Northshore Mining Company, a wholly-owned subsidiary of Cleveland-Cliffs Inc.
注意___
注意___在本10-Q表格的合并财务报表中
NPDES
National Pollutant Discharge Elimination System
NTEC
Nemadji Trail 能源中心
PPA / PSA
能源购买协议 / 能源销售协议
PPACA
2010年《患者保护与平价医保法案》
PSCW
威斯康辛州公共服务委员会
RSOP
养老储蓄和股票所有权计划
SEC
证券交易委员会
SO2
Sulfur Dioxide
Sofidel
Sofidel集团
Square Butte
Square Butte Electric Cooperative，北达科他州合作社
South Shore Energy
South Shore Energy，有限责任公司
圣特纸业
圣特纸业有限责任公司
SWL&P
优良水、光能及电力公司
塔科奈特港
塔科奈特港能源中心
美国交易法案交易所
美利坚合众国
美国钢铁公司
600 Grant Street
ALLETE, Inc. Third Quarter 2024 Form 10-Q
4
Forward-Looking Statements
Statements in this report that are not statements of historical facts are considered “forward-looking” and, accordingly, involve risks and uncertainties that could cause actual results to differ materially from those discussed. Although such forward-looking statements have been made in good faith and are based on reasonable assumptions, there can be no assurance that the expected results will be achieved. Any statements that express, or involve discussions as to, future expectations, risks, beliefs, plans, objectives, assumptions, events, uncertainties, financial performance, or growth strategies (often, but not always, through the use of words or phrases such as “anticipates,” “believes,” “estimates,” “expects,” “intends,” “plans,” “projects,” “likely,” “will continue,” “could,” “may,” “potential,” “target,” “outlook” or words of similar meaning) are not statements of historical facts and may be forward-looking.
In connection with the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, we are providing this cautionary statement to identify important factors that could cause our actual results to differ materially from those indicated in forward-looking statements made by or on behalf of ALLETE in this Form 10-Q, in presentations, on our website, in response to questions or otherwise. These statements are qualified in their entirety by reference to, and are accompanied by, the following important factors, in addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements that could cause our actual results to differ materially from those indicated in the forward-looking statements:
•our ability to successfully implement our strategic objectives;
•global and domestic economic conditions affecting us or our customers;
•changes in and compliance with laws and regulations or changes in tax rates or policies;
•changes in rates of inflation or availability of key materials and supplies;
•the outcome of legal and administrative proceedings (whether civil or criminal) and settlements;
•weather conditions, natural disasters and pandemic diseases;
•our ability to access capital markets, bank financing and other financing sources;
•changes in interest rates and the performance of the financial markets;
•project delays or changes in project costs;
•changes in operating expenses and capital expenditures and our ability to raise revenues from our customers;
•the impacts of commodity prices on ALLETE and our customers;
•our ability to attract and retain qualified, skilled and experienced personnel;
•effects of emerging technology;
•war, acts of terrorism and cybersecurity attacks;
•our ability to manage expansion and integrate acquisitions;
•population growth rates and demographic patterns;
•wholesale power market conditions;
•federal and state regulatory and legislative actions that impact regulated utility economics, including our allowed rates of return, capital structure, ability to secure financing, industry and rate structure, acquisition and disposal of assets and facilities, operation and construction of plant facilities and utility infrastructure, recovery of purchased power, capital investments and other expenses, including present or prospective environmental matters;
•effects of competition, including competition for retail and wholesale customers;
•effects of restructuring initiatives in the electric industry;
•the impacts on our businesses of climate change and future regulation to restrict the emissions of GHG;
•effects of increased deployment of distributed low-carbon electricity generation resources;
•the impacts of laws and regulations related to renewable and distributed generation;
•pricing, availability and transportation of fuel and other commodities and the ability to recover the costs of such commodities;
•our current and potential industrial and municipal customers’ ability to execute announced expansion plans;
•real estate market conditions where our legacy Florida real estate investment is located may deteriorate;
•the success of efforts to realize value from, invest in, and develop new opportunities;
•the risk that Alloy Parent or ALLETE may be unable to obtain governmental and regulatory approvals required for the Merger, or that required governmental and regulatory approvals or agreements with other parties interested therein may delay the Merger, may subject the Merger to or impose adverse conditions or costs, or may cause the parties to abandon the Merger;
•the occurrence of any event, change or other circumstances that could give rise to the termination of the Merger Agreement or could otherwise cause the failure of the Merger to be consummated on the timeline anticipated; and
•the announcement and pendency of the Merger, during which ALLETE is subject to certain operating restrictions, could have an adverse effect on ALLETE’s businesses, results of operations, financial condition or cash flows.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
5
Forward-Looking Statements (Continued)
Additional disclosures regarding factors that could cause our results or performance to differ from those anticipated by this report are discussed in Part I, Item 1A. Risk Factors of our 2023 Form 10-K and Part II, Item 1A. Risk Factors of this Form 10-Q. Any forward-looking statement speaks only as of the date on which such statement is made, and we undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which that statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time, and it is not possible for management to predict all of these factors, nor can it assess the impact of each of these factors on the businesses of ALLETE or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement. Readers are urged to carefully review and consider the various disclosures made by ALLETE in this Form 10-Q and in other reports filed with the SEC that attempt to identify the risks and uncertainties that may affect ALLETE’s business.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
6
PART I. FINANCIAL INFORMATION
ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS
ALLETE
CONSOLIDATED BALANCE SHEET
Unaudited
September 30, 2024
December 31, 2023
Millions
Assets
Current Assets
Cash and Cash Equivalents
$101.9
$71.9
Accounts Receivable (Less Allowance of $1.6 and $1.6)
136.8
137.2
Inventories – Net
166.6
175.4
Prepayments and Other
78.1
83.6
Total Current Assets
483.4
468.1
Property, Plant and Equipment – Net
5,112.8
5,013.4
Regulatory Assets
386.1
425.4
Equity Investments
337.9
331.2
Goodwill and Intangible Assets – Net
155.3
155.4
Other Non-Current Assets
261.7
262.9
Total Assets
$6,737.2
$6,656.4
Liabilities, Redeemable Non-Controlling Interest and Equity
Liabilities
Current Liabilities
Accounts Payable
$110.8
$102.2
Accrued Taxes
60.2
51.0
Accrued Interest
19.1
21.1
Long-Term Debt Due Within One Year
41.8
111.4
Other
102.5
91.9
Total Current Liabilities
334.4
377.6
Long-Term Debt
1,743.7
1,679.9
Deferred Income Taxes
255.5
192.7
Regulatory Liabilities
562.1
574.0
Defined Benefit Pension and Other Postretirement Benefit Plans
134.5
160.8
Other Non-Current Liabilities
314.4
264.3
Total Liabilities
3,344.6
3,249.3
Commitments, Guarantees and Contingencies (Note 6)
Redeemable Non-Controlling Interest
0.7
0.5
Equity
ALLETE Equity
Common Stock Without Par Value, 80.0 Shares Authorized, 57.8 and 57.6 Shares Issued and Outstanding
1,819.1
1,803.7
Accumulated Other Comprehensive Loss
(21.0)
(20.5)
Retained Earnings
1,033.1
1,026.4
Total ALLETE Equity
2,831.2
2,809.6
Non-Controlling Interest in Subsidiaries
560.7
597.0
Total Equity
3,391.9
3,406.6
Total Liabilities, Redeemable Non-Controlling Interest and Equity
$6,737.2
$6,656.4
The accompanying notes are an integral part of these statements.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
7
ALLETE
CONSOLIDATED STATEMENT OF INCOME
Unaudited
Quarter Ended
Nine Months Ended
September 30,
September 30,
2024
2023
2024
2023
Millions Except Per Share Amounts
Operating Revenue
Contracts with Customers – Utility
$310.5
$314.3
$928.6
$919.1
Contracts with Customers – Non-utility
95.4
63.2
232.6
554.1
Other – Non-utility
1.3
1.3
3.8
3.9
Total Operating Revenue
407.2
378.8
1,165.0
1,477.1
Operating Expenses
Fuel, Purchased Power and Gas – Utility
116.5
124.9
357.3
350.8
Transmission Services – Utility
19.6
22.7
43.9
66.3
Cost of Sales – Non-utility
47.0
33.0
103.2
436.7
Operating and Maintenance
92.7
83.6
286.5
254.2
Depreciation and Amortization
70.8
63.1
201.8
188.2
Taxes Other than Income Taxes
15.3
15.5
50.3
43.1
Total Operating Expenses
361.9
342.8
1,043.0
1,339.3
Operating Income
45.3
36.0
122.0
137.8
Other Income (Expense)
Interest Expense
(20.3)
(20.5)
(60.8)
(60.9)
Equity Earnings
5.1
4.7
16.5
16.1
Other
5.5
68.7
20.0
75.3
Total Other Income (Expense)
(9.7)
52.9
(24.3)
30.5
Income Before Income Taxes
35.6
88.9
97.7
168.3
Income Tax Expense
2.9
19.3
8.3
20.4
Net Income
32.7
69.6
89.4
147.9
Net Loss Attributable to Non-Controlling Interest
(12.3)
(16.3)
(39.3)
(47.7)
Net Income Attributable to ALLETE
$45.0
$85.9
$128.7
$195.6
Average Shares of Common Stock
Basic
57.8
57.4
57.7
57.3
Diluted
57.9
57.5
57.8
57.4
Basic Earnings Per Share of Common Stock
$0.78
$1.50
$2.23
$3.41
Diluted Earnings Per Share of Common Stock
$0.78
$1.49
$2.23
$3.41
The accompanying notes are an integral part of these statements.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
8
ALLETE
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
Unaudited
Quarter Ended
Nine Months Ended
September 30,
September 30,
2024
2023
2024
2023
Millions
Net Income
$32.7
$69.6
$89.4
$147.9
Other Comprehensive Loss
Unrealized Gain on Securities
Net of Income Tax Expense of $—, $—, $— and $0.1
0.1
—
0.1
0.1
Defined Benefit Pension and Other Postretirement Benefit Plans
Net of Income Tax Benefit of $(0.1), $—, $(0.3) and $(0.1)
(0.2)
(0.1)
(0.6)
(0.2)
Total Other Comprehensive Loss
(0.1)
(0.1)
(0.5)
(0.1)
Total Comprehensive Income
32.6
69.5
88.9
147.8
Net Loss Attributable to Non-Controlling Interest
(12.3)
(16.3)
(39.3)
(47.7)
Total Comprehensive Income Attributable to ALLETE
$44.9
$85.8
$128.2
$195.5
The accompanying notes are an integral part of these statements.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
9
ALLETE
CONSOLIDATED STATEMENT OF CASH FLOWS
Unaudited
Nine Months Ended
September 30,
2024
2023
Millions
Operating Activities
Net Income
$89.4
$147.9
Adjustments to Reconcile Net Income to Cash provided by Operating Activities:
AFUDC – Equity
(4.0)
(2.5)
Income from Equity Investments – Net of Dividends
0.1
0.6
Loss (Gain) on Investments and Property, Plant and Equipment
(0.5)
0.6
Depreciation Expense
201.7
188.2
Amortization of PSAs
(3.8)
(3.9)
Amortization of Other Intangible Assets and Other Assets
5.2
5.3
Deferred Income Tax Expense (Benefit)
(7.2)
1.3
Share-Based and ESOP Compensation Expense
5.5
4.3
Defined Benefit Pension and Other Postretirement Plan Benefit
(10.3)
(2.5)
Fuel Adjustment Clause
6.7
53.8
Bad Debt Expense
1.1
1.2
Provision for Interim Rate Refund
17.0
21.0
Changes in Operating Assets and Liabilities
Accounts Receivable
1.7
17.2
Inventories
2.5
275.6
Prepayments and Other
(2.0)
0.6
Accounts Payable
(3.1)
(8.0)
Other Current Liabilities
(11.7)
(167.9)
Renewable Tax Credit Sales
58.4
—
Cash Contributions to Defined Benefit Pension Plans
(25.0)
(17.3)
Changes in Regulatory and Other Non-Current Assets
38.5
4.1
Changes in Regulatory and Other Non-Current Liabilities
7.1
0.4
Cash provided by Operating Activities
367.3
520.0
Investing Activities
Proceeds from Sale of Available-for-sale Securities
1.7
0.5
Payments for Purchase of Available-for-sale Securities
(1.9)
(0.8)
Payments for Equity Method Investments
(5.8)
(6.6)
Additions to Property, Plant and Equipment
(230.3)
(184.1)
Other Investing Activities
16.4
(9.6)
Cash used in Investing Activities
(219.9)
(200.6)
Financing Activities
Proceeds from Issuance of Common Stock
9.9
11.4
Proceeds from Issuance of Short-Term and Long-Term Debt
628.0
409.8
Repayments of Short-Term and Long-Term Debt
(633.0)
(533.4)
Proceeds from Non-Controlling Interest in Subsidiaries – Net
4.1
9.9
Distributions to Non-Controlling Interest
(0.9)
(8.5)
Dividends on Common Stock
(122.0)
(116.5)
Other Financing Activities
(1.9)
(1.1)
Cash used in Financing Activities
(115.8)
(228.4)
Change in Cash, Cash Equivalents and Restricted Cash
31.6
91.0
Cash, Cash Equivalents and Restricted Cash at Beginning of Period
79.4
40.2
Cash, Cash Equivalents and Restricted Cash at End of Period
$111.0
$131.2
The accompanying notes are an integral part of these statements.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
10
ALLETE
CONSOLIDATED STATEMENT OF EQUITY
Unaudited
Quarter Ended
Nine Months Ended
September 30,
September 30,
2024
2023
2024
2023
Millions Except Per Share Amounts
Equity
Common Stock
Balance, Beginning of Period
$1,813.8
$1,791.6
$1,803.7
$1,781.5
Common Stock Issued
5.3
5.6
15.4
15.7
Balance, End of Period
1,819.1
1,797.2
1,819.1
1,797.2
Accumulated Other Comprehensive Loss
Balance, Beginning of Period
(20.9)
(24.4)
(20.5)
(24.4)
Other Comprehensive Income – Net of Income Taxes
Unrealized Gain on Debt Securities
0.1
—
0.1
0.1
Defined Benefit Pension and Other Postretirement Plans
(0.2)
(0.1)
(0.6)
(0.2)
Balance, End of Period
(21.0)
(24.5)
(21.0)
(24.5)
Retained Earnings
Balance, Beginning of Period
1,028.8
966.9
1,026.4
934.8
Net Income Attributable to ALLETE
45.0
85.9
128.7
195.6
Common Stock Dividends
(40.7)
(38.9)
(122.0)
(116.5)
Balance, End of Period
1,033.1
1,013.9
1,033.1
1,013.9
Non-Controlling Interest in Subsidiaries
Balance, Beginning of Period
573.0
634.4
597.0
656.4
Proceeds from Non-Controlling Interest in Subsidiaries – Net
—
—
1.4
9.9
Net Loss Attributable to Non-Controlling Interest
(12.1)
(16.3)
(36.8)
(47.7)
Distributions to Non-Controlling Interest
(0.2)
(8.0)
(0.9)
(8.5)
Balance, End of Period
560.7
610.1
560.7
610.1
Total Equity
$3,391.9
$3,396.7
$3,391.9
$3,396.7
Redeemable Non-Controlling Interest
Balance, Beginning of Period
$0.9
—
$0.5
—
Proceeds from Non-Controlling Interest in Subsidiaries
—
—
2.7
—
Net Loss Attributable to Non-Controlling Interest
(0.2)
—
(2.5)
—
Total Redeemable Non-Controlling Interest
$0.7
—
$0.7
—
Dividends Per Share of Common Stock
$0.705
$0.6775
$2.115
$2.0325
The accompanying notes are an integral part of these statements.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
11
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 pursuant to such rules and regulations. Similarly, the December 31, 2023, Consolidated Balance Sheet was derived from audited financial statements, but does not include all disclosures required by GAAP. The presentation of certain prior period amounts on the Consolidated Financial Statements have been adjusted for comparative purposes. In management’s opinion, these unaudited financial statements include all adjustments necessary for a fair statement of financial results. All adjustments are of a normal, recurring nature, except as otherwise disclosed. Operating results for the nine months ended September 30, 2024, are not necessarily indicative of results that may be expected for any other interim period or for the year ending December 31, 2024. For further information, refer to the Consolidated Financial Statements and notes included in our 2023 Form 10-K.
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES
Subsequent Events. The Company performed an evaluation of subsequent events for potential recognition and disclosure through the date of the financial statements issuance.
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 September 30, 2024, restricted cash amounts included in Prepayments and Other on the Consolidated Balance Sheet include collateral deposits required under an ALLETE Clean Energy loan. The restricted cash amounts included in Other Non-Current Assets represent collateral deposits required under an ALLETE Clean Energy loan agreement as well as PSAs.The following table provides a reconciliation of cash, cash equivalents and restricted cash reported within the Consolidated Balance Sheet that aggregate to the amounts presented in the Consolidated Statement of Cash Flows.
Cash, Cash Equivalents and Restricted Cash
September 30, 2024
December 31, 2023
September 30, 2023
December 31, 2022
Millions
Cash and Cash Equivalents
$101.9
$71.9
$125.5
$36.4
Restricted Cash included in Prepayments and Other
6.6
5.1
3.3
1.5
Restricted Cash included in Other Non-Current Assets
2.5
2.4
2.4
2.3
Cash, Cash Equivalents and Restricted Cash on the Consolidated Statement of Cash Flows
$111.0
$79.4
$131.2
$40.2
Inventories – Net. Inventories are stated at the lower of cost or net realizable value. Inventories in our Regulated Operations segment are carried at an average cost or first-in, first-out basis. Inventories in our ALLETE Clean Energy segment and Corporate and Other businesses are carried at an average cost, first-in, first-out or specific identification basis.
Inventories – Net
September 30, 2024
December 31, 2023
Millions
Fuel (a)
$21.7
$27.2
Materials and Supplies
115.5
115.7
Renewable Energy Facilities Under Development (b)
29.4
32.5
Total Inventories – Net
$166.6
$175.4
(a) Fuel consists primarily of coal inventory at Minnesota Power.
(b) Renewable Energy Facilities Under Development as of September 30, 2024, consists primarily of project costs related to renewable energy development projects at New Energy.
Goodwill. The aggregate carrying amount of goodwill was $154.9 million as of September 30, 2024 ($154.9 million as of December 31, 2023). There have been no changes to goodwill by reportable segment for the quarter and nine months ended September 30, 2024.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
12
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Other Non-Current Assets
September 30, 2024
December 31, 2023
Millions
Other Postretirement Benefit Plans
$101.1
$106.3
Contract Assets(a)
16.6
18.5
Operating Lease Right-of-use Assets
10.8
10.7
ALLETE Properties
10.4
10.8
Restricted Cash
2.5
2.4
Finance Lease Right-of-use Assets
2.0
2.1
Other
118.3
112.1
Total Other Non-Current Assets
$261.7
$262.9
(a) Contract Assets consist of payments made to customers as an incentive to execute or extend service agreements. The payments are being amortized over the term of the respective agreements as a reduction to revenue.
Other Current Liabilities
September 30, 2024
December 31, 2023
Millions
Provision for Interim Rate Refund
$17.0
—
Customer Deposits
9.2
$7.4
PSAs
5.9
6.0
Operating Lease Liabilities
3.4
3.0
Finance Lease Liabilities
0.4
0.4
Other
66.6
75.1
Total Other Current Liabilities
$102.5
$91.9
Other Non-Current Liabilities
September 30, 2024
December 31, 2023
Millions
Asset Retirement Obligation (a)(b)
$258.9
$202.9
PSAs
16.5
20.9
Operating Lease Liabilities
7.5
7.7
Finance Lease Liabilities
1.4
1.6
Other
30.1
31.2
Total Other Non-Current Liabilities
$314.4
$264.3
(a)The asset retirement obligation is primarily related to our Regulated Operations and is funded through customer rates over the life of the related assets. Additionally, BNI Energy funds its obligation through its cost-plus coal supply agreements for which BNI Energy has recorded a receivable of $37.2 million in Other Non-Current Assets on the Consolidated Balance Sheet as of September 30, 2024 ($37.2 million as of December 31, 2023).
(b)The increase in Asset Retirement Obligation in 2024 reflects the impact of estimated compliance costs related to the EPA’s CCR Legacy Impoundment Rule finalized in May 2024. (See Note 6. Commitments, Guarantees and Contingencies.)
ALLETE, Inc. Third Quarter 2024 Form 10-Q
13
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Quarter Ended
Nine Months Ended
September 30,
September 30,
Other Income (Expense)
2024
2023
2024
2023
Millions
Pension and Other Postretirement Benefit Plan Non-Service Credits (a)
$3.0
$1.8
$11.0
$5.5
Interest and Investment Income (b)
1.2
6.6
3.9
8.7
AFUDC - Equity
1.5
1.1
4.0
2.5
Gain on Arbitration Award (c)
—
58.4
—
58.4
Other Income (Expense)
(0.2)
0.8
1.1
0.2
Total Other Income
$5.5
$68.7
$20.0
$75.3
(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.)
(b)Interest and Investment Income for the quarter and nine months ended September 30, 2023, reflects $5.1 million of interest income related to interest awarded as part of an arbitration ruling involving a subsidiary of ALLETE Clean Energy. (See Note 6. Commitments, Guarantees, and Contingencies.)
(c)This reflects a gain recognized for the favorable outcome of an arbitration ruling involving a subsidiary of ALLETE Clean Energy. (See Note 6. Commitments, Guarantees, and Contingencies.)
Nine Months Ended
September 30,
Supplemental Statement of Cash Flows Information
2024
2023
Millions
Cash Paid for Interest – Net of Amounts Capitalized
$59.5
$64.8
Cash Paid for Income Taxes – Net
$7.0
$14.1
Noncash Investing and Financing Activities
Increase in Accounts Payable for Capital Additions to Property, Plant and Equipment
$13.5
$11.8
Capitalized Asset Retirement Costs (a)
$51.0
$2.4
AFUDC–Equity
$4.0
$2.5
(a)Capitalized asset retirement costs in 2024 reflect the impact of estimated compliance costs related to the EPA’s CCR Legacy Impoundment Rule finalized in May 2024. (See Note 6. Commitments, Guarantees and Contingencies.)
New Accounting Pronouncements and Disclosure Rules.
See Note 1. Operations and Significant Accounting Policies to the Consolidated Financial Statements in our 2023 Form 10-K, with additional disclosure provided in the following paragraphs.
SEC Climate-related Disclosures Rule. On March 6, 2024, the SEC issued the final rules regarding the enhancement and standardization of climate-related disclosures for investors (Rule). The Rule requires registrants to provide certain climate-related information in their annual reports and registration statements. These requirements include disclosing climate-related risks that materially affect or are reasonably likely to materially affect a registrant’s business strategy, results of operations, or financial condition as well as certain disclosures related to greenhouse-gas emissions, and the effects of severe weather events and other natural conditions. The Rule provides that the disclosure requirements will begin phasing in for annual periods beginning in 2025. The Company is evaluating the final rule to determine its impact on the Company’s disclosures. The Rule is currently being challenged before the U.S. Court of Appeals for the Eighth Circuit (Eighth Circuit Court), and the SEC issued a voluntary stay of the Rule on April 4, 2024, pending judicial review.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
14
NOTE 1. OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES (Continued)
Improvements to Reportable Segment Disclosures. In November 2023, the FASB issued Accounting Standards Update 2023-07, Improvements to Reportable Segment Disclosures (ASU 2023-07). ASU 2023-07 requires that an entity provide enhanced disclosures about significant segment expenses that are regularly provided to the chief operating decision maker, among other disclosures. ASU 2023-07 is effective for annual periods beginning after December 15, 2023, and for quarterly periods beginning after December 15, 2024, with early adoption permitted. We have assessed the impact of this updated guidance and expect to provide enhanced disclosures for our segments in our Form 10-K for the year ended December 31, 2024.
There are no other new accounting pronouncements or rules that we anticipate having a material effect on the presentation of ALLETE’s consolidated financial statements.
NOTE 2. REGULATORY MATTERS
Regulatory matters are summarized in Note 4. Regulatory Matters to the Consolidated Financial Statements in our 2023 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 $15.1 million for the nine months ended September 30, 2024 ($44.9 million for the nine months ended September 30, 2023).
2024 Minnesota General Rate Case. On November 1, 2023, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 12.00 percent for retail customers, net of rider revenue incorporated into base rates. The rate filing seeks a return on equity of 10.30 percent and a 53.00 percent equity ratio. On an annualized basis, the requested final rate increase would generate approximately $89 million in additional revenue. In separate orders dated December 19, 2023, the MPUC accepted the filing as complete and approved an annual interim rate increase of approximately $64 million, net of rider revenue, beginning January 1, 2024, subject to refund.
On May 3, 2024, Minnesota Power entered into a settlement agreement with the Minnesota Department of Commerce, Minnesota Office of the Attorney General, Residential Utilities Division, and Large Power Intervenors to settle the retail rate increase request. As part of the settlement agreement, the parties agreed on all issues, including an overall rate increase of $33.97 million, net of rider revenue and amounts transferring to the fuel adjustment clause, a return on equity of 9.78 percent, all non-financial items and cost allocation. At a hearing on October 24, 2024, the MPUC approved the settlement agreement. Final rates are expected to be implemented in the first quarter of 2025; interim rates will be collected through this period with reserves recorded as necessary. As a result of the settlement, Minnesota Power recorded a reserve for an interim rate refund of $17.0 million pre-tax as of September 30, 2024, which is subject to MPUC approval of Minnesota Power’s refund calculation.
2022 Minnesota General Rate Case. Minnesota Power appealed with the Minnesota Court of Appeals (Court) specific aspects of the MPUC’s February 2023 and May 2023 rate case orders for the ratemaking treatment of Taconite Harbor and Minnesota Power’s prepaid pension asset. Oral arguments on the appeal were heard by the Court on June 27, 2024. On September 9, 2024, the Court affirmed the MPUC’s Taconite Harbor treatment, but reversed and remanded the treatment of Minnesota Power’s prepaid pension asset back to the MPUC. The Court directed the MPUC to determine the amount of Minnesota Power’s prepaid pension asset to be included in rate base. The MPUC has not yet determined the next procedural steps in implementing the Court’s decision.
2024 Wisconsin General Rate Case. On March 29, 2024, SWL&P filed a rate increase request for its electric, gas and water utilities with the PSCW. The filing seeks an overall return on equity of 10.00 percent and a 55.00 percent equity ratio. On an annualized basis, the requested change would increase rates by approximately 5.90 percent for retail customers and generate an estimated $7.3 million of additional revenue. The change to SWL&P customers’ rates will be determined by the PSCW later this year. Any rate adjustments are anticipated to become effective in January 2025. We cannot predict the level of final rates that may be authorized by the PSCW.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
15
NOTE 2. REGULATORY MATTERS (Continued)
Transmission Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for certain transmission investments and expenditures, including a return on the capital invested. Current customer billing rates are based on an MPUC order dated December 19, 2023, which provisionally approved Minnesota Power’s latest transmission factor filing submitted on October 24, 2023. Updated billing rates were included on customer bills starting in the first quarter of 2024, and the MPUC approved Minnesota Power’s transmission factor filing with no changes in an order dated March 5, 2024.
Renewable Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for the costs of certain renewable investments and expenditures, including a return on the capital invested. Current customer billing rates for the renewable cost recovery rider were approved by the MPUC in an order dated October 3, 2023. On March 27, 2024, Minnesota Power submitted its latest renewable factor filing. In an order dated June 25, 2024, the MPUC approved the filing and Minnesota Power is authorized to include updated billing rates on customer bills beginning October 1, 2024.
Solar Cost Recovery Rider. Minnesota Power has an approved cost recovery rider in place to charge retail customers on a current basis for solar costs related to investments and expenditures for meeting the state of Minnesota’s solar energy standard. Current customer billing rates were approved by the MPUC in an order dated December 26, 2023. Updated billing rates were included on customer bills starting in the first quarter of 2024.
Fuel Adjustment Clause. Minnesota Power incurred lower fuel and purchased power costs in 2023 than those factored in its fuel adjustment forecast filed in May 2022 for 2023, which resulted in the recognition of an approximately $13 million regulatory liability as of December 31, 2023. Minnesota Power requested to refund the regulatory liability over 12 months beginning in the third quarter of 2024 as part of its annual true-up filing submitted to the MPUC on March 1, 2024. In an order dated July 1, 2024, the MPUC approved the filing, and authorized Minnesota Power to refund the regulatory liability over 12 months beginning on September 1, 2024.
Minnesota Power filed its annual forecasted fuel and purchased energy rates for 2025 on May 1, 2024.
Energy Conservation and Optimization (ECO) Plan. On April 1, 2024, Minnesota Power submitted its 2023 ECO annual filing (formerly the Conservation Improvement Plan) detailing Minnesota Power’s ECO plan results and requesting a financial incentive of $2.2 million, which will be recognized upon approval by the MPUC. In 2023, a financial incentive of $2.2 million was recognized in the third quarter upon approval by the MPUC of the 2022 ECO annual filing. The financial incentives are recognized in the period in which the MPUC approves the filing.
Regulatory Assets and Liabilities. Our regulated utility operations are subject to accounting standards for the effects 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. The recovery, refund or credit to rates for these regulatory assets and liabilities will occur over the periods either specified by the applicable regulatory authority or over the corresponding period related to the asset or liability.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
16
NOTE 2. REGULATORY MATTERS (Continued)
Regulatory Assets and Liabilities
September 30, 2024
December 31, 2023
Millions
Current Regulatory Assets (a)
Fuel Adjustment Clause
—
$8.7
Other
$0.6
0.6
Total Current Regulatory Assets
$0.6
$9.3
Non-Current Regulatory Assets
Defined Benefit Pension and Other Postretirement Plans
$214.5
$218.6
Income Taxes
81.7
88.1
Asset Retirement Obligations
39.9
37.7
Taconite Harbor
20.6
20.9
Manufactured Gas Plant
12.9
13.2
Cost Recovery Riders
8.6
33.8
PPACA Income Tax Deferral
3.8
3.9
Fuel Adjustment Clause
1.5
5.0
Other
2.6
4.2
Total Non-Current Regulatory Assets
$386.1
$425.4
Current Regulatory Liabilities (b)
Provision for Interim Rate Refund
$17.0
—
Fuel Adjustment Clause
10.0
—
Transmission Formula Rates Refund
—
$1.5
Other
0.8
2.4
Total Current Regulatory Liabilities
$27.8
$3.9
Non-Current Regulatory Liabilities
Income Taxes
$292.8
$310.0
Wholesale and Retail Contra AFUDC
76.2
78.0
Plant Removal Obligations
72.8
67.0
Non-Jurisdictional Land Sales
55.0
30.2
Defined Benefit Pension and Other Postretirement Benefit Plans
39.2
48.6
Investment Tax Credits
13.2
13.6
Boswell Units 1 and 2 Net Plant and Equipment
6.7
6.7
Fuel Adjustment Clause
0.6
15.5
Other
5.6
4.4
Total Non-Current Regulatory Liabilities
$562.1
$574.0
(a)Current regulatory assets are presented within Prepayments and Other on the Consolidated Balance Sheet.
(b)Current regulatory liabilities are presented within Other Current Liabilities on the Consolidated Balance Sheet.
NOTE 3. EQUITY INVESTMENTS
Investment in ATC. Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois.We account for our investment in ATC under the equity method of accounting.
ALLETE’s Investment in ATC
Millions
Equity Investment Balance as of December 31, 2023
$179.7
Cash Investments
5.8
Equity in ATC Earnings
17.8
Distributed ATC Earnings
(14.0)
Amortization of the Remeasurement of Deferred Income Taxes
1.0
Equity Investment Balance as of September 30, 2024
$190.3
ALLETE, Inc. Third Quarter 2024 Form 10-Q
17
NOTE 3. EQUITY INVESTMENTS (Continued)
ATC’s authorized return on equity was 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization (RTO), based on a 2020 FERC order which is subject to various outstanding legal challenges related to the return on equity calculation and refund period ordered by the FERC. In August 2022, the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit) vacated and remanded the 2020 FERC order back to FERC. On October 17, 2024, FERC ordered a return on equity of 9.98 percent, or 10.48 percent including an incentive adder for participation in a RTO effective September 28, 2016.
In addition, the FERC issued a Notice of Proposed Rulemaking in 2021 proposing to limit the 0.50 percent incentive adder for participation in a regional transmission organization to only the first three years of membership in such an organization. If this proposal is adopted, our equity in earnings from ATC would be reduced by approximately $1 million pre-tax annually.
Investment in Nobles 2. Our subsidiary, ALLETE South Wind, owns 49 percent of Nobles 2, the entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota pursuant to a 20-year PPA with Minnesota Power. We account for our investment in Nobles 2 under the equity method of accounting.
ALLETE’s Investment in Nobles 2
Millions
Equity Investment Balance as of December 31, 2023
$151.5
Equity in Nobles 2 Earnings (a)
(1.3)
Distributed Nobles 2 Earnings
(2.6)
Equity Investment Balance as of September 30, 2024
$147.6
(a)The Company also recorded earnings from net loss attributable to non-controlling interest of $8.4 million related to its investment in Nobles 2.
NOTE 4. FAIR VALUE
Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the market approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. These inputs, which are used to measure fair value, are prioritized through the fair value hierarchy. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Descriptions of the three levels of the fair value hierarchy are discussed in Note 7. Fair Value to the Consolidated Financial Statements in our 2023 Form 10-K.
The following tables set forth, by level within the fair value hierarchy, our assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2024, and December 31, 2023. 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 on the Consolidated Balance Sheet approximates the carrying amount and therefore is excluded from the recurring fair value measures in the following tables.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
18
NOTE 4. FAIR VALUE (Continued)
Fair Value as of September 30, 2024
Recurring Fair Value Measures
Level 1
Level 2
Level 3
Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities
$9.2
—
—
$9.2
Available-for-sale – Corporate and Governmental Debt Securities (b)
—
$6.7
—
6.7
Cash Equivalents
7.5
—
—
7.5
Total Fair Value of Assets
$16.7
$6.7
—
$23.4
Liabilities
Deferred Compensation (c)
—
$20.5
—
$20.5
Total Fair Value of Liabilities
—
$20.5
—
$20.5
Fair Value as of December 31, 2023
Recurring Fair Value Measures
Level 1
Level 2
Level 3
Total
Millions
Assets
Investments (a)
Available-for-sale – Equity Securities
$8.7
—
—
$8.7
Available-for-sale – Corporate and Governmental Debt Securities
—
$6.0
—
6.0
Cash Equivalents
5.8
—
—
5.8
Total Fair Value of Assets
$14.5
$6.0
—
$20.5
Liabilities
Deferred Compensation (c)
—
$16.5
—
$16.5
Total Fair Value of Liabilities
—
$16.5
—
$16.5
(a)Included in Other Non-Current Assets on the Consolidated Balance Sheet.
(b)As of September 30, 2024, the aggregate amount of available-for-sale corporate and governmental debt securities maturing in one year or less was $2.2 million, in one year to less than three years was $2.3 million, in three years to less than five years was $1.7 million and in five or more years was $0.5 million.
(c)Included in Other Non-Current Liabilities on the Consolidated Balance Sheet.
Fair Value of Financial Instruments. With the exception of the item listed in the following table, the estimated fair value of all financial instruments approximates the carrying amount. The fair value of the item listed in the following table was based on quoted market prices for the same or similar instruments (Level 2).
Financial Instruments
Carrying Amount
Fair Value
Millions
Short-Term and Long-Term Debt (a)
September 30, 2024
$1,794.4
$1,724.7
December 31, 2023
$1,799.4
$1,670.6
(a)Excludes unamortized debt issuance costs.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
19
NOTE 4. FAIR VALUE (Continued)
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 nine months ended September 30, 2024, and the year ended December 31, 2023, there were no indicators of impairment for these non-financial assets.
We continue to monitor changes in the broader energy markets along with wind resource expectations that could indicate impairment at ALLETE Clean Energy wind energy facilities upon contract expirations or for facilities without long-term contracts for their entire output. A continued decline or volatility in energy prices or lower wind resource expectations could result in a future impairment.
NOTE 5. SHORT-TERM AND LONG-TERM DEBT
The following tables present the Company’s short-term and long-term debt as of September 30, 2024, and December 31, 2023:
September 30, 2024
Principal
Unamortized Debt Issuance Costs
Total
Millions
Short-Term Debt
$41.8
—
$41.8
Long-Term Debt
1,752.6
$(8.9)
1,743.7
Total Debt
$1,794.4
$(8.9)
$1,785.5
December 31, 2023
Principal
Unamortized Debt Issuance Costs
Total
Millions
Short-Term Debt
$111.5
$(0.1)
$111.4
Long-Term Debt
1,687.9
(8.0)
1,679.9
Total Debt
$1,799.4
$(8.1)
$1,791.3
We had $23.4 million outstanding in standby letters of credit and no outstanding draws under our lines of credit as of September 30, 2024 ($19.4 million in standby letters of credit and $34.1 million outstanding draws on our lines of credit as of December 31, 2023). We also have standby letters of credit outstanding under other letter of credit facilities. (See Note 6. Commitments, Guarantees and Contingencies.)
On September 5, 2024, ALLETE issued and sold $150 million of senior unsecured notes (“Notes”) to certain institutional buyers in the private placement market. The Notes were sold in reliance on an exemption from registration under Section 4(a)(2) of the Securities Act of 1933, as amended, to institutional accredited investors. Of the Notes issued and sold, $100 million of the Notes bear interest at a rate of 5.94 percent and mature on September 5, 2029, and $50 million of the Notes bear interest at a rate of 6.18 percent and mature on September 5, 2034. Interest on the Notes will be payable semi-annually on March 5 and September 5 of each year, commencing on March 5, 2025. The Company has the option to prepay all or a portion of the Notes at its discretion, subject to a make-whole provision. The Notes are subject to additional terms and conditions which are customary for these types of transactions. Proceeds from the sale of the Notes were used for refinancing of debt and general corporate purposes.
On July 31, 2024, ALLETE issued a notice to the holders of its 2.65 percent senior notes due September 10, 2025, (“2025 Notes”) regarding the Company’s exercise of its option to prepay all of the issued and outstanding 2025 Notes. ALLETE prepaid all $150 million in aggregate principal amount of the 2025 Notes on September 5, 2024. The 2025 Notes were prepaid at 100 percent of their principal amount, plus accrued and unpaid interest.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
20
NOTE 5. SHORT-TERM AND LONG-TERM DEBT (continued)
On April 23, 2024, ALLETE issued $100 million of its First Mortgage Bonds (Bonds) to certain institutional buyers in the private placement market. The Bonds, which bear interest at 5.72 percent, will mature on April 30, 2039 and pay interest semi-annually in April and October of each year, commencing on October 30, 2024. ALLETE has the option to prepay all or a portion of the Bonds at its discretion, subject to a make-whole provision. The Bonds are subject to additional terms and conditions which are customary for these types of transactions. Proceeds from the sale of the Bonds were used to refinance existing indebtedness and for general corporate purposes. The Bonds were sold in reliance on an exemption from registration under Section 4(a)(2) of the Securities Act of 1933, as amended, to institutional accredited investors.
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 September 30, 2024, our ratio was approximately 0.36 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 September 30, 2024, ALLETE was in compliance with its financial covenants.
NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES
Power Purchase and Sale Agreements. Our long-term PPAs have been evaluated under the accounting guidance for variable interest entities. We have determined that either we have no variable interest in the PPAs or, where we do have variable interests, we are not the primary beneficiary; therefore, consolidation is not required. These conclusions are based on the fact that we do not have both control over activities that are most significant to the entity and an obligation to absorb losses or receive benefits from the entity’s performance. Our financial exposure relating to these PPAs is limited to our capacity and energy payments.
Our PPAs are summarized in Note 9. Commitments, Guarantees and Contingencies to the Consolidated Financial Statements in our 2023 Form 10-K, with additional disclosure provided in the following paragraphs.
Square Butte PPA. As of September 30, 2024, Square Butte had total debt outstanding of $174.2 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 nine months ended September 30, 2024, was $66.0 million ($64.8 million for the same period in 2023). This reflects Minnesota Power’s pro rata share of total Square Butte costs based on the 50 percent output entitlement. Included in this amount was Minnesota Power’s pro rata share of interest expense of $3.8 million ($4.1 million for the same period in 2023). Minnesota Power’s payments to Square Butte are approved as a purchased power expense for ratemaking purposes by both the MPUC and the FERC.
Minnkota Power PSA. Minnesota Power has a PSA with Minnkota Power, which commenced in 2014. Under the PSA, Minnesota Power is selling a portion of its entitlement from Square Butte to Minnkota Power, resulting in Minnkota Power’s net entitlement increasing and Minnesota Power’s net entitlement decreasing until Minnesota Power’s share is eliminated at the end of 2025. Of Minnesota Power’s 50 percent output entitlement, Minnesota Power sold to Minnkota Power approximately 41 percent in 2024 and 37 percent in 2023.
Coal, Rail and Shipping Contracts. Minnesota Power has coal supply agreements providing for the purchase of a significant portion of its coal requirements through December 2025. Minnesota Power also has coal transportation agreements in place for the delivery of a significant portion of its coal requirements through December 2024. The costs of fuel and related transportation costs for Minnesota Power’s generation are recoverable from Minnesota Power’s utility customers through the fuel adjustment clause.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
21
NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters.
Our businesses are subject to regulation of environmental matters by various federal, state, and local authorities. A number of regulatory changes to the Clean Air Act, the Clean Water Act and various waste management requirements have been promulgated by both the EPA and state authorities over the past several years. Minnesota Power’s facilities are subject to additional requirements under many of these regulations. Minnesota Power is reshaping its generation portfolio, over time, to reduce its reliance on coal, has installed cost-effective emission control technology, and advocates for sound science and policy during rulemaking implementation.
We consider our businesses to be in substantial compliance with currently applicable environmental regulations and believe all necessary permits have been obtained. We anticipate that with many state and federal environmental regulations and requirements finalized, or to be finalized in the near future, potential expenditures for future environmental matters may be material and require significant capital investments. Minnesota Power has evaluated various environmental compliance scenarios using possible outcomes of environmental regulations to project power supply trends and impacts on customers.
We review environmental matters on a quarterly basis. Accruals for environmental matters are recorded when it is probable that a liability has been incurred and the amount of the liability can be reasonably estimated based on current law and existing technologies. Accruals are adjusted as assessment and remediation efforts progress, or as additional technical or legal information becomes available. Accruals for environmental liabilities are included in the Consolidated Balance Sheet at undiscounted amounts and exclude claims for recoveries from insurance or other third parties. Costs related to environmental contamination treatment and cleanup are expensed unless recoverable in rates from customers.
Air. The electric utility industry is regulated both at the federal and state level to address air emissions. Minnesota Power’s thermal generating facilities mainly burn low-sulfur western sub-bituminous coal, as well as natural gas and biomass. All of Minnesota Power’s coal-fired generating facilities are equipped with pollution control equipment such as scrubbers, baghouses and low NOX technologies. Under currently applicable environmental regulations, these facilities are substantially compliant with emission requirements.
Cross-State Air Pollution Rule (CSAPR). The CSAPR requires certain states in the eastern half of the U.S., including Minnesota, to reduce power plant emissions that contribute to ozone or fine particulate pollution in other states. The CSAPR does not require installation of controls but does require facilities have sufficient allowances to cover their emissions on an annual basis. These allowances are allocated to facilities from each state’s annual budget and can be bought and sold. Based on our review of the NOX and SO2 allowances issued and pending issuance as well as consideration of current rules, we currently expect generation levels and emission rates will result in continued compliance with the CSAPR. Minnesota Power will continue to monitor ongoing CSAPR rulemakings and compliance implementation, including the EPA’s Good Neighbor Rule which modifies certain aspects of the CSAPR’s program scope and extent (see EPA Good Neighbor Plan for 2015 Ozone NAAQS).
National Ambient Air Quality Standards (NAAQS). The EPA is required to review each NAAQS every five years. If the EPA determines that a state’s air quality is not in compliance with the NAAQS, the state is required to adopt plans describing how it will reduce emissions to attain the NAAQS. Minnesota Power actively monitors NAAQS developments, and the EPA is currently reviewing the secondary NAAQS for NOx, SO2, and particulate matter. Implementation of the EPA’s February 2024 final rule lowering the annual primary standard for fine particulate matter began on May 6, 2024. The EPA also released a draft rule on April 15, 2024, proposing to revise the secondary SO2 NAAQS while retaining certain secondary NOX and particulate matter NAAQS, with a final rule expected by January 2025. Anticipated timelines and compliance costs related to this and other potential NAAQS revisions cannot yet be estimated but costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
22
NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
EPA Good Neighbor Plan for 2015 Ozone NAAQS. On June 5, 2023, after disapproving state implementation plans, the EPA published a final Federal Implementation Plan (FIP) rule in the Federal Register, the Good Neighbor Plan, to address regional ozone transport for the 2015 Ozone NAAQS by reducing NOX emissions during the period of May 1 through September 30 (ozone season). In its justification for the final rule, the EPA asserted that 23 states, including Minnesota, were modeled as significant contributors to downwind states’ challenges in attaining or maintaining ozone NAAQS compliance within their state borders. The Good Neighbor Plan is designed to resolve this interstate transport issue by implementing a variety of NOX reduction strategies, including federal implementation plan requirements, NOX emission limitations, and ozone season allowance program requirements. The final rule imposed restrictions on fossil-fuel fired power plants in 22 states and on certain industrial sources in 20 states, with implementation occurring through changes to the existing CSAPR program for power plants.
Since the EPA partially disapproved the Good Neighbor State Implementation Plans (SIPs) for the states of Minnesota and Wisconsin, among others, Minnesota is subject to the final Good Neighbor Plan. However, Minnesota Power and a coalition of other Minnesota utilities and industry (the parties) co-filed challenges to the EPA’s final Minnesota SIP disapproval, submitting a petition for reconsideration and stay to the EPA, and a petition for judicial review to the Eighth Circuit Court. The parties are challenging and requesting reconsideration of certain technical components of the EPA’s review and subsequent partial disapproval of the state of Minnesota’s SIP. On July 5, 2023, the Eighth Circuit Court granted a stay of the SIP disapproval preventing the Good Neighbor Plan from taking effect in Minnesota; oral arguments occurred on October 22, 2024. On March 28, 2024, the EPA issued a partial denial of several administrative reconsideration and stay petitions, including from the Minnesota coalition.
On September 29, 2023, the EPA issued an updated final interim rule addressing the stays in Minnesota and five other states, formally delaying the effective date of the final FIP for states with active stays in place. The state of Minnesota therefore did not become subject to compliance obligations for the 2023 or 2024 ozone seasons. Future compliance obligations will depend on resolution of the stay. Additionally, challenges have been filed against the final FIP rule by the Minnesota coalition parties and other entities, although the Minnesota coalition FIP challenge is currently in abeyance pending resolution of the SIP disapproval case. On June 27, 2024, the U.S. Supreme Court granted an emergency stay of the FIP rule requested by several states and industry groups, staying enforcement pending the D.C. Circuit’s review and any petition for writ of certiorari. Anticipated timelines and compliance costs related to final Good Neighbor Plan compliance cannot yet be estimated due to uncertainties about SIP approval resolution, implementation timing, FIP rule outcome, and allowance costs and facility emissions during the ozone season. However, the costs could be material, including costs of additional NOx controls, emission allowance program participation, or operational changes, if any are required. Minnesota Power would seek recovery of additional costs through a rate proceeding.
EPA National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial and Institutional Boilers and Process Heaters (Industrial Boiler MACT) Rule. A final rule issued by the EPA for Industrial Boiler MACT became effective in 2013 with compliance required at major existing sources in 2016, which applied to Minnesota Power’s Hibbard Renewable Energy Center and Rapids Energy Center. Compliance consisted largely of adjustments to fuels and operating practices and compliance costs were not material. After this initial rulemaking, litigation from 2016 through 2018 resulted in court orders directing that the EPA reconsider certain aspects of the regulation. A final rule incorporating these revisions became effective in December 2022, with a compliance deadline of October 6, 2025. Compliance costs are not expected to be material.
EPA Mercury and Air Toxics Standards (MATS) Rule. On April 25, 2024, the EPA published a final rule to revise the existing 2012 MATS Rule, which regulates air emissions of hazardous air pollutants from coal- and oil-fired electric generating units (EGUs). The final rule eliminates certain MATS compliance flexibility, lowers the particulate emission standard for all coal-fired EGUs, and reduces the mercury emission standard for lignite-fired EGUs. The rule became effective July 8, 2024, with compliance required beginning July 6, 2027. The MATS regulation applies at Minnesota Power’s Boswell facility, which is currently well-controlled for these emissions and already complying with some of the new requirements. The Company anticipates the new rule will not have material impacts at Boswell. However, compliance costs cannot yet be fully estimated, and recovery of any additional costs would be sought through a rate proceeding. Litigation against the EPA’s latest MATS Rule revision from a number of U.S. states as well as several companies and industry groups is ongoing. Motions to stay the rule were denied by the U.S. Court of Appeals for the D.C. Circuit on August 6, 2024, and the U.S. Supreme Court on October 4, 2024.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
23
NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Climate Change. The scientific community generally accepts that emissions of GHGs are linked to global climate change which creates physical and financial risks. Physical risks could include but are not limited to: increased or decreased precipitation and water levels in lakes and rivers; increased or other changes in temperatures; increased risk of wildfires; 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 April 25, 2024, the EPA issued several final greenhouse gas regulations to establish emissions standards and guidelines for fossil fuel-fired electric generating units (EGUs) under Section 111 of the Clean Air Act (CAA). The final rules revise new source performance standards (NSPS) for new, modified and reconstructed EGUs (Section 111(b) of the CAA) and creates new emission guidelines for existing EGUs (Section 111(d) of the CAA). The action also officially repeals the predecessor regulation “Affordable Clean Energy Rule”, first issued in 2019 and later vacated in 2021. Compliance will be required beginning January 1, 2030 for existing sources, and upon commencing operation of new units. The 111(d) rule also requires states to submit plans to provide for the establishment, implementation and enforcement of performance standards for existing sources. States must submit either a state plan or negative declaration letter to the EPA by May 11, 2026.
The final Section 111 rules apply to several Company assets, including existing EGUs at the Boswell and Laskin facilities as well as the proposed combined cycle natural gas-fired generating facility, Nemadji Trail Energy Center. The Company anticipates compliance with the rules may require operational or planning adjustments. The state implementation plan process for Section 111(d) existing units will also be a factor in determining specific requirements and timing. We are unable to predict compliance costs at this time; however, the costs could be material. Minnesota Power would seek recovery of additional costs through a rate proceeding. The Company is also monitoring litigation of the final Section 111 rules, which began when the rules were published in the Federal Register on May 9, 2024 and continues in federal court. Both the D.C. Circuit and the U.S. Supreme Court have declined requests to block the rule from becoming effective while litigation is ongoing. Outcomes from ongoing litigation may impact both the timing of rule effectiveness and the ultimate compliance obligations required by the rule.
Water. The Clean Water Act requires NPDES permits be obtained from the EPA or delegated state 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.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
24
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 Best Available Control Technology (BACT) for several wastewater streams, including flue gas desulphurization (FGD) water, bottom ash transport water and coal combustion landfill leachate. In October 2020, the EPA published a final ELG Rule allowing re-use of bottom ash transport water in FGD scrubber systems with limited discharges related to maintaining system water balance. The rule set technology standards and numerical pollutant limits for discharges of bottom ash transport water and FGD wastewater. Compliance deadlines depend on subcategory, with compliance generally required as soon as possible, beginning after October 13, 2021, but no later than December 31, 2025, or December 31, 2028, in some specific cases.
On May 9, 2024, the EPA finalized revisions to the 2020 ELG rule. The final rule establishes zero discharge limitations for bottom ash transport water, FGD wastewater, and combustion residual leachate. A definition for legacy wastewater was established, with deferral to state permit programs for setting discharge limits based on best professional judgment. The rule maintains exemptions for units permanently ceasing coal combustion by 2028 and adds a new subcategory for units that are retiring by 2032 and have already complied with either the 2015 or 2020 ELG rules. Additionally, the rule establishes mercury and arsenic limitations for functionally equivalent discharges of leachate via groundwater to surface water. Compliance deadlines are determined by the applicable state permitting authority through permit incorporation as soon as July 8, 2024, but no later than December 31, 2029.
Bottom ash transport and FGD wastewater ELGs are not expected to have a significant impact on Minnesota Power operations. Zero leachate discharge requirements have the potential to impact dewatering associated with the closed Taconite Harbor dry ash landfill. New limitations for arsenic and mercury related to functionally equivalent (groundwater to surface water) discharges are not currently anticipated to impact Minnesota Power facilities.
We estimate no additional material compliance costs for ELG bottom ash water and FGD requirements. Compliance costs we might incur related to other ELG waste streams (e.g., leachate) or other potential future water discharge regulations at Minnesota Power facilities cannot be estimated; however, the costs could be material, including costs associated with wastewater treatment and re-use. Minnesota Power would seek recovery of additional costs through a rate proceeding.
Permitted Water Discharges – Sulfate. In 2017, the MPCA released a draft water quality standard in an attempt to update Minnesota’s existing 10 mg/L sulfate limit for waters used for the production of wild rice with the proposed rulemaking heard before an administrative law judge (ALJ). In 2018, the ALJ rejected significant portions of the proposed rulemaking and the MPCA subsequently withdrew the rulemaking. The existing 10 mg/L limit remains in place, but the MPCA is currently prohibited under state law from listing wild rice waters as impaired or requiring sulfate reduction technology.
The federal Clean Water Act requires the MPCA to update the state's impaired water list every two years. Beginning in 2021 through the latest release approved by the EPA in April 2024, this list now includes Minnesota lakes and streams identified as wild rice waters that are listed for sulfate impairment. The list could subsequently be used to set sulfate limits in discharge permits for power generation facilities and municipal and industrial customers, including paper and pulp facilities, and mining operations. At this time, we are unable to determine the specific impacts these developments may have on Minnesota Power operations or its customers, if any. Minnesota Power would seek recovery of additional costs through a rate proceeding.
Solid and Hazardous Waste. The Resource Conservation and Recovery Act of 1976 regulates the management and disposal of solid and hazardous wastes. We are required to notify the EPA of hazardous waste activity and, consequently, routinely submit reports to the EPA.
Coal Ash Management Facilities. Minnesota Power produces the majority of its coal ash at Boswell, with small amounts of ash generated at Hibbard Renewable Energy Center. Ash storage and disposal methods include storing ash in clay-lined onsite impoundments (ash ponds), disposing of dry ash in a lined dry ash landfill, applying ash to land as an approved beneficial use, and trucking ash to state permitted landfills.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
25
NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Environmental Matters (Continued)
Boswell Ash Wastewater Spill. On August 12, 2024, Minnesota Power received a Notice of Violation (NOV) from the MPCA, related to the spill at Boswell from a pipeline carrying ash wastewater from an inactive onsite storage pond to Blackwater Creek, which the Company reported on July 16, 2024. Minnesota Power responded to the MPCA NOV, clarifying certain statements made by the MPCA, as well as providing a written report and required plans. We are awaiting a proposed Stipulation Agreement from the MPCA. Minnesota Power continues to work with state and federal agencies to evaluate and mitigate the impacts from this event. We are unable to predict the mitigation or other costs related to the ash wastewater spill at this time; however, the costs could be material.
Coal Combustion Residuals from Electric Utilities. In 2015, the EPA published a final rule (2015 Rule) regulating CCR as nonhazardous waste under Subtitle D of the Resource Conservation and Recovery Act (RCRA) in the Federal Register. The rule included additional requirements for new landfill and impoundment construction as well as closure activities related to certain existing impoundments. Costs of compliance for Boswell and Laskin are expected to be incurred primarily over the next 12 years and be between approximately $65 million and $120 million. Compliance costs for CCR at Taconite Harbor are not expected to be material. Minnesota Power would seek recovery of additional costs through a rate proceeding.
Minnesota Power continues to work on minimizing compliance costs through evaluation of beneficial re-use and recycling of CCR. In 2018, a U.S. District Court for the District of Columbia decision vacated specific provisions of the CCR rule, which resulted in a change to the status of existing clay-lined impoundments at Boswell being considered unlined. In September 2020, the EPA finalized the CCR Part A Rule, which required all unlined impoundments to cease disposal and initiate closure. Upon completion of dry ash conversion activities, Boswell ceased disposal in both impoundments in September 2022. Both impoundments are now inactive and have initiated closure.
On May 8, 2024, the EPA's final CCR Legacy Impoundment Rule was published in the Federal Register. The final rule expands the scope of units regulated under the CCR rule to include legacy ponds (inactive surface impoundments at inactive facilities) and creates a new category of units called CCR management units (CCRMU), which includes inactive and closed impoundments and landfills as well as other non-containerized accumulations of CCR. The final rule requires all regulated generating facilities to evaluate and identify past deposits of CCR materials on their sites and close or re-close existing CCR units to meet current closure standards, as well as install groundwater monitoring systems, conduct groundwater monitoring, and implement groundwater corrective actions as necessary. Additionally, the EPA finalized portions of the proposed CCR Part B Rule, which allows CCR units to certify closure while conducting groundwater remediation activities. Impacts to previously closed CCR units at Boswell and Laskin are anticipated. Compliance costs for Minnesota Power’s Boswell and Laskin facilities are estimated to be between approximately $50 million and $85 million and are expected to be incurred over the next 10 years based on our preliminary assessment; however, we continue to evaluate the impact of the rule and these estimates may be revised in future periods. Minnesota Power is expected to seek recovery of these costs through a rate proceeding.
Additionally, the EPA released a proposed CCR Part B rulemaking in February 2020 addressing options for beneficial reuse of CCR materials, alternative liner demonstrations and other CCR regulatory revisions. Portions of the Part B rule addressing alternative liner equivalency standards were finalized in November 2020. A final rule establishing the remaining CCR beneficial reuse requirements is expected but has been moved to EPA’s long term rulemakings, without a publication target date currently. According to its latest Unified Agenda, the EPA plans to publish the final CCR federal permit rule implementing a permitting program for tribal lands and nonparticipating states in October 2024.
Other Environmental Matters.
Manufactured Gas Plant Site. SWL&P has completed a portion of the remediation activities at a former manufactured gas plant site located in Superior, Wisconsin, and formerly operated by SWL&P. We continue working with the Wisconsin Department of Natural Resources on the remaining remediation at the site and surrounding properties. As of September 30, 2024, SWL&P has recorded a liability of approximately $1 million for remediation costs at this site. SWL&P has recorded the recovery of the remediation costs associated with the site as a regulatory asset as we expect recovery of these costs to be allowed by the PSCW.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
26
NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Other Matters
Letters of Credit, Surety Bonds and Other Indemnifications.
We have multiple credit facility agreements in place that provide the ability to issue standby letters of credit to satisfy contractual security requirements across our businesses. As of September 30, 2024, we had $140.0 million of outstanding letters of credit issued, including those issued under our revolving credit facility, and $105.1 million in outstanding surety bonds. We do not believe it is likely that any of these outstanding letters of credit or surety bonds will be drawn upon.
In the second and third quarters of 2024, under the tax credit transferability provision of the Inflation Reduction Act, we entered into agreements with third parties to sell a portion of our renewable tax credits. ALLETE has indemnified the parties for the value of renewable tax credits sold to date of approximately $61.5 million.
Regulated Operations. As of September 30, 2024, we had $31.3 million outstanding in standby letters of credit and surety bonds at our Regulated Operations which are pledged as security to MISO, the NDPSC and state agencies.
ALLETE Clean Energy.ALLETE Clean Energy is party to PSAs that expire in various years between 2024 and 2039. As of September 30, 2024, ALLETE Clean Energy has $81.6 million outstanding in standby letters of credit and surety bonds, the majority of which are pledged as security under these PSAs.
Corporate and Other.
BNI Energy. As of September 30, 2024, BNI Energy had surety bonds outstanding of $82.4 million related to the reclamation liability for closing costs associated with its mine and mine facilities. Although its coal supply agreements obligate the customers to provide for the closing costs, additional assurance is required by federal and state regulations. BNI Energy’s total reclamation liability is currently estimated at $82.1 million. BNI Energy does not believe it is likely that any of these outstanding surety bonds will be drawn upon.
Investment in Nobles 2.The Nobles 2 wind energy facility requires standby letters of credit as security for certain contractual obligations. As of September 30, 2024, ALLETE South Wind has $10.1 million outstanding in standby letters of credit, related to its portion of the security requirements relative to its ownership in Nobles 2.
South Shore Energy. As of September 30, 2024, South Shore Energy had $29.7 million outstanding in standby letters of credit pledged as security in connection with the development of NTEC.
New Energy. As of September 30, 2024, New Energy had surety bonds outstanding of $10.0 million related to the development of renewable energy projects.
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.
We have received a number of demand letters alleging that the disclosures contained in the preliminary proxy statement, as amended, and filed with the SEC in connection with a special meeting of shareholders to consider the Merger (Preliminary Proxy), were deficient and demanding that certain corrective disclosures be made. In addition, two complaints have been filed against ALLETE and its directors. The first was filed on July 1, 2024, in the U.S. District Court for the Southern District of New York, alleging violation of Sections 14(a) and 20(a) of the Securities Exchange Act of 1934, disclosure deficiency in the Preliminary Proxy, and seeking to enjoin the transaction until certain disclosures are corrected. On September 3, 2024, that complaint was voluntarily dismissed without prejudice. The second complaint was filed on August 6, 2024, in the New York State Supreme Court, alleging negligent misrepresentation and negligence related to alleged deficiencies in the Preliminary Proxy. That complaint has not been served on any defendant. The Company believes that the demand letters and remaining complaint are without merit.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
27
NOTE 6. COMMITMENTS, GUARANTEES AND CONTINGENCIES (Continued)
Other Matters (Continued)
In the first quarter of 2023, an ALLETE Clean Energy subsidiary initiated arbitration proceedings seeking damages against a counterparty for non-performance under a contract. Arbitration hearings were held in June and July 2023, and a final arbitration ruling was issued in favor of ALLETE Clean Energy’s subsidiary in September 2023. The final arbitration ruling awarded $68.3 million to ALLETE Clean Energy’s subsidiary, which included prejudgment interest of $5.1 million, recovery of $3.6 million of arbitration-related costs, and resulted in the recognition of a $58.4 million pre-tax gain in the third quarter of 2023. The arbitration ruling also resulted in the receipt of approximately $60 million of cash, net of distribution to non-controlling interest, in the third quarter of 2023.
NOTE 7. EARNINGS PER SHARE AND COMMON STOCK
We compute basic earnings per share using the weighted average number of shares of common stock outstanding during each period. The difference between basic and diluted earnings per share, if any, arises from non-vested restricted stock units and performance share awards granted under our Executive Long-Term Incentive Compensation Plan.
2024
2023
Reconciliation of Basic and Diluted
Dilutive
Dilutive
Earnings Per Share
Basic
Securities
Diluted
Basic
Securities
Diluted
Millions Except Per Share Amounts
Quarter ended September 30,
Net Income Attributable to ALLETE
$45.0
$45.0
$85.9
$85.9
Average Common Shares
57.8
0.1
57.9
57.4
0.1
57.5
Earnings Per Share
$0.78
$0.78
$1.50
$1.49
Nine Months Ended September 30,
Net Income Attributable to ALLETE
$128.7
$128.7
$195.6
$195.6
Average Common Shares
57.7
0.1
57.8
57.3
0.1
57.4
Earnings Per Share
$2.23
$2.23
$3.41
$3.41
NOTE 8. INCOME TAX EXPENSE
Quarter Ended
Nine Months Ended
September 30,
September 30,
2024
2023
2024
2023
Millions
Current Income Tax Expense
Federal (a)
$1.5
$4.0
$8.3
$12.6
State
0.6
1.1
7.2
6.5
Total Current Income Tax Expense
$2.1
$5.1
$15.5
$19.1
Deferred Income Tax Expense (Benefit)
Federal (b)
$(2.7)
$5.2
$(12.7)
$(10.9)
State
3.6
9.1
6.1
12.5
Investment Tax Credit Amortization
(0.1)
(0.1)
(0.6)
(0.3)
Total Deferred Income Tax Expense (Benefit)
$0.8
$14.2
$(7.2)
$1.3
Total Income Tax Expense
$2.9
$19.3
$8.3
$20.4
(a)For the quarter and nine months ended September 30, 2024 and 2023, the federal current tax expense is partially offset by tax credits.
(b)For the quarter and nine months ended September 30, 2024, the federal deferred income tax benefit is primarily due to tax credits. For the nine months ended September 30, 2023, the federal deferred income tax benefit is primarily due to tax credits, partially offset by deferred partnership income. For quarter ended September 30, 2023, the federal deferred tax expense was due to deferred partnership income, partially offset by tax credits.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
28
NOTE 8. INCOME TAX EXPENSE (Continued)
The Company's tax provision for interim periods is determined using an estimate of its annual effective tax rate, adjusted for discrete items arising in that quarter. In each quarter, the Company updates its estimate of the annual effective tax rate and if the estimated annual effective tax rate changes, the Company would make a cumulative adjustment in that quarter.
Quarter Ended
Nine Months Ended
Reconciliation of Taxes from Federal Statutory
September 30,
September 30,
Rate to Total Income Tax Expense
2024
2023
2024
2023
Millions
Income Before Income Taxes
$35.6
$88.9
$97.7
$168.3
Statutory Federal Income Tax Rate
21
%
21
%
21
%
21
%
Income Taxes Computed at Statutory Federal Rate
$7.5
$18.7
$20.5
$35.3
Increase (Decrease) in Income Tax Due to:
State Income Taxes – Net of Federal Income Tax Benefit
3.4
8.0
10.5
15.0
Production Tax Credits (a)
(8.3)
(7.7)
(25.0)
(28.3)
Investment Tax Credits (a)
(0.4)
(1.6)
(1.6)
(5.2)
Regulatory Differences – Excess Deferred Tax
(2.0)
(2.3)
(7.7)
(7.5)
Non-Controlling Interest in Subsidiaries
2.4
3.0
7.6
8.9
AFUDC – Equity
(0.4)
—
(1.3)
—
Nondeductible Portion of Transaction Costs
0.7
—
4.0
—
Other
—
1.2
1.3
2.2
Total Income Tax Expense
$2.9
$19.3
$8.3
$20.4
(a)For the quarter and nine months ended September 30, 2024 and 2023, the credits are presented net of any estimated discount on the sale of certain credits.
For the nine months ended September 30, 2024, the effective tax rate was 8.5 percent (12.1 percent for the nine months ended September 30, 2023). The effective tax rates for 2024 and 2023 were primarily impacted by production tax credits.
Uncertain Tax Positions. As of September 30, 2024, we had gross unrecognized tax benefits of $1.1 million ($1.1 million as of December 31, 2023). 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 an increase to the net deferred tax liability on the Consolidated Balance Sheet.
ALLETE and its subsidiaries file a consolidated federal income tax return as well as combined and separate state income tax returns in various jurisdictions. ALLETE is currently under examination by the state of Minnesota for the tax years 2020 through 2022. ALLETE has no open federal audits and is no longer subject to federal examination for years before 2021 or state examination for years before 2020. Additionally, the statute of limitations related to the federal tax credit carryforwards will remain open until those credits are utilized in subsequent returns.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
29
NOTE 9. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS
Components of Net Periodic Benefit Cost (Credit)
Pension
Other Postretirement
2024
2023
2024
2023
Millions
Quarter Ended September 30,
Service Cost
$1.6
$1.7
$0.3
$0.6
Non-Service Cost Components (a)
Interest Cost
9.7
10.2
1.0
1.6
Expected Return on Plan Assets
(11.2)
(10.9)
(2.7)
(2.9)
Amortization of Prior Service Credits
(0.1)
(0.1)
(2.9)
(1.8)
Amortization of Net Loss (Gain)
1.7
1.4
(0.8)
(0.6)
Net Periodic Benefit Cost (Credit)
$1.7
$2.3
$(5.1)
$(3.1)
Nine Months Ended September 30,
Service Cost
$4.9
$4.9
$1.1
$1.7
Non-Service Cost Components (a)
Interest Cost
29.0
30.4
2.9
4.6
Expected Return on Plan Assets
(33.6)
(32.8)
(8.3)
(8.5)
Amortization of Prior Service Credits
(0.1)
(0.1)
(8.7)
(5.3)
Amortization of Net Loss (Gain)
4.9
4.3
(2.4)
(1.7)
Net Periodic Benefit Cost (Credit)
$5.1
$6.7
$(15.4)
$(9.2)
(a)These components of net periodic benefit cost (credit) are included in the line item “Other” under Other Income (Expense) on the Consolidated Statement of Income.
Employer Contributions. For the nine months ended September 30, 2024, we contributed $25.0 million in cash to the defined benefit pension plans ($17.3 million for the nine months ended September 30, 2023); we do not expect to make additional contributions to our defined benefit pension plans in 2024. For the nine months ended September 30, 2024, and 2023, we made no contributions to our other postretirement benefit plans; we do not expect to make any contributions to our other postretirement benefit plans in 2024.
NOTE 10. BUSINESS SEGMENTS
We present two reportable segments: Regulated Operations and ALLETE Clean Energy. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.
Regulated Operations includes three operating segments which consist of our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC. ALLETE Clean Energy is our business focused on developing, acquiring and operating clean and renewable energy projects. We also present Corporate and Other which includes New Energy, a renewable energy development company, BNI Energy, our coal mining operations in North Dakota, ALLETE Properties, our legacy Florida real estate investment, along with our investment in Nobles 2, South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, land holdings in Minnesota, and earnings on cash and investments.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
30
NOTE 10. BUSINESS SEGMENTS (Continued)
Quarter Ended
Nine Months Ended
September 30,
September 30,
2024
2023
2024
2023
Millions
Operating Revenue
Regulated Operations
Residential
$41.9
$37.9
$130.5
$123.3
Commercial
49.5
49.2
143.0
140.9
Municipal
9.2
8.7
25.6
25.2
Industrial
149.8
154.3
456.1
439.4
Other Power Suppliers
32.0
31.0
102.4
103.2
Other
28.1
33.2
71.0
87.1
Total Regulated Operations
310.5
314.3
928.6
919.1
ALLETE Clean Energy
Long-term PSA
9.9
12.9
42.2
44.5
Sale of Wind Energy Facilities
22.9
—
22.9
348.4
Other
1.3
1.3
3.8
3.9
Total ALLETE Clean Energy
34.1
14.2
68.9
396.8
Corporate and Other
Long-term Contract
26.7
24.6
79.4
74.0
Sale of Renewable Development Projects
29.2
20.8
68.7
73.2
Other
6.7
4.9
19.4
14.0
Total Corporate and Other
62.6
50.3
167.5
161.2
Total Operating Revenue
$407.2
$378.8
$1,165.0
$1,477.1
Net Income (Loss) Attributable to ALLETE
Regulated Operations
$34.0
$34.0
$111.9
$112.4
ALLETE Clean Energy (a)
3.9
54.8
10.1
66.4
Corporate and Other (b)
7.1
(2.9)
6.7
16.8
Total Net Income Attributable to ALLETE
$45.0
$85.9
$128.7
$195.6
(a)Net income in 2023 includes a $44.3 million after-tax gain recognized for a favorable arbitration ruling. (See Note 6. Commitments, Guarantees and Contingencies.)
(b)Net income in 2023 includes a $3.8 million after-tax expense recognized for the consolidated income tax impact of the gain on arbitration. (See Note 6. Commitments, Guarantees and Contingencies.)
September 30, 2024
December 31, 2023
Millions
Assets
Regulated Operations
$4,410.3
$4,335.0
ALLETE Clean Energy
1,581.6
1,594.1
Corporate and Other
745.3
727.3
Total Assets
$6,737.2
$6,656.4
ALLETE, Inc. Third Quarter 2024 Form 10-Q
31
NOTE 11. AGREEMENT AND PLAN OF MERGER
On May 5, 2024, ALLETE entered into the Merger Agreement. Pursuant to the Merger Agreement, on the terms and subject to the conditions set forth therein, Alloy Merger Sub will merge with and into ALLETE, with ALLETE continuing as the surviving corporation in the Merger and becoming a subsidiary of Alloy Parent.
On July 10, 2024, ALLETE filed a definitive proxy statement relating to the Merger Agreement and notice of a special meeting of the shareholders that was held on August 21, 2024, at which shareholders of ALLETE voted to approve and adopt the Merger Agreement, among other matters.
On July 19, 2024, the Company filed requests for approval of the Merger with the MPUC, PSCW and FERC. On October 7, 2024, the MPUC issued an order referring the docket to the Minnesota Office of Administrative Hearings for a contested case proceeding and requesting the Administrative Law Judge issue a report and recommendation by July 15, 2025. Approval of the Merger from these and other regulators is required for consummation of the Merger. The Company received approval from the Committee on Foreign Investment in the United States (CFIUS) and all required international approvals in the third quarter of 2024.
Subject to the terms and conditions set forth in the Merger Agreement, which has been unanimously approved by the board of directors of ALLETE as well as approved and adopted by the shareholders of ALLETE, at the effective time of the Merger (Effective Time), each share of common stock, without par value, of ALLETE (ALLETE common stock) issued and outstanding immediately prior to the Effective Time (other than shares of ALLETE common stock held by any holder who properly exercises dissenters’ rights under Minnesota law in respect of such shares and any shares of ALLETE common stock held by an affiliate of Alloy Parent) shall be converted into the right to receive $67.00 in cash, without interest (Merger Consideration). The aggregate equity value of the ALLETE common stock acquired by Parent will be approximately $3.9 billion as calculated as of May 5, 2024.
In addition, at the Effective Time, each restricted stock unit (RSU) with respect to ALLETE common stock subject to time-based vesting that is outstanding immediately prior to the Effective Time will be cancelled and converted into a contingent right to receive an amount in cash, without interest, equal to the Merger Consideration, payable (i) in the case of such right converted from unvested RSUs, upon the same vesting conditions as applied to the corresponding RSU or (ii) in the case of such right converted from vested RSUs, as soon as reasonably practicable following the closing date of the Merger (the Closing Date). Each performance share award with respect to ALLETE common stock that is outstanding and unvested immediately prior to the Effective Time will be cancelled and converted into a right to receive, without interest, the Merger Consideration multiplied by the number of shares of ALLETE common stock subject to the award, determined based on attainment of the greater of target and actual performance as of the last business day immediately preceding the Closing Date. A pro rata portion (based on the elapsed portion of the performance period at that time) of the converted performance share awards will be paid out as soon as reasonably practicable following the Closing Date, with the remainder of the award being subject to time-vesting for the remainder of the applicable performance period. Further, purchase rights accumulated during the offering period in effect under the Company’s ESPP immediately prior to closing will be automatically exercised into shares of ALLETE common stock no later than five business days prior to the Closing Date, and the ESPP will be terminated as of immediately prior to the Closing Date.
Consummation of the Merger is subject to various closing conditions, including: (1) approval of the shareholders of ALLETE; (2) receipt of all required regulatory approvals without the imposition of a Burdensome Condition (as defined in the Merger Agreement); (3) absence of any law or order prohibiting the consummation of the Merger; (4) subject to materiality qualifiers, the accuracy of each party’s representations and warranties; (5) each party’s compliance in all material respects with its obligations and covenants under the Merger Agreement; and (6) the absence of a material adverse effect with respect to the Company.The Merger Agreement contains certain termination rights for ALLETE and Alloy Parent, which were described in a Current Report of Form 8-K filed by ALLETE on May 6, 2024. In the Merger Agreement, among other things, ALLETE has agreed, subject to certain exceptions, to, and to cause each of its subsidiaries to conduct its business in the ordinary course, consistent with past practice, from the date of the Merger Agreement until the Effective Time, and not to take certain actions prior to the closing of the Merger without the prior written consent of Alloy Parent (which consent shall not be unreasonably withheld, conditioned or delayed, except where ALLETE seeks Alloy Parent’s consent to enter into a material new line of business or cease operations of an existing material line of business). The Merger Agreement also provides that ALLETE may request that Alloy Parent purchase up to a total of $300 million of preferred stock of ALLETE in the second half of 2025, subject to certain parameters. If Alloy Parent declines to purchase the preferred stock, ALLETE will have the right to issue ALLETE common stock up to certain limits.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
32
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 2023 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 and our 2023 Form 10-K under the headings: “Forward-Looking Statements” located on page 7 and “Risk Factors” located in Part I, Item 1A, beginning on page 25 of our 2023 Form 10-K. The risks and uncertainties described in this Form 10-Q and our 2023 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.
On May 5, 2024, ALLETE entered into the Merger Agreement. (See Note 11. Agreement and Plan of Merger.)
Regulated Operations includes our regulated utilities, Minnesota Power and SWL&P, as well as our investment in ATC, a Wisconsin-based regulated utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. Minnesota Power provides regulated utility electric service in northeastern Minnesota to approximately 150,000 retail customers. Minnesota Power also has 14 non-affiliated municipal customers in Minnesota. SWL&P is a Wisconsin utility and a wholesale customer of Minnesota Power. SWL&P provides regulated utility electric, natural gas and water service in northwestern Wisconsin to approximately 15,000 electric customers, 13,000 natural gas customers and 10,000 water customers. Our regulated utility operations include retail and wholesale activities under the jurisdiction of state and federal regulatory authorities. (See Note 2. Regulatory Matters.)
ALLETE Clean Energy focuses on developing, acquiring, and operating clean and renewable energy projects. ALLETE Clean Energy currently owns and operates, in seven states, more than 1,200 MW of nameplate capacity wind energy generation with a majority contracted under PSAs of various durations. In addition, ALLETE Clean Energy also engages in the development of wind energy facilities to operate under long-term PSAs or for sale to others upon completion.
Corporate and Otheris comprised of New Energy, a renewable development company; our investment in Nobles 2, an entity that owns and operates a 250 MW wind energy facility in southwestern Minnesota; South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility; BNI Energy, our coal mining operations in North Dakota; ALLETE Properties, our legacy Florida real estate investment; other business development and corporate expenditures; unallocated interest expense; a small amount of non-rate base generation; land holdings in Minnesota; and earnings on cash and investments.
ALLETE is incorporated under the laws of Minnesota. Our corporate headquarters are in Duluth, Minnesota. Statistical information is presented as of September 30, 2024, 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 nine months ended September 30, 2024, to the nine months ended September 30, 2023.
Net income attributable to ALLETE for the nine months ended September 30, 2024, was $128.7 million, or $2.23 per diluted share, compared to $195.6 million, or $3.41 per diluted share, for the same period in 2023. Net income in 2024 includes transaction expenses of $19.5 million after-tax, or $0.34 per share, related to the Merger. (See Note 11. Agreement and Plan of Merger.) Net income in 2023 included a $40.5 million, or $0.71 per share, after-tax gain recognized for a favorable arbitration ruling involving a subsidiary of ALLETE Clean Energy. (See Note 6. Commitments, Guarantees and Contingencies.)
ALLETE, Inc. Third Quarter 2024 Form 10-Q
33
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS (Continued)
Regulated Operations net income attributable to ALLETE was $111.9 million for the nine months ended September 30, 2024, compared to $112.4 million for the same period in 2023. Net income at Minnesota Power was similar to 2023 reflecting the implementation of interim rates on January 1, 2024, net of reserves related to Minnesota Power’s rate case settlement (see Note 2. Regulatory Matters), and higher transmission margins, which was partially offset by higher operating and maintenance, depreciation, and property tax expenses. Net income at SWL&P was lower than 2023 primarily due to higher operating and maintenance expenses. Our after-tax equity earnings in ATC were similar to 2023. (See Note 3. Equity Investments.)
ALLETE Clean Energy net income attributable to ALLETE was $10.1 million for the nine months ended September 30, 2024, compared to $66.4 million for the same period in 2023. Net income in 2024 includes a $3.5 million after-tax gain on the sale of the Whitetail wind project. Net income in 2023 included a $4.3 million after-tax gain on the sale of the Red Barn project as well as a $44.3 million after-tax gain recognized for a favorable arbitration ruling involving a subsidiary of ALLETE Clean Energy. (See Note 6. Commitments, Guarantees, and Contingencies.)
Corporate and Other net income attributable to ALLETE was $6.7 million for the nine months ended September 30, 2024, compared to net income of $16.8 million for the same period in 2023. Net income in 2024 includes transaction expenses of $19.5 million after-tax related to the Merger (See Note 11. Agreement and Plan of Merger), and also reflects lower earnings from Minnesota solar projects as investment tax credits were recognized in 2023 for the projects. Net income in 2023 reflects a $3.8 million after-tax expense for the consolidated income tax impact of the gain on the favorable arbitration ruling. Net income at New Energy was $23.4 million in 2024 compared to $12.0 million in 2023.
COMPARISON OF THE QUARTER ENDED SEPTEMBER 30, 2024 AND 2023
(See Note 10. Business Segments for financial results by segment.)
Regulated Operations
Quarter Ended September 30,
2024
2023
Millions
Operating Revenue – Utility
$310.5
$314.3
Fuel, Purchased Power and Gas – Utility
117.2
125.6
Transmission Services – Utility
19.6
22.7
Operating and Maintenance
63.6
61.4
Depreciation and Amortization
52.2
44.9
Taxes Other than Income Taxes
12.4
12.3
Operating Income
45.5
47.4
Interest Expense
(16.7)
(16.2)
Equity Earnings
6.1
5.7
Other Income
4.1
2.8
Income Before Income Taxes
39.0
39.7
Income Tax Expense
5.0
5.7
Net Income Attributable to ALLETE
$34.0
$34.0
Operating Revenue – Utility decreased $3.8 million from 2023 primarily due to lower fuel adjustment cause recoveries, the timing of financial incentives compared to 2023, lower transmission revenue, and lower revenue from kWh sales. These increases were partially offset by the implementation of interim rate revenue, net of reserves, in 2024.
Fuel adjustment clause revenue decreased $7.6 million due to lower fuel and purchased power costs attributable to retail and municipal customers. (See Fuel, Purchased Power and Gas – Utility.)
Revenue from financial incentives decreased $2.2 million due to MPUC approval timing differences between 2024 and 2023. In 2023, a financial incentive of $2.2 million was recognized in the third quarter. Minnesota Power submitted its 2023 ECO annual filing on April 1, 2024, requesting a $2.2 million financial incentive which will be recognized upon approval by the MPUC.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
34
COMPARISON OF THE QUARTER ENDED SEPTEMBER 30, 2024 AND 2023 (Continued)
Regulated Operations (Continued)
Transmission revenue decreased $1.5 million primarily due to lower MISO-related revenue.
Lower revenue from kWh sales decreased revenue by $1.5 million from 2023 reflecting lower sales to industrial customers, partially offset by higher sales to residential and municipal customers as well as other power suppliers. Sales to industrial customers decreased primarily due to lower sales to taconite customers.
Kilowatt-hours Sold
Variance
Quarter Ended September 30,
2024
2023
Quantity
%
Millions
Regulated Utility
Retail and Municipal
Residential
262
250
12
4.8
%
Commercial
354
355
(1)
(0.3)
%
Industrial
1,715
1,742
(27)
(1.5)
%
Municipal
120
112
8
7.1
%
Total Retail and Municipal
2,451
2,459
(8)
(0.3)
%
Other Power Suppliers
616
526
90
17.1
%
Total Regulated Utility Kilowatt-hours Sold
3,067
2,985
82
2.7
%
Revenue from electric sales to taconite customers accounted for 32 percent of regulated operating revenue in 2024 (34 percent in 2023). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 5 percent of regulated operating revenue in 2024 (5 percent in 2023). Revenue from electric sales to pipelines and other industrial customers accounted for 11 percent of regulated operating revenue in 2024 (10 percent in 2023).
Interim retail rates for Minnesota Power, subject to refund, were approved by the MPUC and became effective January 1, 2024, resulting in revenue of $10.2 million, net of reserves related to Minnesota Power’s rate case settlement and rider revenue incorporated into base rates. (See Note 2. Regulatory Matters.)
Operating Expenses decreased $1.9 million, or 1 percent, from 2023.
Fuel, Purchased Power and Gas – Utility expense decreased $8.4 million from 2023 primarily due to lower purchased power prices.
Transmission Services – Utility expense decreased $3.1 million from 2023 primarily due to lower MISO-related expense.
Operating and Maintenance expense increased $2.2 million, or 4 percent, from 2023 primarily due to higher salaries and wages, and higher contract and professional services.
Depreciation and Amortization expense increased $7.3 million, or 16 percent, from 2023 reflecting the impact of estimated compliance costs related to the EPA’s CCR Legacy Impoundment Rule finalized in May 2024 and a higher plant in service balance in 2024.
Other Income increased $1.3 million from 2023 reflecting lower pension and other postretirement benefit plan non-service costs.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
35
COMPARISON OF THE QUARTER ENDED SEPTEMBER 30, 2024 AND 2023 (Continued)
ALLETE Clean Energy
Quarter Ended September 30,
2024
2023
Millions
Operating Revenue
Contracts with Customers – Non-utility
$32.8
$12.9
Other – Non-utility (a)
1.3
1.3
Cost of Sales – Non-utility
18.3
—
Operating and Maintenance
12.3
10.6
Depreciation and Amortization
14.4
14.4
Taxes Other than Income Taxes
2.2
2.6
Operating Loss
(13.1)
(13.4)
Interest Expense
—
(0.2)
Other Income
2.0
65.2
Income (Loss) Before Income Taxes
(11.1)
51.6
Income Tax Expense (Benefit)
(4.8)
11.7
Net Income (Loss)
(6.3)
39.9
Net Loss Attributable to Non-Controlling Interest
(10.2)
(14.9)
Net Income Attributable to ALLETE
$3.9
$54.8
(a)Represents non-cash amortization of differences between contract prices and estimated market prices on assumed PSAs.
Operating Revenue increased $19.9 million compared to 2023 primarily due to the sale of ALLETE Clean Energy’s Whitetail wind project in 2024.
Quarter Ended September 30,
2024
2023
Production and Operating Revenue
kWh
Revenue
kWh
Revenue
Millions
Wind Energy Regions
East
34.5
$3.0
31.4
$2.9
Midwest
88.7
3.7
89.5
3.6
South
360.3
1.6
392.5
5.0
West
156.5
2.9
142.3
2.7
Sale of Wind Energy Facility
—
22.9
—
—
Total Production and Operating Revenue
640.0
$34.1
655.7
$14.2
Cost of Sales – Non-utility increased $18.3 million from 2023 reflecting the sale of ALLETE Clean Energy’s Whitetail wind project in 2024.
Operating and Maintenanceexpense increased $1.7 million from 2023 primarily due to higher contract and professional services reflecting the recovery in 2023 of $3.6 million for arbitration-related costs incurred that were awarded as part of a favorable arbitration ruling involving a subsidiary of ALLETE Clean Energy. (See Note 6. Commitments, Guarantees and Contingencies.)
Other Income decreased $63.2 million from 2023 reflecting the $58.4 million gain recognized for a favorable arbitration ruling in 2023 involving a subsidiary of ALLETE Clean Energy and higher interest income related to $5.1 million of interest awarded as part of the favorable arbitration ruling. (See Note 6. Commitments, Guarantees, and Contingencies.)
Income Tax Benefit decreased $16.5 million from 2023 primarily due to lower pre-tax income.
Net Loss Attributable to Non-Controlling Interest decreased $4.7 million from 2023 reflecting lower wind resources at our tax equity financed wind energy facilities. This decrease was partially offset by a higher production tax credit rate, as determined by the Internal Revenue Service, in 2024 compared to 2023.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
36
COMPARISON OF THE QUARTER ENDED SEPTEMBER 30, 2024 AND 2023 (Continued)
Corporate and Other
Operating Revenue increased $12.3 million, or 24 percent, from 2023 primarily due to higher revenue from sales of renewable energy projects at New Energy in 2024 compared to 2023 reflecting the timing of project closings.
Net Income Attributable to ALLETE of $7.1 million in 2024 compared to net loss of $2.9 million in 2023. Net income in 2024 includes higher sales of renewable energy projects at New Energy in 2024 compared to 2023, partially offset by lower earnings from Minnesota solar projects as investment tax credits were recognized in 2023 for the projects and transaction expenses of $3.8 million after-tax related to the Merger. (See Note 11. Agreement and Plan of Merger). Net loss in 2023 also includes a $3.8 million after-tax expense for the consolidated income tax impact of the gain on the favorable arbitration ruling. Net income at New Energy was $11.7 million in 2024 compared to $0.5 million in 2023.
Income Taxes – Consolidated
For the quarter ended September 30, 2024, the effective tax rate was an expense of 8.1 percent (expense of 21.7 percent for the quarter ended September 30, 2023). The lower effective tax rate is primarily due to lower pre-tax income.
We expect our annual effective tax rate in 2024 to be lower than 2023 primarily due to lower estimated pre-tax income. The estimated annual effective tax rate can differ from what a quarterly effective tax rate would otherwise be on a standalone basis, and this may cause quarter to quarter differences in the timing of income taxes. (See Note 8. Income Tax Expense.)
COMPARISON OF THE NINE MONTHS ENDED SEPTEMBER 30, 2024 AND 2023
(See Note 10. Business Segments for financial results by segment.)
Regulated Operations
Nine Months Ended September 30,
2024
2023
Millions
Operating Revenue – Utility
$928.6
$919.1
Fuel, Purchased Power and Gas – Utility
358.9
351.8
Transmission Services – Utility
43.9
66.3
Operating and Maintenance
197.1
184.8
Depreciation and Amortization
145.4
134.0
Taxes Other than Income Taxes
41.8
33.8
Operating Income
141.5
148.4
Interest Expense
(49.0)
(47.9)
Equity Earnings
17.8
17.3
Other Income
15.3
7.9
Income Before Income Taxes
125.6
125.7
Income Tax Expense
13.7
13.3
Net Income Attributable to ALLETE
$111.9
$112.4
Operating Revenue – Utility increased $9.5 million from 2023 primarily due to the implementation of interim rates on January 1, 2024, and higher fuel adjustment clause recoveries. These increases were partially offset by lower transmission revenue, kWh sales, gas sales and the timing of financial incentives compared to 2023.
Interim retail rates for Minnesota Power, subject to refund, were approved by the MPUC and became effective January 1, 2024, resulting in revenue of $30.9 million, net of reserves related to Minnesota Power’s rate case settlement and rider revenue incorporated into base rates. (See Note 2. Regulatory Matters.)
Fuel adjustment clause revenue increased $6.2 million due to higher fuel and purchased power costs attributable to retail and municipal customers. (See Fuel, Purchased Power and Gas – Utility.)
ALLETE, Inc. Third Quarter 2024 Form 10-Q
37
COMPARISON OF THE NINE MONTHS ENDED SEPTEMBER 30, 2024 AND 2023 (Continued)
Regulated Operations (Continued)
Transmission revenue decreased $11.7 million primarily due to lower MISO-related revenue. Transmission revenue in 2024 included the refund of MISO transmission payments that were over collected during 2023. (See Transmission Services – Utility).
Lower kWh sales decreased revenue by $5.4 million from 2023 reflecting lower sales to residential and commercial customers as well as lower sales to other power suppliers, partially offset by higher sales to industrial customers. Sales to residential and commercial customers decreased from 2023 primarily due to milder weather in 2024 compared to 2023. Sales to other power suppliers, which are sold at market-based prices into the MISO market on a daily basis or through PSAs of various durations, decreased reflecting fewer market sales, partially offset by higher market prices in 2024 compared to 2023. Sales to industrial customers increased primarily due to higher sales to paper, pulp and secondary wood product customers and taconite customers reflecting Cliffs’ Northshore mine operating in 2024 compared to being idled in the first quarter of 2023.
Kilowatt-hours Sold
Variance
Nine Months Ended September 30,
2024
2023
Quantity
%
Millions
Regulated Utility
Retail and Municipal
Residential
793
812
(19)
(2.3)
%
Commercial
999
1,022
(23)
(2.3)
%
Industrial
5,242
5,178
64
1.2
%
Municipal
350
350
—
—
%
Total Retail and Municipal
7,384
7,362
22
0.3
%
Other Power Suppliers
1,952
2,008
(56)
(2.8)
%
Total Regulated Utility Kilowatt-hours Sold
9,336
9,370
(34)
(0.4)
%
Revenue from electric sales to taconite customers accounted for 33 percent of regulated operating revenue in 2024 (32 percent in 2023). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 5 percent of regulated operating revenue in 2024 (5 percent in 2023). Revenue from electric sales to pipelines and other industrial customers accounted for 11 percent of regulated operating revenue in 2024 (11 percent in 2023).
Revenue from gas sales at SWL&P decreased $4.5 million reflecting fewer gas sales resulting from warmer winter weather and lower gas prices in 2024 compared to 2023. (See Fuel, Purchased Power and Gas – Utility.)
Revenue from financial incentives decreased $2.2 million due to MPUC approval timing differences between 2024 and 2023. In 2023, a financial incentive of $2.2 million was recognized in the third quarter. Minnesota Power submitted its 2023 ECO annual filing on April 1, 2024, requesting a $2.2 million financial incentive which will be recognized upon approval by the MPUC.
Operating Expenses increased $16.4 million, or 2 percent, from 2023.
Fuel, Purchased Power and Gas – Utility expense increased $7.1 million, or 2 percent, from 2023 primarily due to higher purchased power prices and fuel costs. These increases were partially offset by lower kWh sales as well as lower gas sales and prices.
Transmission Services – Utility expense decreased $22.4 million, or 34 percent, from 2023 primarily due to lower MISO-related expense. Transmission Services – Utility expense in 2024 included the refund of MISO transmission payments that were over billed during 2023. (See Operating Revenue – Utility).
Operating and Maintenance expenseincreased $12.3 million, or 7 percent, from 2023 primarily due to higher salaries and wages, benefit costs, and contract and professional services.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
38
COMPARISON OF THE NINE MONTHS ENDED SEPTEMBER 30, 2024 AND 2023 (Continued)
Regulated Operations (Continued)
Depreciation and Amortization expense increased $11.4 million, or 9 percent, from 2023 primarily due to the impact of estimated compliance costs related to the EPA’s CCR Legacy Impoundment Rule finalized in May 2024 and a higher plant in service balance in 2024.
Taxes Other than Income Taxes increased $8.0 million, or 24 percent, from 2023 primarily due to higher property tax expense. Property tax expense in 2023 included the favorable impact of an updated estimate for 2022 property tax expense recorded in 2023.
Other Income increased $7.4 million from 2023 reflecting lower pension and other postretirement benefit plan non-service costs.
ALLETE Clean Energy
Nine Months Ended September 30,
2024
2023
Millions
Operating Revenue
Contracts with Customers – Non-utility
$65.1
$392.9
Other – Non-utility (a)
3.8
3.9
Cost of Sales – Non-utility
18.3
342.3
Operating and Maintenance
37.5
39.2
Depreciation and Amortization
43.2
43.1
Taxes Other than Income Taxes
6.7
7.4
Operating Loss
(36.8)
(35.2)
Interest Expense
(0.2)
(0.7)
Other Income
5.4
66.4
Income (Loss) Before Income Taxes
(31.6)
30.5
Income Tax Expense (Benefit)
(13.3)
4.5
Net Income (Loss)
(18.3)
26.0
Net Loss Attributable to Non-Controlling Interest
(28.4)
(40.4)
Net Income Attributable to ALLETE
$10.1
$66.4
(a)Represents non-cash amortization of differences between contract prices and estimated market prices on assumed PSAs.
Operating Revenue decreased $327.9 million from 2023 primarily due to the sales of ALLETE Clean Energy’s Northern Wind and Red Barn projects in 2023, partially offset by the sale of ALLETE Clean Energy’s Whitetail wind project in 2024. In addition, operating revenue in 2024 was negatively impacted by a network outage located near Caddo. The network outage began in the fourth quarter of 2023 resulting from a forced outage of a substation and the transmission lines feeding that substation. This forced outage increased congestion experienced by Caddo resulting in lower kWh sales and pricing. The forced outage was resolved in June 2024. (See Outlook - ALLETE Clean Energy.)
Nine Months Ended September 30,
2024
2023
Production and Operating Revenue
kWh
Revenue
kWh
Revenue
Millions
Wind Energy Regions
East
161.3
$14.8
152.6
$14.8
Midwest
400.7
13.8
393.4
13.1
South
962.8
6.9
1,389.1
10.9
West
554.3
10.5
495.4
9.6
Sale of Wind Energy Facility
—
22.9
—
348.4
Total Production and Operating Revenue
2,079.1
$68.9
2,430.5
$396.8
Cost of Sales – Non-utility decreased $324.0 million from 2023 primarily due to the sales of ALLETE Clean Energy’s Northern Wind and Red Barn projects, partially offset by the sale of ALLETE Clean Energy’s Whitetail wind project.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
39
COMPARISON OF THE NINE MONTHS ENDED SEPTEMBER 30, 2024 AND 2023 (Continued)
ALLETE Clean Energy (Continued)
Operating and Maintenanceexpense decreased $1.7 million from 2023 primarily due to business interruption insurance proceeds at Diamond Spring in 2024 related to a transformer outage in the first half of 2024.
Other Income decreased $61.0 million from 2023 primarily due to a $58.4 million gain recognized for a favorable arbitration ruling in 2023 involving a subsidiary of ALLETE Clean Energy and higher interest income related to $5.1 million of interest awarded as part of the favorable arbitration ruling. (See Note 6. Commitments, Guarantees, and Contingencies.)
Income Tax Benefit increased $17.8 million from 2023 primarily due to lower pre-tax income.
Net Loss Attributable to Non-Controlling Interest decreased $12.0 million from 2023 reflecting lower availability at ALLETE Clean Energy’s tax equity financed wind energy facilities resulting from the impacts of a network outage near Caddo and a transformer outage at Diamond Spring. This decrease was partially offset by a higher production tax credit rate, as determined by the Internal Revenue Service, in 2024 compared to 2023.
Corporate and Other
Operating Revenue increased $6.3 million, or 4 percent, from 2023 primarily due to higher revenue at BNI Energy, which operates under cost-plus fixed fee contracts, as a result of higher expenses in 2024 compared to 2023.
Net Income Attributable to ALLETE was $6.7 million in 2024 compared to net income of $16.8 million in 2023. Net income in 2024 includes higher sales of renewable energy projects at New Energy in 2024 compared to 2023, partially offset by lower earnings from Minnesota solar projects as investment tax credits were recognized in 2023 for the projects and transaction expenses of $19.5 million after-tax related to the Merger (See Note 11. Agreement and Plan of Merger). The net income in 2023 also reflects a $3.8 million after tax-expense for the consolidated income tax impact of the gain on the favorable arbitration ruling. Net income at New Energy was $23.4 million in 2024 compared to $12.0 million in 2023.
Income Taxes – Consolidated
For the nine months ended September 30, 2024, the effective tax rate was an expense of 8.5 percent (12.1 percent for the nine months ended September 30, 2023). The lower effective tax rate for 2024 is primarily due to lower pre-tax income.
We expect our annual effective tax rate in 2024 to be lower than 2023 primarily due to lower estimated pre-tax income. The estimated annual effective tax rate can differ from what a quarterly effective tax rate would otherwise be on a standalone basis, and this may cause quarter to quarter differences in the timing of income taxes. (See Note 8. Income Tax Expense.)
CRITICAL ACCOUNTING POLICIES
Certain accounting measurements under GAAP involve management’s judgment about subjective factors and estimates, the effects of which are inherently uncertain. Accounting measurements that we believe are most critical to our reported results of operations and financial condition include: regulatory accounting, pension and postretirement health and life actuarial assumptions, goodwill, impairment of long-lived assets, and taxation. These policies are reviewed with the Audit Committee of our Board of Directors on a regular basis and summarized in Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations of our 2023 Form 10-K.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
40
OUTLOOK
For additional information see our 2023 Form 10-K.
On May 5, 2024, ALLETE entered into the Merger Agreement. (See Note 11. Agreement and Plan of Merger.) As a result of the Merger, transaction costs are expected to be material in 2024.
ALLETE is an energy company committed to earning a financial return that rewards our shareholders, allows for reinvestment in our businesses, and sustains growth. The Company has a long-term objective of achieving consolidated earnings per share growth within a range of 5 percent to 7 percent.
ALLETE is predominately a regulated utility through Minnesota Power, SWL&P, and an investment in ATC. ALLETE’s strategy is to remain predominately a regulated utility while investing in ALLETE Clean Energy and New Energy and its Corporate and Other businesses to complement its regulated businesses, balance exposure to the utility’s industrial customers, and provide potential long-term earnings growth. ALLETE expects net income from Regulated Operations to be approximately 75 percent of total consolidated net income in 2024. ALLETE expects its businesses to generally provide regulated, contracted or recurring revenues, and to support sustained growth in net income and cash flow.
Minnesota Carbon-Free Legislation. On February 7, 2023, the Minnesota Governor signed into law legislation that updates the state’s renewable energy standard and requires Minnesota electric utilities to source retail sales with 100 percent carbon-free energy by 2040. The law increases the renewable energy standard from 25 percent renewable by 2025 to 55 percent renewable by 2035, and requires investor-owned Minnesota utilities to provide 80 percent carbon-free energy by 2030, 90 percent carbon-free energy by 2035 and 100 percent carbon-free energy by 2040. The law utilizes renewable energy credits as the means to demonstrate compliance with both the carbon-free and renewable standards, includes an off-ramp provision that enables the MPUC to protect reliability and customer costs through modification or delay of either the renewable energy standard, the carbon-free standard, or both, and streamlines development and construction of wind energy projects and transmission in Minnesota. The Company is evaluating the law to identify challenges and opportunities it could present.
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. In 2021, Minnesota Power announced its vision of delivering 100 percent carbon-free energy by 2050. 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.
2024 Minnesota General Rate Case. On November 1, 2023, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 12.00 percent for retail customers, net of rider revenue incorporated into base rates. The rate filing seeks a return on equity of 10.30 percent and a 53.00 percent equity ratio. On an annualized basis, the requested final rate increase would generate approximately $89 million in additional revenue. In separate orders dated December 19, 2023, the MPUC accepted the filing as complete and approved an annual interim rate increase of approximately $64 million, net of rider revenue, beginning January 1, 2024, subject to refund.
On May 3, 2024, Minnesota Power entered into a settlement agreement with the Minnesota Department of Commerce, Minnesota Office of the Attorney General, Residential Utilities Division, and Large Power Intervenors to settle the retail rate increase request. As part of the settlement agreement, the parties agreed on all issues, including an overall rate increase of $33.97 million, net of rider revenue and amounts transferring to the fuel adjustment clause, a return on equity of 9.78 percent, all non-financial items and cost allocation. At a hearing on October 24, 2024, the MPUC approved the settlement agreement. Final rates are expected to be implemented in the first quarter of 2025; interim rates will be collected through this period with reserves recorded as necessary. As a result of the settlement, Minnesota Power recorded a reserve for an interim rate refund of $17.0 million pre-tax as of September 30, 2024, which is subject to MPUC approval of Minnesota Power’s refund calculation.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
41
OUTLOOK (Continued)
Regulated Operations (Continued)
2024 Wisconsin General Rate Case. On March 29, 2024, SWL&P filed a rate increase request for its electric, gas and water utilities with the PSCW. The filing seeks an overall return on equity of 10.00 percent and a 55.00 percent equity ratio. On an annualized basis, the requested change would increase revenue by approximately 5.90 percent for retail customers and generate an estimated $7.3 million of additional revenue. The change to SWL&P customers’ rates will be determined by the PSCW later this year. Any rate adjustments are anticipated to become effective in January 2025. We cannot predict the level of final rates that may be authorized by the PSCW.
Solar Energy Request For Proposals. On October 2, 2023, Minnesota Power filed a notice with the MPUC of its intent to issue a request for proposals for up to 300 MW of solar energy resources. Minnesota Power issued the request for proposals on November 15, 2023, which were accepted through January 17, 2024. On September 23, 2024, Minnesota Power announced plans to build an 85 MW solar project and a 119.5 MW solar project in Northern Minnesota, both of which are expected to be in service in mid-2027 subject to MPUC approval.
Wind Energy Request For Proposals. On December 15, 2023, Minnesota Power filed a notice with the MPUC of its intent to issue a request for proposals for up to 400 MW of wind energy resources. Minnesota Power issued the request for proposals on February 15, 2024, which were accepted through April 11, 2024. The proposals are currently being evaluated.
Industrial Customers.
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 56 percent of our regulated utility kWh sales in the nine months ended September 30, 2024, were made to our industrial customers (55 percent in the nine months ended September 30, 2023).
Taconite.
USS Corporation. USS Corporation’s Minntac and Keetac plants are large power industrial customers of Minnesota Power. These plants have the combined capability to produce approximately 22 million tons of iron ore pellets annually which includes 4 million tons of direct-reduced grade pellets.
On December 18, 2023, USS Corporation announced it entered into a definitive agreement in which Nippon Steel will acquire all of the shares of USS Corporation. On April 12, 2024, USS Corporation shareholders approved the proposed acquisition. USS Corporation expects the transaction to close in the second half of 2024, subject to regulatory approvals, at which time USS Corporation stated it will continue to operate under the U.S. Steel brand name and will maintain its headquarters in Pittsburgh, Pennsylvania.
Paper, Pulp and Secondary Wood Products.
Sofidel. ST Paper, a former Large Power Customer of Minnesota Power, announced on January 3, 2024, that it had entered into an agreement to sell the Duluth Mill to Sofidel, a privately held Italian multinational company that is currently the seventh largest manufacturer of tissue paper in the world. Sofidel completed the acquisition of the Duluth Mill in the first quarter of 2024. In the third quarter of 2024, Sofidel announced plans to invest between $200 million and $250 million to add a conversion facility and automated warehouse to the tissue plant.
Transmission.
Investment in ATC. ATC’s most recent 10-year transmission assessment, which covers the years 2023 through 2032, identifies a need for between $6.6 billion and $8.1 billion in transmission system investments. These investments by ATC, if undertaken, are expected to be funded through a combination of internally generated cash, debt and investor contributions. As opportunities arise, we plan to make additional investments in ATC through general capital calls based upon our pro rata ownership interest in ATC.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
42
OUTLOOK (Continued)
Transmission (Continued)
North Plains Connector Development Agreement. In December 2023, ALLETE and Grid United LLC, an independent transmission company, signed development agreements for the North Plains Connector project. The project is a new, approximately 400-mile high-voltage direct-current (HVDC) transmission line from central North Dakota, to Colstrip, Montana that will be the first transmission connection between three regional U.S. electric energy markets: MISO, the Western Interconnection and the Southwest Power Pool. This new link, open to all sources of electric generation, would create 3,000 MW of transfer capacity between the middle of the country and the West Coast, easing congestion on the transmission system, increasing resiliency and reliability in all three energy markets, and enabling fast sharing of renewable energy across a vast area with diverse weather patterns. The project capital cost is expected to be approximately $3.2 billion. On August 6, 2024, the U.S. Department of Energy awarded a $700 million grant to the project. ALLETE expects to pursue up to 35 percent ownership and would oversee the line’s operation. The companies began project permitting in 2023 as they work toward a planned in-service date as early as 2032, pending regulatory and other necessary approvals.
Duluth Loop Reliability Project. In October 2021, Minnesota Power submitted an application for a certificate of need for the Duluth Loop Reliability Project. This transmission project was proposed to enhance reliability in and around Duluth, Minnesota. The project includes the construction of a new 115-kV transmission line; construction of an approximately one-mile extension of an existing 230-kV transmission line; and upgrades to several substations. A certificate of need was granted and a route permit was issued by the MPUC on April 3, 2023. The Duluth Loop Reliability Project is expected to be completed and in service by late 2026 to early 2027, with an estimated cost of $50 million to $70 million.
HVDC Transmission System Project. On June 1, 2023, Minnesota Power submitted an application for a certificate of need and route permit with the MPUC to replace aging critical infrastructure and modernize the terminal stations of its HVDC transmission line. On June 21, 2024, the administrative law judge issued a report containing recommendations to approve the certificate of need and route permit. On August 1, 2024, the MPUC approved the certificate of need and route permit. Minnesota Power uses the 465-mile, 250-kV HVDC transmission line that runs from Center, North Dakota, to Duluth, Minnesota, to transport wind energy from North Dakota while gradually phasing out coal-based electricity delivered to its system over this transmission line from Square Butte’s lignite coal-fired generating unit. The HVDC transmission system project is expected to improve reliability of the transmission system, improve system resiliency, expand the operating capacity of the HVDC terminals, and replace critical infrastructure. Pending regulatory approvals in Minnesota and North Dakota, construction could begin as early as 2024, with an in-service date expected between 2028 and 2030. The project is estimated to cost between $800 million and $900 million. On October 18, 2023, the U.S. Department of Energy awarded a $50 million grant to Minnesota Power for this project, which will be used to prepare the HVDC transmission system for future expansion and help reduce project costs to customers. In addition, this project was awarded $15 million in state funding as part of an energy and climate budget bill passed by the Minnesota Legislature in 2023. Further, Minnesota Power’s application to the Minnesota Department of Commerce (DOC) State Competitiveness Fund Match Program received notification the DOC is reserving $10 million as a cost share for the project. In total, Minnesota Power has been awarded $75 million in federal and state dollars in support of the project.
Northland Reliability Project. Minnesota Power and Great River Energy announced in July 2022 their intent to build a 150-mile, 345-kV transmission line, connecting northern Minnesota to central Minnesota to support continued reliability in the Upper Midwest. Great River Energy, a wholesale electric power cooperative, and Minnesota Power filed a Notice of Intent to Construct, Own and Maintain the transmission line with the MPUC in August 2022. This joint project is part of a portfolio of transmission projects approved in July 2022 by MISO as part of the first phase of its Long Range Transmission Plan. Planning for the approximately $970 million to $1,350 million transmission line is in its early stages with the route anticipated to generally follow existing rights of way in an established power line corridor. The MPUC will determine the final route as well as cost recovery for Minnesota Power’s approximately 50 percent estimated share of the project. On August 4, 2023, Minnesota Power and Great River Energy submitted an application for a certificate of need and route permit with the MPUC. On May 10, 2024, the FERC approved Minnesota Power's request to recover on construction work in progress related to this project from Minnesota Power’s wholesale customers. Subject to regulatory approvals, the transmission line is expected to be in service in 2030.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
43
OUTLOOK (Continued)
Transmission (Continued)
Big Stone South Transmission Project. Northern States Power, Great River Energy, Minnesota Power, Otter Tail Power Company, and Missouri River Energy Resources (Project Developers) announced in July 2022 their intent to build a 150-mile, 345-kV transmission line to improve reliability in North Dakota and South Dakota, and western and central Minnesota. This joint project is part of a portfolio of transmission projects approved in July 2022 by MISO as part of the first phase of its Long Range Transmission Plan. A Notice of Intent to Construct, Own and Maintain the transmission line was filed with the MPUC in October 2022. On September 29, 2023, the Project Developers submitted an application for a certificate of need and route permit with the MPUC, which was approved on October 3, 2024. The project is in its early stages and is expected to cost between $600 million and $700 million. Minnesota Power has asset ownership in the Alexandria-Big Oaks portion of the project which does not require a route permit and will begin construction immediately following the October 3, 2024 Certificate of Need approval. Minnesota Power is a 16.5 percent owner of this portion of the project and will invest at this level for the entire portion of the project. On March 13, 2024, Minnesota Power submitted a filing with the FERC requesting to recover on construction work in progress related to this project from Minnesota Power’s wholesale customers. The Minnesota Power portion of this transmission line is expected to be in service in 2027.
ALLETE Clean Energy.
ALLETE Clean Energy will pursue growth through acquisitions or project development. ALLETE Clean Energy is targeting acquisitions of existing operating portfolios which have a mix of long-term PSAs in place and/or available for repowering and recontracting. Further, ALLETE Clean Energy will evaluate actions that will lead to the addition of complimentary clean energy products and services. At this time, ALLETE Clean Energy is focused on actions that will optimize its clean energy project portfolio of operating and development projects, which may include recontracting, repowering, entering into partnerships and divestitures along with continued acquisitions or development of new projects including wind, solar, energy storage or storage ready facilities across North America.
Starting in September 2023, a substation and the transmission lines feeding that substation located near Caddo, and operated by another party, experienced a forced outage. This forced outage increased congestion experienced by Caddo during the first half of 2024. The forced outage was resolved in June 2024.
Corporate and Other.
Corporate and Other includes New Energy, a renewable energy development company, 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, South Shore Energy, our non-rate regulated, Wisconsin subsidiary developing NTEC, other business development and corporate expenditures, unallocated interest expense, a small amount of non-rate base generation, land in Minnesota, and earnings on cash and investments.
LIQUIDITY AND CAPITAL RESOURCES
Liquidity Position. ALLETE is well-positioned to meet the Company’s liquidity needs. As of September 30, 2024, we had cash and cash equivalents of $101.9 million, $338.6 million in available consolidated lines of credit, 2.1 million original issue shares of common stock available for issuance through a distribution agreement with Lampert Capital Markets and a debt-to-capital ratio of 35 percent. Pursuant to the Merger Agreement, ALLETE has agreed, subject to certain exceptions, to, and to cause each of its subsidiaries to, conduct its business in the ordinary course, consistent with past practice, from the date of the Merger Agreement until the effective time of the Merger, and not to take certain actions prior to the closing of the Merger without the prior written consent of Alloy Parent (which consent shall not be unreasonably withheld, conditioned or delayed, except where ALLETE seeks Alloy Parent’s consent to enter into a material new line of business or cease operations of an existing material line of business). (See Note 11. Agreement and Plan of Merger.)
ALLETE, Inc. Third Quarter 2024 Form 10-Q
44
LIQUIDITY AND CAPITAL RESOURCES (Continued)
Capital Structure. ALLETE’s capital structure is as follows:
September 30, 2024
%
December 31, 2023
%
Millions
ALLETE Equity
$2,831.2
54
$2,809.6
54
Non-Controlling Interest in Subsidiaries
560.7
11
597.0
11
Short-Term and Long-Term Debt (a)
1,794.4
35
1,799.4
35
Redeemable Non-Controlling Interest
0.7
—
0.5
—
$5,187.0
100
$5,206.5
100
(a)Excludes unamortized debt issuance costs.
Cash Flows. Selected information from the Consolidated Statement of Cash Flows is as follows:
For the Nine Months Ended September 30,
2024
2023
Millions
Cash, Cash Equivalents and Restricted Cash at Beginning of Period
$79.4
$40.2
Cash Flows provided by (used in)
Operating Activities
367.3
520.0
Investing Activities
(219.9)
(200.6)
Financing Activities
(115.8)
(228.4)
Change in Cash, Cash Equivalents and Restricted Cash
31.6
91.0
Cash, Cash Equivalents and Restricted Cash at End of Period
$111.0
$131.2
Operating Activities. Cash provided by operating activities was lower in 2024 compared to 2023 reflecting cash proceeds from the sales of ALLETE Clean Energy’s Northern Wind and Red Barn projects in 2023, higher cash contributions to defined benefit pension in 2024, and timing of recovery under Minnesota Power’s fuel adjustment clause. These decreases were partially offset by proceeds from the sale of renewable tax credits in 2024.
Investing Activities. Cash used in investing activities was higher in 2024 compared to 2023 reflecting more payments for additions to property, plant and equipment compared to 2023, partially offset by cash grants received for our HVDC Transmission System Project in 2024. (See Outlook.)
Financing Activities. Cash used in financing activities in 2024 reflected higher repayments of long-term debt in 2024, partially offset by higher proceeds from the issuance of long-term debt compared to 2023.
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 September 30, 2024, we had consolidated bank lines of credit aggregating $362.0 million ($423.1 million as of December 31, 2023), the majority of which expire in January 2027. (See Note 5. Short-Term and Long-Term Debt.) We had $23.4 million outstanding in standby letters of credit and no outstanding draws under our lines of credit as of September 30, 2024 ($19.4 million in standby letters of credit and $34.1 million outstanding draws on our lines of credit as of December 31, 2023). As of September 30, 2024, we also had $116.7 million outstanding in standby letters of credit under other credit facility agreements.
In addition, as of September 30, 2024, we had 2.5 million original issue shares of our common stock available for issuance through Invest Direct, our direct stock purchase and dividend reinvestment plan, and 2.1 million original issue shares of common stock available for issuance through a distribution agreement with Lampert Capital Markets. (See Securities.) The amount and timing of future sales of our securities will depend upon market conditions and our specific needs.
Securities. During the nine months ended September 30, 2024, we issued 0.3 million shares of common stock through Invest Direct, ESPP, and RSOP, resulting in net proceeds of $9.9 million (0.2 million shares were issued for the nine months ended September 30, 2023, resulting in net proceeds of $11.4 million).
Financial Covenants. See Note 5. Short-Term and Long-Term Debt for information regarding our financial covenants.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
45
LIQUIDITY AND CAPITAL RESOURCES (Continued)
Pension and Other Postretirement Benefit Plans. Management considers various factors when making funding decisions, such as regulatory requirements, actuarially determined minimum contribution requirements and contributions required to avoid benefit restrictions for the defined benefit pension plans. (See Note 9. Pension and Other Postretirement Benefit Plans.)
Off-Balance Sheet Arrangements. Off-balance sheet arrangements are summarized in our 2023 Form 10-K, with additional disclosure in Note 6. Commitments, Guarantees and Contingencies.
Credit Ratings. Access to reasonably priced capital markets is dependent in part on credit and ratings. Our securities have been rated by S&P Global Ratings and by Moody’s. Rating agencies use both quantitative and qualitative measures in determining a company’s credit rating. These measures include business risk, liquidity risk, competitive position, capital mix, financial condition, predictability of cash flows, management strength and future direction. Some of the quantitative measures can be analyzed through a few key financial ratios, while the qualitative ones are more subjective. Our current credit ratings are listed in the following table:
Credit Ratings
S&P Global Ratings(a)
Moody’s
Issuer Credit Rating
BBB
Baa1
Commercial Paper
A-2
P-2
First Mortgage Bonds
(b)
A2
(a) On May 7, 2024, S&P Global Ratings revised its outlook on ALLETE to negative from stable and affirmed all of its ratings on ALLETE. S&P Global Ratings cited the possibility for higher leverage and weaker financial measures because of the Merger as its rationale for issuing the negative outlook.
(b) Not rated by S&P Global Ratings.
The disclosure of these credit ratings is not a recommendation to buy, sell or hold our securities. Ratings are subject to revision or withdrawal at any time by the assigning rating organization. Each rating should be evaluated independently of any other rating.
Capital Requirements. For the nine months ended September 30, 2024, capital expenditures totaled $229.5 million ($182.0 million for the nine months ended September 30, 2023). The expenditures were primarily made in the Regulated Operations segment.
OTHER
Environmental Matters.
Our businesses are subject to regulation of environmental matters by various federal, state and local authorities. A number of regulatory changes to the Clean Air Act, the Clean Water Act and various waste management requirements have been promulgated by both the EPA and state authorities over the past several years. Minnesota Power’s facilities are subject to additional requirements under many of these regulations. Minnesota Power is reshaping its generation portfolio, over time, to reduce its reliance on coal, has installed cost-effective emission control technology, and advocates for sound science and policy during rulemaking implementation. (See Note 6. Commitments, Guarantees and Contingencies.)
Employees.
As of September 30, 2024, ALLETE had 1,622 employees, of which 1,564 were full-time.
Minnesota Power and SWL&P have an aggregate of 490 employees covered under collective bargaining agreements, of which most are members of International Brotherhood of Electrical Workers (IBEW) Local 31. The current labor agreements with IBEW Local 31 expire on April 30, 2026, for Minnesota Power and January 31, 2027, for SWL&P.
BNI Energy has 181 employees, of which 131 are subject to a labor agreement with IBEW Local 1593. The current labor agreement with IBEW Local 1593 expires on March 31, 2026.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
46
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 September 30, 2024, 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 September 30, 2024, an increase of 100 basis points in interest rates would impact the amount of pre-tax interest expense by $0.3 million. This amount was determined by considering the impact of a hypothetical 100 basis point increase to the average variable interest rate on the variable rate debt outstanding as of September 30, 2024.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
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ITEM 4. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures. As of September 30, 2024, evaluations were performed, under the supervision and with the participation of management, including our principal executive officer and principal financial officer, on the effectiveness of the design and operation of ALLETE’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934 (Exchange Act)). Based upon those evaluations, our principal executive officer and principal financial officer have concluded that such disclosure controls and procedures are effective to provide assurance that information required to be disclosed in ALLETE’s reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.
Changes in Internal Controls. There has been no change in our internal control over financial reporting that occurred during our most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
For information regarding material legal and regulatory proceedings, see Note 4. Regulatory Matters and Note 9. Commitments, Guarantees and Contingencies to the Consolidated Financial Statements in our 2023 Form 10-K and Note 2. Regulatory Matters and Note 6. Commitments, Guarantees and Contingencies herein. Such information is incorporated herein by reference.
ITEM 1A. RISK FACTORS
Our 2023 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 2023 Form 10-K.
Risks Relating to the Merger
On May 5, 2024, ALLETE entered into the Merger Agreement. (See Note 11. Agreement and Plan of Merger.)
There is no assurance when or if the Merger will be completed.
Consummation of the Merger is subject to various closing conditions, including: (1) approval of the shareholders of ALLETE; (2) receipt of all required regulatory approvals without the imposition of a Burdensome Condition; (3) absence of any law or order prohibiting the consummation of the Merger; (4) subject to materiality qualifiers, the accuracy of each party’s representations and warranties; (5) each party’s compliance in all material respects with its obligations and covenants under the Merger Agreement; and (6) the absence of a material adverse effect with respect to the Company. The Merger Agreement also contains certain termination rights for both ALLETE and Alloy Parent, including if the Merger is not consummated by August 5, 2025 (subject to extension for an additional two successive three-month periods if all of the conditions to closing, other than the conditions related to obtaining regulatory approvals, have been satisfied). There can be no assurance that the conditions to completion of the Merger will be satisfied or waived or that other events will not intervene to delay or result in the failure to close the proposed Merger. The Merger Agreement also provides for certain termination rights for each of ALLETE and Alloy Parent. If the Merger Agreement is terminated, there may be various material, adverse consequences to the Company, including that the Company could be required to pay Alloy Parent a termination fee of $116 million under certain specified circumstances.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
48
ITEM 1A. RISK FACTORS (Continued)
The announcement and pendency of the Merger, during which the Company is subject to certain operating restrictions, could have an adverse effect on the Company’s businesses, results of operations, financial condition or cash flows.
The announcement and pendency of the Merger could disrupt the Company’s businesses, and uncertainty about the effect of the Merger may have an adverse effect on the Company. These uncertainties could affect existing employee relationships, disrupt the business of the Company, and could cause suppliers, vendors, partners, lenders and others that deal with the Company to: (1) defer entering into contracts with the Company; or (2) making other decisions concerning the Company or seek to change or cancel existing business relationships with the Company.
The Merger Agreement also requires the Company to obtain Parent’s consent prior to taking certain specified actions while the Merger is pending. These restrictions may prevent the Company from pursuing otherwise attractive business opportunities or making other changes to its business prior to the completion of the Merger.
The Company will incur substantial transaction fees and costs in connection with the Merger.
The Company has incurred transaction costs of $19.5 million after-tax through September 30, 2024, and expects to incur additional material expenses in connection with the Merger and completion of the transactions contemplated by the Merger Agreement. Further, even if the proposed Merger is not completed, the Company will need to pay certain costs relating to the proposed Merger incurred prior to the date the proposed Merger was abandoned, such as legal, accounting, financial advisory, filing and printing fees.
We have received demand letters and complaints related to the Merger and may become the target of securities class action and derivative lawsuits which could result in substantial costs and may delay or prevent the Merger from being completed.
Securities class action lawsuits and derivative lawsuits are often brought against companies that have entered into merger agreements. Even if the lawsuits are without merit, defending against these claims can result in substantial costs to us and divert management time and resources. Additionally, if a plaintiff is successful in obtaining an injunction prohibiting consummation of the Merger, then that injunction may delay or prevent the Merger from being completed. We have received a number of demand letters alleging that the disclosures contained in the preliminary proxy statement, as amended, and filed with the SEC in connection with a special meeting of shareholders to consider the Merger (Preliminary Proxy), were deficient and demanding that certain corrective disclosures be made. In addition, a complaint has been filed in the U.S. District Court for the Southern District of New York alleging violation of Sections 14(a) and 20(a) of the Securities Exchange Act of 1934, disclosure deficiency in the Preliminary Proxy, and seeking to enjoin the transaction until certain disclosures are corrected. On September 3, 2024, that complaint was voluntarily dismissed without prejudice. A second complaint was filed on August 6, 2024, in the New York State Supreme Court, alleging negligent misrepresentation and negligence related to alleged deficiencies in the Preliminary Proxy. That complaint has not been served on any defendant. The Company believes that the demand letters and remaining complaint are without merit.
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.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
49
ITEM 5. OTHER INFORMATION
Trading Plans. During the quarter ended September 30, 2024, no director or officer of the Company adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K.
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)
*Schedules and exhibits have been omitted pursuant to Item 601(b)(2) of Regulation S-K. A copy of any omitted schedules will be furnished supplementally to the SEC upon request; provided, however, that the parties may request confidential treatment pursuant to Rule 24b-2 of the Exchange Act for any document so furnished.
ALLETE agrees to furnish to the SEC upon request any instrument with respect to long-term debt that ALLETE has not filed as an exhibit pursuant to the exemption provided by Item 601(b)(4)(iii)(A) of Regulation S-K.
ALLETE, Inc. Third Quarter 2024 Form 10-Q
50
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.
October 30, 2024
/s/ Steven W. Morris
Steven W. Morris
Senior Vice President and Chief Financial Officer
(Principal Financial Officer and Principal Accounting Officer)