production in August 2020. Hibbing Taconite has the capability to produce approximately 8 million tons annually.

Paper, Pulp and Secondary Wood Products. The North American paper and pulp industry faces declining demand due to the impact of electronic substitution for print and changing customer needs. As a result, certain paper and pulp customers have reduced their existing operations in recent years and have pursued or are pursuing product changes in response to the declining demand. In addition, the ongoing COVID-19 pandemic and related federal and state government responses have adversely impacted these customers’ operations and resulted in lower operating levels than expected as well as the indefinite shutdown of Verso Corporations’ paper mill in Duluth, Minnesota. (See Verso Corporation.) These customers could continue to be adversely impacted by the COVID-19 pandemic resulting in lower operating levels than expected or the temporary idling or indefinite shutdown of other facilities.

Boise. On April 1, 2020, Packaging Corporation of America announced an idling of both paper machines and the sheet-converting operation at its Jackson Mill in Alabama for the months of May and June 2020. As part of that announcement, Packaging Corporation of America also stated that the company's Boise paper mill in International Falls, Minnesota, which is a customer of Minnesota Power, would continue to operate at capacity during the same period.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

39

OUTLOOK (Continued)

Industrial Customers and Prospective Additional Load (Continued)

Verso Corporation. In June 2020, Verso Corporation indefinitely idled its paper mill in Duluth, Minnesota. Verso Corporation stated the decision was due to the accelerated decline in graphic paper demand resulting from the COVID-19 pandemic and that it will explore alternatives for the mill including restarting if market conditions improve, marketing for sale or closing permanently.

Pipeline and Other Industries.

Husky Energy. In April 2018, a fire at Husky Energy’s refinery in Superior, Wisconsin, disrupted operations at the facility. Under normal operating conditions, SWL&P provides approximately 14 MW of average monthly demand to Husky Energy in addition to water service. In September 2019, Husky Energy announced that it had received the required permit approvals to begin reconstruction. In June 2020, Husky Energy announced that rebuild construction at the refinery had resumed following a suspension in March 2020 due to the COVID-19 pandemic. The facility remains at minimal operations, and the refinery is not expected to resume normal operations until 2022.

Prospective Additional Load. Minnesota Power is pursuing new wholesale and retail loads in and around its service territory. Currently, several companies in northeastern Minnesota continue to progress in the development of natural resource-based projects that represent long-term growth potential and load diversity for Minnesota Power. We cannot predict the outcome of these projects.

PolyMet. PolyMet is planning to start a new copper-nickel and precious metal (non-ferrous) mining operation in northeastern Minnesota. In 2015, PolyMet announced the completion of the final EIS by state and federal agencies, which was subsequently published in the Federal Register and Minnesota Environmental Quality Board Monitor. The Minnesota Department of Natural Resources (DNR) and the U.S. Army Corps of Engineers have both issued final Records of Decision, finding the final EIS adequate.

In 2016, PolyMet submitted applications for water-related permits with the DNR and MPCA, an air quality permit with the MPCA, and a state permit to mine application with the DNR detailing its operational plans for the mine. In June 2018, the U.S. Forest Service and PolyMet closed on a land exchange, which resulted in PolyMet obtaining surface rights to land needed to develop its mining operation. In November 2018, the DNR issued PolyMet’s permit to mine and certain water-related permits. In December 2018, the MPCA issued PolyMet’s final state water and air quality permits. On March 21, 2019, the U.S. Army Corps of Engineers issued PolyMet’s final federal permit. PolyMet was issued all necessary permits to construct and operate its new mining operation; however, on January 13, 2020, the Minnesota Court of Appeals reversed the DNR’s decisions granting PolyMet’s permit to mine and dam-safety permits, and remanded them back to the DNR to hold a contested-case hearing. On February 11, 2020, PolyMet announced it had filed a petition for further review with the Minnesota Supreme Court seeking to overturn the Minnesota Court of Appeals decision, which was accepted for review by the Minnesota Supreme Court on March 25, 2020. Minnesota Power could supply between 45 MW and 50 MW of load under a 10-year power supply contract with PolyMet that would begin upon start-up of operations.

EnergyForward. Minnesota Power is executing EnergyForward, a strategic plan for assuring reliability, protecting affordability and further improving environmental performance. The plan includes completed and planned investments in wind, solar, natural gas and hydroelectric power, construction of additional transmission capacity, the installation of emissions control technology and the idling of certain coal-fired generating facilities.

Integrated Resource Plan. In a 2016 order, the MPUC approved Minnesota Power’s 2015 IRP with modifications. The order accepted Minnesota Power’s plans for the economic idling of Taconite Harbor Units 1 and 2 and the ceasing of coal-fired operations at Taconite Harbor in 2020, directed Minnesota Power to retire Boswell Units 1 and 2 no later than 2022, required an analysis of generation and demand response alternatives to be filed with a natural gas resource proposal, and required Minnesota Power to conduct requests for proposal for additional wind, solar and demand response resource additions. Minnesota Power retired Boswell Units 1 and 2 in the fourth quarter of 2018. The MPUC also has required a baseload retirement evaluation in Minnesota Power’s next IRP filing analyzing its existing fleet, including potential early retirement scenarios of Boswell Units 3 and 4, as well as a securitization plan. Minnesota Power’s next IRP filing w due October 1, 2020; however, on May 29, 2020, Minnesota Power filed a request to extend the deadline for submitting its next IRP filing citing the COVID-19 pandemic. On July 30, 2020, the MPUC granted an extension of the deadline for submission until February 1, 2021, with interim reports due in the fourth quarter of 2020.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

40

OUTLOOK (Continued)

EnergyForward (Continued)

Nemadji Trail Energy Center. In 2017, Minnesota Power submitted a resource package to the MPUC which included requesting approval of a 250 MW natural gas capacity dedication agreement. The natural gas capacity dedication agreement was subject to MPUC approval of the construction of NTEC, a 525 MW to 550 MW combined-cycle natural gas-fired generating facility which will be jointly owned by Dairyland Power Cooperative and a subsidiary of ALLETE. Minnesota Power would purchase approximately 50 percent of the facility's output starting in 2025. In an order dated January 24, 2019, the MPUC approved Minnesota Power’s request for approval of the NTEC natural gas capacity dedication agreement. On December 23, 2019, the Minnesota Court of Appeals reversed and remanded the MPUC’s decision to approve certain affiliated-interest agreements. The MPUC was ordered to determine whether NTEC may have the potential for significant environmental effects and, if so, to prepare an environmental assessment worksheet before reassessing the agreements. On January 22, 2020, Minnesota Power filed a petition for further review with the Minnesota Supreme Court requesting that it review and overturn the Minnesota Court of Appeals decision, which petition was accepted for review by the Minnesota Supreme Court on March 18, 2020. On January 8, 2019, an application for a certificate of public convenience and necessity for NTEC was submitted to the PSCW, which was approved by the PSCW at a hearing on January 16, 2020. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $700 million, of which ALLETE’s portion is expected to be approximately $350 million. ALLETE’s portion of NTEC project costs incurred through June 30, 2020, is approximately $14 million.

Renewable Energy. Minnesota Power’s 2015 IRP includes an update on its plans and progress in meeting the Minnesota renewable energy milestones through 2025. Minnesota Power continues to execute its renewable energy strategy and expects approximately 50 percent of its energy will be supplied by renewable energy sources by 2021.

Solar Energy. Minnesota Power’s solar energy supply consists of Camp Ripley, a 10 MW solar energy facility at the Camp Ripley Minnesota Army National Guard base and training facility near Little Falls, Minnesota, and a community solar garden project in northeastern Minnesota, which is comprised of a 1 MW solar array owned and operated by a third party with the output purchased by Minnesota Power and a 40 kW solar array that is owned and operated by Minnesota Power.

On June 17, 2020, Minnesota Power filed a proposal with the MPUC to accelerate its plans for solar energy with an estimated $40 million investment in approximately 20 MW of solar energy projects in Minnesota. (See Note 2. Regulatory Matters.)

Minnesota Power has approval for current cost recovery of investments and expenditures related to compliance with the Minnesota Solar Energy Standard. On June 30, 2020, Minnesota Power filed a petition seeking MPUC approval of a customer billing rate for solar costs related to investments and expenditures for meeting the state of Minnesota’s solar energy standard.

Wind Energy. Minnesota Power’s wind energy facilities consist of Bison (497 MW) located in North Dakota, and Taconite Ridge (25 MW) located in northeastern Minnesota. Minnesota Power also has two long-term wind energy PPAs with an affiliate of NextEra Energy, Inc. to purchase the output from Oliver Wind I (50 MW) and Oliver Wind II (48 MW) located in North Dakota.

Minnesota Power uses the 465-mile, 250-kV DC transmission line that runs from Center, North Dakota, to Duluth, Minnesota, to transport wind energy from North Dakota while gradually phasing out coal-based electricity delivered to its system over this transmission line from Square Butte’s lignite coal-fired generating unit. Minnesota Power is currently pursuing a modernization and capacity upgrade of its DC transmission system to continue providing reliable operations and additional system capabilities.

Minnesota Power has an approved cost recovery rider for certain renewable investments and expenditures. The cost recovery rider allows Minnesota Power to charge retail customers on a current basis for the costs of certain renewable investments plus a return on the capital invested. Updated customer billing rates for the renewable cost recovery rider were provisionally approved by the MPUC in a November 2018 order.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

41

OUTLOOK (Continued)

EnergyForward (Continued)

Nobles 2 PPA. In the third quarter of 2018, Minnesota Power and Nobles 2 signed an amended long-term PPA that provides for Minnesota Power to purchase the energy and associated capacity from a 250 MW wind energy facility in southwestern Minnesota for a 20-year period beginning in 2020. The agreement provides for the purchase of output from the facility at fixed energy prices. There are no fixed capacity charges, and Minnesota Power will only pay for energy as it is delivered. This agreement is subject to construction of the wind energy facility. (See Note 3. Equity Investments.)

Manitoba Hydro. Minnesota Power has three long-term PPAs with Manitoba Hydro. Under the first PPA, Minnesota Power is purchasing surplus energy through April 2022. This energy-only agreement primarily consists of surplus hydro energy on Manitoba Hydro’s system that is delivered to Minnesota Power on a non-firm basis. The pricing is based on forward market prices. Under this agreement, Minnesota Power will purchase at least one million MWh of energy over the contract term.

The second PPA provides for Minnesota Power to purchase 250 MW of capacity and energy from Manitoba Hydro through May 2035. The energy price is based on a formula that includes an annual fixed price component adjusted for the change in a governmental inflationary index and a natural gas index, as well as market prices.

The third PPA provides for Minnesota Power to purchase up to 133 MW of energy from Manitoba Hydro through June 2040. The pricing under this PPA is based on forward market prices.

Transmission. We continue to make investments in transmission opportunities that strengthen or enhance the transmission grid or take advantage of our geographical location between sources of renewable energy and end users. These include the GNTL, investments to enhance our own transmission facilities, investments in other transmission assets (individually or in combination with others) and our investment in ATC.

Great Northern Transmission Line. As a condition of the 250-MW long-term PPA entered into with Manitoba Hydro, construction of additional transmission capacity was required. As a result, Minnesota Power constructed the GNTL, an approximately 220-mile 500-kV transmission line between Manitoba and Minnesota’s Iron Range that was proposed by Minnesota Power and Manitoba Hydro in order to strengthen the electric grid, enhance regional reliability and promote a greater exchange of sustainable energy. On June 1, 2020, Minnesota Power placed the GNTL into service with project costs of $307.1 million incurred by Minnesota Power through June 30, 2020. Total project costs, including those costs contributed by a subsidiary of Manitoba Hydro, incurred through June 30, 2020 totaled $657.0 million. Also on June 1, 2020, Manitoba Hydro placed the MMTP into service.

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. As of June 30, 2020, our equity investment in ATC was $145.6 million ($141.6 million as of December 31, 2019). In the six months ended June 30, 2020, we invested $1.1 million in ATC, and on July 31, 2020, we invested an additional $0.8 million. We expect to make additional investments of $0.8 million in 2020.

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 May 21, 2020, FERC order that granted rehearing of a November 2019 FERC order, which had reduced the base return on equity for regional transmission organizations to 9.88 percent, or 10.38 percent including an incentive adder.

ATC’s 10-year transmission assessment, which covers the years 2019 through 2028, identifies a need for between $2.9 billion and $3.6 billion in transmission system investments. These investments by ATC, if undertaken, are expected to be funded through a combination of internally generated cash, debt and investor contributions. As opportunities arise, we plan to make additional investments in ATC through general capital calls based upon our pro rata ownership interest in ATC.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

42

OUTLOOK (Continued)

ALLETE Clean Energy.

ALLETE Clean Energy focuses on developing, acquiring, and operating clean and renewable energy projects. ALLETE Clean Energy currently owns and operates, in six states, approximately 740 MW of nameplate capacity wind energy generation that is contracted under PSAs of various durations. In addition, ALLETE Clean Energy currently has approximately 600 MW of wind energy facilities under construction or development that it will own and operate with long-term PSAs in place. 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 believes the market for renewable energy in North America is robust, driven by several factors including environmental regulation, tax incentives, societal expectations and continual technology advances. State renewable portfolio standards and state or federal regulations to limit GHG emissions are examples of environmental regulation or public policy that we believe will drive renewable energy development.

ALLETE Clean Energy’s strategy includes the safe, reliable, optimal and profitable operation of its existing facilities. This includes a strong safety culture, the continuous pursuit of operational efficiencies at existing facilities and cost controls. ALLETE Clean Energy generally acquires facilities in liquid power markets and its strategy includes the exploration of PSA extensions upon expiration of existing contracts and production tax credit requalification of existing facilities.

ALLETE Clean Energy will pursue growth through acquisitions or project development. ALLETE Clean Energy is targeting acquisitions of existing facilities up to 200 MW each, which have long-term PSAs in place for the facilities’ output. At this time, ALLETE Clean Energy expects acquisitions or development of new facilities will be primarily wind or solar facilities in North America. ALLETE Clean Energy is also targeting the development of new facilities up to 200 MW each, which will have long-term PSAs in place for the output or may be sold upon completion.

Federal production tax credit qualification is important to the economics of project development, and ALLETE Clean Energy has invested in equipment to meet production tax credit safe harbor provisions which provides an opportunity to seek development of up to approximately 1,000 MW of production tax credit qualified wind projects through 2022. ALLETE Clean Energy will also invest approximately $80 million through 2020 for production tax credit requalification of up to approximately 500 WTGs at its Storm Lake I, Storm Lake II, Lake Benton and Condon wind energy facilities. We anticipate annual production tax credits relating to these projects of approximately $17 million in 2020, $17 million to $22 million annually in 2021 through 2027 and decreasing thereafter through 2030. Disruptions in our supply chains or a lack of available financing resulting from the ongoing COVID-19 pandemic, if they occur, could jeopardize our ability to complete certain capital projects in time to qualify them for production tax credits. To date we have not experienced disruptions in our supply chains. (See Part II, Item 1A. Risk Factors.)

In 2018, ALLETE Clean Energy announced that it will build, own and operate the South Peak wind project, an 80 MW wind energy facility in Montana, pursuant to a 15-year PSA with NorthWestern Corporation; construction was completed and tax equity funding of $67.8 million in cash, net of issuance costs, was received in the second quarter of 2020.

In May 2019, ALLETE Clean Energy acquired the Diamond Spring wind project in Oklahoma from Apex Clean Energy. ALLETE Clean Energy will build, own and operate the approximately 300 MW wind energy facility. The Diamond Spring wind project is fully contracted to sell wind power under long-term power sales agreements. Construction is expected to be completed in late 2020.

On March 10, 2020, ALLETE Clean Energy acquired the rights to the approximately 300 MW Caddo wind project in Oklahoma from Apex Clean Energy for approximately $8 million with additional payments required to be made at defined milestones. The full development of this wind project will involve the sale of energy to corporate customers under long-term PSAs.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

43

OUTLOOK (Continued)

ALLETE Clean Energy (Continued)

ALLETE Clean Energy manages risk by having a diverse portfolio of assets, which includes PSA expiration, technology and geographic diversity. The current operating portfolio of approximately 740 MW is subject to typical variations in seasonal wind with higher wind resources typically available in the winter months. The majority of its planned maintenance leverages this seasonality and is performed during lower wind periods. The current mix of PSA expiration and geographic location for existing facilities is as follows:

Wind Energy Facility	Location	Capacity MW	PSA MW	PSA Expiration
Armenia Mountain	East	101	100%	2024
Chanarambie/Viking	Midwest	98
PSA 1 (a)			12%	2023
PSA 2			88%	2023
Condon	West	50	100%	2022
Glen Ullin	West	106	100%	2039
Lake Benton	Midwest	104	100%	2028
South Peak	West	80	100%	2035
Storm Lake I	Midwest	108	100%	2027
Storm Lake II	Midwest	77
PSA 1			90%	2022
PSA 2			10%	2032
Other	Midwest	17	100%	2028

(a)The PSA expiration assumes the exercise of all renewal options that ALLETE Clean Energy has the sole right to exercise.

Corporate and Other.

BNI Energy. BNI Energy anticipates selling 4.4 million tons of lignite coal in 2020 (4.1 million tons were sold in 2019) and has sold 2.1 million tons for the six months ended June 30, 2020 (2.2 million tons were sold for the six months ended June 30, 2019). BNI Energy operates under cost-plus fixed fee agreements extending through December 31, 2037.

Investment in Nobles 2. Our wholly-owned subsidiary, ALLETE South Wind, owns 49 percent of Nobles 2, the entity that will own and operate a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20-year PPA with Minnesota Power. The wind energy facility will be built in Nobles County, Minnesota, and is expected to be completed in late 2020, with an estimated total project cost of approximately $350 million to $400 million. In the fourth quarter of 2019, we entered into a tax equity funding agreement to finance approximately $116 million of the project costs. We account for our investment in Nobles 2 under the equity method of accounting. As of June 30, 2020, our equity investment in Nobles 2 was $121.5 million ($56.0 million at December 31, 2019). In the six months ended June 30, 2020, we invested $65.5 million in Nobles 2, and in July 2020 we invested an additional $15.0 million. We expect to make approximately $35 million in additional investments in 2020.

ALLETE Properties. ALLETE Properties represents our legacy Florida real estate investment. ALLETE Properties’ major project in Florida is Town Center at Palm Coast, with approximately 800 acres of land available for sale. In addition to this project, ALLETE Properties has approximately 600 acres of other land available for sale. Market conditions can impact land sales and could result in our inability to cover our cost basis and operating expenses including fixed carrying costs such as community development district assessments and property taxes.

Our strategy incorporates the possibility of a bulk sale of the entire ALLETE Properties portfolio. Proceeds from a bulk sale would be strategically deployed to support growth initiatives at our Regulated Operations and ALLETE Clean Energy. ALLETE Properties also continues to pursue sales of individual parcels over time and will continue to maintain key entitlements and infrastructure.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

44

OUTLOOK (Continued)

Income Taxes.

ALLETE’s aggregate federal and multi-state statutory tax rate is approximately 28 percent for 2020. ALLETE also has tax credits and other tax adjustments that reduce the combined statutory rate to the effective tax rate. These tax credits and adjustments historically have included items such as investment tax credits, production tax credits, AFUDC-Equity, depletion, as well as other items. The annual effective rate can also be impacted by such items as changes in income before income taxes, state and federal tax law changes that become effective during the year, business combinations, tax planning initiatives and resolution of prior years’ tax matters. We expect our effective tax rate to be a benefit of approximately 35 percent to 40 percent for 2020 primarily due to federal production tax credits as a result of wind energy generation. We also expect that our effective tax rate will be lower than the combined statutory rate over the next 10 years due to production tax credits attributable to our wind energy generation.

LIQUIDITY AND CAPITAL RESOURCES

Liquidity Position. ALLETE is well-positioned to meet the Company’s liquidity needs; however, the Company is monitoring capital markets and other financing sources in light of the ongoing COVID-19 pandemic. (See Part II, Item 1A. Risk Factors.) A disruption in capital markets could lead to increased borrowing costs or adversely impact our ability to access capital markets or other financing sources. If we are not able to access capital on acceptable terms in sufficient amounts and when needed, or at all, the ability to maintain our businesses or to implement our business plans would be adversely affected.

As of June 30, 2020, we had cash and cash equivalents of $25.7 million, $383.5 million in available consolidated lines of credit, 2.9 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 44 percent. (See Working Capital.)

In addition, ALLETE issued $140 million of the Company's first mortgage bonds on August 3, 2020, and in April 2020, we received $67.8 million in cash, net of issuance costs, from a third-party investor as part of a tax equity financing for ALLETE Clean Energy’s South Peak wind energy facility. The Company also has approximately $116 million in commitments from tax equity partners for our investment in Nobles 2, and the Company is actively seeking tax equity funding for ALLETE Clean Energy’s Diamond Spring and Caddo wind projects.

Capital Structure. ALLETE’s capital structure is as follows:

	June 30, 2020	%	December 31, 2019	%
Millions
ALLETE Equity	$2,265.7	52	$2,231.9	56
Non-Controlling Interest in Subsidiaries	166.5	4	103.7	3
Short-Term and Long-Term Debt	1,899.0	44	1,622.6	41
	$4,331.2	100	$3,958.2	100

Cash Flows. Selected information from the Consolidated Statement of Cash Flows is as follows:

For the Six Months Ended June 30,	2020	2019
Millions
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	$92.5	$79.0
Cash Flows from (used for)
Operating Activities	144.5	95.2
Investing Activities	(487.4)	46.0
Financing Activities	287.8	(13.6)
Change in Cash, Cash Equivalents and Restricted Cash	(55.1)	127.6
Cash, Cash Equivalents and Restricted Cash at End of Period	$37.4	$206.6

ALLETE, Inc. Second Quarter 2020 Form 10-Q

45

LIQUIDITY AND CAPITAL RESOURCES (Continued)

Cash Flows (Continued)

Operating Activities. Cash from operating activities was higher in 2020 compared to 2019. Cash from operating activities in 2019 included the refund of Minnesota Power’s provisions for interim rates and tax reform, and the impact of U.S. Water Services prior to its sale. Cash from operating activities in 2020 reflected lower collections of accounts receivable due to timing and lower cash collected from current cost recovery riders.

Investing Activities. Cash used for investing activities was higher in 2020 compared to 2019. Cash from investing activities in 2019 included proceeds received from the sale of U.S. Water Services. Cash used for investing activities in 2020 included higher additions to property, plant and equipment and additional payments for equity method investments compared to 2019.

Financing Activities. Cash from financing activities was higher in 2020 compared to 2019 primarily due to higher proceeds from the issuance of long-term debt, proceeds from a tax equity financing (non-controlling interest in subsidiaries) and lower repayments of 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, 2020, we had consolidated bank lines of credit aggregating $407.0 million ($407.0 million as of December 31, 2019), the majority of which expire in January 2024. We had $23.5 million outstanding in standby letters of credit and no outstanding draws under our lines of credit as of June 30, 2020 ($62.0 million in standby letters of credit and no outstanding draws as of December 31, 2019). In addition, as of June 30, 2020, we had 3.5 million original issue shares of our common stock available for issuance through Invest Direct, our direct stock purchase and dividend reinvestment plan, and 2.9 million original issue shares of common stock available for issuance through a distribution agreement with Lampert Capital Markets, as amended most recently in May 2020. The amount and timing of future sales of our securities will depend upon market conditions and our specific needs. In July 2019, we filed Registration Statement No. 333-232905, pursuant to which the remaining shares under this agreement will continue to be offered for sale, from time to time.

Securities. During the six months ended June 30, 2020, 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 $7.9 million (0.2 million shares were issued for the six months ended June 30, 2019, resulting in net proceeds of $1.5 million). These shares of common stock were registered under Registration Statement Nos. 333-231030, 333-183051 and 333-162890.

Financial Covenants. See Note 5. 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 9. Pension and Other Postretirement Benefit Plans.)

Off-Balance Sheet Arrangements. Off-balance sheet arrangements are summarized in our 2019 Form 10-K, with additional disclosure in Note 6. Commitments, Guarantees and Contingencies.

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.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

46

LIQUIDITY AND CAPITAL RESOURCES (Continued)

Credit Ratings (Continued)

On April 22, 2020, S&P Global Ratings downgraded ALLETE’s long-term issuer credit rating to BBB stable from BBB+ outlook negative and affirmed its short-term rating at A-2. S&P Global Ratings noted the impacts of debt coverage ratios going forward along with the lack of a revenue decoupling mechanism at Minnesota Power combined with the large commercial and industrial presence in its service territory as its rationale for the downgrade.

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 2020 are now expected to be approximately $635 million. The increase from the 2020 capital expenditures projected in our 2019 Form 10-K is primarily due to the Caddo wind project. (See Outlook – ALLETE Clean Energy.) The Company is also evaluating its planned capital expenditures and may make adjustments to mitigate impacts of the ongoing COVID-19 pandemic, if appropriate. For the six months ended June 30, 2020, capital expenditures totaled $356.1 million ($249.3 million for the six months ended June 30, 2019). The expenditures were primarily made in the Regulated Operations and ALLETE Clean Energy segments.

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 6. Commitments, Guarantees and Contingencies.)

Employees.

As of June 30, 2020, ALLETE had 1,355 employees, of which 1,332 were full-time.

Minnesota Power and SWL&P have an aggregate of 471 employees who 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 February 1, 2021, for SWL&P.

BNI Energy has 183 employees, of which 136 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.

ITEM 3.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

SECURITIES INVESTMENTS

Available-for-Sale Securities. As of June 30, 2020, our available-for-sale securities portfolio consisted primarily of securities held in other postretirement plans to fund employee benefits.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

47

ITEM 3.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK (Continued)

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, 2020, an increase of 100 basis points in interest rates would impact the amount of pre-tax interest expense by $4.3 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, 2020.

ITEM 4.  CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures. As of June 30, 2020, 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 2020 Form 10-Q

48

PART II.  OTHER INFORMATION

ITEM 1.  LEGAL PROCEEDINGS

For information regarding material legal and regulatory proceedings, see Note 4. Regulatory Matters and Note 9. Commitments, Guarantees and Contingencies to the Consolidated Financial Statements in our 2019 Form 10-K and Note 2. Regulatory Matters and Note 6. Commitments, Guarantees and Contingencies herein. Such information is incorporated herein by reference.

ITEM 1A.  RISK FACTORS

Our 2019 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 2019 Form 10-K.

We could be materially adversely affected by the ongoing COVID-19 pandemic for which we are unable to predict the ultimate impact as the extent and duration of the COVID-19 pandemic is uncertain.

The ongoing COVID-19 pandemic has resulted in widespread impacts on the global economy and on our employees, customers, contractors, and suppliers. There is considerable uncertainty regarding the extent to which COVID-19 will spread and the extent and duration of measures to try to contain the virus, such as travel bans and restrictions, quarantines, shelter-in-place orders (including those in effect in areas our businesses operate), and business and government shutdowns. We are responding to the COVID-19 pandemic by taking steps to mitigate the potential risks to us posed by its spread and have implemented our company-wide business continuity plans in response to the pandemic. These plans guide our emergency response, business continuity, and the precautionary measures we are taking on behalf of employees and the public. We have taken additional precautions for our employees who work in the field and for employees who continue to work in our facilities, and we have implemented work from home policies where appropriate. We continue to implement physical and cyber-security measures to ensure that our systems remain functional in order to both serve our operational needs with a remote workforce and keep them running to ensure uninterrupted service to our customers.

The ongoing COVID-19 pandemic and related federal and state government responses has led to a disruption of economic activity, and could result in an extended disruption of economic activity. The governors of Minnesota and Wisconsin issued executive orders in March 2020 in response to the COVID-19 pandemic which restricted economic activity in these states. The state of Minnesota continues to have restrictions that remain in effect through at least August 12, 2020, while the state of Wisconsin’s order was overturned in May 2020 and has not been replaced. This disruption has resulted and is expected to continue to result in reduced sales and revenue from commercial, municipal and industrial customers as well as an increase in uncollectible accounts from residential and commercial customers. Many commercial and industrial customers were operating at reduced levels or were temporarily closed or idled during the second quarter of 2020. In addition, USS Corporation indefinitely idled its Keetac plant and Verso Corporation indefinitely idled its paper mill in Duluth, Minnesota. (See Outlook – Regulated Operations – Industrial Customers and Prospective Additional Load.) The current disruption of economic activity or an extended disruption of economic activity may lead to additional adverse impacts on our taconite mining, paper, pulp and secondary wood products, and pipeline customers’ operations including further reduced production or the temporary idling or indefinite shutdown of other facilities, which would result in lower sales and revenue from these customers. In Minnesota Power’s service territory, we have also voluntarily and as requested by state regulators extended Minnesota’s cold weather rule as well as temporarily suspended disconnections for non-payment and waived late payment charges for residential and small business customers. In SWL&P’s service territory, we have implemented state regulator requested customer service actions to further limit service disconnections and late payment charges for residential, commercial and industrial customers.

ALLETE, Inc. Second Quarter 2020 Form 10-Q

49

ITEM 1A.  RISK FACTORS (Continued)

We could be materially adversely affected by the ongoing COVID-19 pandemic for which we are unable to predict the ultimate impact as the extent and duration of the COVID-19 pandemic is uncertain (Continued)

The Company is monitoring the capital markets and has access to liquidity to enable us to operate our businesses and fund capital projects; however, a disruption in capital markets could lead to increased borrowing costs or adversely impact our ability to access capital markets or other financing sources. If we are not able to access capital on acceptable terms in sufficient amounts and when needed, or at all, the ability to maintain our businesses or to implement our business plans would be adversely affected. In addition, the performance of capital markets impacts the values of the assets that are held in trust to satisfy future obligations under our pension and other postretirement benefit plans. A decline in the market value of these assets would increase the funding requirements under our benefit plans and future costs recognized for the benefit plans if the asset market values do not recover. The Company is also monitoring supply chains for key materials, supplies and services for our operations and large capital projects. We have received notices of force majeure from certain suppliers and the pandemic could result in a disruption to our supply chains which could adversely impact our operations and capital projects; however, there has been limited impact on our supply chains as to the availability of materials, supplies and services to date. In addition, disruptions in our supply chains or a lack of available financing could jeopardize our ability to complete certain capital projects in time to qualify them for production tax credits.

We will continue to monitor developments affecting our workforce, operations and customers, and we will take additional precautions that we determine are necessary in order to mitigate the impacts of the COVID-19 pandemic. Despite our efforts to manage these impacts to the Company, their ultimate impact also depends on factors beyond our control, including the duration and severity of this pandemic as well as governmental and third-party actions taken to contain its spread and mitigate its public health effects. As a result, we cannot predict the ultimate impact of the COVID-19 pandemic and whether it will have a material impact on our liquidity, financial position, results of operations and cash flows.

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 2020 Form 10-Q

50

ITEM 6.  EXHIBITS

Exhibit Number
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 5, 2020, announcing 2020 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 2020 Form 10-Q

51

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 5, 2020	/s/ Robert J. Adams
	Robert J. Adams
	Senior Vice President and Chief Financial Officer
	(Principal Financial Officer)
August 5, 2020	/s/ Steven W. Morris
	Steven W. Morris
	Vice President, Controller and Chief Accounting Officer
	(Principal Accounting Officer)

ALLETE, Inc. Second Quarter 2020 Form 10-Q

52

EX-31.A

Exhibit 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

I, Bethany M. Owen, of ALLETE, Inc. (ALLETE), certify that:

1.I have reviewed this quarterly report on Form 10-Q for the period ended June 30, 2020, of ALLETE;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 5, 2020	/s/ Bethany M. Owen
	Bethany M. Owen
	President and Chief Executive Officer

EX-31.B

Exhibit 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

I, Robert J. Adams, of ALLETE, Inc. (ALLETE), certify that:

1.I have reviewed this quarterly report on Form 10-Q for the period ended June 30, 2020, of ALLETE;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): 

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 5, 2020	/s/ Robert J. Adams
	Robert J. Adams
	Senior Vice President and Chief Financial Officer

EX-32

Exhibit 32

Section 1350 Certification of Periodic Report

By the Chief Executive Officer and Chief Financial Officer

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350, each of the undersigned officers of ALLETE, Inc. (ALLETE), does hereby certify that:

1.The Quarterly Report on Form 10-Q of ALLETE for the period ended June 30, 2020, (Report) fully complies with the requirements of Section 13(a) of the Securities Exchange Act of 1934 (15 U.S.C. 78m); and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of ALLETE.

Date: August 5, 2020
	/s/ Bethany M. Owen
	Bethany M. Owen
	President and Chief Executive Officer

Date: August 5, 2020
	/s/ Robert J. Adams
	Robert J. Adams
	Senior Vice President and Chief Financial Officer

This certification shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to liability pursuant to that section. Such certification shall not be deemed to be incorporated by reference into any filing under the Securities Act of 1933 or the Securities Exchange Act of 1934, except to the extent that ALLETE specifically incorporates it by reference.

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to ALLETE and will be retained by ALLETE and furnished to the Securities and Exchange Commission or its staff upon request.

EX-95

Exhibit 95

Mine Safety Disclosure

Mine or Operating Name/MSHA Identification Number

Section 104 S&S Citations (#)

Section 104(b) Orders (#)

Section 104(d) Citations and Orders (#)

Section 110(b)(2) Violations (#)

Section 107(a) Orders (#)

Total Dollar Value of MSHA Assessments Proposed ($)

Total Number of Mining Related Fatalities (#)

Received Notice of Pattern of Violation Under Section 104(e) (yes/no)

Received Notice of Potential to Have Pattern Under Section 104(e) (yes/no)

Legal Actions Pending as of Last Day of Period (#)

Legal Actions Initiated During Period (#)

Legal Actions Resolved During Period (#)

Center Mine / 3200218

—

—

—

—

—

—

—

No

No

—

—

—

For the six months ended June 30, 2020, BNI Energy, owner of Center Mine, received five citations under Section 104(a) of the Mine Safety Act, none were significant and substantial (S&S) citations. For the six months ended June 30, 2020, BNI Energy paid $934 in penalties for citations closed during the period. For the six months ended June 30, 2020, there were no citations, orders, violations or notices under Sections 104(b), 104(d), 107(a), 104(e) or 110(b)(2) of the Mine Safety Act and there were no fatalities.

EX-99

		Exhibit 99
	For Release:	August 5, 2020
	Investor Contact:	Vince Meyer
		218-723-3952
NEWS		vmeyer@allete.com

ALLETE, Inc. reports second quarter earnings

•Reinstates 2020 annual GAAP earnings guidance, with range of $3.09 - $3.29, in light of improved visibility of industrial customer production levels for the remainder of the year

•Announces 2020 annual adjusted earnings guidance range (Non-GAAP) of $3.25 - $3.45, excluding the Minnesota Power rate case settlement charge, net of tax

DULUTH, Minn. - ALLETE, Inc. (NYSE: ALE) today reported second quarter 2020 earnings of 39 cents per share on net income of $20.1 million. Last year’s results were 66 cents per share on net income of $34.2 million. Results in the second quarter of 2020 included a 16 cent per share charge for the recent Minnesota Power rate case resolution. Results in the second quarter of 2019 included 2 cents per share of a U.S. Water Services gain on sale adjustment.

“From many aspects, including cultural, operational and financial results, this quarter demonstrates the commitment and resilience of ALLETE’s talented employees,” said ALLETE President and CEO Bethany Owen. “We’re proud of the resourcefulness demonstrated in our ability to provide essential quality of life services while delivering a fair level of financial results even against the challenging backdrop of the COVID-19 pandemic.”

ALLETE’s Regulated Operations segment, which includes Minnesota Power, Superior Water, Light and Power and the Company’s investment in the American Transmission Co., recorded net income of $11.1 million, compared to $30.3 million in the second quarter of 2019. Earnings reflect lower net income at Minnesota Power primarily due to the rate case settlement, lower kilowatt-hour sales to commercial and industrial customers due to COVID-19 impacts, lower sales to municipal customers and other power suppliers due to the expiration of related contracts, and timing impacts of fuel adjustment clause recoveries. These decreases were partially offset by lower operating and maintenance expense, higher sales to residential customers and higher equity earnings in the American Transmission Co.

ALLETE Clean Energy recorded second quarter 2020 net income of $4.0 million compared to $1.9 million in 2019. Net income in 2020 reflects additional production tax credits and earnings from the new Glen Ullin and South Peak wind energy facilities, partially offset by higher depreciation expense.

Corporate and Other businesses, which include BNI Energy and ALLETE Properties, recorded net income of $5.0 million in 2020 compared to net income of $2.0 million in 2019. Net income in 2020 included higher earnings from marketable equity securities held in certain benefit trusts and additional income tax benefit which varies quarter to quarter based on an estimated annual effective tax rate. Net income in 2019 included a gain on the sale of U.S. Water Services adjustment of $1.2 million after-tax.

“Although results for the quarter reflect obvious negative economic impacts of the COVID-19 pandemic, on a year to date comparison, our financial results are similar to those in 2019, excluding the second quarter rate case resolution impact,” said ALLETE Senior Vice President and Chief Financial Officer Bob Adams. “With constructive indications of improving production from Minnesota Power’s industrial customers, ALLETE’s 2020 annual adjusted earnings guidance (Non-GAAP) is expected to be in the range of $3.25 to $3.45 per share, excluding the 16 cent per share charge related to the Minnesota Power rate case resolution, net of tax. This guidance reflects year to date results along with several expectations and assumptions into the end of the year. These primarily include, lower power demands related to taconite and paper customers that remain idled, and lower kilowatt-hour sales to commercial, industrial and municipal customers, both due to the impacts of the COVID-19 pandemic, offset by lower operating and maintenance expense.”

Live Webcast on August 5, 2020; updated 2020 guidance slides posted on company website

ALLETE’s earnings conference call will be at 10:00 a.m. (EST), August 5, 2020, at which time management will discuss the second quarter of 2020 financial results and 2020 earnings guidance. Interested parties may listen live by calling 877-303-5852, pass code 9239038, ten minutes prior to the start time, or may listen to the live audio-only webcast and view supporting slides, which will be available on ALLETE’s Investor Relations website http://investor.allete.com/events-presentations. A replay of the call will be available through August 12, 2020 by calling (855) 859-2056, pass code 9239038. The webcast will be accessible for one year at www.allete.com.

ALLETE is an energy company headquartered in Duluth, Minn. In addition to its electric utilities, Minnesota Power and Superior Water, Light and Power of Wisconsin, ALLETE owns ALLETE Clean Energy, based in Duluth, BNI Energy in Bismarck, N.D., and has an eight percent equity interest in the American Transmission Co. More information about ALLETE is available at www.allete.com. ALE-CORP

The statements contained in this release and statements that ALLETE may make orally in connection with this release that are not historical facts, are forward-looking statements. Actual results may differ materially from those projected in the forward-looking statements. These forward-looking statements involve risks and uncertainties and investors are directed to the risks discussed in documents filed by ALLETE with the Securities and Exchange Commission.

ALLETE's press releases and other communications may include certain non-Generally Accepted Accounting Principles (GAAP) financial measures. A "non-GAAP financial measure" is defined as a numerical measure of a company's financial performance, financial position or cash flows that excludes (or includes) amounts that are included in (or excluded from) the most directly comparable measure calculated and presented in accordance with GAAP in the company's financial statements.

Non-GAAP financial measures utilized by the company include presentations of earnings (loss) per share. ALLETE's management believes that these non-GAAP financial measures provide useful information to investors by removing the effect of variances in GAAP reported results of operations that are not indicative of changes in the fundamental earnings power of the company's operations, such as the charge for the recent Minnesota Power rate case resolution. Management believes that the presentation of non-GAAP financial measures is appropriate and enables investors and analysts to more accurately compare the company's ongoing financial performance over the periods presented. See page 4 in this release for a reconciliation of 2020 annual GAAP earnings guidance range to 2020 annual adjusted earnings guidance range (Non-GAAP).

ALLETE, Inc.

Consolidated Statement of Income

Millions Except Per Share Amounts - Unaudited

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Operating Revenue
Contracts with Customers – Utility	$200.8	$249.8	$466.1	$532.0
Contracts with Customers – Non-utility	39.6	37.7	83.1	109.8
Other – Non-utility	2.8	2.9	5.6	5.8
Total Operating Revenue	243.2	290.4	554.8	647.6
Operating Expenses
Fuel, Purchased Power and Gas – Utility	69.3	87.9	158.3	197.7
Transmission Services – Utility	16.4	19.2	34.9	37.5
Cost of Sales – Non-utility	16.3	16.5	33.2	47.1
Operating and Maintenance	59.0	66.7	120.0	142.9
Depreciation and Amortization	54.5	50.2	107.9	102.1
Taxes Other than Income Taxes	15.0	13.7	27.6	27.3
Total Operating Expenses	230.5	254.2	481.9	554.6
Operating Income	12.7	36.2	72.9	93.0
Other Income (Expense)
Interest Expense	(15.9)	(16.3)	(31.6)	(32.8)
Equity Earnings	6.4	4.8	11.6	10.4
Gain on Sale of U.S. Water Services	—	0.5	—	20.6
Other	5.2	4.2	6.2	11.6
Total Other Income (Expense)	(4.3)	(6.8)	(13.8)	9.8
Income Before Income Taxes	8.4	29.4	59.1	102.8
Income Tax Expense (Benefit)	(8.5)	(4.8)	(22.3)	(1.9)
Net Income	$16.9	$34.2	$81.4	$104.7
Net Loss Attributable to Non-Controlling Interest	(3.2)	—	(5.0)	—
Net Income Attributable to ALLETE	$20.1	$34.2	$86.4	$104.7
Average Shares of Common Stock
Basic	51.8	51.6	51.8	51.6
Diluted	51.9	51.7	51.8	51.7
Basic Earnings Per Share of Common Stock	$0.39	$0.66	$1.67	$2.03
Diluted Earnings Per Share of Common Stock	$0.39	$0.66	$1.67	$2.02
Dividends Per Share of Common Stock	$0.6175	$0.5875	$1.235	$1.175

Consolidated Balance Sheet

Millions - Unaudited

	Jun. 30	Dec. 31,		Jun. 30	Dec. 31,
	2020	2019		2020	2019
Assets			Liabilities and Equity
Cash and Cash Equivalents	$25.7	$69.3	Current Liabilities	$727.7	$507.4
Other Current Assets	197.3	200.2	Long-Term Debt	1,381.0	1,400.9
Property, Plant and Equipment – Net	4,644.5	4,377.0	Deferred Income Taxes	202.3	212.8
Regulatory Assets	424.7	420.5	Regulatory Liabilities	569.6	560.3
Equity Investments	267.1	197.6	Defined Benefit Pension and Other Postretirement Benefit Plans	159.5	172.8
Other Non-Current Assets	201.1	218.2	Other Non-Current Liabilities	288.1	293.0
			Equity	2,432.2	2,335.6
Total Assets	$5,760.4	$5,482.8	Total Liabilities and Equity	$5,760.4	$5,482.8

	Quarter Ended		Six Months Ended
ALLETE, Inc.	June 30,		June 30,
Income (Loss)	2020	2019	2020	2019
Millions
Regulated Operations	$11.1	$30.3	$68.6	$81.8
ALLETE Clean Energy	4.0	1.9	15.7	7.7
U.S. Water Services	—	—	—	(1.1)
Corporate and Other	5.0	2.0	2.1	16.3
Net Income Attributable to ALLETE	$20.1	$34.2	$86.4	$104.7
Diluted Earnings Per Share	$0.39	$0.66	$1.67	$2.02

Statistical Data
Corporate
Common Stock
High	$64.90	$86.52	$84.71	$86.52
Low	$48.22	$78.86	$48.22	$72.50
Close	$54.61	$83.21	$54.61	$83.21
Book Value	$43.67	$42.69	$43.67	$42.69

Kilowatt-hours Sold
Millions
Regulated Utility
Retail and Municipal
Residential	246	232	567	581
Commercial	286	317	638	683
Industrial	1,235	1,773	3,137	3,587
Municipal	131	170	287	373
Total Retail and Municipal	1,898	2,492	4,629	5,224
Other Power Suppliers	706	714	1,528	1,536
Total Regulated Utility Kilowatt-hours Sold	2,604	3,206	6,157	6,760

Regulated Utility Revenue
Millions
Regulated Utility Revenue
Retail and Municipal Electric Revenue
Residential	$24.7	$26.7	$61.1	$66.4
Commercial	27.7	33.6	63.0	70.1
Industrial	87.7	120.0	205.7	240.6
Municipal	9.0	12.2	19.3	27.6
Total Retail and Municipal Electric Revenue	149.1	192.5	349.1	404.7
Other Power Suppliers	27.4	35.2	65.7	74.6
Other (Includes Water and Gas Revenue)	24.3	22.1	51.3	52.7
Total Regulated Utility Revenue	$200.8	$249.8	$466.1	$532.0

A reconciliation of 2020 annual GAAP earnings guidance range to 2020 annual adjusted earnings guidance range (Non-GAAP) is as follows:

2020 Annual GAAP Earnings Guidance Range	$3.09 - $3.29
Rate Case Settlement Charge	$0.23
Less: Income Tax Benefit	$(0.07)
Rate Case Settlement Charge, Net of Income Tax Benefit	$0.16
2020 Annual Adjusted Earnings Guidance Range (Non-GAAP)	$3.25 - $3.45

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.

XML

Document and Entity Information Document	6 Months Ended
	Jun. 30, 2020 shares
Document and Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2020
Document Transition Report	false
Entity File Number	1-3548
Entity Registrant Name	ALLETE, Inc.
State of Incorporation	MN
Entity Tax Identification Number	41-0418150
Entity Address, Address Line One	30 West Superior Street
Entity Address, City or Town	Duluth
Entity Address, State or Province	MN
Entity Address, Postal Zip Code	55802-2093
City Area Code	218
Local Phone Number	279-5000
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	ALE
Name of Exchange	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	51,880,664
Entity Central Index Key	0000066756
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Small Business	false
Entity Emerging Growth Company	false

XML

Consolidated Balance Sheet - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Current Assets [Abstract]
Cash and Cash Equivalents	$ 25.7	$ 69.3
Accounts Receivable (Less Allowance of $1.3 and $0.9)	85.8	96.4
Inventories – Net	82.0	72.8
Prepayments and Other	29.5	31.0
Total Current Assets	223.0	269.5
Property, Plant and Equipment – Net	4,644.5	4,377.0
Regulatory Assets	424.7	420.5
Equity Investments	267.1	197.6
Other Non-Current Assets	201.1	218.2
Total Assets	5,760.4	5,482.8
Current Liabilities [Abstract]
Accounts Payable	86.1	165.2
Accrued Taxes	48.5	50.8
Accrued Interest	18.0	18.1
Long-Term Debt Due Within One Year	509.7	212.9
Other	65.4	60.4
Total Current Liabilities	727.7	507.4
Long-Term Debt	1,381.0	1,400.9
Deferred Income Taxes	202.3	212.8
Regulatory Liabilities	569.6	560.3
Defined Benefit Pension and Other Postretirement Benefit Plans	159.5	172.8
Other Non-Current Liabilities	288.1	293.0
Total Liabilities	3,328.2	3,147.2
Commitments, Guarantees and Contingencies (Note 6)
Equity [Abstract]
Common Stock Without Par Value, 80.0 Shares Authorized, 51.9 and 51.7 Shares Issued and Outstanding	1,447.7	1,436.7
Accumulated Other Comprehensive Loss	(23.3)	(23.6)
Retained Earnings	841.3	818.8
Total ALLETE Equity	2,265.7	2,231.9
Non-Controlling Interest in Subsidiaries	166.5	103.7
Total Equity	2,432.2	2,335.6
Total Liabilities and Equity	$ 5,760.4	$ 5,482.8

XML

Consolidated Balance Sheet Parentheticals - USD ($) shares in Millions, $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Accounts Receivable [Abstract]
Accounts Receivable, Allowance	$ 1.3	$ 0.9
Common Stock [Abstract]
Common Stock, Par Value	$ 0	$ 0
Common Stock, Shares Authorized	80.0	80.0
Common Stock, Shares Outstanding	51.9	51.7
Common Stock, Shares Issued	51.9	51.7

XML

Consolidated Statement of Income - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Operating Revenues [Abstract]
Contracts with Customers - Utility	$ 200.8	$ 249.8	$ 466.1	$ 532.0
Contracts with Customers - Non-utility	39.6	37.7	83.1	109.8
Other - Non-utility	2.8	2.9	5.6	5.8
Total Operating Revenue	243.2	290.4	554.8	647.6
Operating Expenses [Abstract]
Fuel, Purchased Power and Gas - Utility	69.3	87.9	158.3	197.7
Transmission Services - Utility	16.4	19.2	34.9	37.5
Cost of Sales - Non-utility	16.3	16.5	33.2	47.1
Operating and Maintenance	59.0	66.7	120.0	142.9
Depreciation and Amortization	54.5	50.2	107.9	102.1
Taxes Other than Income Taxes	15.0	13.7	27.6	27.3
Total Operating Expenses	230.5	254.2	481.9	554.6
Operating Income	12.7	36.2	72.9	93.0
Other Income (Expense) [Abstract]
Interest Expense	(15.9)	(16.3)	(31.6)	(32.8)
Equity Earnings	6.4	4.8	11.6	10.4
Gain on Sale of U.S. Water Services	0.0	0.5	0.0	20.6
Other	5.2	4.2	6.2	11.6
Total Other Income (Expense)	(4.3)	(6.8)	(13.8)	9.8
Income Before Income Taxes	8.4	29.4	59.1	102.8
Income Tax Expense (Benefit)	(8.5)	(4.8)	(22.3)	(1.9)
Net Income	16.9	34.2	81.4	104.7
Net Loss Attributable to Non-Controlling Interest	(3.2)	0.0	(5.0)	0.0
Net Income Attributable to ALLETE	$ 20.1	$ 34.2	$ 86.4	$ 104.7
Earnings Per Share [Abstract]
Basic (Shares)	51.8	51.6	51.8	51.6
Diluted (Shares)	51.9	51.7	51.8	51.7
Basic Earnings Per Share of Common Stock	$ 0.39	$ 0.66	$ 1.67	$ 2.03
Diluted Earnings Per Share of Common Stock	$ 0.39	$ 0.66	$ 1.67	$ 2.02

XML

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Comprehensive Income [Abstract]
Net Income	$ 16.9	$ 34.2	$ 81.4	$ 104.7
Other Comprehensive Income (Loss) [Abstract]
Unrealized Gain on Securities Net of Income Tax Expense of $0.1, $0.1, $– and $0.1	0.4	0.1	0.0	0.2
Defined Benefit Pension and Other Postretirement Benefit Plans Net of Income Tax Expense of $–, $–, $0.1 and $0.1	0.1	0.2	0.3	0.2
Total Other Comprehensive Income	0.5	0.3	0.3	0.4
Total Comprehensive Income	17.4	34.5	81.7	105.1
Net Loss Attributable to Non-Controlling Interest	(3.2)	0.0	(5.0)	0.0
Total Comprehensive Income Attributable to ALLETE	$ 20.6	$ 34.5	$ 86.7	$ 105.1

XML

Consolidated Statement of Comprehensive Income Parentheticals - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Statement of Comprehensive Income [Abstract]
Unrealized Gain (Loss) on Securities, Income Tax Expense	$ 0.1	$ 0.1	$ 0.0	$ 0.1
Defined Benefit Pension and Other Postretirement Benefit Plans, Income Tax Expense	$ 0.0	$ 0.0	$ 0.1	$ 0.1

XML

Consolidated Statement of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Operating Activities [Abstract]
Net Income	$ 81.4	$ 104.7
AFUDC – Equity	(1.4)	(1.3)
Income from Equity Investments – Net of Dividends	(2.2)	(2.2)
Realized and Unrealized (Gain) Loss on Investments and Property, Plant and Equipment	1.1	(2.6)
Depreciation Expense	107.9	100.8
Amortization of PSAs	(5.6)	(5.8)
Amortization of Other Intangible Assets and Other Assets	5.2	7.0
Deferred Income Tax Benefit	(22.3)	(2.1)
Share-Based and ESOP Compensation Expense	3.1	3.3
Defined Benefit Pension and Postretirement Benefit Expense	0.0	2.1
Payments / Provision for Interim Rate Refund	11.7	(40.0)
Payments / Provision for Tax Reform Refund	(0.1)	(10.3)
Bad Debt Expense	1.1	(0.6)
Gain on Sale of U.S. Water Services	0.0	(20.6)
Changes in Operating Assets and Liabilities [Abstract]
Accounts Receivable	9.5	34.0
Inventories	(9.3)	(9.5)
Prepayments and Other	3.3	3.4
Accounts Payable	(11.6)	(11.2)
Other Current Liabilities	(8.5)	(24.2)
Cash Contributions to Defined Benefit Pension Plans	(10.7)	(10.4)
Changes in Regulatory and Other Non-Current Assets	(16.8)	(8.5)
Changes in Regulatory and Other Non-Current Liabilities	8.7	(10.8)
Cash from Operating Activities	144.5	95.2
Investing Activities [Abstract]
Proceeds from Sale of Available-for-sale Securities	2.1	6.0
Payments for Purchase of Available-for-sale Securities	(2.3)	(5.9)
Payments for Equity Investments	(66.6)	(4.6)
Return of Capital From Equity Investments	0.0	8.3
Proceeds from Sale of U.S. Water Services - Net of Transaction Costs and Cash Retained	0.0	264.2
Additions to Property, Plant and Equipment	(419.9)	(236.0)
Payments for (Proceeds from) Other Investing Activities	(0.7)	14.0
Cash from (for) Investing Activities	(487.4)	46.0
Financing Activities [Abstract]
Proceeds from Issuance of Common Stock	7.9	1.5
Proceeds from Issuance of Long-term Debt	297.4	100.0
Repayments of Long-Term Debt	(20.9)	(49.8)
Proceeds from Noncontrolling Interests	67.8	0.0
Acquisition-Related Contingent Consideration Payments	0.0	(3.8)
Dividends on Common Stock	(63.9)	(60.7)
Other Financing Activities	(0.5)	(0.8)
Cash from (for) Financing Activities	287.8	(13.6)
Change in Cash, Cash Equivalents and Restricted Cash	(55.1)	127.6
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	$ 37.4	$ 206.6

XML

Consolidated Statement of Shareholders' Equity - USD ($)	Total	Common Stock [Member]	AOCI Attributable to Parent [Member]	Retained Earnings [Member]	Noncontrolling Interest [Member]
Balance, Beginning Balance at Dec. 31, 2018		$ 1,428,500,000	$ (27,300,000)	$ 754,600,000	$ 0
Consolidated Statement of Shareholders' Equity [Roll Forward]
Common Stock Issued		4,800,000
Unrealized Gain (Loss) on Debt Securities	$ 200,000		200,000
Defined Benefit Pension and Other Postretirement Plans	200,000		200,000
Net Income (Loss) Attributable to ALLETE	104,700,000			104,700,000
Common Stock Dividends	60,700,000			(60,700,000)
Proceeds from Noncontrolling Interests	0				0
Net Loss Attributable to Non-Controlling Interest	0				0
Balance, End of Period at Jun. 30, 2019	$ 2,205,000,000.0	1,433,300,000	(26,900,000)	798,600,000	0
Consolidated Statement of Shareholders' Equity [Roll Forward]
Dividends Per Share of Common Stock	$ 1.175
Balance, Beginning Balance at Mar. 31, 2019		1,431,100,000	(27,200,000)	794,800,000	0
Consolidated Statement of Shareholders' Equity [Roll Forward]
Common Stock Issued		2,200,000
Unrealized Gain (Loss) on Debt Securities	$ 100,000		100,000
Defined Benefit Pension and Other Postretirement Plans	200,000		200,000
Net Income (Loss) Attributable to ALLETE	34,200,000			34,200,000
Common Stock Dividends				(30,400,000)
Proceeds from Noncontrolling Interests					0
Net Loss Attributable to Non-Controlling Interest	0				0
Balance, End of Period at Jun. 30, 2019	$ 2,205,000,000.0	1,433,300,000	(26,900,000)	798,600,000	0
Consolidated Statement of Shareholders' Equity [Roll Forward]
Dividends Per Share of Common Stock	$ 0.5875
Balance, Beginning Balance at Dec. 31, 2019	$ 2,335,600,000	1,436,700,000	(23,600,000)	818,800,000	103,700,000
Consolidated Statement of Shareholders' Equity [Roll Forward]
Common Stock Issued		11,000,000.0
Unrealized Gain (Loss) on Debt Securities	0		0
Defined Benefit Pension and Other Postretirement Plans	300,000		300,000
Net Income (Loss) Attributable to ALLETE	86,400,000			86,400,000
Common Stock Dividends	63,900,000			(63,900,000)
Proceeds from Noncontrolling Interests	67,800,000				67,800,000
Net Loss Attributable to Non-Controlling Interest	(5,000,000.0)				(5,000,000.0)
Balance, End of Period at Jun. 30, 2020	$ 2,432,200,000	1,447,700,000	(23,300,000)	841,300,000	166,500,000
Consolidated Statement of Shareholders' Equity [Roll Forward]
Dividends Per Share of Common Stock	$ 1.235
Balance, Beginning Balance at Mar. 31, 2020		1,441,700,000	(23,800,000)	853,200,000	101,900,000
Consolidated Statement of Shareholders' Equity [Roll Forward]
Common Stock Issued		6,000,000.0
Unrealized Gain (Loss) on Debt Securities	$ 400,000		400,000
Defined Benefit Pension and Other Postretirement Plans	100,000		100,000
Net Income (Loss) Attributable to ALLETE	20,100,000			20,100,000
Common Stock Dividends				(32,000,000.0)
Proceeds from Noncontrolling Interests					67,800,000
Net Loss Attributable to Non-Controlling Interest	(3,200,000)				(3,200,000)
Balance, End of Period at Jun. 30, 2020	$ 2,432,200,000	$ 1,447,700,000	$ (23,300,000)	$ 841,300,000	$ 166,500,000
Consolidated Statement of Shareholders' Equity [Roll Forward]
Dividends Per Share of Common Stock	$ 0.6175

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Operations and Significant Accounting Policies - Supplemental Statement of Cash Flows Information - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Supplemental Cash Flow Information [Abstract]
Cash Paid for Interest – Net of Amounts Capitalized	$ 30.9	$ 33.8
Recognition of Right-of-use Assets and Lease Liabilities	0.0	31.2
Noncash Investing and Financing Activities [Abstract]
Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment	(67.5)	21.1
Capitalized Asset Retirement Costs	2.1	1.4
AFUDC–Equity	$ 1.4	$ 1.3

XML

Operations and Significant Accounting Policies

6 Months Ended

Jun. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Operations and Significant Accounting Policies [Text Block]

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, 2020, 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 ALLETE Clean Energy PSAs and construction projects. In December 31, 2018 balance presented, the amount also includes deposits from a SWL&P customer in aid of future capital expenditures. 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, 2020	December 31, 2019	June 30, 2019	December 31, 2018
Millions
Cash and Cash Equivalents	$25.7	$69.3	$203.1	$69.1
Restricted Cash included in Prepayments and Other	7.3	2.8	0.9	1.3
Restricted Cash included in Other Non-Current Assets	4.4	20.4	2.6	8.6
Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows	$37.4	$92.5	$206.6	$79.0

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, 2020	December 31, 2019
Millions
Fuel (a)	$33.5	$25.9
Materials and Supplies	48.5	46.9
Total Inventories – Net	$82.0	$72.8

(a) Fuel consists primarily of coal inventory at Minnesota Power.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Other Non-Current Assets	June 30, 2020	December 31, 2019
Millions
Contract Assets (a)	$26.7	$28.0
Operating Lease Right-of-use Assets	25.4	28.6
ALLETE Properties	21.5	21.9
Restricted Cash	4.4	20.4
Other Postretirement Benefit Plans	38.4	37.5
Other	84.7	81.8
Total Other Non-Current Assets	$201.1	$218.2

(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, 2020	December 31, 2019
Millions
PSAs	$12.4	$12.3
Provision for Interim Rate Refund (a)	11.7	—
Operating Lease Liabilities	6.6	6.9
Other	34.7	41.2
Total Other Current Liabilities	$65.4	$60.4

(a)Provision for Interim Rate Refund represents reserves for interim rates resulting from the MPUC’s approval of Minnesota Power’s petition and proposal to resolve and withdraw its rate case. (See Note 2. Regulatory Matters.)

Other Non-Current Liabilities	June 30, 2020	December 31, 2019
Millions
Asset Retirement Obligation	$164.8	$160.3
PSAs	58.3	64.6
Operating Lease Liabilities	18.8	21.8
Other	46.2	46.3
Total Other Non-Current Liabilities	$288.1	$293.0

Other Income
Six Months Ended June 30,	2020	2019
Millions
Pension and Other Postretirement Benefit Plan Non-Service Credits (a)	$4.8	$3.6
Interest and Investment Income (Loss)	(0.5)	2.5
AFUDC - Equity	1.4	1.3
Gain on Land Sales	0.1	2.0
Other	0.4	2.2
Total Other Income	$6.2	$11.6

(a)These are components of net periodic pension and other postretirement benefit cost other than service cost. (See Note 9. Pension and Other Postretirement Benefit Plans.)

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Supplemental Statement of Cash Flows Information.

Six Months Ended June 30,	2020	2019
Millions
Cash Paid for Interest – Net of Amounts Capitalized	$30.9	$33.8
Recognition of Right-of-use Assets and Lease Liabilities	—	$31.2
Noncash Investing and Financing Activities
Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment	$(67.5)	$21.1
Capitalized Asset Retirement Costs	$2.1	$1.4
AFUDC–Equity	$1.4	$1.3

Sale of U.S. Water Services. In February 2019, the Company entered into a stock purchase agreement providing for the sale of U.S. Water Services to a subsidiary of Kurita Water Industries Ltd. In March 2019, ALLETE completed the sale and received approximately $270 million in cash, net of transaction costs and cash retained. The gain on sale of U.S. Water Services in 2019 was $13.2 million after-tax.

ALLETE Clean Energy Asset Acquisition. On March 10, 2020, ALLETE Clean Energy acquired the rights to the approximately 300 MW Caddo wind project in Oklahoma from Apex Clean Energy for approximately $8 million with additional payments required to be made at defined milestones. The full development of this wind project will involve the sale of energy to corporate customers under long-term power sales agreements.

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 as of and during the quarter and six months ended June 30, 2020, related to the tax equity financing structure for ALLETE Clean Energy’s 106 MW Glen Ullin and 80 MW South Peak wind energy facilities.

On April 16, 2020, ALLETE Clean Energy commenced operations of South Peak, an 80 MW wind energy facility in Montana, and on April 29, 2020, received $67.8 million in cash, net of issuance costs, from a third-party investor as part of a tax equity financing for this 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.

New Accounting Pronouncements.

Credit Losses. In 2016, the FASB issued an accounting standard update that requires entities to recognize an allowance for expected credit losses for financial instruments within its scope. Examples of financial instruments within the scope include trade receivables, certain financial guarantees, and held-to-maturity debt securities. The allowance for expected credit losses should be based on historical information, current conditions and reasonable and supportable forecasts. The new standard also revises the other-than-temporary impairment model for available-for-sale debt securities. The new guidance became effective January 1, 2020, and was adopted by the Company in the first quarter of 2020. Adoption of this standard did not have a material impact on our Consolidated Financial Statements.

XML

Regulatory Matters

6 Months Ended

Jun. 30, 2020

Regulated Operations [Abstract]

Regulatory Matters [Text Block]

REGULATORY MATTERS

Regulatory matters are summarized in Note 4. Regulatory Matters to the Consolidated Financial Statements in our 2019 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 $14.9 million for the six months ended June 30, 2020 ($17.4 million for six months ended June 30, 2019).

NOTE 2. REGULATORY MATTERS (Continued)

Electric Rates (Continued)

2020 Minnesota General Rate Case. In November 2019, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 10.6 percent for retail customers. The rate filing sought a return on equity of 10.05 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would have generated approximately $66 million in additional revenue. In orders dated December 23, 2019, the MPUC accepted the filing as complete and authorized an annual interim rate increase of $36.1 million that began January 1, 2020.

On April 23, 2020, Minnesota Power filed a request with the MPUC that proposed a resolution of Minnesota Power’s 2020 general rate case. Key components of our proposal included removing the power marketing margin credit in base rates and reflecting actual power marketing margins in the fuel adjustment clause effective May 1, 2020; refunding to customers interim rates collected through April 2020; increasing customer rates 4.1 percent compared to the 5.8 percent increase reflected in interim rates; and a provision that Minnesota Power would not file another rate case until at least November 1, 2021, unless certain events occur. In an order dated June 30, 2020, the MPUC approved Minnesota Power’s petition and proposal to resolve and withdraw the general rate case. Effective May 1, 2020, customer rates were set at an increase of 4.1 percent with the removal of the power marketing margin credit from base rates. Actual power marketing margins will be reflected in the fuel adjustment clause on an ongoing basis. As of June 30, 2020, reserves for interim rates of $11.7 million were recorded, which are expected to be refunded to customers in the third quarter of 2020.

Transmission Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place for certain transmission investments and expenditures. In a 2016 order, the MPUC approved Minnesota Power’s updated customer billing rates allowing Minnesota Power to charge retail customers on a current basis for the costs of constructing certain transmission facilities plus a return on the capital invested. On July 9, 2019, Minnesota Power filed a petition seeking MPUC approval to update the customer billing factor to include investments made for the GNTL, which was approved at a hearing on May 14, 2020. (See Note 6. Commitments, Guarantees and Contingencies.)

Renewable Cost Recovery Rider. Minnesota Power has an approved cost recovery rider for certain renewable investments and expenditures. The cost recovery rider allows Minnesota Power to charge retail customers on a current basis for the costs of certain renewable investments plus a return on the capital invested. Current customer billing rates for the renewable cost recovery rider were approved by the MPUC in a November 2018 order. On August 15, 2019, Minnesota Power filed a petition seeking MPUC approval to update the customer billing factor.

On June 30, 2020, Minnesota Power filed a petition seeking MPUC approval of a customer billing rate for solar costs related to investments and expenditures for meeting the state of Minnesota’s solar energy standard.

Fuel Adjustment Clause Reform. In a 2017 order, the MPUC adopted a program to implement certain procedural reforms to Minnesota utilities’ automatic fuel adjustment clause (FAC) for fuel and purchased power. With this order, the method of accounting for all Minnesota electric utilities changed to a monthly budgeted, forward-looking FAC with annual prudence review and true-up to actual allowed costs. On May 1, 2019, Minnesota Power filed its fuel adjustment forecast for 2020, which was accepted by the MPUC in an order dated November 14, 2019, for purposes of setting fuel adjustment clause rates for 2020, subject to a true-up filing in 2021. On May 1, 2020, Minnesota Power filed its fuel adjustment forecast for 2021, subject to MPUC approval.

COVID-19 Related Costs. In an order dated March 24, 2020, the PSCW authorized public utilities, which includes SWL&P, to defer expenditures incurred by the utility resulting from its compliance with state government or regulator orders, and as otherwise required to ensure the provision of safe, reliable and affordable access to utility services during Wisconsin’s declared public health emergency for COVID-19. On April 20, 2020, Minnesota Power along with other regulated electric and natural gas service providers in Minnesota filed a joint petition to request MPUC authorization to track incremental costs and expenses incurred as a result of the COVID-19 pandemic, and to defer and record such costs as a regulatory asset, subject to recovery in a future proceeding. In an order dated May 22, 2020, the MPUC approved the joint petition requiring the joint petitioners to track cost and revenue impacts resulting from the COVID-19 pandemic with review for recovery in a future rate proceeding.

NOTE 2. REGULATORY MATTERS (Continued)

Integrated Resource Plan. In a 2016 order, the MPUC approved Minnesota Power’s 2015 IRP with modifications. The order accepted Minnesota Power’s plans for the economic idling of Taconite Harbor Units 1 and 2 and the ceasing of coal-fired operations at Taconite Harbor in 2020, directed Minnesota Power to retire Boswell Units 1 and 2 no later than 2022, required an analysis of generation and demand response alternatives to be filed with a natural gas resource proposal, and required Minnesota Power to conduct requests for proposal for additional wind, solar and demand response resource additions. Minnesota Power retired Boswell Units 1 and 2 in the fourth quarter of 2018. The MPUC also has required a baseload retirement evaluation in Minnesota Power’s next IRP filing analyzing its existing fleet, including potential early retirement scenarios of Boswell Units 3 and 4, as well as a securitization plan. Minnesota Power’s next IRP filing was due October 1, 2020; however, on May 29, 2020, Minnesota Power filed a request to extend the deadline for submitting its next IRP filing citing the COVID-19 pandemic. On July 30, 2020, the MPUC granted an extension of the deadline for submission until February 1, 2021, with interim reports due in the fourth quarter of 2020.

Nemadji Trail Energy Center. In 2017, Minnesota Power submitted a resource package to the MPUC which included requesting approval of a 250 MW natural gas capacity dedication agreement. The natural gas capacity dedication agreement was subject to MPUC approval of the construction of NTEC, a 525 MW to 550 MW combined-cycle natural gas-fired generating facility which will be jointly owned by Dairyland Power Cooperative and a subsidiary of ALLETE. Minnesota Power would purchase approximately 50 percent of the facility's output starting in 2025. In an order dated January 24, 2019, the MPUC approved Minnesota Power’s request for approval of the NTEC natural gas capacity dedication agreement. On December 23, 2019, the Minnesota Court of Appeals reversed and remanded the MPUC’s decision to approve certain affiliated-interest agreements. The MPUC was ordered to determine whether NTEC may have the potential for significant environmental effects and, if so, to prepare an environmental assessment worksheet before reassessing the agreements. On January 22, 2020, Minnesota Power filed a petition for further review with the Minnesota Supreme Court requesting that it review and overturn the Minnesota Court of Appeals decision, which petition was accepted for review by the Minnesota Supreme Court on March 18, 2020. On January 8, 2019, an application for a certificate of public convenience and necessity for NTEC was submitted to the PSCW, which was approved by the PSCW at a hearing on January 16, 2020. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $700 million, of which ALLETE’s portion is expected to be approximately $350 million. ALLETE’s portion of NTEC project costs incurred through June 30, 2020, is approximately $14 million.

Conservation Improvement Program. On July 1, 2020, Minnesota Power submitted its CIP triennial filing for 2021 through 2023 to the MPUC, which outlines Minnesota Power’s CIP spending and energy-saving goals for those years. Minnesota Power’s CIP investment goals are $10.5 million for 2021, $10.7 million for 2022 and $10.9 million for 2023, subject to MPUC approval.

MISO Return on Equity Complaint. MISO transmission owners, including ALLETE and ATC, have an authorized return on equity of 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization, based on a May 21, 2020, FERC order that granted rehearing of a November 2019 FERC order, which had reduced the base return on equity for regional transmission organizations to 9.88 percent, or 10.38 percent including an incentive adder.

Minnesota Solar Energy Standard. On May 20, 2020, the MPUC issued a notice requesting all regulated gas and electric utilities provide a list of all ongoing, planned, or possible investments that support Minnesota’s energy policy objectives and aid economic recovery in Minnesota, among other items. On June 17, 2020, Minnesota Power filed a response which included outlining a proposal to accelerate its plans for solar energy with an estimated $40 million investment in approximately 20 MW of solar energy projects in Minnesota.

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.

NOTE 2. REGULATORY MATTERS (Continued)

Regulatory Assets and Liabilities (Continued)

Regulatory Assets and Liabilities	June 30, 2020	December 31, 2019
Millions
Non-Current Regulatory Assets
Defined Benefit Pension and Other Postretirement Benefit Plans	$208.0	$212.9
Income Taxes	122.1	123.4
Cost Recovery Riders	39.3	24.7
Asset Retirement Obligations	31.7	32.0
Manufactured Gas Plant	8.3	8.2
Boswell Units 1 and 2 Net Plant and Equipment	7.8	10.7
PPACA Income Tax Deferral	4.7	4.8
Other	2.8	3.8
Total Non-Current Regulatory Assets	$424.7	$420.5
Current Regulatory Liabilities (a)
Provision for Interim Rate Refund (b)	$11.7	—
Transmission Formula Rates Refund	0.8	$1.7
Other	1.7	0.2
Total Current Regulatory Liabilities	14.2	1.9
Non-Current Regulatory Liabilities
Income Taxes	395.5	407.2
Wholesale and Retail Contra AFUDC	87.4	79.3
Plant Removal Obligations	39.3	35.5
Defined Benefit Pension and Other Postretirement Benefit Plans	14.1	17.0
North Dakota Investment Tax Credits	12.2	12.3
Fuel Adjustment Clause (c)	12.2	—
Conservation Improvement Program	5.4	5.4
Other	3.5	3.6
Total Non-Current Regulatory Liabilities	569.6	560.3
Total Regulatory Liabilities	$583.8	$562.2

(a)Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.

(b)Provision for Interim Rate Refund represents reserves for interim rates resulting from the MPUC’s approval of Minnesota Power’s petition and proposal to resolve and withdraw its rate case. This amount is expected to be refunded to Minnesota Power regulated retail customers in the third quarter of 2020. (See 2020 Minnesota General Rate Case.)

(c)Fuel adjustment clause regulatory liability represents the amount expected to be refunded to customers for the over-collection of fuel adjustment clause recoveries. (See Fuel Adjustment Clause Reform.)

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Equity Investments

6 Months Ended

Jun. 30, 2020

Equity Method Investments and Joint Ventures [Abstract]

Equity Investments [Text Block]

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. In the six months ended June 30, 2020, we invested $1.1 million in ATC, and on July 31, 2020, we invested an additional $0.8 million. We expect to make additional investments of $0.8 million in 2020.

ALLETE’s Investment in ATC
Millions
Equity Investment Balance as of December 31, 2019	$141.6
Cash Investments	1.1
Equity in ATC Earnings (a)	11.6
Distributed ATC Earnings	(9.4)
Amortization of the Remeasurement of Deferred Income Taxes	0.7
Equity Investment Balance as of June 30, 2020	$145.6

(a)Equity in ATC Earnings includes $1.2 million of additional earnings resulting from the FERC’s May 21, 2020, order increasing ATC’s authorized return on equity to 10.52 percent including an incentive adder for participation in a regional transmission organization.

NOTE 3. EQUITY INVESTMENTS (Continued)

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 May 21, 2020, FERC order that granted rehearing of a November 2019 FERC order. (See Note 2. Regulatory Matters.)

Investment in Nobles 2. Our wholly-owned subsidiary, ALLETE South Wind, owns 49 percent of Nobles 2, the entity that will own and operate 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. As of June 30, 2020, our equity investment in Nobles 2 was $121.5 million ($56.0 million at December 31, 2019). In the six months ended June 30, 2020, we invested $65.5 million in Nobles 2, and in July 2020 we invested an additional $15.0 million. We expect to make approximately $35 million in additional investments in 2020.

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Fair Value

6 Months Ended

Jun. 30, 2020

Fair Value Disclosures [Abstract]

Fair Value [Text Block]

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 7. Fair Value to the Consolidated Financial Statements in our 2019 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, 2020, and December 31, 2019. 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.

NOTE 4. FAIR VALUE (Continued)

	Fair Value as of June 30, 2020
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities	$10.1	—	—	$10.1
Available-for-sale – Corporate and Governmental Debt Securities (b)	—	$9.8	—	9.8
Cash Equivalents	0.8	—	—	0.8
Total Fair Value of Assets	$10.9	$9.8	—	$20.7
Liabilities
Deferred Compensation (c)	—	$20.0	—	$20.0
Total Fair Value of Liabilities	—	$20.0	—	$20.0
Total Net Fair Value of Assets (Liabilities)	$10.9	$(10.2)	—	$0.7
	Fair Value as of December 31, 2019
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities	$11.1	—	—	$11.1
Available-for-sale – Corporate and Governmental Debt Securities	—	$9.7	—	9.7
Cash Equivalents	0.9	—	—	0.9
Total Fair Value of Assets	$12.0	$9.7	—	$21.7
Liabilities
Deferred Compensation (c)	—	$21.2	—	$21.2
Total Fair Value of Liabilities	—	$21.2	—	$21.2
Total Net Fair Value of Assets (Liabilities)	$12.0	$(11.5)	—	$0.5

(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.

(b)As of June 30, 2020, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $3.8 million, in one year to less than three years was $5.0 million, in three years to less than five years was $1.0 million and in five or more years was zero.

(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
June 30, 2020	$1,899.0	$2,163.4
December 31, 2019	$1,622.6	$1,791.8

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, 2020, and the year ended December 31, 2019, there were no indicators of impairment for these non-financial assets.

We continue to monitor changes in the broader energy markets that could indicate impairment at an ALLETE Clean Energy wind energy facility which currently has undiscounted future cash flows that are marginally in excess of the asset carrying value of approximately $11 million. A continued decline in energy prices would likely result in a future impairment.

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Short-Term and Long-Term Debt

6 Months Ended

Jun. 30, 2020

Debt Disclosure [Abstract]

Short-Term and Long-Term Debt [Text Block]

SHORT-TERM AND LONG-TERM DEBT

The following tables present the Company’s short-term and long-term debt as of June 30, 2020, and December 31, 2019:

June 30, 2020	Principal	Unamortized Debt Issuance Costs	Total
Millions
Short-Term Debt	$510.0	$(0.3)	$509.7
Long-Term Debt	1,389.0	(8.0)	1,381.0
Total Debt	$1,899.0	$(8.3)	$1,890.7

December 31, 2019	Principal	Unamortized Debt Issuance Costs	Total
Millions
Short-Term Debt	$213.3	$(0.4)	$212.9
Long-Term Debt	1,409.3	(8.4)	1,400.9
Total Debt	$1,622.6	$(8.8)	$1,613.8

We had $23.5 million outstanding in standby letters of credit and no outstanding draws under our lines of credit as of June 30, 2020 ($62.0 million in standby letters of credit and no outstanding draws as of December 31, 2019).

On January 10, 2020, ALLETE entered into a $200 million unsecured term loan agreement (Term Loan) of which we have borrowed the full amount as of June 30, 2020. The Term Loan is due on February 10, 2021, and may be repaid at any time. Interest is payable monthly at a rate per annum equal to LIBOR plus 0.55 percent. Proceeds from the Term Loan were used for construction-related expenditures.

On March 26, 2020, ALLETE agreed to sell first mortgage bonds (Bonds) to certain institutional buyers in the private placement market, which were issued on August 3, 2020, in two series as follows:

Maturity Date	Principal Amount	Interest Rate
August 1, 2030	$46 Million	2.50%
August 1, 2050	$94 Million	3.30%

ALLETE has the option to prepay all or a portion of the Bonds at its discretion, subject to a make-whole provision. The Bonds are subject to additional terms and conditions which are customary for these types of transactions. ALLETE plans to use the proceeds from the sale of the Bonds to fund utility capital investment and for general corporate purposes. The Bonds were sold in reliance on an exemption from registration under Section 4(a)(2) of the Securities Act of 1933, as amended, to institutional accredited investors.

On April 8, 2020, ALLETE entered into a $115 million unsecured term loan agreement (Term Loan) and borrowed $95 million upon execution. The additional draw of $20 million provided for under the Term Loan was made in July 2020. The Term Loan is due on April 7, 2021, and may be repaid at any time. Interest is payable monthly at a rate per annum equal to LIBOR plus 1.7 percent with a LIBOR floor of 0.75 percent. Proceeds from the Term Loan will be 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, 2020, our ratio was approximately 0.44 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, 2020, ALLETE was in compliance with its financial covenants.

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Commitments, Guarantees and Contingencies

6 Months Ended

Jun. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments, Guarantees and Contingencies [Text Block]

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 9. Commitments, Guarantees and Contingencies to the Consolidated Financial Statements in our 2019 Form 10-K, with additional disclosure provided in the following paragraphs.

Square Butte PPA. As of June 30, 2020, Square Butte had total debt outstanding of $272.9 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, 2020, was $40.8 million ($41.1 million for the same period in 2019). 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 $3.7 million ($4.2 million for the same period in 2019). 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, it sold to Minnkota Power approximately 28 percent in 2020 and in 2019.

Minnesota Power Short-term PSAs. Minnesota Power has entered into various short-term PSAs to sell 300 MW of energy in 2020 and 2021. These PSAs were entered into to proactively mitigate the uncertainty of customers’ energy needs and potential load loss due to the COVID-19 pandemic. Additional transactions, purchases or sales, could be entered into as the extent and duration of the COVID-19 pandemic becomes known.

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 2021. Minnesota Power also has coal transportation agreements in place for the delivery of a significant portion of its coal requirements through December 2021. 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.

Transmission. We continue to make investments in transmission opportunities that strengthen or enhance the transmission grid or take advantage of our geographical location between sources of renewable energy and end users. These include the GNTL, investments to enhance our own transmission facilities, investments in other transmission assets (individually or in combination with others) and our investment in ATC.

Great Northern Transmission Line. As a condition of the 250-MW long-term PPA entered into with Manitoba Hydro, construction of additional transmission capacity was required. As a result, Minnesota Power constructed the GNTL, an approximately 220-mile 500-kV transmission line between Manitoba and Minnesota’s Iron Range that was proposed by Minnesota Power and Manitoba Hydro in order to strengthen the electric grid, enhance regional reliability and promote a greater exchange of sustainable energy. On June 1, 2020, Minnesota Power placed the GNTL into service with project costs of $307.1 million incurred by Minnesota Power through June 30, 2020. Total project costs, including those costs contributed by a subsidiary of Manitoba Hydro, incurred through June 30, 2020 totaled $657.0 million. Also on June 1, 2020, Manitoba Hydro placed the MMTP into service.

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.

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 SO₂ allowances issued and pending issuance, we currently expect generation levels and emission rates will result in continued compliance with the CSAPR. The ongoing CSAPR “good neighbor” provision and interstate transport litigation is also not currently projected to affect Minnesota Power’s CSAPR compliance. The State of Minnesota has not been identified by the downwind litigant states as a culpable upwind source, and previous EPA air quality modeling has demonstrated that Minnesota is not a significant contributor to downwind air quality attainment challenges. Minnesota Power also does not currently anticipate being affected by the EPA’s expected upcoming rulemakings to address the remand of certain CSAPR rules. Minnesota Power will continue to monitor ongoing CSAPR litigation and associated rulemakings.

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 expected to be material.

NOTE 6. 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; increases 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. On June 19, 2019, the EPA finalized several separate rulemakings regarding regulating carbon emissions from electric utility generating units.

The EPA repealed the Clean Power Plan (CPP), following a determination by the EPA that the CPP exceeded the EPA’s statutory authority under the Clean Air Act (CAA). The primary reason for the repeal was the CPP’s attempt to regulate electric generating unit’s carbon emissions through measures outside of the affected unit’s direct control. The CPP was first announced as a proposed rule under Section 111(d) of the Clean Air Act for existing power plants entitled “Carbon Pollution Emission Guidelines for Existing Stationary Sources: Electric Generating Units”.

With the repeal of the CPP, the Affordable Clean Energy Rule was finalized. The rule establishes emissions guidelines for states to use when developing plans to limit carbon dioxide at coal-fired power plants. The rule identifies heat rate improvements made at individual units as the best system of emission reduction. Affected facilities for Minnesota Power include Boswell Units 3 and 4. Based on our initial review of the rule, many of the candidate heat rate improvements are already installed on Boswell Units 3 and 4.

Additionally, the EPA finalized new regulations for the state implementation of the Affordable Clean Energy Rule and any future emission guidelines issued under CAA Section 111(d). States will have three years to submit State Implementation Plans (SIPs), and the EPA has 12 months to review and approve those plans. Since the Affordable Clean Energy Rule allows states considerable flexibility in how to best implement its requirements, Minnesota Power plans to work closely with the MPCA and the Minnesota Department of Commerce, who are currently co-reviewing the rule as the state develops its SIP. If a state does not submit a SIP or submits a SIP that is unacceptable to the EPA, the EPA will develop a Federal Implementation Plan. The MPCA currently plans to develop a SIP for the Affordable Clean Energy Rule and Minnesota Power is working with the MPCA to provide requested information for the SIP.

Minnesota had already initiated several measures consistent with those called for under the now repealed CPP and finalized 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 the Affordable Clean Energy Rule and the resulting SIP; however, the costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.

NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

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 reconsiders the bottom ash transport water 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 November 22, 2019, the EPA published a draft rulemaking that proposes to allow re-use of bottom ash transport water in FGD scrubber systems with minor discharges related to maintaining system water balance. The proposed rulemaking would also allow future discharge of FGD wastewater discharge provided it meets new BACT standards. A final rulemaking is anticipated in late 2020.

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 if additional water treatment measures are implemented. Under the current ELG rule, bottom ash transport water discharge to surface waters must cease no later than December 31, 2023. Bottom ash contact water will either need to be re-used in a closed-loop process, routed to a FGD scrubber, or the bottom ash handling system will need to be converted to a dry process. The ELG rule provision regarding these two waste-streams are being reconsidered and may change prior to November 1, 2020. Efforts have been underway at Boswell to reduce the amount of water discharged and evaluate potential re-use options in its plant processes. The EPA’s additional reconsideration of legacy wastewater discharge requirements have the potential to reduce timelines for dewatering Boswell’s existing bottom ash pond. The timing of a draft rule addressing legacy wastewater and leachate is currently unknown.

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 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.

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 stores or disposes coal ash at four of its electric generating facilities by the following methods: 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 occur 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.

NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

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 and in March 2018, published the first phase of the proposed rule revisions in the Federal Register. In July 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 August 2018, a U.S. District Court for the District of Columbia decision vacated specific provisions of the CCR rule. The court decision changed the status of three existing impoundments at Boswell that must now be considered unlined. The EPA proposed additional rule revisions in August and December 2019 to address outstanding issues from litigation and closure timelines for unlined impoundments, respectively. These rules are anticipated to be finalized in 2020 and could impact the timing of closure activities for Boswell’s three impoundments. Additionally, the EPA recently released a proposed Part B rulemaking that addresses options for beneficial reuse of CCR materials, alternative liner demonstrations, and other CCR regulatory revisions. 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.

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. SWL&P has been working with the Wisconsin Department of Natural Resources (WDNR) in determining the extent of contamination at the site and surrounding properties. In December 2017, the WDNR authorized SWL&P to transition from site investigation into the remedial design process. As of June 30, 2020, we have recorded a liability of approximately $7 million for remediation costs at this site (approximately $7 million as of December 31, 2019). 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 2023.

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Earnings Per Share and Common Stock

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

Earnings Per Share and Common Stock [Text Block]

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.

		2020			2019
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	$20.1		$20.1	$34.2		$34.2
Average Common Shares	51.8	0.1	51.9	51.6	0.1	51.7
Earnings Per Share	$0.39		$0.39	$0.66		$0.66
Six Months Ended June 30,
Net Income Attributable to ALLETE	$86.4		$86.4	$104.7		$104.7
Average Common Shares	51.8	—	51.8	51.6	0.1	51.7
Earnings Per Share	$1.67		$1.67	$2.03		$2.02

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Income Tax Expense

6 Months Ended

Jun. 30, 2020

Income Tax Disclosure [Abstract]

Income Tax Expense [Text Block]

INCOME TAX EXPENSE

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Millions
Current Income Tax Expense (a)
Federal	—	—	—	—
State	—	$(0.1)	—	$0.2
Total Current Income Tax Expense (Benefit)	—	$(0.1)	—	$0.2
Deferred Income Tax Expense (Benefit)
Federal (b)	$(8.6)	$(7.1)	$(26.2)	$(16.8)
State (c)	0.2	2.5	4.2	15.0
Investment Tax Credit Amortization	(0.1)	(0.1)	(0.3)	(0.3)
Total Deferred Income Tax Benefit	$(8.5)	$(4.7)	$(22.3)	$(2.1)
Total Income Tax Benefit	$(8.5)	$(4.8)	$(22.3)	$(1.9)

(a)For each of the six months ended June 30, 2020 and 2019, 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 each of the six months ended June 30, 2020 and 2019, the federal income tax benefit is primarily due to production tax credits.

(c)For the six months ended June 30, 2019, the state income tax expense is primarily related to the sale of U.S. Water Services.

NOTE 8. 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	2020		2019		2020		2019
Millions
Income Before Income Taxes	$8.4		$29.4		$59.1		$102.8
Statutory Federal Income Tax Rate	21	%	21	%	21	%	21	%
Income Taxes Computed at Statutory Federal Rate	$1.7		$6.2		$12.4		$21.6
Increase (Decrease) in Income Tax Due to:
State Income Taxes – Net of Federal Income Tax Benefit	0.1		1.9		3.3		12.0
Production Tax Credits	(9.6)		(9.8)		(33.4)		(26.1)
Regulatory Differences – Excess Deferred Tax	(0.9)		(1.6)		(5.3)		(4.8)
U.S. Water Services Sale of Stock Basis Difference	—		(0.7)		—		1.7
Share-Based Compensation	—		—		(0.1)		(0.9)
Other	0.2		(0.8)		0.8		(5.4)
Total Income Tax Benefit	$(8.5)		$(4.8)		$(22.3)		$(1.9)

For the six months ended June 30, 2020, the effective tax rate was a benefit of 37.8 percent (benefit of 1.8 percent for the six months ended June 30, 2019). The effective tax rate for 2020 was primarily impacted by production tax credits. The effective tax rate for 2019 was primarily impacted by production tax credits and the gain on sale of U.S. Water Services.

Uncertain Tax Positions. As of June 30, 2020, we had gross unrecognized tax benefits of $1.4 million ($1.4 million as of December 31, 2019). 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 2016, or state examination for years before 2015.

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Pension and Other Postretirement Benefit Plans

6 Months Ended

Jun. 30, 2020

Retirement Benefits [Abstract]

Pension and Other Postretirement Benefit Plans [Text Block]

PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS

	Pension		Other Postretirement
Components of Net Periodic Benefit Cost (Credit)	2020	2019	2020	2019
Millions
Quarter Ended June 30,
Service Cost	$2.7	$2.4	$0.9	$1.0
Non-Service Cost Components (a)
Interest Cost	7.0	8.0	1.2	1.9
Expected Return on Plan Assets	(10.7)	(11.1)	(2.4)	(2.7)
Amortization of Prior Service Credits	(0.1)	(0.1)	(2.0)	(0.4)
Amortization of Net Loss	3.2	1.9	0.2	0.1
Net Periodic Benefit Cost (Credit)	$2.1	$1.1	$(2.1)	$(0.1)
Six Months Ended June 30,
Service Cost	$5.3	$4.7	$1.7	$2.0
Non-Service Cost Components (a)
Interest Cost	14.0	16.0	2.5	3.8
Expected Return on Plan Assets	(21.4)	(22.1)	(4.9)	(5.3)
Amortization of Prior Service Credits	(0.1)	(0.1)	(4.0)	(0.8)
Amortization of Net Loss	6.4	3.7	0.5	0.2
Net Periodic Benefit Cost (Credit)	$4.2	$2.2	$(4.2)	$(0.1)

(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, 2020, we contributed $10.7 million in cash to the defined benefit pension plans ($10.4 million for the six months ended June 30, 2019); we do not expect to make additional contributions to our defined benefit pension plans in 2020. For the six months ended June 30, 2020, and 2019, 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 2020.

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Business Segments

6 Months Ended

Jun. 30, 2020

Segment Reporting [Abstract]

Business Segments [Text Block]

BUSINESS SEGMENTS

We present three reportable segments: Regulated Operations, ALLETE Clean Energy and U.S. Water Services. 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. U.S. Water Services was our integrated water management company, which is reflected in operating results until it was sold in March 2019. We also present Corporate and Other which includes two operating segments, BNI Energy, our coal mining operations in North Dakota, and ALLETE Properties, our legacy Florida real estate investment, along with our investment in Nobles 2, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, approximately 4,000 acres of land in Minnesota, and earnings on cash and investments.

NOTE 10. BUSINESS SEGMENTS (Continued)

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Millions
Operating Revenue
Regulated Operations
Residential	$27.4	$29.2	$68.3	$74.4
Commercial	28.8	34.9	66.1	73.8
Municipal	9.0	12.2	19.3	27.6
Industrial	88.0	120.3	206.8	241.9
Other Power Suppliers	27.4	35.2	65.7	74.6
Other	20.2	18.0	39.9	39.7
Total Regulated Operations	200.8	249.8	466.1	532.0
ALLETE Clean Energy
Long-term PSA	14.8	12.5	32.1	27.1
Other	2.8	2.9	5.6	5.8
Total ALLETE Clean Energy	17.6	15.4	37.7	32.9
U.S. Water Services (a)
Point-in-Time	—	—	—	19.0
Contract	—	—	—	9.2
Capital Project	—	—	—	5.2
Total U.S. Water Services	—	—	—	33.4
Corporate and Other
Long-term Contract	22.5	21.2	44.9	41.4
Other	2.3	4.0	6.1	7.9
Total Corporate and Other	24.8	25.2	51.0	49.3
Total Operating Revenue	$243.2	$290.4	$554.8	$647.6
Net Income (Loss) Attributable to ALLETE
Regulated Operations	$11.1	$30.3	$68.6	$81.8
ALLETE Clean Energy	4.0	1.9	15.7	7.7
U.S. Water Services (a)	—	—	—	(1.1)
Corporate and Other (a)	5.0	2.0	2.1	16.3
Total Net Income Attributable to ALLETE	$20.1	$34.2	$86.4	$104.7

(a)  In March 2019, ALLETE sold U.S. Water Services. The Company recognized a gain on the sale of $11.1 million after-tax during the six months ended June 30, 2019, which is reflected in Corporate and Other.

	June 30, 2020	December 31, 2019
Millions
Assets
Regulated Operations	$4,139.8	$4,130.8
ALLETE Clean Energy	1,250.2	1,001.5
Corporate and Other	370.4	350.5
Total Assets	$5,760.4	$5,482.8

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Operations and Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Cash and Cash Equivalents, Policy [Policy Text Block]	We consider all investments purchased with original maturities of three months or less to be cash equivalents.
Inventories – Net [Policy Text Block]	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.
New Accounting Standards [Policy Text Block]	New Accounting Pronouncements.Credit Losses. In 2016, the FASB issued an accounting standard update that requires entities to recognize an allowance for expected credit losses for financial instruments within its scope. Examples of financial instruments within the scope include trade receivables, certain financial guarantees, and held-to-maturity debt securities. The allowance for expected credit losses should be based on historical information, current conditions and reasonable and supportable forecasts. The new standard also revises the other-than-temporary impairment model for available-for-sale debt securities. The new guidance became effective January 1, 2020, and was adopted by the Company in the first quarter of 2020. Adoption of this standard did not have a material impact on our Consolidated Financial Statements.
Regulatory Assets and Liabilities [Policy Text Block]	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.
Equity Method Investments [Policy Text Block]	We account for our investment in ATC under the equity method of accounting.We account for our investment in Nobles 2 under the equity method of accounting.
Fair Value Measurement [Policy Text Block]	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. 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.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.
Power Purchase Agreements [Policy Text Block]	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.
Environmental Accruals [Policy Text Block]	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.
Earnings Per Share [Policy Text Block]	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.
Income Tax [Policy Text Block]	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.
Uncertain Tax Positions [Policy Text Block]	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.
Business Segments [Policy Text Block]	We present three reportable segments: Regulated Operations, ALLETE Clean Energy and U.S. Water Services. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.

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Operations and Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Cash, Cash Equivalents and Restricted Cash [Table Text Block]

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, 2020	December 31, 2019	June 30, 2019	December 31, 2018
Millions
Cash and Cash Equivalents	$25.7	$69.3	$203.1	$69.1
Restricted Cash included in Prepayments and Other	7.3	2.8	0.9	1.3
Restricted Cash included in Other Non-Current Assets	4.4	20.4	2.6	8.6
Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows	$37.4	$92.5	$206.6	$79.0

Inventories – Net [Table Text Block]

Inventories – Net	June 30, 2020	December 31, 2019
Millions
Fuel (a)	$33.5	$25.9
Materials and Supplies	48.5	46.9
Total Inventories – Net	$82.0	$72.8

(a) Fuel consists primarily of coal inventory at Minnesota Power.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

Other Non-Current Assets [Table Text Block]

Other Non-Current Assets	June 30, 2020	December 31, 2019
Millions
Contract Assets (a)	$26.7	$28.0
Operating Lease Right-of-use Assets	25.4	28.6
ALLETE Properties	21.5	21.9
Restricted Cash	4.4	20.4
Other Postretirement Benefit Plans	38.4	37.5
Other	84.7	81.8
Total Other Non-Current Assets	$201.1	$218.2

(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 [Table Text Block]

Other Current Liabilities	June 30, 2020	December 31, 2019
Millions
PSAs	$12.4	$12.3
Provision for Interim Rate Refund (a)	11.7	—
Operating Lease Liabilities	6.6	6.9
Other	34.7	41.2
Total Other Current Liabilities	$65.4	$60.4

(a)Provision for Interim Rate Refund represents reserves for interim rates resulting from the MPUC’s approval of Minnesota Power’s petition and proposal to resolve and withdraw its rate case. (See Note 2. Regulatory Matters.)

Other Non-Current Liabilities [Table Text Block]

Other Non-Current Liabilities	June 30, 2020	December 31, 2019
Millions
Asset Retirement Obligation	$164.8	$160.3
PSAs	58.3	64.6
Operating Lease Liabilities	18.8	21.8
Other	46.2	46.3
Total Other Non-Current Liabilities	$288.1	$293.0

Other Income [Table Text Block]

Other Income
Six Months Ended June 30,	2020	2019
Millions
Pension and Other Postretirement Benefit Plan Non-Service Credits (a)	$4.8	$3.6
Interest and Investment Income (Loss)	(0.5)	2.5
AFUDC - Equity	1.4	1.3
Gain on Land Sales	0.1	2.0
Other	0.4	2.2
Total Other Income	$6.2	$11.6

(a)These are components of net periodic pension and other postretirement benefit cost other than service cost. (See Note 9. Pension and Other Postretirement Benefit Plans.)

Supplemental Statement of Cash Flows Information [Table Text Block]

Supplemental Statement of Cash Flows Information.

Six Months Ended June 30,	2020	2019
Millions
Cash Paid for Interest – Net of Amounts Capitalized	$30.9	$33.8
Recognition of Right-of-use Assets and Lease Liabilities	—	$31.2
Noncash Investing and Financing Activities
Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment	$(67.5)	$21.1
Capitalized Asset Retirement Costs	$2.1	$1.4
AFUDC–Equity	$1.4	$1.3

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Regulatory Matters (Tables)

6 Months Ended

Jun. 30, 2020

Regulated Operations [Abstract]

Regulatory Assets and Liabilities [Table Text Block]

Regulatory Assets and Liabilities	June 30, 2020	December 31, 2019
Millions
Non-Current Regulatory Assets
Defined Benefit Pension and Other Postretirement Benefit Plans	$208.0	$212.9
Income Taxes	122.1	123.4
Cost Recovery Riders	39.3	24.7
Asset Retirement Obligations	31.7	32.0
Manufactured Gas Plant	8.3	8.2
Boswell Units 1 and 2 Net Plant and Equipment	7.8	10.7
PPACA Income Tax Deferral	4.7	4.8
Other	2.8	3.8
Total Non-Current Regulatory Assets	$424.7	$420.5
Current Regulatory Liabilities (a)
Provision for Interim Rate Refund (b)	$11.7	—
Transmission Formula Rates Refund	0.8	$1.7
Other	1.7	0.2
Total Current Regulatory Liabilities	14.2	1.9
Non-Current Regulatory Liabilities
Income Taxes	395.5	407.2
Wholesale and Retail Contra AFUDC	87.4	79.3
Plant Removal Obligations	39.3	35.5
Defined Benefit Pension and Other Postretirement Benefit Plans	14.1	17.0
North Dakota Investment Tax Credits	12.2	12.3
Fuel Adjustment Clause (c)	12.2	—
Conservation Improvement Program	5.4	5.4
Other	3.5	3.6
Total Non-Current Regulatory Liabilities	569.6	560.3
Total Regulatory Liabilities	$583.8	$562.2

(a)Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.

(b)Provision for Interim Rate Refund represents reserves for interim rates resulting from the MPUC’s approval of Minnesota Power’s petition and proposal to resolve and withdraw its rate case. This amount is expected to be refunded to Minnesota Power regulated retail customers in the third quarter of 2020. (See 2020 Minnesota General Rate Case.)

(c)Fuel adjustment clause regulatory liability represents the amount expected to be refunded to customers for the over-collection of fuel adjustment clause recoveries. (See Fuel Adjustment Clause Reform.)

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Equity Investments (Tables)

6 Months Ended

Jun. 30, 2020

Equity Method Investments and Joint Ventures [Abstract]

Equity Method Investments

ALLETE’s Investment in ATC
Millions
Equity Investment Balance as of December 31, 2019	$141.6
Cash Investments	1.1
Equity in ATC Earnings (a)	11.6
Distributed ATC Earnings	(9.4)
Amortization of the Remeasurement of Deferred Income Taxes	0.7
Equity Investment Balance as of June 30, 2020	$145.6

(a)Equity in ATC Earnings includes $1.2 million of additional earnings resulting from the FERC’s May 21, 2020, order increasing ATC’s authorized return on equity to 10.52 percent including an incentive adder for participation in a regional transmission organization.

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Fair Value (Tables)

6 Months Ended

Jun. 30, 2020

Fair Value Disclosures [Abstract]

Recurring Fair Value Measures [Table Text Block]

	Fair Value as of June 30, 2020
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities	$10.1	—	—	$10.1
Available-for-sale – Corporate and Governmental Debt Securities (b)	—	$9.8	—	9.8
Cash Equivalents	0.8	—	—	0.8
Total Fair Value of Assets	$10.9	$9.8	—	$20.7
Liabilities
Deferred Compensation (c)	—	$20.0	—	$20.0
Total Fair Value of Liabilities	—	$20.0	—	$20.0
Total Net Fair Value of Assets (Liabilities)	$10.9	$(10.2)	—	$0.7
	Fair Value as of December 31, 2019
Recurring Fair Value Measures	Level 1	Level 2	Level 3	Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities	$11.1	—	—	$11.1
Available-for-sale – Corporate and Governmental Debt Securities	—	$9.7	—	9.7
Cash Equivalents	0.9	—	—	0.9
Total Fair Value of Assets	$12.0	$9.7	—	$21.7
Liabilities
Deferred Compensation (c)	—	$21.2	—	$21.2
Total Fair Value of Liabilities	—	$21.2	—	$21.2
Total Net Fair Value of Assets (Liabilities)	$12.0	$(11.5)	—	$0.5

(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.

(b)As of June 30, 2020, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $3.8 million, in one year to less than three years was $5.0 million, in three years to less than five years was $1.0 million and in five or more years was zero.

(c)Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.

Financial Instruments [Table Text Block]

Financial Instruments	Carrying Amount	Fair Value
Millions
Short-Term and Long-Term Debt
June 30, 2020	$1,899.0	$2,163.4
December 31, 2019	$1,622.6	$1,791.8

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Short-Term and Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2020

Debt Disclosure [Abstract]

Schedule of Short-Term and Long-Term Debt [Table Text Block]

The following tables present the Company’s short-term and long-term debt as of June 30, 2020, and December 31, 2019:

June 30, 2020	Principal	Unamortized Debt Issuance Costs	Total
Millions
Short-Term Debt	$510.0	$(0.3)	$509.7
Long-Term Debt	1,389.0	(8.0)	1,381.0
Total Debt	$1,899.0	$(8.3)	$1,890.7

December 31, 2019	Principal	Unamortized Debt Issuance Costs	Total
Millions
Short-Term Debt	$213.3	$(0.4)	$212.9
Long-Term Debt	1,409.3	(8.4)	1,400.9
Total Debt	$1,622.6	$(8.8)	$1,613.8

Schedule of Long-term Debt Instruments [Table Text Block]

On March 26, 2020, ALLETE agreed to sell first mortgage bonds (Bonds) to certain institutional buyers in the private placement market, which were issued on August 3, 2020, in two series as follows:

Maturity Date	Principal Amount	Interest Rate
August 1, 2030	$46 Million	2.50%
August 1, 2050	$94 Million	3.30%

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Earnings Per Share and Common Stock (Tables)

6 Months Ended

Jun. 30, 2020

Earnings Per Share [Abstract]

Reconciliation of Basic and Diluted Earnings Per Share [Table Text Block]

		2020			2019
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	$20.1		$20.1	$34.2		$34.2
Average Common Shares	51.8	0.1	51.9	51.6	0.1	51.7
Earnings Per Share	$0.39		$0.39	$0.66		$0.66
Six Months Ended June 30,
Net Income Attributable to ALLETE	$86.4		$86.4	$104.7		$104.7
Average Common Shares	51.8	—	51.8	51.6	0.1	51.7
Earnings Per Share	$1.67		$1.67	$2.03		$2.02

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Income Tax Expense (Tables)

6 Months Ended

Jun. 30, 2020

Income Tax Disclosure [Abstract]

Income Tax Expense [Table Text Block]

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Millions
Current Income Tax Expense (a)
Federal	—	—	—	—
State	—	$(0.1)	—	$0.2
Total Current Income Tax Expense (Benefit)	—	$(0.1)	—	$0.2
Deferred Income Tax Expense (Benefit)
Federal (b)	$(8.6)	$(7.1)	$(26.2)	$(16.8)
State (c)	0.2	2.5	4.2	15.0
Investment Tax Credit Amortization	(0.1)	(0.1)	(0.3)	(0.3)
Total Deferred Income Tax Benefit	$(8.5)	$(4.7)	$(22.3)	$(2.1)
Total Income Tax Benefit	$(8.5)	$(4.8)	$(22.3)	$(1.9)

(a)For each of the six months ended June 30, 2020 and 2019, 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 each of the six months ended June 30, 2020 and 2019, the federal income tax benefit is primarily due to production tax credits.

(c)For the six months ended June 30, 2019, the state income tax expense is primarily related to the sale of U.S. Water Services.

Reconciliation of Taxes from Federal Statutory Rate to Total Income Tax Expense [Table Text Block]

	Quarter Ended				Six Months Ended
Reconciliation of Taxes from Federal Statutory	June 30,				June 30,
Rate to Total Income Tax Expense	2020		2019		2020		2019
Millions
Income Before Income Taxes	$8.4		$29.4		$59.1		$102.8
Statutory Federal Income Tax Rate	21	%	21	%	21	%	21	%
Income Taxes Computed at Statutory Federal Rate	$1.7		$6.2		$12.4		$21.6
Increase (Decrease) in Income Tax Due to:
State Income Taxes – Net of Federal Income Tax Benefit	0.1		1.9		3.3		12.0
Production Tax Credits	(9.6)		(9.8)		(33.4)		(26.1)
Regulatory Differences – Excess Deferred Tax	(0.9)		(1.6)		(5.3)		(4.8)
U.S. Water Services Sale of Stock Basis Difference	—		(0.7)		—		1.7
Share-Based Compensation	—		—		(0.1)		(0.9)
Other	0.2		(0.8)		0.8		(5.4)
Total Income Tax Benefit	$(8.5)		$(4.8)		$(22.3)		$(1.9)

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Pension and Other Postretirement Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2020

Retirement Benefits [Abstract]

Components of Net Periodic Benefit Expense (Income) [Table Text Block]

	Pension		Other Postretirement
Components of Net Periodic Benefit Cost (Credit)	2020	2019	2020	2019
Millions
Quarter Ended June 30,
Service Cost	$2.7	$2.4	$0.9	$1.0
Non-Service Cost Components (a)
Interest Cost	7.0	8.0	1.2	1.9
Expected Return on Plan Assets	(10.7)	(11.1)	(2.4)	(2.7)
Amortization of Prior Service Credits	(0.1)	(0.1)	(2.0)	(0.4)
Amortization of Net Loss	3.2	1.9	0.2	0.1
Net Periodic Benefit Cost (Credit)	$2.1	$1.1	$(2.1)	$(0.1)
Six Months Ended June 30,
Service Cost	$5.3	$4.7	$1.7	$2.0
Non-Service Cost Components (a)
Interest Cost	14.0	16.0	2.5	3.8
Expected Return on Plan Assets	(21.4)	(22.1)	(4.9)	(5.3)
Amortization of Prior Service Credits	(0.1)	(0.1)	(4.0)	(0.8)
Amortization of Net Loss	6.4	3.7	0.5	0.2
Net Periodic Benefit Cost (Credit)	$4.2	$2.2	$(4.2)	$(0.1)

(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.

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Business Segments (Tables)

6 Months Ended

Jun. 30, 2020

Segment Reporting [Abstract]

Business Segments [Table Text Block]

	Quarter Ended		Six Months Ended
	June 30,		June 30,
	2020	2019	2020	2019
Millions
Operating Revenue
Regulated Operations
Residential	$27.4	$29.2	$68.3	$74.4
Commercial	28.8	34.9	66.1	73.8
Municipal	9.0	12.2	19.3	27.6
Industrial	88.0	120.3	206.8	241.9
Other Power Suppliers	27.4	35.2	65.7	74.6
Other	20.2	18.0	39.9	39.7
Total Regulated Operations	200.8	249.8	466.1	532.0
ALLETE Clean Energy
Long-term PSA	14.8	12.5	32.1	27.1
Other	2.8	2.9	5.6	5.8
Total ALLETE Clean Energy	17.6	15.4	37.7	32.9
U.S. Water Services (a)
Point-in-Time	—	—	—	19.0
Contract	—	—	—	9.2
Capital Project	—	—	—	5.2
Total U.S. Water Services	—	—	—	33.4
Corporate and Other
Long-term Contract	22.5	21.2	44.9	41.4
Other	2.3	4.0	6.1	7.9
Total Corporate and Other	24.8	25.2	51.0	49.3
Total Operating Revenue	$243.2	$290.4	$554.8	$647.6
Net Income (Loss) Attributable to ALLETE
Regulated Operations	$11.1	$30.3	$68.6	$81.8
ALLETE Clean Energy	4.0	1.9	15.7	7.7
U.S. Water Services (a)	—	—	—	(1.1)
Corporate and Other (a)	5.0	2.0	2.1	16.3
Total Net Income Attributable to ALLETE	$20.1	$34.2	$86.4	$104.7

(a)  In March 2019, ALLETE sold U.S. Water Services. The Company recognized a gain on the sale of $11.1 million after-tax during the six months ended June 30, 2019, which is reflected in Corporate and Other.

	June 30, 2020	December 31, 2019
Millions
Assets
Regulated Operations	$4,139.8	$4,130.8
ALLETE Clean Energy	1,250.2	1,001.5
Corporate and Other	370.4	350.5
Total Assets	$5,760.4	$5,482.8

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Operations and Significant Accounting Policies (Details) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Recognition of Right-of-use Assets and Lease Liabilities		$ 0.0	$ 31.2
Cash, Cash Equivalents and Restricted Cash [Abstract]
Cash and Cash Equivalents		25.7	203.1	$ 69.3	$ 69.1
Restricted Cash included in Prepayments and Other		7.3	0.9	2.8	1.3
Restricted Cash, Non-Current		4.4	2.6	20.4	8.6
Total Cash, Cash Equivalents and Restricted Cash		37.4	206.6	92.5	79.0
Inventories – Net [Abstract]
Fuel	[1]	33.5		25.9
Materials and Supplies		48.5		46.9
Total Inventories – Net		82.0		72.8
Other Non-Current Assets [Abstract]
Contract Assets	[2]	26.7		28.0
Operating Lease, Right-of-Use Asset		25.4		28.6
ALLETE Properties		21.5		21.9
Restricted Cash, Non-Current		4.4	$ 2.6	20.4	$ 8.6
Other Postretirement Benefit Plans		38.4		37.5
Other		84.7		81.8
Total Other Non-Current Assets		201.1		218.2
Other Current Liabilites [Abstract]
PSAs		12.4		12.3
Provision for Interim Rate Refund	[3]	11.7		0.0
Operating Lease Liabilities		6.6		6.9
Other		34.7		41.2
Total Other Current Liabilities		65.4		60.4
Other Non-Current Liabilities [Abstract]
Asset Retirement Obligation		164.8		160.3
PSAs		58.3		64.6
Operating Lease Liabilities		18.8		21.8
Other		46.2		46.3
Total Other Non-Current Liabilities		$ 288.1		$ 293.0

[1] Fuel consists primarily of coal inventory at Minnesota Power.

[2] 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.

[3] Provision for Interim Rate Refund represents reserves for interim rates resulting from the MPUC’s approval of Minnesota Power’s petition and proposal to resolve and withdraw its rate case. (See Note 2. Regulatory Matters.)

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Operations and Significant Accounting Policies - Other Income (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Other Income (Expense) - Other [Line Items]
Total Other Income		$ 5.2	$ 4.2	$ 6.2	$ 11.6
Pension and Other Postretirement Benefit Plans Non-Service Credit [Member]
Other Income (Expense) - Other [Line Items]
Total Other Income	[1]			4.8	3.6
Interest and Investment Income (Loss) [Member]
Other Income (Expense) - Other [Line Items]
Total Other Income				(0.5)	2.5
AFUDC - Equity [Member]
Other Income (Expense) - Other [Line Items]
Total Other Income				1.4	1.3
Gain on Land Sales [Member]
Other Income (Expense) - Other [Line Items]
Total Other Income				0.1	2.0
Other [Member]
Other Income (Expense) - Other [Line Items]
Total Other Income				$ 0.4	$ 2.2

[1] These are components of net periodic pension and other postretirement benefit cost other than service cost. (See Note 9. Pension and Other Postretirement Benefit Plans.)

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Operations and Significant Accounting Policies - Sale of U.S. Water Services (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($)
Business Segments [Line Items]
Proceeds from Sale of U.S. Water Services - Net of Transaction Costs and Cash Retained	$ 270.0
Gain on Sale of U.S. Water Services, After-tax	$ 13.2

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Operations and Significant Accounting Policies - ALLETE Clean Energy Asset Acquisition (Details) - Caddo [Member] - ALLETE Clean Energy [Member] $ in Millions	6 Months Ended
	Jun. 30, 2020 MW	Mar. 10, 2020 USD ($)
Business Segments [Line Items]
Cash Paid for Assets Acquired | $		$ 8
Generating Capacity Under Development (MW) | MW	300

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Operations and Significant Accounting Policies - Non-Controlling Interest (Details) $ in Millions			6 Months Ended
	Apr. 29, 2020 USD ($)	Apr. 16, 2020 MW	Jun. 30, 2020 USD ($) MW	Jun. 30, 2019 USD ($)
Non-Controlling Interest Details [Line Items]
Proceeds from Noncontrolling Interests | $			$ 67.8	$ 0.0
South Peak [Member]
Non-Controlling Interest Details [Line Items]
Proceeds from Noncontrolling Interests | $	$ 67.8
Generating Capacity Subject to Tax Equity Financing | MW		80	80
Glen Ullin Energy Center [Member]
Non-Controlling Interest Details [Line Items]
Generating Capacity Subject to Tax Equity Financing | MW			106

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Regulatory Matters - Electric Rates (Details) - USD ($) $ in Millions				4 Months Ended	6 Months Ended
		May 01, 2020	Nov. 01, 2019	Apr. 30, 2020	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Regulatory Matters [Line Items]
Public Utilities Reserve for Interim Rates	[1]				$ 11.7		$ 0.0
Electric Rates [Member] | MPUC [Member] | Minnesota Cost Recovery Riders [Member] | Minnesota Power [Member] | Retail Customers [Member]
Regulatory Matters [Line Items]
Revenue from Cost Recovery Riders					14.9	$ 17.4
Electric Rates [Member] | MPUC [Member] | 2020 Minnesota General Rate Case [Member] | Minnesota Power [Member] | Retail Customers [Member]
Regulatory Matters [Line Items]
Annual Additional Revenue Generated from Requested Final Rate Increase			$ 66.0
Requested Rate Increase Percent			10.60%
Interim Rate Increase			$ 36.1
Requested Return on Equity			10.05%
Requested Equity Capital Structure			53.81%
Ongoing Customer Rate Increase		4.10%
Public Utilities, Interim Rate Increase (Decrease), Percentage				5.80%
Public Utilities Reserve for Interim Rates					$ 11.7

[1] Provision for Interim Rate Refund represents reserves for interim rates resulting from the MPUC’s approval of Minnesota Power’s petition and proposal to resolve and withdraw its rate case. (See Note 2. Regulatory Matters.)

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Regulatory Matters - Nemadji Trail Energy Center (Details) $ in Millions	Jul. 28, 2017 MW	Jun. 30, 2020 USD ($)
Nemadji Trail Energy Center [Member] | Maximum [Member]
Regulatory Matters [Line Items]
Estimated Capital Expenditures, Including Past Expenditures | $		$ 700
ALLETE, Inc. [Member] | Nemadji Trail Energy Center [Member]
Regulatory Matters [Line Items]
Estimated Capital Expenditures, Including Past Expenditures | $		350
ALLETE, Inc. [Member] | Nemadji Trail Energy Center [Member] | Maximum [Member]
Regulatory Matters [Line Items]
Total Project Costs Incurred to Date | $		$ 14
MPUC [Member] | Resource Package [Member] | Natural Gas-fired [Member] | Combined-Cycle Natural Gas-Fired Generating Facility [Member] | Minimum [Member] | Jointly Owned by ALLETE and Dairyland Power Cooperative [Member] | Natural Gas PPA [Member] | Jointly Owned Electricity Generation Plant [Member]
Regulatory Matters [Line Items]
Generating Capacity to be Jointly Owned (MW) | MW	525
MPUC [Member] | Resource Package [Member] | Natural Gas-fired [Member] | Combined-Cycle Natural Gas-Fired Generating Facility [Member] | Maximum [Member] | Jointly Owned by ALLETE and Dairyland Power Cooperative [Member] | Natural Gas PPA [Member] | Jointly Owned Electricity Generation Plant [Member]
Regulatory Matters [Line Items]
Generating Capacity to be Jointly Owned (MW) | MW	550
MPUC [Member] | Resource Package [Member] | Minnesota Power [Member] | Natural Gas PPA [Member]
Regulatory Matters [Line Items]
Output Being Purchased (MW) | MW	250
MPUC [Member] | Resource Package [Member] | Minnesota Power [Member] | Natural Gas-fired [Member] | Natural Gas PPA [Member]
Regulatory Matters [Line Items]
Expected Output Entitlement (Percent)	50.00%

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Regulated Operations - Conservation Improvement Program (Details) $ in Millions	Jun. 30, 2020 USD ($)
Regulated Operations [Abstract]
Conservation Improvement Program Goal, Next Fiscal Year	$ 10.5
Conservation Improvement Program Goal, In 2 Years	10.7
Conservation Improvement Program Goal, In 3 Years	$ 10.9

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Regulatory Matters - MISO Return on Equity Complaint (Details) - FERC [Member]	Jun. 30, 2020	Dec. 31, 2019
Loss Contingencies [Line Items]
FERC Authorized Return on Common Equity	10.02%	9.88%
FERC Authorized Return on Equity, Including Incentive Adder	10.52%	10.38%

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Regulated Operations - Minnesota Solar Energy Standard (Details) $ in Millions	Jun. 30, 2020 USD ($) MW
Regulated Operations [Abstract]
Estimated Investment Amount | $	$ 40
Estimated Generation from Projects Under Development | MW	20

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Regulatory Matters - Regulatory Assets and Liabilities (Details) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2020		Dec. 31, 2019
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets Currently Earning a Return		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.
Non-Current Regulatory Assets		$ 424.7		$ 420.5
Current Regulatory Liabilities	[1]	14.2		1.9
Non-Current Regulatory Liabilities		569.6		560.3
Total Regulatory Liabilities		583.8		562.2
Transmission Formula Rates [Member]
Regulatory Assets and Liabilities [Line Items]
Current Regulatory Liabilities	[1]	0.8		1.7
Income Taxes [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		395.5		407.2
Wholesale and Retail Contra AFUDC [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		87.4		79.3
Plant Removal Obligations [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		39.3		35.5
Pension and Other Postretirement Plan Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		14.1		17.0
North Dakota Investment Tax Credits [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		12.2		12.3
Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities	[2]	12.2		0.0
Conservation Improvement Program [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Liabilities		5.4		5.4
Other
Regulatory Assets and Liabilities [Line Items]
Current Regulatory Liabilities	[1]	1.7		0.2
Non-Current Regulatory Liabilities		3.5		3.6
Public Utilities Reserve for Interim Rates
Regulatory Assets and Liabilities [Line Items]
Current Regulatory Liabilities	[2]	11.7	[1]	0.0
Pension and Other Postretirement Plan Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		208.0		212.9
Income Taxes [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		122.1		123.4
Asset Retirement Obligations [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		31.7		32.0
Boswell 1 & 2 [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		7.8		10.7
Cost Recovery Riders [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		39.3		24.7
Manufactured Gas Plant [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		8.3		8.2
PPACA Income Tax Deferral [Member]
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		4.7		4.8
Other
Regulatory Assets and Liabilities [Line Items]
Non-Current Regulatory Assets		$ 2.8		$ 3.8

[1] Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.(b)Provision for Interim Rate Refund represents reserves for interim rates resulting from the MPUC’s approval of Minnesota Power’s petition and proposal to resolve and withdraw its rate case. This amount is expected to be refunded to Minnesota Power regulated retail customers in the third quarter of 2020. (See 2020 Minnesota General Rate Case.)

[2] Fuel adjustment clause regulatory liability represents the amount expected to be refunded to customers for the over-collection of fuel adjustment clause recoveries. (See Fuel Adjustment Clause Reform.)

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Equity Investments - Investment in ATC (Details) - USD ($) $ in Millions			3 Months Ended		6 Months Ended
		Jul. 31, 2020	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
ALLETE's Investment in ATC [Roll Forward]
Equity Investment Balance as of December 31, 2019					$ 197.6
Cash Investments					66.6	$ 4.6
Equity in ATC Earnings (a)			$ 6.4	$ 4.8	11.6	$ 10.4
Equity Investment Balance as of June 30, 2020			$ 267.1		$ 267.1
ATC [Member]
Investment in ATC [Line Items]
Ownership Percentage			8.00%		8.00%
Expected Additional Investment in 2020			$ 0.8		$ 0.8
ALLETE's Investment in ATC [Roll Forward]
Equity Investment Balance as of December 31, 2019					141.6
Cash Investments					1.1
Equity in ATC Earnings (a)	[1]				11.6
Distributed ATC Earnings					(9.4)
Amortization of the Remeasurement of Deferred Income Taxes					0.7
Equity Investment Balance as of June 30, 2020			$ 145.6		$ 145.6
Authorized Return on Equity					10.02%
Authorized Return on Equity, Including Incentive Adder			10.52%		10.52%
Additional Equity in Earnings During the Period					$ 1.2
ATC [Member] | Subsequent Event [Member]
ALLETE's Investment in ATC [Roll Forward]
Cash Investments		$ 0.8

[1] Equity in ATC Earnings includes $1.2 million of additional earnings resulting from the FERC’s May 21, 2020, order increasing ATC’s authorized return on equity to 10.52 percent including an incentive adder for participation in a regional transmission organization.

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Equity Investments - Investment in Nobles 2 (Details) $ in Millions	1 Months Ended	6 Months Ended
	Jul. 31, 2020 USD ($)	Jun. 30, 2020 USD ($) MW	Jun. 30, 2019 USD ($)	Dec. 31, 2019 USD ($)
Investment in Nobles 2 [Line Items]
Equity Investment Balance		$ 267.1		$ 197.6
Cash Investments		$ 66.6	$ 4.6
Nobles 2 [Member]
Investment in Nobles 2 [Line Items]
Ownership Percentage		49.00%
Equity Investment Balance		$ 121.5		$ 56.0
Cash Investments		65.5
Expected Additional Investment in 2020		$ 35.0
Wind Turbine Generators [Member] | Resource Package [Member] | Tenaska [Member] | MPUC [Member] | Minnesota Power [Member] | Tenaska PPA [Member]
Investment in Nobles 2 [Line Items]
Generating Capacity Counterparty Owned (MW) | MW		250
Long-term Contract for Purchase of Electric Power, Term of Contract (Years)		20 years
Subsequent Event [Member] | Nobles 2 [Member]
Investment in Nobles 2 [Line Items]
Cash Investments	$ 15.0

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Fair Value - Recurring Fair Value Measures (Details) - USD ($) $ in Millions		Jun. 30, 2020		Dec. 31, 2019
Investments [Abstract]
Available-for-sale Securities, Debt Maturities, within One Year, Fair Value		$ 3.8
Available-for-sale Securities, Debt Maturities, After One Year Through Three Years, Fair Value		5.0
Available-for-sale Securities, Debt Maturities, After Three Years Through Five Years, Fair Value		1.0
Available-for-sale Securities, Debt Maturities, After Five Years, Fair Value		0.0
Recurring Fair Value Measures [Member]
Investments [Abstract]
Available-for-sale – Equity Securities	[1]	10.1		$ 11.1
Available-for-sale – Corporate and Governmental Debt Securities (b)	[1]	9.8	[2]	9.7
Cash Equivalents	[1]	0.8		0.9
Total Fair Value of Assets		20.7		21.7
Liabilities [Abstract]
Deferred Compensation	[3]	20.0		21.2
Total Fair Value of Liabilities		20.0		21.2
Total Net Fair Value of Assets (Liabilities)		0.7		0.5
Recurring Fair Value Measures [Member] | Level 1 [Member]
Investments [Abstract]
Available-for-sale – Equity Securities	[1]	10.1		11.1
Available-for-sale – Corporate and Governmental Debt Securities (b)	[1]	0.0	[2]	0.0
Cash Equivalents	[1]	0.8		0.9
Total Fair Value of Assets		10.9		12.0
Liabilities [Abstract]
Deferred Compensation	[3]	0.0		0.0
Total Fair Value of Liabilities		0.0		0.0
Total Net Fair Value of Assets (Liabilities)		10.9		12.0
Recurring Fair Value Measures [Member] | Level 2 [Member]
Investments [Abstract]
Available-for-sale – Equity Securities	[1]	0.0		0.0
Available-for-sale – Corporate and Governmental Debt Securities (b)	[1]	9.8	[2]	9.7
Cash Equivalents	[1]	0.0		0.0
Total Fair Value of Assets		9.8		9.7
Liabilities [Abstract]
Deferred Compensation	[3]	20.0		21.2
Total Fair Value of Liabilities		20.0		21.2
Total Net Fair Value of Assets (Liabilities)		(10.2)		(11.5)
Recurring Fair Value Measures [Member] | Level 3 [Member]
Investments [Abstract]
Available-for-sale – Equity Securities	[1]	0.0		0.0
Available-for-sale – Corporate and Governmental Debt Securities (b)	[1]	0.0	[2]	0.0
Cash Equivalents	[1]	0.0		0.0
Total Fair Value of Assets		0.0		0.0
Liabilities [Abstract]
Deferred Compensation	[3]	0.0		0.0
Total Fair Value of Liabilities		0.0		0.0
Total Net Fair Value of Assets (Liabilities)		$ 0.0		$ 0.0

[1] Included in Other Non-Current Assets on the Consolidated Balance Sheet.

[2] As of June 30, 2020, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $3.8 million, in one year to less than three years was $5.0 million, in three years to less than five years was $1.0 million and in five or more years was zero.

[3] Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.

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Fair Value - Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Fair Value of Financial Instruments [Line Items]
Short-Term and Long-Term Debt - Carrying Amount	$ 1,899.0	$ 1,622.6
ALLETE Clean Energy [Member]
Fair Value of Financial Instruments [Line Items]
Asset Carrying Value	11.0
Level 2 [Member]
Fair Value of Financial Instruments [Line Items]
Short-Term and Long-Term Debt - Fair Value	$ 2,163.4	$ 1,791.8

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Short-Term and Long-Term Debt (Details) - USD ($) $ in Millions	Aug. 03, 2020	Apr. 08, 2020	Jan. 10, 2020	Jul. 06, 2020	Jun. 30, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Short-Term Debt - Principal					$ 510.0	$ 213.3
Short-Term Debt - Unamortized Debt Issuance Costs					(0.3)	(0.4)
Short-Term Debt - Total					509.7	212.9
Long-Term Debt - Principal					1,389.0	1,409.3
Long-Term Debt - Unamortized Debt Issuance Costs					(8.0)	(8.4)
Long-Term Debt - Total					1,381.0	1,400.9
Total Debt - Principal					1,899.0	1,622.6
Total Debt - Unamortized Debt Issuance Costs					(8.3)	(8.8)
Total Debt - Total					1,890.7	1,613.8
Unsecured Term Loan Due in 2021 [Member]
Debt Instrument [Line Items]
Unsecured Term Loan, Amount			$ 200.0
Variable Rate Basis			LIBOR
Basis Spread on Variable Rate			0.55%
Unsecured Term Loan Due April 2021 [Member]
Debt Instrument [Line Items]
Unsecured Term Loan, Amount		$ 115.0
Proceeds from Issuance of Unsecured Debt		$ 95.0
Variable Rate Basis		LIBOR
Basis Spread on Variable Rate		1.70%
Debt Instrument, Interest Rate Floor		0.75%
Line of Credit [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount					23.5	62.0
Line of Credit, Current					$ 0.0	$ 0.0
Subsequent Event [Member] | ALLETE Bonds 2.50% Due August 2030 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of First Mortgage Bond	$ 46.0
Interest Rate	2.50%
Subsequent Event [Member] | Unsecured Term Loan Due April 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount				$ 20.0
Subsequent Event [Member] | ALLETE Bonds 3.30% Due August 2050 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of First Mortgage Bond	$ 94.0
Interest Rate	3.30%

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Short-Term and Long-Term Debt - Financial Covenants (Details)	Jun. 30, 2020
Debt Instrument [Line Items]
Actual Ratio of Indebtedness to Total Capitalization	0.44
Maximum [Member]
Debt Instrument [Line Items]
Required Ratio of Indebtedness to Total Capitalization	0.65

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Commitments, Guarantees and Contingencies - Power Purchase Agreements (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020 USD ($) MW	Jun. 30, 2019 USD ($)
Square Butte [Member] | Square Butte PPA [Member]
Power Purchase Agreements [Line Items]
PPA Counterparty Total Debt Outstanding	$ 272.9
Square Butte [Member] | Square Butte PPA [Member] | Minnesota Power [Member]
Power Purchase Agreements [Line Items]
Cost of Power Purchased	40.8	$ 41.1
Pro Rata Share of PPA Counterparty Interest Expense	$ 3.7	$ 4.2
Square Butte [Member] | Square Butte PPA [Member] | Minnesota Power [Member] | Square Butte Coal-fired Unit [Member]
Power Purchase Agreements [Line Items]
Expected Output Entitlement	50.00%
Minnkota Power [Member] | Square Butte PPA [Member] | Minnesota Power [Member] | Square Butte Coal-fired Unit [Member] | Minnkota Power PSA [Member]
Power Purchase Agreements [Line Items]
Expected Output Entitlement	28.00%	28.00%
Minnesota Power Short-term PSAs in 2020 and 2021 [Member]
Power Purchase Agreements [Line Items]
MW Sold Under Short-term PSAs | MW	300

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Commitments, Guarantees and Contingencies - Transmission (Details) $ in Millions	Jun. 30, 2020 USD ($) kV Miles MW
Great Northern Transmission Line [Member]
Transmission [Line Items]
Total Project Costs To Date	$ 657.0
Minnesota Power [Member] | Great Northern Transmission Line [Member]
Transmission [Line Items]
Transmission Line Length (Miles) | Miles	220
Transmission Line Capacity (kV) | kV	500
Total Project Costs Incurred to Date	$ 307.1
Manitoba Hydro PPA [Member] | Manitoba Hydro [Member]
Transmission [Line Items]
Output Being Purchased (MW) | MW	250

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Commitments, Guarantees and Contingencies - Environmental Matters (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
Coal Combustion Residuals [Member] | Minnesota Power [Member]
Environmental Matters [Line Items]
Expected Period for Costs of Compliance	15 years
Coal Combustion Residuals [Member] | Minimum [Member] | Minnesota Power [Member]
Environmental Matters [Line Items]
Estimated Costs of Compliance	$ 65
Coal Combustion Residuals [Member] | Maximum [Member] | Minnesota Power [Member]
Environmental Matters [Line Items]
Estimated Costs of Compliance	120
Manufactured Gas Plant [Member] | SWL&P [Member] | Superior, WI [Member]
Environmental Matters [Line Items]
Estimated Costs of Compliance (Accrued)	$ 7	$ 7

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Commitments, Guarantees and Contingencies - Other Matters (Details) - USD ($)	6 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
ALLETE Clean Energy [Member] | Letters of Credit [Member]
Guarantor Obligations [Line Items]
Letters of Credit Outstanding, Amount	$ 63,600,000
BNI Energy Reclamation Liability [Member]
Guarantor Obligations [Line Items]
Estimated Obligation	67,300,000
BNI Energy Reclamation Liability [Member] | Surety Bonds [Member]
Guarantor Obligations [Line Items]
Collateral	67,700,000
ALLETE Properties Development and Maintenance Obligations [Member]
Guarantor Obligations [Line Items]
Estimated Obligation	1,300,000
ALLETE Properties Development and Maintenance Obligations [Member] | Surety Bonds and Letters of Credit [Member]
Guarantor Obligations [Line Items]
Collateral	$ 2,300,000
Town Center District Capital Improvement Bonds [Member]
Guarantor Obligations [Line Items]
Ownership Percentage of Benefited Property	53.00%	53.00%
Annual Assessment	$ 1,900,000
ALLETE South Wind [Member] | Letters of Credit [Member]
Guarantor Obligations [Line Items]
Letters of Credit Outstanding, Amount	14,000,000.0
Minnesota Power [Member] | Letters of Credit [Member]
Guarantor Obligations [Line Items]
Letters of Credit Outstanding, Amount	6,400,000
ALLETE, Inc. [Member] | Letters of Credit [Member]
Guarantor Obligations [Line Items]
Letters of Credit Outstanding, Amount	$ 84,000,000.0

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Earnings Per Share and Common Stock (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Earnings Per Share - Basic [Abstract]
Net Income (Loss) Attributable to ALLETE	$ 20.1	$ 34.2	$ 86.4	$ 104.7
Average Common Shares	51.8	51.6	51.8	51.6
Earnings Per Share	$ 0.39	$ 0.66	$ 1.67	$ 2.03
Earnings Per Share - Diluted [Abstract]
Net Income	$ 20.1	$ 34.2	$ 86.4	$ 104.7
Average Common Shares	51.9	51.7	51.8	51.7
Earnings Per Share	$ 0.39	$ 0.66	$ 1.67	$ 2.02
Dilutive Securities (Shares)	0.1	0.1	0.0	0.1

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Income Tax Expense (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Current Income Tax Expense (Benefit) [Abstract]
Federal	[1]	$ 0.0	$ 0.0	$ 0.0	$ 0.0
State	[1]	0.0	(0.1)	0.0	0.2
Total Current Income Tax Expense		0.0	(0.1)	0.0	0.2
Deferred Income Tax Expense (Benefit) [Abstract]
Federal	[2]	(8.6)	(7.1)	(26.2)	(16.8)
State	[3]	0.2	2.5	4.2	15.0
Investment Tax Credit Amortization		(0.1)	(0.1)	(0.3)	(0.3)
Total Deferred Income Tax Expense (Benefit)		(8.5)	(4.7)	(22.3)	(2.1)
Total Income Tax Expense (Benefit)		(8.5)	(4.8)	(22.3)	(1.9)
Reconciliation of Taxes from Federal Statutory Rate to Total Income Tax Expense [Abstract]
Income Before Income Taxes		$ 8.4	$ 29.4	$ 59.1	$ 102.8
Statutory Federal Income Tax Rate		21.00%	21.00%	21.00%	21.00%
Income Taxes Computed at Statutory Federal Rate		$ 1.7	$ 6.2	$ 12.4	$ 21.6
Increase (Decrease) in Income Tax Due to: [Abstract]
State Income Taxes – Net of Federal Income Tax Benefit		0.1	1.9	3.3	12.0
Production Tax Credits		(9.6)	(9.8)	(33.4)	(26.1)
Regulatory Differences – Excess Deferred Tax		(0.9)	(1.6)	(5.3)	(4.8)
U.S. Water Services Sale of Stock Basis Difference		0.0	(0.7)	0.0	1.7
Share-Based Compensation		0.0	0.0	(0.1)	(0.9)
Other		0.2	(0.8)	0.8	(5.4)
Total Income Tax Expense (Benefit)		(8.5)	$ (4.8)	$ (22.3)	$ (1.9)
Effective Tax Rate				(37.80%)	(1.80%)
Uncertain Tax Positions [Abstract]
Gross Unrecognized Tax Benefits		1.4		$ 1.4		$ 1.4
Gross Unrecognized Tax Benefits That Would Favorably Impact Effective Income Tax Rate		$ 0.6		$ 0.6

[1] For each of the six months ended June 30, 2020 and 2019, 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.

[2] For each of the six months ended June 30, 2020 and 2019, the federal income tax benefit is primarily due to production tax credits.

[3] For the six months ended June 30, 2019, the state income tax expense is primarily related to the sale of U.S. Water Services.

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Pension and Other Postretirement Benefit Plans (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Pension [Member]
Components of Net Periodic Benefit Cost (Credit) [Abstract]
Service Cost		$ 2.7	$ 2.4	$ 5.3	$ 4.7
Interest Cost	[1]	7.0	8.0	14.0	16.0
Expected Return on Plan Assets	[1]	(10.7)	(11.1)	(21.4)	(22.1)
Amortization of Prior Service Credits	[1]	(0.1)	(0.1)	(0.1)	(0.1)
Amortization of Net Loss	[1]	3.2	1.9	6.4	3.7
Net Periodic Benefit Cost (Credit)		2.1	1.1	4.2	2.2
Employer Contributions to Defined Benefit Plans				10.7	10.4
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		0.0		0.0
Other Postretirement [Member]
Components of Net Periodic Benefit Cost (Credit) [Abstract]
Service Cost		0.9	1.0	1.7	2.0
Interest Cost	[1]	1.2	1.9	2.5	3.8
Expected Return on Plan Assets	[1]	(2.4)	(2.7)	(4.9)	(5.3)
Amortization of Prior Service Credits	[1]	(2.0)	(0.4)	(4.0)	(0.8)
Amortization of Net Loss	[1]	0.2	0.1	0.5	0.2
Net Periodic Benefit Cost (Credit)		(2.1)	$ (0.1)	(4.2)	(0.1)
Employer Contributions to Defined Benefit Plans				0.0	$ 0.0
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 0.0		$ 0.0

[1] 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.

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Business Segments (Details) $ in Millions		3 Months Ended		6 Months Ended				12 Months Ended
		Jun. 30, 2020 USD ($) a	Jun. 30, 2019 USD ($)	Jun. 30, 2020 USD ($) a Segments		Jun. 30, 2019 USD ($)		Dec. 31, 2019 USD ($)
Business Segments [Line Items]
Number of Reportable Segments | Segments				3
Operating Revenue		$ 243.2	$ 290.4	$ 554.8		$ 647.6
Net Income (Loss) Attributable to ALLETE		20.1	34.2	86.4		104.7
Gain on Sale of U.S. Water Services, After-tax								$ 13.2
Assets		5,760.4		$ 5,760.4				5,482.8
Regulated Operations [Member]
Business Segments [Line Items]
Number of Operating Segments | Segments				3
Operating Revenue		200.8	249.8	$ 466.1		532.0
Net Income (Loss) Attributable to ALLETE		11.1	30.3	68.6		81.8
Assets		4,139.8		4,139.8				4,130.8
Regulated Operations [Member] | Residential [Member]
Business Segments [Line Items]
Operating Revenue		27.4	29.2	68.3		74.4
Regulated Operations [Member] | Commercial [Member]
Business Segments [Line Items]
Operating Revenue		28.8	34.9	66.1		73.8
Regulated Operations [Member] | Municipal [Member]
Business Segments [Line Items]
Operating Revenue		9.0	12.2	19.3		27.6
Regulated Operations [Member] | Industrial [Member]
Business Segments [Line Items]
Operating Revenue		88.0	120.3	206.8		241.9
Regulated Operations [Member] | Other Power Suppliers [Member]
Business Segments [Line Items]
Operating Revenue		27.4	35.2	65.7		74.6
Regulated Operations [Member] | Other [Member]
Business Segments [Line Items]
Operating Revenue		20.2	18.0	39.9		39.7
ALLETE Clean Energy [Member]
Business Segments [Line Items]
Operating Revenue		17.6	15.4	37.7		32.9
Net Income (Loss) Attributable to ALLETE		4.0	1.9	15.7		7.7
Assets		1,250.2		1,250.2				1,001.5
ALLETE Clean Energy [Member] | Long-term PSA [Member]
Business Segments [Line Items]
Operating Revenue		14.8	12.5	32.1		27.1
ALLETE Clean Energy [Member] | Other [Member]
Business Segments [Line Items]
Operating Revenue, Other Than Customer Revenue		2.8	2.9	5.6		5.8
U.S. Water Services [Member]
Business Segments [Line Items]
Operating Revenue		0.0	0.0	0.0	[1]	33.4	[1]
Net Income (Loss) Attributable to ALLETE	[1]	0.0	0.0	0.0		(1.1)
U.S. Water Services [Member] | Point-in-Time [Member]
Business Segments [Line Items]
Operating Revenue	[1]	0.0	0.0	0.0		19.0
U.S. Water Services [Member] | Contract [Member]
Business Segments [Line Items]
Operating Revenue		0.0	0.0	0.0	[1]	9.2	[1]
U.S. Water Services [Member] | Capital Project [Member]
Business Segments [Line Items]
Operating Revenue		$ 0.0	0.0	$ 0.0	[1]	5.2	[1]
Corporate and Other [Member]
Business Segments [Line Items]
Number of Operating Segments | Segments				2
Land in Minnesota (Acres) | a		4,000		4,000
Operating Revenue		$ 24.8	25.2	$ 51.0		49.3
Net Income (Loss) Attributable to ALLETE	[1]	5.0	2.0	2.1		16.3
Gain on Sale of U.S. Water Services, After-tax						11.1
Assets		370.4		370.4				$ 350.5
Corporate and Other [Member] | Long-term Contract [Member]
Business Segments [Line Items]
Operating Revenue		22.5	21.2	44.9		41.4
Corporate and Other [Member] | Other [Member]
Business Segments [Line Items]
Operating Revenue		$ 2.3	$ 4.0	$ 6.1		$ 7.9

[1] In March 2019, ALLETE sold U.S. Water Services. The Company recognized a gain on the sale of $11.1 million after-tax during the six months ended June 30, 2019, which is reflected in Corporate and Other.