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, 2019~~March 31, 2020



☐	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,

~~51,655,541~~51,787,412 shares outstanding

as of ~~June 30, 2019~~March 31, 2020

Index




Definitions			3
Forward-Looking Statements			5
Part I.	Financial Information
	Item 1.	Consolidated Financial Statements - Unaudited	76
		Consolidated Balance Sheet	6
		Consolidated Statement of Income	7
		Consolidated Statement of Comprehensive Income	8
		Consolidated Statement of ~~Comprehensive Income~~Cash Flows	9
		Consolidated Statement of ~~Cash Flows~~Equity	10
		~~Consolidated Statement of Shareholders’ Equity~~	11
		Notes to Consolidated Financial Statements	1211
		Note 1. Operations and Significant Accounting Policies	1211
		Note 2. Regulatory Matters	1613
		Note 3. Equity Investments	1816
		Note 4. ~~Goodwill~~Fair Value	16
		Note 5. Short-Term and ~~Intangible Assets~~Long-Term Debt	18
		Note 6. Commitments, Guarantees and Contingencies	19
		Note ~~5. Fair Value~~7. Earnings Per Share and Common Stock	19
		~~Note 6. Short-Term and Long-Term Debt~~	21
		~~Note 7. Commitments, Guarantees and Contingencies~~	2223
		Note 8. ~~Earnings Per Share and Common Stock~~Income Tax Expense	2724
		Note 9. ~~Income Tax Expense~~Pension and Other Postretirement Benefit Plans	2725
		Note 10. ~~Pension and Other Postretirement Benefit Plans~~	29
		~~Note 11.~~ Business Segments	2925
	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	31
		~~Comparison of Quarters Ended~~	3227
		Comparison of the ~~Six~~Three Months Ended	3529
		Critical Accounting Policies	3832
		Outlook	3832
		Liquidity and Capital Resources	4439
		Other	4641
	Item 3.	Quantitative and Qualitative Disclosures about Market Risk	4742
	Item 4.	Controls and Procedures	4742
Part II.	Other Information
	Item 1.	Legal Proceedings	4843
	Item 1A.	Risk Factors	4843
	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	4844
	Item 3.	Defaults Upon Senior Securities	4844
	Item 4.	Mine Safety Disclosures	4844
	Item 5.	Other Information	4844
	Item 6.	Exhibits	4945
Signatures			5046

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
Bison	Bison Wind Energy Center
BNI Energy	BNI Energy, Inc. and its subsidiary
Boswell	Boswell Energy Center
Camp Ripley	Camp Ripley Solar Array
~~CIP~~	~~Conservation Improvement Program~~
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
~~EITE~~	~~Energy-Intensive Trade-Exposed~~
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
~~Montana-Dakota Utilities~~	~~Montana-Dakota Utilities Co., a subsidiary of MDU Resources Group, Inc.~~
Moody’s	Moody’s Investors Service, Inc.
~~MPCA~~	~~Minnesota Pollution Control Agency~~



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~~ NO_X	Nitrogen Oxides
~~Northern States Power~~	~~Northern States Power Company, a subsidiary of Xcel Energy Inc.~~
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
~~Palm Coast Park District~~	~~Palm Coast Park Community Development District in Florida~~
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
~~TCJA~~	~~Tax Cuts and Job Act of 2017 (Public Law 115-97)~~
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

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;~~diseases, including the ongoing COVID-19 pandemic;

our ability to access capital markets, bank financing and ~~bank financing;~~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 in regulated rates or contract price increases at our Energy Infrastructure and Related Services and other businesses;~~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 ~~Regulated Operations segment~~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 in, our Energy Infrastructure and Related Services businesses; and~~

factors affecting our Energy Infrastructure and Related Services businesses, including unanticipated cost increases, changes in legislation and regulations impacting the industries in which the customers served operate, the effects of weather, creditworthiness of customers, ability to obtain materials required to perform services, and changing market conditions.

~~Forward-Looking Statements (Continued)~~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 ~~2018~~2019 Form ~~10-K.~~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.

PART I. FINANCIAL INFORMATION

ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS

ALLETE

CONSOLIDATED BALANCE SHEET

Unaudited


	June 30, 2019			December 31, 2018			March 31, 2020			December 31, 2019
Millions
Assets
Current Assets
Cash and Cash Equivalents		$203.1			$69.1			$67.0			$69.3
Accounts Receivable (Less Allowance of $1.1 and $1.7)	87.4			144.4
Accounts Receivable (Less Allowance of $1.2 and $0.9)							99.4			96.4
Inventories – Net	78.2			86.7			79.0			72.8
Prepayments and Other	28.6			34.1			29.4			31.0
Total Current Assets	397.3			334.3			274.8			269.5
Property, Plant and Equipment – Net	4,062.9			3,904.4			4,496.3			4,377.0
Regulatory Assets	391.2			389.5			423.8			420.5
Equity Investments	160.2			161.1			225.7			197.6
Goodwill and Intangible Assets – Net	1.1			223.3
Other Non-Current Assets	163.8			152.4			198.9			218.2
Total Assets		$5,176.5			$5,165.0			$5,619.5			$5,482.8
Liabilities and Shareholders’ Equity
Liabilities and Equity
Liabilities
Current Liabilities
Accounts Payable		$150.4			$149.8			$164.4			$165.2
Accrued Taxes	41.3			51.4			63.0			50.8
Accrued Interest	17.7			17.9			15.1			18.1
Long-Term Debt Due Within One Year	27.7			57.5			323.0			212.9
Other	59.5			128.5			57.6			60.4
Total Current Liabilities	296.6			405.1			623.1			507.4
Long-Term Debt	1,505.9			1,428.5			1,399.9			1,400.9
Deferred Income Taxes	213.5			223.6			207.0			212.8
Regulatory Liabilities	508.8			512.1			566.4			560.3
Defined Benefit Pension and Other Postretirement Benefit Plans	163.9			177.3			161.4			172.8
Other Non-Current Liabilities	282.8			262.6			288.7			293.0
Total Liabilities	2,971.5			3,009.2			3,246.5			3,147.2
Commitments, Guarantees and Contingencies (Note 7)
Shareholders’ Equity
Common Stock Without Par Value, 80.0 Shares Authorized, 51.7 and 51.5 Shares Issued and Outstanding	1,433.3			1,428.5
Commitments, Guarantees and Contingencies (Note 6)
Equity
ALLETE Equity
Common Stock Without Par Value, 80.0 Shares Authorized, 51.8 and 51.7 Shares Issued and Outstanding							1,441.7			1,436.7
Accumulated Other Comprehensive Loss	(26.9		)	(27.3		)	(23.8		)	(23.6		)
Retained Earnings	798.6			754.6			853.2			818.8
Total Shareholders’ Equity	2,205.0			2,155.8
Total Liabilities and Shareholders’ Equity		$5,176.5			$5,165.0
Total ALLETE Equity							2,271.1			2,231.9
Non-Controlling Interest in Subsidiaries							101.9			103.7
Total Equity							2,373.0			2,335.6
Total Liabilities and Equity								$5,619.5			$5,482.8

The accompanying notes are an integral part of these statements.

ALLETE

CONSOLIDATED STATEMENT OF INCOME

Unaudited


	Quarter Ended						Six Months Ended						Three Months Ended
	June 30,						June 30,						March 31,
	2019			2018			2019			2018			2020			2019
Millions Except Per Share Amounts
Operating Revenue
Contracts with Customers – Utility		$249.8			$257.8			$532.0			$528.0			$265.3			$282.2
Contracts with Customers – Non-utility	37.7			80.4			109.8			162.4			43.5			72.1
Other – Non-utility	2.9			5.9			5.8			11.9			2.8			2.9
Total Operating Revenue	290.4			344.1			647.6			702.3			311.6			357.2
Operating Expenses
Fuel, Purchased Power and Gas – Utility	87.9			96.5			197.7			197.4			89.0			109.8
Transmission Services – Utility	19.2			16.8			37.5			35.2			18.5			18.3
Cost of Sales – Non-utility	16.5			37.0			47.1			69.9			16.9			30.6
Operating and Maintenance	66.7			86.8			142.9			173.3			61.0			76.2
Depreciation and Amortization	50.2			56.1			102.1			101.9			53.4			51.9
Taxes Other than Income Taxes	13.7			14.4			27.3			30.7			12.6			13.6
Total Operating Expenses	254.2			307.6			554.6			608.4			251.4			300.4
Operating Income	36.2			36.5			93.0			93.9			60.2			56.8
Other Income (Expense)
Interest Expense	(16.3		)	(17.1		)	(32.8		)	(34.0		)	(15.7		)	(16.5		)
Equity Earnings	4.8			4.3			10.4			9.0			5.2			5.6
Gain on Sale of U.S. Water Services	0.5			—			20.6			—			—			20.1
Other	4.2			2.2			11.6			4.3			1.0			7.4
Total Other Income (Expense)	(6.8		)	(10.6		)	9.8			(20.7		)	(9.5		)	16.6
Income Before Income Taxes	29.4			25.9			102.8			73.2			50.7			73.4
Income Tax Benefit	(4.8		)	(5.4		)	(1.9		)	(9.1		)
Income Tax Expense (Benefit)													(13.8		)	2.9
Net Income		$34.2			$31.3			$104.7			$82.3		64.5			70.5
Net Loss Attributable to Non-Controlling Interest													(1.8		)	—
Net Income Attributable to ALLETE														$66.3			$70.5
Average Shares of Common Stock
Basic	51.6			51.3			51.6			51.2			51.7			51.6
Diluted	51.7			51.5			51.7			51.4			51.8			51.7
Basic Earnings Per Share of Common Stock		$0.66			$0.61			$2.03			$1.61			$1.28			$1.37
Diluted Earnings Per Share of Common Stock		$0.66			$0.61			$2.02			$1.60			$1.28			$1.37

The accompanying notes are an integral part of these statements.

ALLETE

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

Unaudited


	Quarter Ended				Six Months Ended					Three Months Ended
	June 30,				June 30,					March 31,
	2019		2018		2019		2018			2020			2019
Millions
Net Income		$34.2		$31.3		$104.7		$82.3			$64.5			$70.5
Other Comprehensive Income (Loss)
Unrealized Gain (Loss) on Securities
Net of Income Tax Expense of $0.1, $–, $0.1 and $–	0.1		—		0.2		(0.1		)
Net of Income Tax Expense (Benefit) of $(0.1) and $–										(0.4		)	0.1
Defined Benefit Pension and Other Postretirement Benefit Plans
Net of Income Tax Expense of $–, $0.1, $0.1 and $0.2	0.2		0.3		0.2		0.7
Total Other Comprehensive Income	0.3		0.3		0.4		0.6
Net of Income Tax Expense of $0.1 and $0.1										0.2			—
Total Other Comprehensive Income (Loss)										(0.2		)	0.1
Total Comprehensive Income		$34.5		$31.6		$105.1		$82.9		64.3			70.6
Net Loss Attributable to Non-Controlling Interest										(1.8		)	—
Total Comprehensive Income Attributable to ALLETE											$66.1			$70.6

The accompanying notes are an integral part of these statements.

ALLETE

CONSOLIDATED STATEMENT OF CASH FLOWS

Unaudited


	Six Months Ended						Three Months Ended
	June 30,						March 31,
	2019			2018			2020			2019
Millions
Operating Activities
Net Income		$104.7			$82.3			$64.5			$70.5
AFUDC – Equity	(1.3		)	(0.5		)	(0.5		)	(0.6		)
Income from Equity Investments – Net of Dividends	(2.2		)	(0.4		)	—			(1.2		)
Realized and Unrealized (Gain) Loss on Investments and Property, Plant and Equipment							3.1			(2.2		)
Depreciation Expense	100.8			99.2			53.4			50.7
Amortization of PSAs	(5.8		)	(11.9		)	(2.8		)	(2.9		)
Amortization of Other Intangible Assets and Other Assets	3.2			5.0			2.6			3.8
Deferred Income Tax Benefit	(2.1		)	(9.5		)
Deferred Income Tax Expense (Benefit)							(13.8		)	2.6
Share-Based and ESOP Compensation Expense	3.3			3.3			1.7			1.8
Defined Benefit Pension and Postretirement Benefit Expense	2.1			4.3			—			1.1
Payments / Provision for Interim Rate Refund	(40.0		)	8.8
Payments / Provision for Tax Reform Refund	(10.3		)	6.7
Provision for Interim Rate Refund							—			0.6
Payments for Tax Reform Refund							—			(10.2		)
Bad Debt Expense	(0.6		)	0.7			0.4			0.4
Gain on Sale of U.S. Water Services	(20.6		)	—			—			(20.1		)
Changes in Operating Assets and Liabilities
Accounts Receivable	34.0			1.7			(3.4		)	20.9
Inventories	(9.5		)	(3.2		)	(6.2		)	(5.1		)
Prepayments and Other	3.3			2.8			4.0			2.9
Accounts Payable	(11.2		)	8.1			(5.5		)	(5.5		)
Other Current Liabilities	(23.9		)	(1.3		)	7.1			(9.1		)
Cash Contributions to Defined Benefit Pension Plans	(10.4		)	(15.0		)	(10.7		)	(10.4		)
Changes in Regulatory and Other Non-Current Assets	(11.9		)	5.8			(11.4		)	—
Changes in Regulatory and Other Non-Current Liabilities	(6.4		)	7.5			6.3			(8.9		)
Cash from Operating Activities	95.2			194.4			88.8			79.1
Investing Activities
Proceeds from Sale of Available-for-sale Securities	6.0			7.2			0.9			2.7
Payments for Purchase of Available-for-sale Securities	(5.9		)	(9.8		)	(1.1		)	(2.6		)
Payments for Equity Investments	(4.6		)	(3.9		)	(27.8		)	(0.5		)
Return of Capital from Equity Investments	8.3			—			—			8.3
Proceeds from Sale of U.S. Water Services – Net of Transaction Costs and Cash Retained	264.2			—			—			264.7
Additions to Property, Plant and Equipment	(236.0		)	(133.4		)	(154.3		)	(89.3		)
Other Investing Activities	14.0			1.4			(0.2		)	1.8
Cash from (for) Investing Activities	46.0			(138.5		)	(182.5		)	185.1
Financing Activities
Proceeds from Issuance of Common Stock	1.5			10.7			3.3			0.8
Proceeds from Issuance of Long-Term Debt	100.0			72.0			110.0			100.0
Repayments of Long-Term Debt	(49.8		)	(57.9		)	(1.4		)	(43.8		)
Acquisition-Related Contingent Consideration Payments	(3.8		)	—			—			(3.8		)
Dividends on Common Stock	(60.7		)	(57.4		)	(31.9		)	(30.3		)
Other Financing Activities	(0.8		)	(0.6		)	0.1			(0.9		)
Cash for Financing Activities	(13.6		)	(33.2		)
Cash from Financing Activities							80.1			22.0
Change in Cash, Cash Equivalents and Restricted Cash	127.6			22.7			(13.6		)	286.2
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	79.0			110.1			92.5			79.0
Cash, Cash Equivalents and Restricted Cash at End of Period		$206.6			$132.8			$78.9			$365.2

The accompanying notes are an integral part of these statements.

ALLETE

CONSOLIDATED STATEMENT OF ~~SHAREHOLDERS’~~ EQUITY

Unaudited


	Quarter Ended						Six Months Ended						Three Months Ended
	June 30,						June 30,						March 31,
	2019			2018			2019			2018			2020			2019
Millions Except Per Share Amounts
Common Stock
Balance, Beginning of Period		$1,431.1			$1,407.4			$1,428.5			$1,401.4			$1,436.7			$1,428.5
Common Stock Issued	2.2			8.0			4.8			14.0			5.0			2.6
Balance, End of Period	1,433.3			1,415.4			1,433.3			1,415.4			1,441.7			1,431.1

Accumulated Other Comprehensive Loss
Balance, Beginning of Period	(27.2		)	(27.9		)	(27.3		)	(28.2		)	(23.6		)	(27.3		)
Other Comprehensive Income - Net of Income Taxes
Unrealized Gain (Loss) on Debt Securities	0.1			—			0.2			(0.1		)	(0.4		)	0.1
Defined Benefit Pension and Other Postretirement Plans	0.2			0.3			0.2			0.7			0.2			—
Balance, End of Period	(26.9		)	(27.6		)	(26.9		)	(27.6		)	(23.8		)	(27.2		)

Retained Earnings
Balance, Beginning of Period	794.8			717.8			754.6			695.5			818.8			754.6
Net Income	34.2			31.3			104.7			82.3
Net Income Attributable to ALLETE													66.3			70.5
Common Stock Dividends	(30.4		)	(28.7		)	(60.7		)	(57.4		)	(31.9		)	(30.3		)
Balance, End of Period	798.6			720.4			798.6			720.4			853.2			794.8

Total Shareholders’ Equity		$2,205.0			$2,108.2			$2,205.0			$2,108.2
Non-Controlling Interest in Subsidiaries
Balance, Beginning of Period													103.7			—
Net Loss Attributable to Non-Controlling Interest													(1.8		)	—
Balance, End of Period													101.9			—

Total Equity														$2,373.0			$2,198.7

Dividends Per Share of Common Stock		$0.5875			$0.56			$1.175			$1.12			$0.6175			$0.5875

The accompanying notes are an integral part of these statements.

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, ~~2018~~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 ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, are not necessarily indicative of results that may be expected for any other interim period or for the year ending December 31, ~~2019~~2020. For further information, refer to the Consolidated Financial Statements and notes included in our ~~2018~~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, 2019,~~March 31, 2020, restricted cash amounts included in Prepayments and Other on the Consolidated Balance Sheet include collateral deposits required under an ALLETE Clean Energy loan agreement. In prior ~~periods~~period balances presented, the amounts also include U.S. Water Services' standby letters of credit. The restricted cash amounts included in Other Non-Current Assets represent collateral deposits required under an ALLETE Clean Energy loan agreement, PSAs and ~~PSAs.~~construction projects. In prior ~~periods~~period balances presented, the amounts also include 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, 2019		December 31, 2018		June 30, 2018		December 31, 2017		March 31, 2020		December 31, 2019		March 31, 2019		December 31, 2018
Millions
Cash and Cash Equivalents		$203.1		$69.1		$121.9		$98.9		$67.0		$69.3		$353.3		$69.1
Restricted Cash included in Prepayments and Other	0.9		1.3		2.3		2.6		6.1		2.8		7.2		1.3
Restricted Cash included in Other Non-Current Assets	2.6		8.6		8.6		8.6		5.8		20.4		4.7		8.6
Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows		$206.6		$79.0		$132.8		$110.1		$78.9		$92.5		$365.2		$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, 2019		December 31, 2018			March 31, 2020		December 31, 2019
Millions
Fuel (a)		$33.4		$26.0			$31.4		$25.9
Materials and Supplies	44.8		44.2			47.6		46.9
Raw Materials (b)	—		2.8
Work in Progress (b)	—		6.1
Finished Goods (b)	—		8.4
Reserve for Obsolescence (b)	—		(0.8		)
Total Inventories – Net		$78.2		$86.7			$79.0		$72.8


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


~~(b)~~	~~On March 26, 2019, ALLETE completed the sale of U.S. Water Services which resulted in the removal of the related inventory items from the Consolidated Balance Sheet.~~

~~NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)~~


Other Non-Current Assets	June 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Millions
Contract Assets (a)		$29.2		$30.7		$27.3		$28.0
Finance Receivable (b)	—		10.4
Operating Lease Right-of-use Assets (c)	31.2		—
Operating Lease Right-of-use Assets					26.8		28.6
ALLETE Properties	22.6		24.4		21.5		21.9
Restricted Cash					5.8		20.4
Other Postretirement Benefit Plans					38.0		37.5
Other	80.8		86.9		79.5		81.8
Total Other Non-Current Assets		$163.8		$152.4		$198.9		$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.


~~(b)~~	~~Finance Receivable related to the 2016 sale of Ormond Crossings and Lake Swamp, which was collected in the second quarter of 2019.~~


~~(c)~~	~~See Leases.~~

Other Current Liabilities June 30,
2019
December 31,
2018
Millions
Provision for Interim Rate Refund (a)
—

$40.0
PSAs
$12.4
12.6
Contract Liabilities (b)
—
7.6
Provision for Tax Reform Refund (c)
0.4
10.7
Contingent Consideration (d)
—
3.8
Operating Lease Liabilities (e)
7.2
—
Other 39.5
53.8
Total Other Current Liabilities
$59.5

$128.5


~~(a)~~	~~Provision for Interim Rate Refund was refunded to Minnesota Power’s retail customers in the second quarter of 2019.~~


~~(b)~~	~~Contract Liabilities consist of deposits received as a result of entering into contracts with our customers prior to completing our performance obligations.~~


~~(c)~~	Provision for Tax Reform Refund related to the income tax benefits of the TCJA in 2018 was refunded to Minnesota Power customers in the first quarter of 2019 and will be refunded to SWL&P customers in 2019 and 2020.


~~(d)~~	~~Contingent Consideration related to the earnings-based payment resulting from the U.S. Water Services acquisition was paid in the first quarter of 2019.~~


~~(e)~~	~~See Leases.~~

Other Non-Current Liabilities June 30,
2019
December 31,
2018
Millions
Asset Retirement Obligation
$142.7

$138.6
PSAs 70.7
76.9
Operating Lease Liabilities (a)
24.0
—
Other 45.4
47.1
Total Other Non-Current Liabilities
$282.8

$262.6


~~(a)~~	~~See Leases.~~

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)



Other Current Liabilities	March 31, 2020		December 31, 2019
Millions
PSAs		$12.4		$12.3
Operating Lease Liabilities	6.9		6.9
Other	38.3		41.2
Total Other Current Liabilities		$57.6		$60.4



Other Non-Current Liabilities	March 31, 2020		December 31, 2019
Millions
Asset Retirement Obligation		$163.2		$160.3
PSAs	61.5		64.6
Operating Lease Liabilities	20.0		21.8
Other	44.0		46.3
Total Other Non-Current Liabilities		$288.7		$293.0



Other Income
Three Months Ended March 31,	2020			2019
Millions
Pension and Other Postretirement Benefit Plan Non-Service Credits (a)		$2.6			$2.0
Interest and Investment Income (Loss)	(2.6		)	1.0
AFUDC - Equity	0.5			0.6
Gain on Land Sales	0.1			1.8
Other	0.4			2.0
Total Other Income		$1.0			$7.4


(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.

Six Months Ended June 30, 2019
2018
Millions
Cash Paid for Interest – Net of Amounts Capitalized
$33.8

$33.0
Noncash Investing and Financing Activities

Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment $21.1 $(39.4)
Reclassification of Property, Plant and Equipment to Inventory (a)
—

$46.3
Recognition of Right-of-use Assets and Lease Liabilities (b)
$31.2 —
Capitalized Asset Retirement Costs
$1.4

$20.8
AFUDC–Equity
$1.3

$0.5


~~(a)~~	In February 2018, Montana-Dakota Utilities exercised its option to purchase the Thunder Spirit II wind energy facility upon completion, resulting in a reclassification from Property, Plant and Equipment – Net to Inventories – Net for project costs incurred in the prior year.


~~(b)~~	~~See Leases.~~

~~New Accounting Pronouncements.~~

~~Recently Adopted Pronouncements~~

~~Disclosure Update and Simplification~~. In November 2018, the SEC adopted amendments to certain disclosure requirements. The amendments adopted include requirements that interim financial statements should include comparative statements for the same period in the prior financial year, except that the requirement for comparative balance sheet information may be satisfied by presenting the year-end balance sheet. It further includes a requirement analyzing the changes in each caption of shareholders’ equity either separately in a note or on the face of the financial statement. These amendments were effective for ALLETE in the first quarter of 2019. We have included the presentation of our Statement of Shareholders’ Equity to meet these requirements.

~~Leases.~~ In 2016, the FASB issued an accounting standard update which revised the existing guidance for leases. Under the revised guidance, lessees are required to recognize right-of-use assets and lease liabilities on the Consolidated Balance Sheet for leases with terms greater than 12 months. The new standard also requires additional qualitative and quantitative disclosures by lessees and lessors to enable users of the financial statements to assess the amount, timing and uncertainty of cash flows arising from leases. The accounting for leases by lessors and the recognition, measurement and presentation of expenses and cash flows from leases is not expected to significantly change as a result of the new guidance. The Company adopted this guidance in the first quarter of 2019 using the optional transition method and the package of practical expedients, which allowed for the adoption of the standard as of January 1, 2019, without restating previously disclosed information. Management elected the optional transition method of adoption due to the overall immateriality of the balance sheet gross up in the period of adoption. The package of practical expedients allowed management to not reassess the lease classification for leases, including those that had expired during the periods presented or that still existed at the time of adoption. We have included additional disclosures in the notes to the consolidated financial statements. (See ~~Leases~~.)

~~Leases.~~ We determine if a contract is, or contains, a lease at inception and recognize a right-of-use asset and lease liability for all leases with a term greater than 12 months. Our right-of-use assets and lease liabilities for operating leases are included in Other Non-Current Assets, Other Current Liabilities and Other Non-Current Liabilities, respectively, in our Consolidated Balance Sheet. We currently do not have any finance leases.

Right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent the obligation to make lease payments arising from the lease. Operating lease right-of-use assets and lease liabilities are recognized at the commencement date based on the estimated present value of lease payments over the lease term. As our leases do not provide an explicit rate, we determine the present value of future lease payments based on our estimated incremental borrowing rate using information available at the lease commencement date. The operating lease right-of-use asset includes lease payments to be made during the lease term and any lease incentives, as applicable.

~~NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)~~

~~Leases (Continued)~~

Our leases may include options to extend or buy out the lease at certain points throughout the term, and if it is reasonably certain that we will exercise that option at lease commencement, we include those rental payments in our calculation of the right-of-use asset and lease liability. Lease and rent expense is recognized on a straight-line basis over the lease term. Leases with a term of 12 months or less are not recognized on the Consolidated Balance Sheet.

The majority of our operating leases are for heavy equipment, vehicles and land with fixed monthly payments which we group into two categories: Vehicles and Equipment; and Land and Other. Our largest operating lease is for the dragline at BNI Energy which includes a termination payment at the end of the lease term if we do not exercise our purchase option. The amount of this payment is $3 million and is included in our calculation of the right-of-use asset and lease liability recorded. None of our other leases contain residual value guarantees.

~~Additional information on the components of lease cost and presentation of cash flows were as follows:~~

Quarter Ended Six Months Ended
June 30, June 30,
2019 2019
Millions
Operating Lease Cost
$2.8

$5.7

Other Information:
Operating Cash Flows From Operating Leases
$2.8

$5.7

~~Additional information related to leases was as follows:~~



	~~June 30,~~
	~~2019~~
~~Millions~~
~~Balance Sheet Information Related to Leases:~~
~~Other Non-Current Assets~~		~~$31.2~~
~~Total Operating Lease Right-of-use Assets~~		~~$31.2~~

~~Other Current Liabilities~~		~~$7.2~~
~~Other Non-Current Liabilities~~	~~24.0~~
~~Total Operating Lease Liabilities~~		~~$31.2~~

~~Weighted Average Remaining Lease Term (Years):~~
~~Operating Leases - Vehicles and Equipment~~	4
~~Operating Leases - Land and Other~~	29

~~Weighted Average Discount Rate:~~
~~Operating Leases - Vehicles and Equipment~~	~~3.2~~		%
~~Operating Leases - Land and Other~~	~~4.5~~		%

~~NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)~~

~~Leases (Continued)~~

~~Maturities of lease liabilities were as follows:~~

June 30, 2019
Millions
2019
$4.2
2020 7.9
2021 6.1
2022 4.9
2023 3.1
Thereafter 9.4
Total Lease Payments Due 35.6
Less: Imputed Interest 4.4
Total Lease Obligations 31.2
Less: Current Lease Obligations 7.2
Long-term Lease Obligations
$24.0



Three Months Ended March 31,	2020		2019
Millions
Cash Paid for Interest – Net of Amounts Capitalized		$18.3		$19.7
Recognition of Right-of-use Assets and Lease Liabilities	—			$34.0
Noncash Investing and Financing Activities
Increase (Decrease) in Accounts Payable for Capital Additions to Property, Plant and Equipment	$4.7		$(1.1)
Capitalized Asset Retirement Costs		$1.6		$1.6
AFUDC–Equity		$0.5		$0.6

Sale of U.S. Water Services. OnIn February 8, 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. ~~for a cash purchase price of $270 million. On~~In March ~~26,~~ 2019, ALLETE completed the sale and received approximately ~~$265~~$270 million in cash, ~~at closing,~~ net of transaction costs and cash retained. The Company recognized a gain on the sale of U.S. Water Services of ~~$11.1~~$9.9 million after-tax in the first quarter of 2019. The full year gain on sale of U.S. Water Services in 2019 was $13.2 million after-tax.

NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)

ALLETE Clean Energy Asset Acquisition. On ~~May 3, 2019,~~March 10, 2020, ALLETE Clean Energy acquired the ~~Diamond Spring~~rights to the Caddo wind project in Oklahoma from Apex Clean ~~Energy. ALLETE Clean~~ Energy ~~will build, own and operate the~~for approximately $8 million with additional payments required to be made at defined milestones. The full development of this approximately 300 MW wind project would involve the sale of energy ~~facility. The Diamond Spring wind project is fully contracted~~ to ~~sell wind power to Walmart Inc., Smithfield Foods, Inc. and Starbucks Corporation~~corporate customers under long-term power sales agreements. ~~Construction is expected~~

Non-Controlling Interest in Subsidiaries. Non-controlling interest in subsidiaries on the Consolidated Balance Sheet and net loss attributable to ~~begin~~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 three months ended March 31, 2020, related to the tax equity financing structure for ALLETE Clean Energy’s 106 MW Glen Ullin wind energy facility.

On April 16, 2020, ALLETE Clean Energy commenced operations of South Peak, an 80 MW wind energy facility in ~~late 2019~~Montana, and ~~be completed~~on April 29, 2020, received approximately $70 million in cash from a third-party investor as part of a tax equity financing for the ~~second half of 2020.~~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 ~~2018~~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 ~~$17.4~~$9.6 million for the ~~six~~three months ended ~~June 30, 2019~~March 31, 2020 ($~~52.1~~7.4 million for ~~six~~three months ended ~~June 30, 2018)~~March 31, 2019). ~~With the implementation of final rates in Minnesota Power’s general rate case, certain revenue previously recognized under cost recovery riders was incorporated into base rates. (See~~

~~2016~~2020 Minnesota General Rate ~~Case~~Case. .)

~~2016~~On November 1, 2019, Minnesota ~~General Rate Case.~~Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 10.6 percent for retail customers. The ~~MPUC issued an order dated March 12, 2018, in Minnesota Power’s general~~ rate ~~case approving~~filing seeks a return on ~~common~~ equity of ~~9.25~~10.05 percent and a 53.81 percent equity ratio. ~~Final rates went into effect on December 1, 2018, which is expected to result~~On an annualized basis, the requested final rate increase would generate approximately $66 million in additional ~~revenue~~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. We cannot predict the level of final rates that may be authorized by the MPUC.

On April 23, 2020, Minnesota Power filed a request with the MPUC that proposes a resolution for Minnesota Power’s 2020 general rate case. Key components of our proposal include removing the current 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 of approximately ~~$13~~$12 million on an annualized basis. Interim rates were collected from January 1, 2017, through November 30, 2018, which were fully offset by the recognition of a corresponding reserve. Minnesota Power recorded a reserve for an interim rate refund, net of discounts provided to EITE customers, of $40.0($9 million as of ~~December~~March 31, ~~2018, which was refunded~~2020,); increasing ongoing customer rates 4.1 percent compared to the 5.8 percent increase reflected in current interim rates; and a provision that Minnesota Power would not file another rate case until at least March 1, 2021, unless certain events occur. Minnesota Power would withdraw its general rate case upon approval of this filing and proposed resolution by the ~~second quarter~~MPUC. At a hearing on April 30, 2020, the MPUC approved lowering current interim rates to 4.1 percent effective May 1, 2020, as requested by Minnesota Power in this filing. A final decision on Minnesota Power’s full proposal in this filing is expected in June 2020. At this time, we are unable to predict whether the MPUC will ultimately approve this filing and proposed resolution, and thus, as of ~~2019.~~March 31, 2020, we have not recorded reserves for interim rates.

NOTE 2. REGULATORY MATTERS (Continued)

Electric Rates (Continued)

~~2018 Wisconsin General Rate Case.~~ In an order dated December 20, 2018, the PSCW approved a rate increase for SWL&P including a return on equity of 10.4 percent and a 55.0 percent equity ratio. Final rates went into effect January 1, 2019, which is expected to result in additional revenue of approximately $1.3 million on an annualized basis.

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. (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.

Fuel Adjustment Clause Reform. In a ~~December~~ 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.

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 ~~MPUC.~~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 COVID-19, and to defer and record such costs as a regulatory asset, subject to recovery in a future proceeding.

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. Minnesota Power’s next IRP filing is due October 1, 2020.

Nemadji Trail Energy Center. In 2017, Minnesota Power submitted a resource package to the MPUC which included requesting ~~approval of PPAs for the output of a 250 MW wind energy facility and a 10 MW solar energy facility as well as~~ 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~~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. Separately, the MPUC 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. 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. A decision on the application is expected in 2020.~~

~~Conservation Improvement Program.~~ On April 1, 2019, Minnesota Power submitted its 2018 consolidated filing, which detailed Minnesota Power’s CIP program results and requested a CIP financial incentive of $2.8 million based upon MPUC procedures,PSCW, which was approved by the ~~MPUC~~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 March 31, 2020, is approximately $13 million.

MISO Return on Equity Complaint. MISO transmission owners, including ALLETE and ATC, have an authorized return on equity of 9.88 percent, or 10.38 percent including an incentive adder for participation in a regional transmission organization, based on a November 2019 FERC order. In this order, the FERC reduced the base return on equity for regional transmission organizations as recommended by an ~~order dated July 19, 2019. In 2018,~~administrative law judge with refunds ordered for prior periods, which are immaterial to ALLETE. Multiple parties to the ~~CIP financial incentive~~complaint have filed requests for rehearing of ~~$3.0 million was recognized in~~ the ~~third quarter upon approval by the MPUC of Minnesota Power’s 2017 CIP consolidated filing. CIP financial incentives are recognized in the period in which the MPUC approves the filing.~~FERC order.

NOTE 2. REGULATORY MATTERS (Continued)

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

~~NOTE 2. REGULATORY MATTERS (Continued)~~


Regulatory Assets and Liabilities	June 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Millions
Non-Current Regulatory Assets
Defined Benefit Pension and Other Postretirement Benefit Plans		$216.5		$218.5		$211.1		$212.9
Income Taxes	102.2		105.5		121.0		123.4
Cost Recovery Riders					34.1		24.7
Asset Retirement Obligations	32.3		32.6		31.8		32.0
Boswell 1 and 2 Net Plant and Equipment	13.5		16.3
Cost Recovery Riders	10.0		—
Boswell Units 1 and 2 Net Plant and Equipment					9.3		10.7
Manufactured Gas Plant	8.1		8.0		8.3		8.2
PPACA Income Tax Deferral	4.9		5.0		4.7		4.8
Other	3.7		3.6		3.5		3.8
Total Non-Current Regulatory Assets		$391.2		$389.5		$423.8		$420.5

Current Regulatory Liabilities (a)
Provision for Interim Rate Refund (b)	—			$40.0
Transmission Formula Rates Refund		$3.1	4.4			$1.3		$1.7
Provision for Tax Reform Refund (c)	0.4		10.7
Provision for Tax Reform Refund					0.2		0.2
Total Current Regulatory Liabilities	3.5		55.1		1.5		1.9
Non-Current Regulatory Liabilities
Income Taxes	386.2		396.4		397.1		407.2
Wholesale and Retail Contra AFUDC	70.6		64.4		84.2		79.3
Plant Removal Obligations	29.3		25.1		37.4		35.5
Defined Benefit Pension and Other Postretirement Benefit Plans					15.6		17.0
North Dakota Investment Tax Credits	12.3		14.7		12.3		12.3
Fuel Adjustment Clause (b)					8.4		—
Conservation Improvement Program	7.0		1.5		7.4		5.4
Transmission Formula Rates Refund	0.8		1.6
Cost Recovery Riders	—		6.9
Other	2.6		1.5		4.0		3.6
Total Non-Current Regulatory Liabilities	508.8		512.1		566.4		560.3
Total Regulatory Liabilities		$512.3		$567.2		$567.9		$562.2


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


(b)	~~This~~Fuel adjustment clause regulatory liability represents the amount ~~was refunded~~expected to ~~Minnesota Power’s regulated retail customers in the second quarter of 2019.~~


~~(c)~~	~~Provision for Tax Reform Refund related to the income tax benefits of the TCJA in 2018 was refunded to Minnesota Power customers in the first quarter of 2019 and will~~ be refunded to ~~SWL&P~~ customers ~~in 2019 and 2020.~~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 ~~inve~~s~~tment~~investment in ATC under the equity method of accounting. In the~~six~~ three months ended ~~June 30, 2019,~~March 31, 2020, we ~~invested $2.7~~invested $0.4 million in ATC, andand on ~~July 31, 2019,~~ weApril 30, 2020, we invested an additional ~~$1.9~~$0.8 million. We expect to make ~~approximately $4~~additional investments of $1.6 million in ~~additional investments in 2019.~~2020.



ALLETE’s Investment in ATC
Millions
Equity Investment Balance as of December 31, ~~2018~~2019		$~~128.1~~141.6
Cash Investments	~~2.7~~0.4
Equity in ATC Earnings	~~10.4~~5.2
Distributed ATC Earnings	(~~8.2~~5.2		)
Amortization of the Remeasurement of Deferred Income Taxes	~~0.6~~0.3
Equity Investment Balance as of ~~June 30, 2019~~March 31, 2020		$~~133.6~~142.3

ATC’s authorized return on equity is ~~10.32~~9.88 percent, or ~~10.82 percent including an incentive adder for participation in a regional transmission organization.~~

~~NOTE 3. EQUITY INVESTMENTS (Continued)~~

~~Investment in ATC (Continued)~~

~~In 2016, a federal administrative law judge ruled on a complaint proposing a reduction in the base return on equity to 9.70 percent, or 10.20~~10.38 percent including an incentive adder for participation in a regional transmission organization ~~subject to approval or adjustment by the FERC. A final decision from the~~based on a November 2019 FERC ~~on the administrative law judge’s recommendation is pending.~~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, 2019,~~March 31, 2020, our equity investment in Nobles 2 was ~~$26.6~~$83.4 million ($~~33.0~~56.0 million at December 31, ~~2018)~~2019). In the ~~first quarter of 2019,~~three months ended March 31, 2020, we invested $27.4 million in Nobles 2, ~~returned capital of $8.3 million based on its cash needs.~~and in April 2020 we invested an additional $21.7 million. We expect to make approximately ~~$33~~$65 million in additional investments in ~~2019.~~2020.

NOTE 4. ~~GOODWILL AND INTANGIBLE ASSETS~~

~~As a result of completing the sale of U.S. Water Services on March 26, 2019, there was no goodwill recorded as of June 30, 2019 ($148.5 million at December 31, 2018).~~

~~The balance of intangible assets, net, as of June 30, 2019, is as follows:~~

December 31,
2018
Amortization
Other (b)
June 30,
2019
Millions
Intangible Assets
Definite-Lived Intangible Assets
Customer Relationships
$50.7
$(1.1) $(49.6) —
Developed Technology and Other (a)
7.5
(0.3) (6.1)
$1.1
Total Definite-Lived Intangible Assets 58.2
(1.4) (55.7) 1.1
Indefinite-Lived Intangible Assets
Trademarks and Trade Names 16.6
n/a (16.6) —
Total Intangible Assets
$74.8
$(1.4) $(72.3)
$1.1


~~(a)~~	~~Developed Technology and Other includes patents, non-compete agreements, land easements and trade names with finite lives.~~


~~(b)~~	~~On March 26, 2019, ALLETE completed the sale of U.S. Water Services which resulted in the removal of the related intangible assets from the Consolidated Balance Sheet.~~

Amortization expense for intangible assets was $1.4 million for the six months ended June 30, 2019 ($2.7 million for the six months ended June 30, 2018). The remaining definite-lived intangible assets will continue to be amortized ratably through 2028.

~~NOTE 5.~~ FAIR VALUE

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the market approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. These inputs, which are used to measure fair value, are prioritized through the fair value hierarchy. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Descriptions of the three levels of the fair value hierarchy are discussed in Note 9.7. Fair Value to the Consolidated Financial Statements in our ~~2018~~2019 Form 10-K.

~~NOTE 5. FAIR VALUE (Continued)~~

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, 2019~~March 31, 2020, and December 31, ~~2018~~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.

Fair Value as of June 30, 2019
Recurring Fair Value Measures Level 1
Level 2
Level 3
Total
Millions
Assets
Investments (a)

Available-for-sale – Equity Securities
$10.9
—
—

$10.9
Available-for-sale – Corporate and Governmental Debt Securities (b)
—

$9.5
—
9.5
Cash Equivalents 1.1
—
—
1.1
Total Fair Value of Assets
$12.0

$9.5
—

$21.5

Liabilities
Deferred Compensation (c)
—

$21.7
—

$21.7
Total Fair Value of Liabilities —

$21.7
—

$21.7
Total Net Fair Value of Assets (Liabilities)
$12.0
$(12.2) —
$(0.2)

Fair Value as of December 31, 2018
Recurring Fair Value Measures Level 1
Level 2
Level 3
Total
Millions
Assets
Investments (a)

Available-for-sale – Equity Securities
$12.2
—
—

$12.2
Available-for-sale – Corporate and Governmental Debt Securities —

$8.0
—
8.0
Cash Equivalents 1.0
—
—
1.0
Total Fair Value of Assets
$13.2

$8.0
—

$21.2

Liabilities
Deferred Compensation (c)
—

$19.8
—

$19.8
U.S. Water Services Contingent Consideration (d)
—
—

$3.8
3.8
Total Fair Value of Liabilities —

$19.8

$3.8

$23.6
Total Net Fair Value of Assets (Liabilities)
$13.2
$(11.8) $(3.8) $(2.4)

NOTE 4. FAIR VALUE (Continued)



	Fair Value as of March 31, 2020
Recurring Fair Value Measures	Level 1		Level 2		Level 3	Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities		$8.4	—		—		$8.4
Available-for-sale – Corporate and Governmental Debt Securities (b)	—			$9.3	—	9.3
Cash Equivalents	0.8		—		—	0.8
Total Fair Value of Assets		$9.2		$9.3	—		$18.5

Liabilities
Deferred Compensation (c)	—			$19.3	—		$19.3
Total Fair Value of Liabilities	—			$19.3	—		$19.3
Total Net Fair Value of Assets (Liabilities)		$9.2	$(10.0)		—	$(0.8)


	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, 2019,~~March 31, 2020, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was ~~$3.1~~$2.9 million, in one year to less than three years was ~~$3.9~~$5.9 million, in three years to less than five years was ~~$1.6~~$0.2 million and in five or more years was ~~$0.9~~$0.3 million.


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


~~(d)~~	~~Included in Other Current Liabilities on the Consolidated Balance Sheet.~~

The Level 3 liability in the preceding table is related to the contingent consideration liability that resulted from the 2015 acquisition of U.S. Water Services. Based on the terms and conditions of the acquisition agreement, a final payout of $3.8 million was made in the first quarter of 2019 for the remaining outstanding shares.

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 ~~for~~of the item listed in the following table was based on quoted market prices for the same or similar instruments (Level 2).

~~NOTE 5. FAIR VALUE (Continued)~~


Financial Instruments	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Millions
Long-Term Debt, Including Long-Term Debt Due Within One Year
June 30, 2019	$1,543.0	$1,684.3
December 31, 2018	$1,495.2	$1,534.6
March 31, 2020			$1,731.3	$1,880.2
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~~three months ended ~~June 30, 2019,~~March 31, 2020, and the year ended December 31, ~~2018,~~2019, there were no ~~triggering events or~~ indicators of impairment for these non-financial assets.

NOTE 6.5. SHORT-TERM AND LONG-TERM DEBT

The following tables present the Company’s short-term and long-term debt as of ~~June 30, 2019,~~March 31, 2020, and December 31, ~~2018:~~2019:


June 30, 2019	Principal		Unamortized Debt Issuance Costs	Total
March 31, 2020						Principal		Unamortized Debt Issuance Costs	Total
Millions
Short-Term Debt		$28.1	$(0.4)		$27.7		$323.3	$(0.3)		$323.0
Long-Term Debt	1,514.9		(9.0)	1,505.9		1,408.0		(8.1)	1,399.9
Total Debt		$1,543.0	$(9.4)		$1,533.6		$1,731.3	$(8.4)		$1,722.9


December 31, 2018	Principal		Unamortized Debt Issuance Costs	Total
December 31, 2019						Principal		Unamortized Debt Issuance Costs	Total
Millions
Short-Term Debt		$57.9	$(0.4)		$57.5		$213.3	$(0.4)		$212.9
Long-Term Debt	1,437.3		(8.8)	1,428.5		1,409.3		(8.4)	1,400.9
Total Debt		$1,495.2	$(9.2)		$1,486.0		$1,622.6	$(8.8)		$1,613.8

On January 10, 2019, ALLETE entered into an amended and restated $400 million credit agreement, as amended (Credit Agreement). The Credit Agreement is unsecured, has a variable interest rate and will expire in January 2024. At ALLETE’s request and subject to certain conditions, the Credit Agreement may be increased by up to $150 million and ALLETE may make two requests to extend the maturity date, each for a one-year extension. Advances may be used by ALLETE for general corporate purposes, to provide liquidity in support of ALLETE’s commercial paper program and to issue up to $100 million in letters of credit.

We had ~~$56.3~~$66.3 million outstanding in standby letters of credit and no$0.2 million in outstanding draws under our lines of credit as of ~~June 30, 2019~~March 31, 2020 ($~~18.4~~62.0 million in standby letters of credit and no0 outstanding draws as of December 31, ~~2018)~~2019).

On January 10, 2020, ALLETE entered into a $200 million unsecured term loan agreement (Term Loan) of which we have borrowed $110 million as of March 31, 2020. The Term Loan provides for the ability to borrow up to an additional $90 million, 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 will be used for construction-related expenditures.

On March ~~1, 2019,~~26, 2020, ALLETE agreed to sell first mortgage bonds (Bonds) to certain institutional buyers in the private placement market, which will be issued ~~and sold the following First Mortgage Bonds (the Bonds):~~on or before August 3, 2020, in two series as follows:



Maturity Date	Principal Amount	Interest Rate
~~March~~August 1, ~~2029~~2030	$7046 Million	~~4.08%~~2.50%
~~March~~August 1, ~~2049~~2050	$3094 Million	~~4.47%~~3.30%

ALLETE ~~has~~will have the option to prepay all or a portion of the Bonds at its discretion, subject to a make-whole provision. The Bonds ~~are~~will be subject to additional terms and conditions which are customary for these types of transactions. ALLETE ~~intends~~plans to use the proceeds from the sale of the Bonds to fund utility capital investment and for general corporate purposes. The Bonds ~~were~~will be 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.

~~NOTE 6. SHORT-TERM AND LONG-TERM DEBT (Continued)~~On April 8, 2020, ALLETE entered into a $115 million unsecured term loan agreement (Term Loan) and borrowed $95 million upon execution. The Term Loan provides for an additional draw of $20 million on or after July 1, 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, 2019~~March 31, 2020, our ratio was approximately ~~0.42~~0.43 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, 2019~~March 31, 2020, ALLETE was in compliance with its financial covenants.

NOTE 7.6. 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 ~~11.~~9. Commitments, Guarantees and Contingencies to the Consolidated Financial Statements in our ~~2018~~2019 Form 10-K, with additional disclosure provided in the following paragraphs.

Square Butte PPA. As of ~~June 30, 2019~~March 31, 2020, Square Butte had total debt outstanding of ~~$301.9~~$276.2 million. Fuel expenses are recoverable through Minnesota Power’s fuel adjustment clause and include the cost of coal purchased from BNI Energy under a long-term contract. Minnesota Power’s cost of power purchased from Square Butte during the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, was ~~$41.1~~$20.1 million ($~~37.7~~20.5 million for the ~~six months ended June 30, 2018)~~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 ~~$4.2~~$1.9 million ($~~4.6~~2.1 million for the same period in ~~2018)~~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 ~~2019~~2020 and in ~~2018.~~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 2019 and a~~ 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 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 is required. As a result, Minnesota Power is constructing 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.

~~NOTE 7. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)~~

~~Transmission (Continued)~~

In a 2016 order, the MPUC approved the route permit for the GNTL, and in 2016, the U.S. Department of Energy issued a presidential permit to cross the ~~U.S.‑Canadian~~U.S.-Canadian border, which was the final major regulatory approval needed before construction in the U.S. could begin. Construction activities commenced in the first quarter of 2017, and ~~with construction on schedule,~~ Minnesota Power expects the GNTL to be ~~complete and~~ in-service by mid-2020. The total project cost in the U.S., including substation work, is estimated to be approximately ~~$750~~$700 million, of which Minnesota Power’s portion is expected to be approximately ~~$345~~$325 million; the difference will be recovered from a subsidiary of Manitoba Hydro as non-shareholder contributions to capital. Total project costs of ~~$510.8~~$647.7 million have been incurred through ~~June 30, 2019,~~March 31, 2020, of which ~~$272.7~~$344.6 million has been recovered from a subsidiary of Manitoba Hydro.

In ~~2015,~~June 2019, Manitoba Hydro ~~submitted~~announced the ~~final preferred route and EIS for~~Canadian federal government’s approval of the MMTP ~~to the Manitoba Conservation~~project and ~~Water Stewardship for siting and environmental approval, which was received on April 4, 2019. In 2016, Manitoba Hydro filed an application with~~in August 2019, the Canadian National Energy Board ~~(NEB) requesting authorization to construct and operate~~granted final pre-construction approvals. Construction on the MMTP ~~which was recommended for approval on November 15, 2018.~~commenced in the third quarter of 2019. On ~~June 14, 2019,~~April 16, 2020, Manitoba Hydro announced ~~Canada’s federal government approved~~that construction of the MMTP ~~project, subject~~was complete and that testing and commissioning of the line, communications equipment and substation will take place to ~~certain compliance conditions.~~

meet the anticipated in-service deadline of June 1, 2020. The MMTP is still subject to legal ~~and regulatory~~ challenges which Minnesota Power is actively monitoring. Manitoba Hydro has informed Minnesota Power that it continues to work towards completing the MMTP on schedule. In order to meet the transmission in‑service requirements in PPAs with Minnesota Power, Manitoba Hydro has indicated that it would need to start construction of the MMTP by September 2019. We are unable to predict the outcome of the Canadian regulatory review process, including the timing thereof or whether any onerous conditions may be imposed, or the timing of the completion of the MMTP, including the impact of any delays that may result in construction schedule adjustments. In the event the MMTP is delayed and not in-service by June 1, 2020, Minnesota Power has construction and related agreements in place with Manitoba Hydro and a Manitoba Hydro subsidiary that will protect Minnesota Power and its customers.

NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Transmission (Continued)

Construction of Manitoba Hydro’s Keeyask hydroelectric generation facility, which will provide the power to be sold under PPAs with Minnesota Power and transmitted on the MMTP and the GNTL, commenced in 2014 and is anticipated to be ~~in service~~completely in-service by early 2021.

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 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.

~~NOTE 7. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)~~

~~Environmental Matters (Continued)~~

Cross-State Air Pollution Rule (CSAPR). The CSAPR requires certain states in the eastern half of the U.S., including Minnesota, to reduce power plant emissions that contribute to ozone or fine particulate pollution in other states. The CSAPR does not require installation of controls but does require facilities have sufficient allowances to cover their emissions on an annual basis. These allowances are allocated to facilities from each state’s annual budget, and can be bought and sold. Based on our review of the NO_x and SO₂ allowances issued and pending issuance, we currently expect generation levels and emission rates will result in continued compliance with the CSAPR.

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. None of the compliance costs for proposed or current NAAQS revisions are 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; increased 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 this was that the CPP attempted 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 4.4 and the currently economically idled Taconite Harbor 1 and 2.

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 ~~(SIP)~~(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.

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. (See Note 2. Regulatory Matters.) 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 7. 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.

NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

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 mid to late 2020.

The ~~final~~ 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.~~future if additional water treatment measures are implemented. Under the ~~existing~~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. ~~If FGD wastewater is discharged in the future, it will require additional wastewater treatment.~~ 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~~re-use options in its plant processes. The EPA’s additional reconsideration of legacy wastewater discharge requirements have the potential to reduce time lines 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 cannot estimate what compliance costs we might incur related to these or other potential future water discharge regulations; however, the costs could be material, including costs associated with retrofits for bottom ash handling, pond dewatering, pond closure, and 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 ~~lined~~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. The EPA has indicated to Minnesota Power that the landfill at Taconite Harbor, which has been idled and has a temporary landfill cover in place, is a CCR unit based on the EPA’s interpretation of the CCR rule language.

~~Minnesota Power has agreed to post the required CCR information for the Taconite Harbor landfill on Minnesota Power’s website while the CCR issue is resolved.~~ Compliance costs for CCR at Taconite Harbor are not expected to be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.

Minnesota Power continues to work on minimizing costs through evaluation of beneficial re-use and recycling of CCR and CCR‑related waters. In 2017, the EPA announced its intention to formally reconsider the CCR rule under Subtitle D of the RCRA 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~~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 ~~changes~~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. Compliance costs at Boswell due to the court decision are unknown at this time. Minnesota Power would seek recovery of additional costs through a rate proceeding.

NOTE 7.6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)

Environmental Matters (Continued)

Other Environmental Matters

Manufactured Gas Plant Site. We are reviewing and addressing environmental conditions at a former manufactured gas plant site located in Superior, Wisconsin. 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, 2019,~~March 31, 2020, we have recorded a liability of approximately $7 million for remediation costs at this site (approximately $7 million as of December 31, ~~2018), and~~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.

ALLETE Clean Energy. ALLETE Clean Energy’s wind energy facilities have PSAs in place for their entire output and expire in various years between ~~2019~~2022 and ~~2032.~~2039. As of ~~June 30, 2019,~~March 31, 2020, ALLETE Clean Energy has ~~$58.4~~$59.6 million outstanding in standby letters of ~~credit.~~credit, the majority of which are held as security under these PSAs and PSAs for wind energy facilities under development.

BNI Energy. As of ~~June 30, 2019,~~March 31, 2020, BNI Energy had surety bonds outstanding of ~~$66.5~~$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 ~~$65.8~~$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, 2019,~~March 31, 2020, ALLETE Properties had surety bonds outstanding and letters of credit to governmental entities totaling ~~$8.6~~$4.1 million primarily related to development and maintenance obligations for various projects. The estimated cost of the remaining development work is ~~$6.1~~$2.0 million. ALLETE Properties does not believe it is likely that any of these outstanding surety bonds or letters of credit will be drawn upon.

Community Development District Obligations. As of ~~June 30, 2019~~March 31, 2020, we owned 6653 percent of the assessable land in the Town Center District ~~(68~~(53 percent as of December 31, ~~2018) and 12 percent of the assessable land in the Palm Coast Park District (19 percent as of~~ ~~December 31, 2018~~)2019). As of ~~June 30, 2019~~March 31, 2020, ownership levels, our annual assessments related to capital improvement and special assessment bonds for the ALLETE Properties ~~projects~~project within ~~these districts are~~the district is approximately ~~$1.4 million for Town Center at Palm Coast and $0.6 million for Palm Coast Park.~~$1.9 million. As we sell property at ~~these projects,~~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 8.7. 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.


			2019					2018					2020					2019
Reconciliation of Basic and Diluted			Dilutive					Dilutive					Dilutive					Dilutive
Earnings Per Share	Basic		Securities	Diluted		Basic		Securities	Diluted		Basic		Securities	Diluted		Basic		Securities	Diluted
Millions Except Per Share Amounts
Quarter ended June 30,
Net Income		$34.2			$34.2		$31.3			$31.3
Three Months Ended March 31,
Net Income Attributable to ALLETE												$66.3			$66.3		$70.5			$70.5
Average Common Shares	51.6		0.1	51.7		51.3		0.2	51.5		51.7		0.1	51.8		51.6		0.1	51.7
Earnings Per Share		$0.66			$0.66		$0.61			$0.61		$1.28			$1.28		$1.37			$1.37
Six Months Ended June 30,
Net Income		$104.7			$104.7		$82.3			$82.3
Average Common Shares	51.6		0.1	51.7		51.2		0.2	51.4
Earnings Per Share		$2.03			$2.02		$1.61			$1.60

NOTE 9.8. INCOME TAX EXPENSE


	Quarter Ended				Six Months Ended						Three Months Ended
	June 30,				June 30,						March 31,
	2019		2018		2019			2018			2020		2019
Millions
Current Income Tax Expense (Benefit) (a)
Current Income Tax Expense (a)
Federal	—		—		—			—			—		—
State	$(0.1)		$(0.3)			$0.2			$0.4		—			$0.3
Total Current Income Tax Expense (Benefit)	$(0.1)		$(0.3)			$0.2			$0.4
Total Current Income Tax Expense											—			$0.3
Deferred Income Tax Expense (Benefit)
Federal (b)	$(7.1)		$(7.4)		$(16.8)			$(14.2)			$(17.6)		$(9.7)
State (c)	2.5		2.4		15.0			5.0			4.0		12.5
Investment Tax Credit Amortization	(0.1	)	(0.1	)	(0.3		)	(0.3		)	(0.2	)	(0.2		)
Total Deferred Income Tax Benefit	$(4.7)		$(5.1)		$(2.1)			$(9.5)
Total Income Tax Benefit	$(4.8)		$(5.4)		$(1.9)			$(9.1)
Total Deferred Income Tax Expense (Benefit)											$(13.8)			$2.6
Total Income Tax Expense (Benefit)											$(13.8)			$2.9

(a)

For each of the ~~six~~three months ended ~~June 30,~~March 31, 2020, and 2019, ~~and 2018,~~ the federal and state current tax expense was minimal due to NOLs which resulted from the bonus depreciation provisions of the Protecting Americans from Tax Hikes Act of 2015, the Tax Increase Prevention Act of 2014 and the American Taxpayer Relief Act of 2012. Federal and state NOLs are being carried forward to offset current and future taxable income.


(b)	For each of the ~~six~~three months ended ~~June 30,~~March 31, 2020, and 2019, ~~and 2018,~~ the federal income tax benefit is primarily due to production tax credits.


(c)	For the ~~six~~three months ended ~~June 30,~~March 31, 2019,, the state income tax expense is primarily ~~due~~related to the sale of U.S. Water Services.

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.

~~NOTE 9. INCOME TAX EXPENSE (Continued)~~


	Quarter Ended						Six Months Ended						Three Months Ended
Reconciliation of Taxes from Federal Statutory	June 30,												March 31,
Rate to Total Income Tax Expense	2019			2018			2019			2018			2020			2019
Millions
Income Before Income Taxes		$29.4			$25.9			$102.8			$73.2			$50.7			$73.4
Statutory Federal Income Tax Rate	21		%	21		%	21		%	21		%	21		%	21		%
Income Taxes Computed at Statutory Federal Rate		$6.2			$5.4			$21.6			$15.4			$10.6			$15.4
Increase (Decrease) in Income Tax Due to:
State Income Taxes – Net of Federal Income Tax Benefit	1.9			1.6			12.0			4.2			3.2			10.1
Production Tax Credits	(9.8		)	(11.2		)	(26.1		)	(25.6		)	(23.8		)	(16.3		)
Regulatory Differences – Excess Deferred Tax	(1.6		)	(2.2		)	(4.8		)	(4.4		)	(4.4		)	(3.2		)
U.S. Water Services Sale of Stock Basis Difference	(0.7		)	—			1.7			—			—			2.4
Share-Based Compensation	—			—			(0.9		)	(0.5		)	(0.1		)	(0.9		)
Other	(0.8		)	1.0			(5.4		)	1.8			0.7			(4.6		)
Total Income Tax Benefit	$(4.8)			$(5.4)			$(1.9)			$(9.1)
Total Income Tax Expense (Benefit)													$(13.8)			$2.9

For the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, the effective tax rate was a benefit of ~~1.8~~27.2 percent ~~(benefit~~(expense of ~~12.4~~4.0 percent for the ~~six~~three months ended ~~June 30, 2018)~~March 31, 2019). The effective tax rate for 2020 was primarily impacted by production tax credits. The effective tax rate for 2019 was ~~a lower benefit~~ primarily ~~due to a higher~~impacted by production tax ~~rate on~~credits and the gain on ~~the~~ sale of U.S. Water ~~Services and higher pre-tax income.~~Services.

Uncertain Tax Positions. As of ~~June 30, 2019,~~March 31, 2020, we had gross unrecognized tax benefits of ~~$1.3~~$1.4 million ($~~1.6~~1.4 million as of December 31, ~~2018)~~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.

NOTE 8. INCOME TAX EXPENSE (Continued)

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 ~~2015,~~2016, or state examination for years before ~~2014.~~2015.

NOTE ~~10.~~9. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS


	Pension						Other Postretirement						Pension						Other Postretirement
Components of Net Periodic Benefit Cost	2019			2018			2019			2018
Components of Net Periodic Benefit Cost (Credit)													2020			2019			2020			2019
Millions
Quarter Ended June 30,
Three Months Ended March 31,
Service Cost		$2.4			$2.8			$1.0			$1.3			$2.6			$2.3			$0.8			$1.0
Non-Service Cost Components (a)
Interest Cost	8.0			7.4			1.9			1.8			7.0			8.0			1.3			1.9
Expected Return on Plan Assets	(11.1		)	(11.1		)	(2.7		)	(2.8		)	(10.7		)	(11.0		)	(2.5		)	(2.6		)
Amortization of Prior Service Credits	(0.1		)	—			(0.4		)	(0.5		)	—			—			(2.0		)	(0.4		)
Amortization of Net Loss	1.9			3.0			0.1			0.2			3.2			1.8			0.3			0.1
Net Periodic Benefit Cost		$1.1			$2.1		$(0.1)			—

Six Months Ended June 30,
Service Cost		$4.7			$5.5			$2.0			$2.5
Non-Service Cost Components (a)
Interest Cost	16.0			14.8			3.8			3.6
Expected Return on Plan Assets	(22.1		)	(22.1		)	(5.3		)	(5.5		)
Amortization of Prior Service Credits	(0.1		)	—			(0.8		)	(0.9		)
Amortization of Net Loss	3.7			6.0			0.2			0.4
Net Periodic Benefit Cost		$2.2			$4.2		$(0.1)				$0.1
Net Periodic Benefit Cost (Credit)														$2.1			$1.1		$(2.1)			—


(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~~three months ended ~~June 30, 2019,~~March 31, 2020, we contributed ~~$10.4~~$10.7 million in cash to the defined benefit pension plans ($~~15.0~~10.4 million for the ~~six~~three months ended ~~June 30, 2018)~~March 31, 2019); we do ~~not~~0t expect to make additional contributions to our defined benefit pension plans in ~~2019.~~2020. For the ~~six~~three months ended ~~June 30,~~March 31, 2020, and 2019, ~~and 2018,~~ we made no0 contributions to our other postretirement benefit plans; we do ~~not~~0t expect to make any contributions to our other postretirement benefit plans in ~~2019.~~2020.

NOTE ~~11.~~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~~3 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 ~~reflects~~is reflected in operating results until ~~the closing date of its sale on~~it was sold in March ~~26,~~ 2019. ~~The ALLETE Clean Energy and U.S. Water Services reportable segments comprise our Energy Infrastructure and Related Services businesses.~~ We also present Corporate and Other which includes ~~two~~2 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 ~~11.~~10. BUSINESS SEGMENTS (Continued)


	Quarter Ended					Six Months Ended						Three Months Ended
	June 30,					June 30,						March 31,
	2019		2018			2019			2018			2020			2019
Millions
Operating Revenue
Regulated Operations
Residential		$29.2		$30.7			$74.4			$71.4			$40.9			$45.2
Commercial	34.9		36.2			73.8			72.8			37.3			38.9
Municipal	12.2		13.7			27.6			27.7			10.3			15.4
Industrial	120.3		115.3			241.9			230.2			118.8			121.6
Other Power Suppliers	35.2		42.7			74.6			86.4			38.3			39.4
Other	18.0		19.2			39.7			39.5			19.7			21.7
Total Regulated Operations	249.8		257.8			532.0			528.0			265.3			282.2

Energy Infrastructure and Related Services

ALLETE Clean Energy
Long-term PSA	12.5		12.4			27.1			31.0			17.3			14.6
Other	2.9		5.9			5.8			11.9			2.8			2.9
Total ALLETE Clean Energy	15.4		18.3			32.9			42.9			20.1			17.5

U.S. Water Services (a)
Point-in-Time	—		25.7			19.0			48.0			—			19.0
Contract	—		9.5			9.2			19.0			—			9.2
Capital Project	—		6.3			5.2			12.7			—			5.2
Total U.S. Water Services	—		41.5			33.4			79.7			—			33.4

Corporate and Other
Long-term Contract	21.2		22.7			41.4			42.7			22.4			20.2
Other	4.0		3.8			7.9			9.0			3.8			3.9
Total Corporate and Other	25.2		26.5			49.3			51.7			26.2			24.1
Total Operating Revenue		$290.4		$344.1			$647.6			$702.3			$311.6			$357.2
Net Income (Loss)
Net Income (Loss) Attributable to ALLETE
Regulated Operations		$30.3		$26.0			$81.8			$69.9			$57.5			$51.5

Energy Infrastructure and Related Services
ALLETE Clean Energy	1.9		6.8			7.7			14.9			11.7			5.8

U.S. Water Services (a)	—		0.2			(1.1		)	(1.2		)	—			(1.1		)

Corporate and Other (a)	2.0		(1.7		)	16.3			(1.3		)	(2.9		)	14.3
Total Net Income		$34.2		$31.3			$104.7			$82.3
Total Net Income Attributable to ALLETE													$66.3			$70.5


(a)	OnIn March ~~26,~~ 2019, ALLETE ~~completed the sale of~~sold U.S. Water Services. The Company recognized a gain on the sale of ~~$11.1~~$9.9 million after-tax during the three months ended March 31, 2019, which is reflected in Corporate and ~~Other in 2019. (See Note 1. Operations and Significant Accounting Policies.)~~Other.


	June 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Millions
Assets
Regulated Operations		$4,004.4		$3,952.5		$4,145.5		$4,130.8

Energy Infrastructure and Related Services
ALLETE Clean Energy	755.0		606.6		1,099.6		1,001.5
U.S. Water Services (a)	—		295.8

Corporate and Other	417.1		310.1		374.4		350.5
Total Assets		$5,176.5		$5,165.0		$5,619.5		$5,482.8


~~(a)~~	~~On March 26, 2019, ALLETE completed the sale of U.S. Water Services. (See Note 1. Operations and Significant Accounting Policies.)~~

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 ~~2018~~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 ~~2018~~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 2321 of our ~~2018~~2019 Form 10-K. The risks and uncertainties described in this Form 10-Q and our ~~2018~~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.

Our financial position, results of operations and cash flows were not materially impacted during the three months ended March 31, 2020, by the ongoing COVID-19 pandemic; however, the trends and results for the first three 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 1615 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 ~~four~~six states, approximately ~~555~~740 MW of nameplate capacity wind energy generation that is contracted under PSAs of various durations. In addition, ALLETE Clean Energy currently has approximately 300 MW of wind energy facilities under construction 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. ~~On February 8,~~In March 2019, the Company ~~entered into a stock purchase agreement providing for the sale of~~sold U.S. Water Services to a subsidiary of Kurita Water Industries Ltd. pursuant to a stock purchase agreement for ~~a cash purchase price of~~approximately $270 ~~million. On March 26, 2019, ALLETE completed the sale and received approximately $265~~ million in cash, ~~at closing,~~ 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, ~~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.

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, 2019~~March 31, 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~~three months ended ~~June 30, 2019,~~March 31, 2020, to the ~~six~~three months ended ~~June 30, 2018.~~March 31, 2019. The trends and results for the first three 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~~three months ended ~~June 30, 2019,~~March 31, 2020, was ~~$104.7~~$66.3 million, or ~~$2.02~~$1.28 per diluted share, compared to ~~$82.3~~$70.5 million, or ~~$1.60~~$1.37 per diluted share, for the same period in ~~2018.~~2019. Net income in 2019 included a gain on the sale of U.S. Water Services of $9.9 million after-tax, or $0.19 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 the first quarter. The full year gain on sale of U.S. Water Services ~~of $11.1~~in 2019 was $13.2 million after-tax, or ~~$0.21~~$0.26 per share. ~~Earnings per share dilution was $0.02 due to additional shares of common stock outstanding as of June 30, 2019.~~

~~ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL~~

~~CONDITION AND RESULTS OF OPERATIONS (Continued)~~

Regulated Operations net income attributable to ALLETE was ~~$81.8~~$57.5 million for the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, compared to ~~$69.9~~$51.5 million for the same period in ~~2018.~~2019. Net income at Minnesota Power was higher than ~~2018~~2019 primarily due to ~~lower operating and maintenance and property tax expenses,~~the implementation of interim rates on January 1, 2020, increased cost recovery rider revenue, 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 (see Note 2. Regulatory Matters), and ~~higher revenue from wholesale customers under FERC formula-based rates.~~the timing of income taxes. These increases were partially offset by higher expenses, and lower kWh ~~sales.~~sales to residential, commercial and municipal customers in 2020. Net income at ~~Superior Water, Light and Power~~SWL&P was ~~higher~~lower than ~~2018~~2019 primarily due to ~~higher rates~~fewer gas and ~~lower operating~~kWh sales to commercial and ~~maintenance expenses.~~residential customers resulting from warmer weather in 2020 compared to 2019. Our after-tax equity earnings in ATC were ~~higher than 2018 primarily due~~similar to ~~additional investments.~~2019.

ALLETE Clean Energy net income attributable to ALLETE was ~~$7.7~~$11.7 million for the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, compared to ~~$14.9~~$5.8 million for the same period in ~~2018.~~2019. Net income in ~~2018~~2020 included $2.6 million of production tax credits that resulted from the retrospective qualification of additional wind turbine generators in 2016 and 2017. Net income in 2019 included lower revenue resulting from lower wind resources and availability due to weather as well as lower non-cash amortization related to the expiration of power sales agreements, and higher depreciation expense. These decreases were partially offset by $2.0$2.3 million of additional production tax credits generated ~~in 2019~~ compared to ~~production~~2019, higher revenue resulting from higher wind resources and availability, and earnings from the Glen Ullin wind energy facility which commenced operations in December 2019. Net income in 2020 also included additional income tax ~~credits generated~~benefit recorded in ~~2018~~2020 as ~~ALLETE Clean Energy continues to execute its refurbishment strategy.~~GAAP requires the recognition of income taxes at the estimated annual effective tax rate. These increases were partially offset by higher depreciation expense.

U.S. Water Services net loss attributable to ALLETE was $1.1 million for ~~the six~~three months ended ~~June 30, 2019, compared to a net loss of $1.2 million for the same period in 2018.~~March 31, 2019. ALLETE completed the sale of U.S. Water Services in the first quarter of 2019.

Corporate and Other net ~~income~~loss attributable to ALLETE was ~~$16.3~~$2.9 million for the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, compared to a net ~~loss~~income of ~~$1.3~~$14.3 million for the same period in ~~2018.~~2019. Net income in 2019 included ~~the~~a gain on the sale of U.S. Water Services of ~~$11.1~~$9.9 million after-tax. Net income in ~~2019~~2020 included lower earnings from marketable equity securities held in benefit trusts. Net income in 2020 also included additional income tax ~~benefit~~expense recorded in ~~2019~~2020 as GAAP requires the recognition of income ~~tax expense~~taxes at the estimated annual effective tax rate.

COMPARISON OF THE ~~QUARTERS~~THREE MONTHS ENDED ~~JUNE 30,~~MARCH 31, 2020 AND 2019 ~~AND 2018~~

(See Note ~~11.~~10. Business Segments for financial results by segment.)

Regulated Operations


Quarter Ended June 30,	2019			2018
Three Months Ended March 31,							2020			2019
Millions
Operating Revenue – Utility		$249.8			$257.8			$265.3			$282.2
Fuel, Purchased Power and Gas – Utility	87.9			96.5			89.0			109.8
Transmission Services – Utility	19.2			16.8			18.5			18.3
Operating and Maintenance	54.2			54.9			49.3			47.7
Depreciation and Amortization	40.2			44.5			41.7			39.8
Taxes Other than Income Taxes	12.5			13.0			11.3			12.3
Operating Income	35.8			32.1			55.5			54.3
Interest Expense	(14.4		)	(15.1		)	(14.6		)	(15.5		)
Equity Earnings	4.8			4.3			5.2			5.6
Other Income	2.8			1.0			3.4			4.3
Income Before Income Taxes	29.0			22.3			49.5			48.7
Income Tax Benefit	(1.3		)	(3.7		)
Net Income		$30.3			$26.0
Income Tax Expense (Benefit)							(8.0		)	(2.8		)
Net Income Attributable to ALLETE								$57.5			$51.5

Operating Revenue – Utility decreased ~~$8.0~~$16.9 million ~~or 3 percent,~~ from ~~2018 as a result of~~2019 primarily due to lower fuel adjustment clause recoveries, revenue from kWh sales and ~~the timing of the provision for tax reform refund in 2018 related to income tax changes resulting from the TCJA,~~conservation improvement program recoveries, partially offset by ~~higher~~the implementation of interim rates on January 1, 2020, and increased cost recovery rider revenue.

Fuel adjustment clause revenue decreased $12.2 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 ~~increased cost recovery rider revenue and higher FERC formula-based rates.~~

~~COMPARISON OF THE QUARTERS ENDED JUNE 30, 2019 AND 2018 (Continued)~~

~~Regulated Operations (Continued)~~in 2019. Beginning in 2020, Minnesota utilities adopted a new fuel adjustment clause methodology. (See Note 2. Regulatory Matters.)

Revenue from kWh sales decreased ~~$15.0~~$9.0 million from ~~2018~~2019 reflecting lower sales to residential, commercial and municipal ~~customers as well as lower sales to other power suppliers.~~customers. Sales to residential and commercial customers decreased from ~~2018~~2019 primarily due to ~~milder~~warmer weather in ~~2019 compared to the same period in 2018.~~2020. Sales to municipal customers decreased infrom 2019 as a result of ~~additional~~the expiration of a contract with a municipal customer ~~self-generation~~ in June 2019. Sales to ~~other power suppliers decreased in 2019~~industrial customers increased primarily due to ~~fewer market~~additional sales ~~and sales under PSAs as a result~~to Silver Bay Power, which ceased self-generation in the third quarter of ~~less generation available for sale, partially offset by the commencement of Minnesota Power’s PSA with Oconto Electric Cooperative in January~~ 2019. ~~Sales to other power suppliers are sold at market-based prices into the MISO market on a daily basis or through PSAs of various durations.~~


Kilowatt-hours Sold			Quantity		%				Quantity		%
Quarter Ended June 30,	2019	2018	Variance		Variance
Three Months Ended March 31,							2020	2019	Variance		Variance
Millions
Regulated Utility
Retail and Municipal
Residential	232	243	(11	)	(4.5	)%	321	349	(28	)	(8.0	)%
Commercial	317	339	(22	)	(6.5	)%	352	366	(14	)	(3.8	)%
Industrial	1,773	1,781	(8	)	(0.4	)%	1,902	1,814	88		4.9	%
Municipal	170	188	(18	)	(9.6	)%	156	203	(47	)	(23.2	)%
Total Retail and Municipal	2,492	2,551	(59	)	(2.3	)%	2,731	2,732	(1	)	—
Other Power Suppliers	714	1,005	(291	)	(29.0	)%	822	822	—		—
Total Regulated Utility Kilowatt-hours Sold	3,206	3,556	(350	)	(9.8	)%	3,553	3,554	(1	)	—

Revenue from electric sales to taconite ~~and iron concentrate~~ customers accounted for 2726 percent of consolidated operating revenue in ~~2019~~2020 (22 percent in ~~2018)~~2019). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 65 percent of consolidated operating revenue in ~~2019~~2020 (5 percent in ~~2018)~~2019). Revenue from electric sales to pipelines and other industrial customers accounted for 87 percent of consolidated operating revenue in ~~2019 (6~~2020 (7 percent in ~~2018)~~2019).

~~Revenue was $3.4~~Conservation improvement program recoveries decreased $2.1 million ~~lower than 2018 reflecting the timing of Minnesota Power’s provision for tax reform refund~~from 2019 primarily due to a decrease in 2018. In the first quarter of 2018, Minnesota Power reserved for income tax benefits resulting from the reduction of the federal income tax rate enacted as part of the TCJA. In the second quarter of 2018, Minnesota Power reversed the reserve as the MPUC allowed Minnesota Power to retain these income tax benefits to mostly offset an increase in depreciation expense resulting from the reconsideration of its decision in Minnesota Power’s general rate case to reduce the depreciable lives of Boswell Unit 3, Unit 4 and common facilities to 2035.related expenditures. (See Operating Expenses - ~~Depreciation~~Operating and ~~Amortization~~Maintenance.)

~~Fuel adjustment clause~~

COMPARISON OF THE THREE MONTHS ENDED MARCH 31, 2020 AND 2019 (Continued)

Regulated Operations (Continued)

Interim retail rates for Minnesota Power, subject to refund, were approved by the MPUC and became effective January 1, 2020, resulting in revenue ~~increased $5.9 million due to period over period timing~~ of ~~recoveries for fuel and purchased power costs attributable to retail and municipal customers.~~$9.0 million. (See Note 2. Regulatory Matters.)

Cost recovery rider revenue ~~contributed an incremental $4.2~~increased $2.3 million ~~over current base rates compared to 2018 (see Note 2. Regulatory Matters)~~ primarily due to higher expenditures related to the construction of the GNTL and lower transmission margins related to our portion of CapX2020 transmission lines. Transmission margins for CapX2020 transmission lines recognized below those assumed in Minnesota Power base rates result in increased cost recovery rider revenue to offset the impact of the lower margins.

~~Revenue from wholesale customers under FERC formula-based rates increased $1.8 million from 2018 primarily due to higher rates.~~GNTL.

Operating Expenses decreased ~~$11.7~~$18.1 million, or 58 percent, from ~~2018.~~2019.

Fuel, Purchased Power and Gas – Utility expense decreased ~~$8.6~~$20.8 million, or 919 percent, from ~~2018~~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 increased $2.4 million, or 14 percent, from 2018 primarily due to higher MISO‑related expense.~~

~~COMPARISON OF THE QUARTERS ENDED JUNE 30, 2019 AND 2018 (Continued)~~

~~Regulated Operations (Continued)~~

Operating and Maintenance expense ~~decreased $0.7~~increased $1.6 million, or 13 percent, from ~~2018~~2019 primarily due to ~~lower salary~~higher contract and ~~benefit~~professional service expenses and ~~lower bad debt expense,~~materials purchased for generation facilities, partially offset by ~~higher expenses for planned maintenance outages at our generation facilities.~~a $2.1 million decrease in conservation improvement program expenses.

Depreciation and Amortization expense decreased $4.3 million, or 10 percent, from 2018 primarily due to the timing of modifications of the depreciable lives for Boswell as part of Minnesota Power’s general rate case. As part of its decision in Minnesota Power’s general rate case in 2018, the MPUC extended the depreciable lives of Boswell Unit 3, Unit 4 and common facilities to 2050, and shortened the depreciable lives of Boswell Unit 1 and Unit 2 to 2022, resulting in a net decrease to depreciation expense in the first quarter of 2018. In the second quarter of 2018, as part of the reconsideration of its decision in Minnesota Power’s general rate case, the MPUC reduced the depreciable lives of Boswell Unit 3, Unit 4 and common facilities to 2035, resulting in higher depreciation expense beginning in the second quarter of 2018. (See ~~Operating Revenue~~.)

~~Interest Expense~~ ~~decreased $0.7~~increased $1.9 million, or 5 percent, from ~~2018~~2019 primarily due to additional property, plant and equipment in service.

Taxes Other than Income Taxes decreased $1.0 million, or 8 percent, from 2019 primarily due to lower ~~average long-term debt balances and~~property tax expenses resulting from lower ~~interest rates. We record interest expense for Regulated Operations primarily based on rate base and authorized capital structure, and allocate the balance to Corporate and Other.~~estimated taxable market values.

~~Equity Earnings~~Income Tax Benefit increased ~~$0.5~~$5.2 million from 2019 primarily due to higher production tax credits. 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



Three Months Ended March 31,	2020			2019
Millions
Operating Revenue
Contracts with Customers – Non-utility	$17.3			$14.6
Other – Non-utility (a)	2.8			2.9
Operating and Maintenance	8.2			7.2
Depreciation and Amortization	8.2			6.5
Taxes and Other	0.7			0.6
Operating Income	3.0			3.2
Interest Expense	(0.5		)	(0.8		)
Other Income	0.2			1.8
Income Before Income Taxes	2.7			4.2
Income Tax Expense (Benefit)	(7.2		)	(1.6		)
Net Income	9.9			5.8
Net Loss Attributable to Non-Controlling Interest	(1.8		)	—
Net Income Attributable to ALLETE		$11.7			$5.8


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

Operating Revenue increased $2.6 million, or 1215 percent, from 2019 primarily due to revenue from the Glen Ullin wind energy facility which commenced operations in December 2019 as well as higher wind resources and availability compared to 2019.

COMPARISON OF THE THREE MONTHS ENDED MARCH 31, 2020 AND 2019 (Continued)

ALLETE Clean Energy (Continued)



	Three Months Ended March 31,
	2020			2019
Production and Operating Revenue	kWh	Revenue		kWh	Revenue
Millions
Wind Energy Regions
East	78.6		$7.1	80.4		$7.4
Midwest	244.4	8.5		212.9	9.0
West	141.8	4.5		13.4	1.1
Total Production and Operating Revenue	464.8		$20.1	306.7		$17.5

Operating and Maintenance ~~2018~~expense increased $1.0 million, or 14 percent, from 2019 primarily due to operating and maintenance expenses for the Glen Ullin wind energy facility which commenced operations in December 2019.

Depreciation and Amortizationexpense increased $1.7 million, or 26 percent, from 2019 primarily due to additional ~~investments~~property, plant and equipment in ~~ATC.~~service related to the Glen Ullin wind energy facility which commenced operations in December 2019.

Other Income~~increased $1.8 million from~~ ~~2018~~decreased $1.6 million from 2019 reflecting various individually immaterial items.

Income Tax Benefit ~~decreased $2.4~~increased $5.6 million from ~~2018~~2019 primarily due to ~~higher pre-tax income. We expect our annual effective tax rate in 2019 to be a lower income tax benefit than in 2018 primarily due to higher pre-tax income.~~

~~ALLETE Clean Energy~~

Quarter Ended June 30, 2019
2018
Millions
Operating Revenue
$15.4

$18.3
Net Income
$1.9

$6.8

~~Operating Revenue~~ ~~decreased $2.9 million, or 16 percent, from 2018 primarily due to lower non-cash amortization related to the expiration of power sales agreements.~~

Quarter Ended June 30,
2019 2018
Production and Operating Revenue kWh Revenue kWh Revenue
Millions
Wind Energy Facilities
Armenia Mountain 64.0

$5.8
55.5

$5.1
Chanarambie/Viking 56.8
2.9
59.4
3.3
Condon 22.7
1.8
24.0
1.9
Lake Benton 48.9
2.9
49.0
2.8
Storm Lake I 44.6
0.9
41.3
2.9
Storm Lake II 31.8
0.8
31.7
2.3
Other 9.4
0.3
—
—
Total Production and Operating Revenue 278.2

$15.4
260.9

$18.3

~~Net Income~~ decreased $4.9 million from 2018. Net income in 2018 included $2.6 million of production tax credits that resulted from the retrospective qualification of additional wind turbine generators in 2016 and 2017. Net income in 2019 included lower revenue resulting from lower non-cash amortization related to the expiration of power sales agreements and higher depreciation expense. These decreases were partially offset by $0.8 million of additional production tax credits generated in ~~2019 compared to~~2020 and additional income tax benefit recorded in 2020 as GAAP requires the recognition of income taxes at the estimated annual effective tax rate. The income tax benefit in 2020 reflected production tax credits generated of $4.2 million compared to $1.9 million in ~~2018 as ALLETE Clean Energy continues~~2019.

Net Loss Attributable to ~~execute its refurbishment strategy.~~Non-Controlling Interest increased $1.8 million from 2019 reflecting net losses attributable to non-controlling interest for the Glen Ullin wind energy facility which commenced operations in December 2019.

~~COMPARISON OF THE QUARTERS ENDED JUNE 30, 2019 AND 2018 (Continued)~~

U.S. Water Services


Quarter Ended June 30,	2019	2018
Three Months Ended March 31,				2020	2019
Millions
Operating Revenue	—		$41.5	—	$33.4
Net Income	—		$0.2
Net Loss Attributable to ALLETE				—	$(1.1)

Operating Revenue ~~decreased $41.5~~was $33.4 million ~~from 2018.~~for the three months ended March 31, 2019. ALLETE completed the sale of U.S. Water Services in the first quarter of 2019. ~~(See Note 1. Operations and Significant Accounting Policies.)~~

Net ~~Income~~Loss Attributable to ALLETE ~~decreased $0.2~~was$1.1 million ~~from 2018.~~for the three months ended March 31, 2019. ALLETE completed the sale of U.S. Water Services in the first quarter of 2019.

Corporate and Other

Operating Revenue ~~decreased $1.3~~increased $2.1 million, or 59 percent, from ~~2018~~2019 primarily due to ~~lower~~higher revenue at BNI Energy, which operates under cost-plus fixed fee contracts, as a result of ~~lower~~higher expenses and ~~fewer~~more tons sold in ~~2019~~2020 compared to ~~2018 and lower revenue from non-rate base generation, partially offset by an increase in land sales at ALLETE Properties.~~2019.

Net ~~Income~~Loss Attributable to ALLETE was ~~$2.0~~$2.9 million in ~~2019~~2020 compared to a net ~~loss of $1.7~~income $14.3 million in ~~2018.~~2019. Net income in 2019 included ~~additional income tax benefit as GAAP requires the recognition of income tax expense at the estimated annual effective tax rate, additional~~a gain on the sale of U.S. Water Services ~~resulting from the finalization~~ of working capital, and higher earnings on cash and short-term investments. Net income at BNI Energy was $1.7 million in 2019 compared to net income of $1.8 million in 2018. The net loss at ALLETE Properties was $0.5 million in 2019 compared to a net loss of $0.7 million in 2018.

~~Income Taxes – Consolidated~~

~~For the quarter ended June 30, 2019, the effective tax rate was a benefit of 16.3 percent (benefit of 20.8 percent for the quarter ended June 30, 2018).~~

~~COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2019 AND 2018~~

~~(See Note 11. Business Segments for financial results by segment.)~~

~~Regulated Operations~~

Six Months Ended June 30, 2019
2018
Millions
Operating Revenue – Utility
$532.0

$528.0
Fuel, Purchased Power and Gas – Utility 197.7
197.4
Transmission Services – Utility 37.5
35.2
Operating and Maintenance 101.9
110.4
Depreciation and Amortization 80.0
78.8
Taxes Other than Income Taxes 24.8
28.1
Operating Income 90.1
78.1
Interest Expense (29.9 ) (30.0 )
Equity Earnings 10.4
9.0
Other Income 7.1
2.6
Income Before Income Taxes 77.7
59.7
Income Tax Benefit (4.1 ) (10.2 )
Net Income
$81.8

$69.9

~~Operating Revenue~~ – ~~Utility~~ increased $4.0 million, or 1 percent, from 2018 primarily due to higher fuel adjustment clause recoveries, increased cost recovery rider revenue and higher FERC formula-based rates, partially offset by lower revenue from kWh sales.

~~COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2019 AND 2018 (Continued)~~

~~Regulated Operations (Continued)~~

~~Fuel adjustment clause revenue increased $12.7 million due to period over period timing of recoveries for fuel and purchased power costs attributable to retail and municipal customers.~~

Cost recovery rider revenue contributed an incremental $11.6 million over current base rates compared to 2018 (see Note 2. Regulatory Matters) primarily due to higher expenditures related to the construction of the GNTL and lower transmission margins related to our portion of CapX2020 transmission lines. Transmission margins for CapX2020 transmission lines recognized below those assumed in Minnesota Power base rates result in increased cost recovery rider revenue to offset the impact of the lower margins.

~~Revenue from wholesale customers under FERC formula-based rates increased $2.7 million from 2018 primarily due to higher rates.~~

Revenue from kWh sales decreased $22.4 million from 2018 reflecting lower sales to residential, commercial, industrial and municipal customers as well as lower sales to other power suppliers. Sales to residential and commercial customers decreased from 2018 primarily due to milder weather in the second quarter of 2019. Sales to industrial customers decreased in 2019 reflecting in part lower sales to Husky Energy due to an April 2018 fire at its refinery in Superior, Wisconsin. Sales to municipal customers decreased from 2018 as a result of additional customer self-generation in 2019. Sales to other power suppliers decreased in 2019 primarily due to fewer market sales and sales under PSAs as a result of less generation available for sale, partially offset by the commencement of Minnesota Power’s PSA with Oconto Electric Cooperative in January 2019. Sales to other power suppliers are sold at market-based prices into the MISO market on a daily basis or through PSAs of various durations.

Kilowatt-hours Sold Quantity %
Six Months Ended June 30, 2019
2018
Variance Variance
Millions
Regulated Utility
Retail and Municipal
Residential 581
585
(4 ) (0.7 )%
Commercial 683
706
(23 ) (3.3 )%
Industrial 3,587
3,624
(37 ) (1.0 )%
Municipal 373
407
(34 ) (8.4 )%
Total Retail and Municipal 5,224
5,322
(98 ) (1.8 )%
Other Power Suppliers 1,536
2,008
(472 ) (23.5 )%
Total Regulated Utility Kilowatt-hours Sold 6,760
7,330
(570 ) (7.8 )%

Revenue from electric sales to taconite and iron concentrate customers accounted for 24 percent of consolidated operating revenue in 2019 (21 percent in 2018). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 5 percent of consolidated operating revenue in 2019 (5 percent in 2018). Revenue from electric sales to pipelines and other industrial customers accounted for 8 percent of consolidated operating revenue in 2019 (7 percent in 2018).

~~Operating Expenses~~ ~~decreased $8.0 million, or 2 percent, from 2018.~~

~~Transmission Services – Utility~~ ~~expense increased $2.3 million, or 7 percent, from 2018 primarily due to higher MISO‑related expense.~~

~~Operating and Maintenance~~ ~~expensedecreased $8.5 million, or 8 percent, from 2018 primarily due to lower salary and benefit expenses and lower materials purchased for generation facilities.~~

~~Taxes Other than Income Taxes~~ ~~decreased $3.3 million, or 12 percent, from 2018 primarily due to lower property tax expenses resulting from lower estimated taxable market values.~~

~~Equity Earnings~~ ~~increased $1.4 million, or 16 percent, from2018 primarily due to additional investments in ATC.~~

~~Other Income~~ ~~increased $4.5 million from2018 reflecting various individually immaterial items.~~

~~COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2019 AND 2018 (Continued)~~

~~Regulated Operations (Continued)~~

~~Income Tax Benefit~~ decreased $6.1 million from 2018 primarily due to higher pre-tax income. We expect our annual effective tax rate in 2019 to be a lower income tax benefit than in 2018 primarily due to higher pre-tax income.

~~ALLETE Clean Energy~~

Six Months Ended June 30, 2019
2018
Millions
Operating Revenue
$32.9

$42.9
Net Income
$7.7

$14.9

~~Operating Revenue~~ decreased $10.0 million, or 23 percent, from 2018 primarily due to lower kWh sales resulting from lower wind resources and availability due to weather as well as lower non-cash amortization related to the expiration of power sales agreements.

Six Months Ended June 30,
2019 2018
Production and Operating Revenue kWh Revenue kWh Revenue
Millions
Wind Energy Facilities
Armenia Mountain 144.4

$13.2
147.0

$13.4
Chanarambie/Viking 122.0
6.1
138.1
7.2
Condon 36.1
2.9
58.3
4.7
Lake Benton 101.5
5.8
119.4
6.2
Storm Lake I 98.0
2.0
103.8
6.2
Storm Lake II 66.6
2.4
79.6
5.2
Other 16.3
0.5
—
—
Total Production and Operating Revenue 584.9

$32.9
646.2

$42.9

~~Net Income~~ decreased $7.2 million, or 48 percent, from 2018. Net income in 2018 included $2.6 million of production tax credits that resulted from the retrospective qualification of additional wind turbine generators in 2016 and 2017. Net income in 2019 included lower revenue resulting from lower wind resources and availability due to weather as well as lower non-cash amortization related to the expiration of power sales agreements, and higher depreciation expense. These decreases were partially offset by $2.0 million of additional production tax credits generated in 2019 compared to production tax credits generated in 2018 as ALLETE Clean Energy continues to execute its refurbishment strategy.

~~U.S. Water Services~~

Six Months Ended June 30, 2019
2018
Millions
Operating Revenue
$33.4

$79.7
Net Loss $(1.1) $(1.2)

~~Operating Revenue~~ ~~decreased $46.3 million, or 58 percent, from 2018. ALLETE completed the sale of U.S. Water Services in the first quarter of 2019. (See Note 1. Operations and Significant Accounting Policies.)~~

~~Net Loss~~ ~~decreased $0.1 million from 2018. ALLETE completed the sale of U.S. Water Services in the first quarter of 2019.~~

~~Corporate and Other~~

~~Operating Revenue~~ decreased $2.4 million, or 5 percent, from 2018 primarily due to lower revenue at BNI Energy, which operates under cost-plus fixed fee contracts, as a result of lower expenses and fewer tons sold in 2019 compared to 2018 and lower revenue from non-rate base generation, partially offset by an increase in land sales at ALLETE Properties.

~~COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 2019 AND 2018 (Continued)~~

~~Corporate and Other (Continued)~~

~~Net Income~~ ~~was $16.3 million in 2019 compared to a net loss of $1.3 million in 2018. Net income in 2019 included the gain on sale of U.S. Water Services of $11.1~~$9.9 million after-tax. Net income in ~~2019~~2020 included lower earnings from marketable equity securities held in benefit trusts. Net income in 2020 also included additional income tax ~~benefit~~expense recorded in ~~2019~~2020 as GAAP requires the recognition of income ~~tax expense~~taxes at the estimated annual effective tax rate. Net income at BNI Energy was ~~$3.6~~$0.7 million in 2020 compared to $1.9 million in 2019, ~~and~~reflecting lower earnings from marketable equity securities held in ~~2018.~~benefit trusts in 2020. The net loss at ALLETE Properties was ~~$1.1~~$0.5 million in ~~2019 and~~2020 compared to a net loss of $0.6 million in ~~2018.~~2019.

COMPARISON OF THE THREE MONTHS ENDED MARCH 31, 2020 AND 2019 (Continued)

Income Taxes – Consolidated

For the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, the effective tax rate was a benefit of ~~1.8~~27.2 percent ~~(benefit~~(expense of ~~12.4~~4.0 percent for the ~~six~~three months ended ~~June 30, 2018)~~March 31, 2019). The effective tax rate for ~~2019~~2020 was a ~~lower~~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 ~~and higher pre-tax income.~~in 2019.

We expect our annual effective tax rate in ~~2019~~2020 to be ~~similar~~a higher benefit as compared to ~~2018 reflecting the sale of U.S. Water Services and~~2019 primarily due to higher production tax credits generated by ALLETE Clean ~~Energy.~~Energy in 2020 and lower pre-tax income as 2019 reflected the gain on sale of U.S. Water Services. The effective rate deviated from the combined statutory rate of approximately 28 percent primarily due to production tax credits. (See Note 9.8. 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 ~~2018~~2019 Form 10-K.

OUTLOOK

For additional information see our ~~2018~~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 ~~Energy Infrastructure~~Corporate and ~~Related Services~~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 ~~its~~ALLETE Clean Energy ~~Infrastructure~~ and ~~Related Services~~our Corporate and ~~other~~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 ~~2019.~~2020. Over the next several years, the contribution of ~~the~~ALLETE Clean Energy ~~Infrastructure~~ and ~~Related Services~~our Corporate and ~~other~~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. ~~Minnesota Power anticipates filing a rate case in the fourth quarter of 2019 with a 2020 test year.~~

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.

~~2016~~2020 Minnesota General Rate Case.On November 1, 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 ~~MPUC issued an order dated March 12, 2018, in Minnesota Power’s general~~ rate ~~case approving~~filing seeks a return on ~~common~~ equity of ~~9.25~~10.05 percent and a 53.81 percent equity ratio. ~~Final rates went into effect on December 1, 2018, which is expected to result~~On an annualized basis, the requested final rate increase would generate approximately $66 million in additional ~~revenue~~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. We cannot predict the level of final rates that may be authorized by the MPUC.

2018 Wisconsin General Rate Case. ~~In an~~SWL&P’s current retail rates are based on a December 2018 PSCW order ~~dated December 20, 2018, the PSCW approved a rate increase~~that allows for ~~SWL&P including~~ a return on equity of 10.4 percent and a 55.0 percent equity ratio. ~~Final rates went into effect January 1, 2019, which is expected~~The PSCW has ordered SWL&P to ~~result~~file a general rate case in ~~additional revenue of approximately $1.3 million on an annualized basis.~~2020.

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 5354 percent of our regulated utility kWh sales in the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, were made to our industrial customers ~~(49~~(51 percent in the ~~six~~three months ended ~~June 30, 2018)~~March 31, 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 federal and state government responses has led to a disruption of economic activity, and could result in an extended disruption of economic activity. This disruption is expected to result in reduced sales and revenue from industrial customers. The states of Minnesota and Wisconsin issued stay-at-home or shelter-in-place orders in March 2020 that remain in effect, and many non-essential commercial and industrial customers are operating at reduced levels or are temporarily closed or idled. In addition, Cliffs temporarily idled its Northshore Mining operation, Hibbing Taconite temporarily idled production and USS Corporation indefinitely idled its Keetac plant as well as announced a temporary partial shutdown at its Minntac plant, each of which are served by Minnesota Power. (See Northshore Mining, Hibbing Taconite and USS 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 ~~and Iron Concentrate~~. 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.

OUTLOOK (Continued)

Industrial Customers and Prospective Additional Load (Continued)

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 81 percent of capacity during the first ~~six~~three months of ~~2019~~2020 compared to 7682 percent in the first ~~six~~three months of ~~2018.~~2019; however, the American Iron and Steel Institute also reported that U.S. raw steel production in the last week of April 2020 had decreased to approximately 51 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 October 2019 that U.S. steel consumption in ~~2019~~2020 will increase by approximately one percent compared to ~~2018.~~2019; however, this projection was made before the COVID-19 pandemic and the World Steel Association announced in April 2020 that it had decided to postpone its U.S. steel consumption update projection typically released in April each year due to continuing disruption caused by the COVID-19 pandemic.

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. 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 has announced that it has completed an investment in its Minnesota ore operations with an approximately $92 million investment to expand capacity for producing direct reduced-grade pellets at Northshore Mining. Cliffs is currently constructing a hot briquetted iron production plant in Toledo, Ohio, and ~~has~~had begun shipping direct reduced-grade pellets form Northshore Mining to the Toledo plant in anticipation of the planned start of operations in mid-2020. On March 19, 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. On April 13, 2020, Cliffs announced that based on current market conditions, it will 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 plans to restart the facility by August 2020, subject to business conditions. 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 ~~has~~had previously been served predominately through self-generation by Silver Bay Power. ~~Through 2019,~~Starting in 2016, Minnesota Power ~~will supply~~supplied Silver Bay Power with at least 50 MW of energy and Silver Bay Power ~~has~~had the option to purchase additional energy from Minnesota Power as it ~~transitions~~transitioned away from self-generation. ~~By December 31,~~In the third quarter of 2019, Silver Bay Power ~~is expected to cease~~ceased self-generation and Minnesota Power ~~is expected to supply~~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, on May 1, 2020, USS Corporation announced reduced production expected temporarily at its Minntac Plant in Mountain Iron, Minnesota until July 2020. USS Corporation has the capability to produce approximately 20 million tons annually at its Minntac and Keetac plants.

Hibbing Taconite. On April 20, 2020, ArcelorMittal announced that Hibbing Taconite in Hibbing, Minnesota, would idle production until July 2020 due to the COVID-19 pandemic. 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 could adversely impact these customers’ operations and result in lower operating levels than expected or the temporary idling or indefinite shutdown of 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, will continue to operate at capacity during this period.

OUTLOOK (Continued)

Industrial Customers and Prospective Additional Load (Continued)

~~Paper, Pulp and Secondary Wood Products. We expect operating levels in 2019 at the four major paper and pulp mills we serve to be similar to 2018.~~

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. ~~The~~On September 30, 2019, Husky Energy announced that it had received the required permit approvals to begin reconstruction. On April 20, 2020, Husky Energy announced that rebuild construction at the refinery had been suspended due to the COVID-19 pandemic. Husky Energy did not provide a timeline for when construction would resume. The facility remains at minimal operations ~~and the refinery is not expected to resume normal operations until~~ ~~2021.~~.

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 ~~now holds~~was issued all necessary permits to construct and operate its new mining ~~operation. In June 2018,~~operation; however, on January 13, 2020, the ~~U.S. Forest Service~~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 ~~closed~~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 ~~a land exchange, which resulted in PolyMet obtaining surface rights to land needed to develop its mining operation.~~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.

Nemadji Trail Energy Center. In 2017, Minnesota Power submitted a resource package to the MPUC which included requesting ~~approval of PPAs for the output of a 250 MW wind energy facility (see~~ ~~Nobles 2 PPA) and a 10 MW solar energy facility as well as~~ 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. Separately, the MPUC 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. 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. A decision~~PSCW, which was approved by the PSCW at a hearing on ~~the application~~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 ~~in 2020.~~to be approximately $350 million. ALLETE’s portion of NTEC project costs incurred through March 31, 2020, is approximately $13 million.

OUTLOOK (Continued)

EnergyForward (Continued)

~~OUTLOOK (Continued)~~

~~EnergyForward (Continued)~~

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 ~~through renewable projects that will ensure it meets the identified state mandate at the lowest cost for customers. Minnesota Power has exceeded the interim milestone requirements to date~~ and expects ~~between 25 percent and 30~~approximately 50 percent of its ~~applicable retail and municipal~~ energy ~~sales~~ will be supplied by renewable energy sources ~~in 2019.~~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.

Minnesota Power has approval for current cost recovery of investments and expenditures related to compliance with the Minnesota Solar Energy Standard. Currently, there is no approved customer billing rate for solar costs.

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 ~~increasing amounts of~~ 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.

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 five long-term PPAs with Manitoba Hydro. The first PPA expires in May 2020. Under this agreement, Minnesota Power is purchasing 50 MW of capacity and the energy associated with that capacity. Both the capacity price and the energy price are adjusted annually by the change in a governmental inflationary index. Under the second 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 third PPA provides for Minnesota Power to purchase 250 MW of capacity and energy from Manitoba Hydro for 15 years beginning in 2020. The PPA is subject to the construction of the GNTL and MMTP. (See Note 7.6. Commitments, Guarantees and Contingencies.) The capacity price is adjusted annually until 2020 by the change in a governmental inflationary index. 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 fourth PPA provides for Minnesota Power to purchase up to 133 MW of energy from Manitoba Hydro for 20 years beginning in 2020. The pricing under this PPA is based on forward market prices. The PPA is subject to the construction of the GNTL and MMTP. (See Note 7.6. Commitments, Guarantees and Contingencies.)

OUTLOOK (Continued)

EnergyForward (Continued)

The fifth PPA provides for Minnesota Power to purchase 50 MW of capacity from Manitoba Hydro at fixed prices. The PPA began in June 2017 and expires in May 2020.

~~OUTLOOK (Continued)~~

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, 2019,~~March 31, 2020, our equity investment in ATC was ~~$133.6~~$142.3 million ($~~128.1~~141.6 million as of December 31, ~~2018)~~2019). In the ~~first six~~three months ~~of 2019,~~ended March 31, 2020, we ~~invested $2.7~~invested $0.4 million in ATC, ~~and~~and on ~~July 31, 2019, we~~April 30, 2020, we invested an additional ~~$1.9~~$0.8 million. We expect to make ~~approximately $4 million of~~ additional investments of $1.6 million in ~~2019. (See Note 3. Equity Investments.)~~2020.

ATC’s authorized return on equity is ~~10.32~~9.88 percent, or 10.82 percent including an incentive adder for participation in a regional transmission organization. In 2016, a federal administrative law judge ruled on a complaint proposing a reduction in the base return on equity to 9.70 percent, or 10.2010.38 percent including an incentive adder for participation in a regional transmission organization ~~subject to approval or adjustment by the FERC. A final decision from~~based on a November 2019 FERC order. In this order, the FERC reduced the base return on ~~the~~equity for regional transmission organizations as recommended by an administrative law ~~judge’s recommendation is pending.~~judge with refunds ordered for prior periods. Multiple parties to the complaint have filed requests for rehearing of the FERC order.

ATC’s 10-year transmission assessment, which covers the years ~~2018~~2019 through ~~2027,~~2028, identifies a need for between ~~$2.8~~$2.9 billion and ~~$3.4~~$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.

~~Energy Infrastructure and Related Services.~~

ALLETE Clean Energy.

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.

OUTLOOK (Continued)

ALLETE Clean Energy (Continued)

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 ~~in 2016, 2017 and 2018~~ 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 ~~1,500~~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 ~~468~~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 ~~$12~~$20 million in ~~2019,~~2020, $17 million to $22 million annually in ~~2020~~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. (See Part II, Item 1A. Risk Factors.)

In 2017, ALLETE Clean Energy announced it will build, own and operate a 100 MW wind energy facility pursuant to a 20-year PSA with Northern States Power; construction is expected to be completed in late 2019. In March 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 ~~is expected to be~~was completed and tax equity funding was received in ~~2019.~~the second quarter of 2020.

OnIn May 3, 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 ~~to Walmart Inc., Smithfield Foods, Inc. and Starbucks Corporation~~ under long-term power sales agreements. Construction is expected to ~~begin in late 2019 and~~ be completed in ~~the second half of~~late 2020.

On March 10, 2020, ALLETE Clean Energy acquired the rights to the 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 approximately 300 MW wind project would involve the sale of energy to corporate customers under long-term power sales agreements.

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 ~~555~~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	Location	Capacity MW	PSA MW	PSA Expiration
Armenia Mountain	Pennsylvania	101	100%	2024	East	101	100%	2024
Chanarambie/Viking	Minnesota	98			Midwest	98
PSA 1 (a)			12%	2023			12%	2023
PSA 2			88%	2023			88%	2023
Condon	Oregon	50	100%	2022	West	50	100%	2022
Glen Ullin					West	106	100%	2039
Lake Benton	Minnesota	104	100%	2028	Midwest	104	100%	2028
South Peak					West	80	100%	2035
Storm Lake I	Iowa	108	100%	2027	Midwest	108	100%	2027
Storm Lake II	Iowa	77			Midwest	77
PSA 1			90%	2020			90%	2022
PSA 2			10%	2032			10%	2032
Other	Minnesota	17	100%	2028	Midwest	17	100%	2028


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

~~U.S. Water Services.~~

On February 8, 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. for a cash purchase price of $270 million. On March 26, 2019, ALLETE completed the sale and received approximately $265 million in cash at closing, net of transaction costs and cash retained. ALLETE plans to use the proceeds from the sale primarily to reinvest in growth initiatives at our Regulated Operations and ALLETE Clean Energy.

OUTLOOK (Continued)

Corporate and Other.

BNI Energy. BNI Energy anticipates selling ~~4.4~~4.6 million tons of lignite coal in ~~2019 (4.3~~2020 (4.1 million tons were sold in ~~2018)~~2019) and has sold ~~2.2~~1.2 million tons for the ~~six~~three months ended ~~June 30, 2019 (2.3~~March 31, 2020 (1.1 million tons were sold for the ~~six~~three months ended ~~June 30, 2018)~~March 31, 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 ~~which our portion is expected to be approximately $170 million to $200 million. We expect to utilize tax equity to finance a portion of our~~the project costs. We account for our investment in Nobles 2 under the equity method of accounting. As of ~~June 30, 2019,~~March 31, 2020, our equity investment in Nobles 2 was ~~$26.6~~$83.4 million ($~~33.0~~56.0 million at December 31, ~~2018)~~2019). In the ~~first quarter of 2019,~~ three months ended March 31, 2020, we invested $27.4 million in Nobles 2 ~~returned capital of $8.3 million based on its cash needs.~~, and in April 2020 we invested an additional $21.7 million. We expect to make approximately ~~$33~~$65 million in additional investments in ~~2019.~~2020.

ALLETE Properties. ALLETE Properties represents our legacy Florida real estate investment. ALLETE Properties’ major ~~projects~~project in Florida ~~are~~is Town Center at Palm Coast, ~~and Palm Coast Park,~~ with approximately ~~1,500~~800 acres ~~combined~~ of land available for sale. In addition to ~~these two projects,~~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.

Income Taxes.

ALLETE’s aggregate federal and multi-state statutory tax rate is approximately 28 percent for ~~2019.~~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 ~~in the range~~ of 5approximately 25 percent to 1030 percent for ~~2019~~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.~~ 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, 2019,~~March 31, 2020, we had cash and cash equivalents of ~~$203.1~~$67.0 million, ~~$350.7~~$340.5 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, $90 million available for borrowing under a $200 million term loan entered into in January 2020 and a debt-to-capital ratio of 4142 percent. (See Working Capital.)

In addition, ALLETE has agreed to sell $140 million of the Company's first mortgage bonds to be issued on or before August 3, 2020, and on April 8, 2020, ALLETE entered into a $115 million term loan agreement with $95 million borrowed upon execution. (See Note 5. Short-Term and Long-Term Debt.) On April 29, 2020, we received approximately $70 million in cash 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 wind project.

LIQUIDITY AND CAPITAL RESOURCES (Continued)

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

June 30,
2019
% December 31,
2018
%
Millions
Shareholders’ Equity
$2,205.0
59
$2,155.8
59
Long-Term Debt (Including Long-Term Debt Due Within One Year) 1,543.0
41 1,495.2
41

$3,748.0
100
$3,651.0
100

~~LIQUIDITY AND CAPITAL RESOURCES (Continued)~~



	March 31, 2020		%	December 31, 2019		%
Millions
ALLETE Equity		$2,271.1	55		$2,231.9	56
Non-Controlling Interest	101.9		3	103.7		3
Long-Term Debt (Including Long-Term Debt Due Within One Year)	1,731.3		42	1,622.6		41
		$4,104.3	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,	2019			2018
For the Three Months Ended March 31,							2020			2019
Millions
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		$79.0			$110.1			$92.5			$79.0
Cash Flows from (used for)
Operating Activities	95.2			194.4			88.8			79.1
Investing Activities	46.0			(138.5		)	(182.5		)	185.1
Financing Activities	(13.6		)	(33.2		)	80.1			22.0
Change in Cash, Cash Equivalents and Restricted Cash	127.6			22.7			(13.6		)	286.2
Cash, Cash Equivalents and Restricted Cash at End of Period		$206.6			$132.8			$78.9			$365.2

Operating Activities. Cash from operating activities was ~~lower~~slightly higher in 2020 compared to 2019 as cash from operating activities in 2019 ~~compared to 2018 primarily due to~~included higher non-cash earnings resulting from the gain on sale of U.S. Water Services, the refund of Minnesota Power’s ~~provisions~~provision for tax reform, and ~~interim rates~~the impact of U.S. Water Services prior to ~~customers, fewer customer deposits received and~~its sale. Cash from operating activities in 2020 reflected lower ~~recoveries from customers under cost recovery riders in 2019. These decreases were partially offset by the timing of~~ collections of accounts ~~receivable.~~receivable due to timing and lower cash collected from current cost recovery riders.

Investing Activities. Cash ~~from~~used for investing activities was higher in ~~2019~~2020 compared to ~~2018 primarily due to~~2019. Cash from investing activities in 2019 included proceeds received from the sale of U.S. Water ~~Services, partially offset by~~Services. Cash used for investing activities in 2020 included higher additions to property, plant and ~~equipment.~~equipment and additional payments for equity method investments compared to 2019.

Financing Activities. Cash ~~used for~~from financing activities was ~~lower~~higher in 2020 compared to 2019 primarily due to ~~higher proceeds from the issuance~~lower repayments of long-term ~~debt.~~debt in 2020.

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, 2019,~~March 31, 2020, we had consolidated bank lines of credit aggregating $407.0 million ($407.0 million as of December 31, ~~2018)~~2019), the majority of which expire in January 2024. We had ~~$56.3~~$66.3 million outstanding in standby letters of credit and no$0.2 million outstanding draws under our lines of credit as of ~~June 30, 2019~~March 31, 2020 ($~~18.4~~62.0 million in standby letters of credit and no outstanding draws as of December 31, ~~2018)~~2019). In addition, as of ~~June 30, 2019,~~March 31, 2020, we had ~~2.8~~3.6 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, Inc. (See~~ ~~Securities.~~)Markets. The amount and timing of future sales of our securities will depend upon market conditions and our specific needs. OnIn July ~~31,~~ 2019, we filed Registration Statement No. 333-232905, pursuant to which the remaining shares will continue to be offered for sale, from time to time.

Securities. During the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, we issued ~~0.2~~0.1 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 ~~$1.5~~$3.3 million ~~(0.3~~(0.1 million shares were issued for the ~~six~~three months ended ~~June 30, 2018,~~March 31, 2019, resulting in net proceeds of ~~$10.7~~$0.8 million). These shares of common stock were registered under Registration Statement Nos. 333-231030, 333-211075, 333-183051 and 333-162890.

Financial Covenants. See Note 6.5. 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 ~~10.~~9. Pension and Other Postretirement Benefit Plans.)

LIQUIDITY AND CAPITAL RESOURCES (Continued)

Off-Balance Sheet Arrangements. Off-balance sheet arrangements are summarized in our ~~2018~~2019 Form 10-K, with additional disclosure in Note 7.6. Commitments, Guarantees and Contingencies.

~~LIQUIDITY AND CAPITAL RESOURCES (Continued)~~

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



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


(a)	Not rated by S&P Global Ratings.

On ~~March 26, 2019, Moody’s~~April 22, 2020, S&P Global Ratings downgraded ~~the~~ALLETE’s long-term ~~ratings of ALLETE, including its~~ issuer credit rating to ~~Baa1 from A3, and changed its credit rating outlook to~~BBB stable from ~~negative. Moody’s~~BBB+ outlook negative and affirmed its short-term rating at A-2. S&P Global Ratings noted the ~~combined impact~~impacts of ~~the 2018 adverse general rate case outcome at Minnesota Power as well as its~~ 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 ~~2019 and~~ 2020 are ~~now~~ expected to be approximately ~~$695 million~~$535 million; however, the Company is evaluating its planned capital expenditures and ~~$495 million, respectively. The increases from~~may make adjustments to mitigate impacts of the ~~2019~~ongoing COVID-19 pandemic, if appropriate. At this time, we do not have an update to the amount of capital expenditures expected in 2020 due to uncertainty regarding the extent and duration of the COVID-19 pandemic. For the three months ended March 31, 2020, capital expenditures projected in our 2018 Form 10-K is primarily due to the Diamond Spring wind energy facility ALLETE Clean Energy will build, own and operate pursuant to long-term PSAs with Walmart Inc., Smithfield Foods, Inc. and Starbucks Corporation. (See Outlook – ALLETE Clean Energy.) For the six months ended June 30, 2019, capital expenditures totaled ~~$249.3~~$161.8 million ($~~113.9~~85.1 million for the ~~six~~three months ended ~~June 30, 2018)~~March 31, 2019). The expenditures were primarily made in the Regulated Operations and ALLETE Clean Energy segments.

OTHER

Environmental Matters.

Employees.

As of ~~June 30, 2019,~~March 31, 2020, ALLETE had ~~1,369~~1,352 employees, of which ~~1,326~~1,328 were full-time.

Minnesota Power and SWL&P have an aggregate of ~~458~~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, ~~2020,~~2023, for Minnesota Power and February 1, 2021, for SWL&P.

BNI Energy has 181 employees, of which 135 are subject to a labor agreement with IBEW Local 1593. The current labor agreement with IBEW Local 1593 ~~expired~~expires on March 31, ~~2019. Negotiations are proceeding and we believe a ratified agreement will be agreed upon with no disruption to operations.~~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, 2019~~March 31, 2020, our available-for-sale securities portfolio consisted primarily of securities held in other postretirement plans to fund employee benefits.

COMMODITY PRICE RISK

Our regulated utility operations incur costs for power and fuel (primarily coal and related transportation) in Minnesota, and power and natural gas purchased for resale in our regulated service territory in Wisconsin. Minnesota Power’s exposure to price risk for these commodities is significantly mitigated by the current ratemaking process and regulatory framework, which allows recovery of fuel costs in excess of those included in base rates or distribution of savings in fuel costs to ratepayers. SWL&P’s exposure to price risk for natural gas is significantly mitigated by the current ratemaking process and regulatory framework, which allows the commodity cost to be passed through to customers. We seek to prudently manage our customers’ exposure to price risk by entering into contracts of various durations and terms for the purchase of power and coal and related transportation costs (Minnesota Power), and natural gas (SWL&P).

POWER MARKETING

Minnesota Power’s power marketing activities consist of: (1) purchasing energy in the wholesale market to serve its regulated service territory when energy requirements exceed generation output; and (2) selling excess available energy and purchased power. From time to time, Minnesota Power may have excess energy that is temporarily not required by retail and municipal customers in our regulated service territory. Minnesota Power actively sells any excess energy to the wholesale market to optimize the value of its generating facilities.

We are exposed to credit risk primarily through our power marketing activities. We use credit policies to manage credit risk, which includes utilizing an established credit approval process and monitoring counterparty limits.

INTEREST RATE RISK

We are exposed to risks resulting from changes in interest rates as a result of our issuance of variable rate debt. We manage our interest rate risk by varying the issuance and maturity dates of our fixed rate debt, limiting the amount of variable rate debt, and continually monitoring the effects of market changes in interest rates. We may also enter into derivative financial instruments, such as interest rate swaps, to mitigate interest rate exposure. Interest rates on variable rate long-term debt are reset on a periodic basis reflecting prevailing market conditions. Based on the variable rate debt outstanding as of ~~June 30, 2019~~March 31, 2020, an increase of 100 basis points in interest rates would impact the amount of pre-tax interest expense by ~~$0.5~~$2.6 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, 2019~~March 31, 2020.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures. As of ~~June 30, 2019~~March 31, 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.

ITEM 4. CONTROLS AND PROCEDURES (Continued)

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.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

For information regarding material legal and regulatory proceedings, see Note 4. Regulatory Matters and Note ~~11.~~9. Commitments, Guarantees and Contingencies to the Consolidated Financial Statements in our ~~2018~~2019 Form 10-K and Note 2. Regulatory Matters and Note 7.6. Commitments, Guarantees and Contingencies herein. Such information is incorporated herein by reference.

ITEM 1A. RISK FACTORS

~~There have been no material changes from~~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 ~~2018~~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. 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. The states of Minnesota and Wisconsin issued stay-at-home or shelter-in-place orders in March 2020 that remain in effect, and many non-essential commercial and industrial customers are operating at reduced levels or are temporarily closed or idled. In addition, as a result of the COVID-19 pandemic, Cliffs temporarily idled its Northshore Mining operation, Hibbing Taconite temporarily idled production and USS Corporation indefinitely idled its Keetac plant as well as announced a temporary partial shutdown at its Minntac plant, each of which are served by Minnesota Power. (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 waved 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.

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.

ITEM 6. EXHIBITS



Exhibit Number
3		Bylaws, as amended effective April 13, 2020 (filed as Exhibit 3 to the April 14, 2020, Form 8-K, File No. 1-3548).
4		~~First Amendment to Amended and Restated Credit~~Term Loan Agreement dated as of ~~May 15, 2019,~~April 6, 2020, among ALLETE, Inc., as Borrower, the ~~lenders~~Lenders party hereto, ~~JPMorgan~~U.S. Bank National Association, as Administrative Agent and CoBank, ACB, J.P. Morgan Chase Bank, N.A. and Bank of America, N.A., as ~~Administrative Agent.~~Co-Documentation Agents and U.S. Bank National Association as Lead Arranger and Book Runner.
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 1, 2019,~~May 6, 2020, announcing ~~2019 second~~2020 first 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)

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 1, 2019~~May 6, 2020		/s/ Robert J. Adams
		Robert J. Adams
		Senior Vice President and Chief Financial Officer
		(Principal Financial Officer)




~~August 1, 2019~~May 6, 2020		/s/ Steven W. Morris
		Steven W. Morris
		Vice President, Controller and Chief Accounting Officer
		(Principal Accounting Officer)

ALLETE, Inc. ~~Second~~First Quarter ~~2019~~2020 Form 10-Q

5046



	December 31, 2018		Amortization	Other (b)	June 30, 2019
Millions
Intangible Assets
Definite-Lived Intangible Assets
Customer Relationships		$50.7	$(1.1)	$(49.6)	—
Developed Technology and Other (a)	7.5		(0.3)	(6.1)		$1.1
Total Definite-Lived Intangible Assets	58.2		(1.4)	(55.7)	1.1
Indefinite-Lived Intangible Assets
Trademarks and Trade Names	16.6		n/a	(16.6)	—
Total Intangible Assets		$74.8	$(1.4)	$(72.3)		$1.1



	Fair Value as of June 30, 2019
Recurring Fair Value Measures	Level 1		Level 2		Level 3		Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities		$10.9	—		—			$10.9
Available-for-sale – Corporate and Governmental Debt Securities (b)	—			$9.5	—		9.5
Cash Equivalents	1.1		—		—		1.1
Total Fair Value of Assets		$12.0		$9.5	—			$21.5

Liabilities
Deferred Compensation (c)	—			$21.7	—			$21.7
Total Fair Value of Liabilities	—			$21.7	—			$21.7
Total Net Fair Value of Assets (Liabilities)		$12.0	$(12.2)		—		$(0.2)


	Fair Value as of December 31, 2018
Recurring Fair Value Measures	Level 1		Level 2		Level 3		Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities		$12.2	—		—			$12.2
Available-for-sale – Corporate and Governmental Debt Securities	—			$8.0	—		8.0
Cash Equivalents	1.0		—		—		1.0
Total Fair Value of Assets		$13.2		$8.0	—			$21.2

Liabilities
Deferred Compensation (c)	—			$19.8	—			$19.8
U.S. Water Services Contingent Consideration (d)	—		—			$3.8	3.8
Total Fair Value of Liabilities	—			$19.8		$3.8		$23.6
Total Net Fair Value of Assets (Liabilities)		$13.2	$(11.8)		$(3.8)		$(2.4)