EDGAR 10-K Filing

Company CIK: 66756
Filing Year: 2024
Filename: 66756_10-K_2024_0000066756-24-000007.json

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ITEM 1. BUSINESS
Item 1. Business
Overview.
ALLETE is a leader in the nation’s clean-energy transformation. Our businesses and dedicated employees deliver sustainable energy solutions that mitigate climate change, build thriving communities, help customers reach their sustainability goals and drive value for shareholders. In 2020, ALLETE’s largest business, Minnesota Power, reached a milestone of providing 50 percent renewable energy to its retail and municipal customers in Minnesota, and in 2023 delivered 50 percent renewable energy to those customers. The Company envisions delivering 100 percent carbon-free energy to customers by 2050-a vision grounded in a steadfast commitment to climate, customers and community through its EnergyForward strategy. ALLETE Clean Energy, our second-largest business, is positioned at the heart of society’s clean-energy transformation and owns, operates and has developed for others more than 1,600 megawatts of wind energy generation across eight states-helping some of the largest companies in the country reduce their carbon footprint. Our newest business, New Energy, is a leading developer of community, commercial and industrial, and small utility-scale renewable energy projects that has completed more than 500 MW in its history.
Minnesota Power’s latest IRP, approved by the MPUC in an order dated January 9, 2023, outlines its clean-energy transition plans through 2035. These plans include expanding its renewable energy supply to 70 percent by 2030, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. Minnesota Power has also set a target to achieve an 80 percent reduction in carbon emissions by 2035 compared to 2005 levels. As part of these plans, Minnesota Power anticipates adding up to 700 MW of new wind and solar energy resources, and ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably.
In recent years, Minnesota Power has transformed its company-owned energy supply from more than a 95 percent reliance on coal to become a leader in the nation’s clean-energy transformation. Since 2013, the company has closed or converted seven of its nine coal-fired units and added nearly 900 megawatts of renewable energy sources. Additionally, Minnesota Power has been a leader in energy conservation, surpassing the state’s conservation goals each year for the past decade.
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 Company is evaluating the law to identify challenges and opportunities it could present. Minnesota Power is also working with various stakeholders and participating in the regulatory process to implement this legislation. (See Regulated Operations - Minnesota Legislation.)
ALLETE is committed to earning a financial return that rewards our shareholders, allows for reinvestment in our businesses, and sustains growth. 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, 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.
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 4. 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 engages in the development of wind energy facilities to operate under long-term PSAs or for sale to others upon completion.
ALLETE, Inc. 2023 Form 10-K
Overview (Continued)
Corporate and Other is 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 December 31, 2023, 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.
Year Ended December 31 2023 2022 2021
Consolidated Operating Revenue - Millions (a)
$1,879.8 $1,570.7 $1,419.2
Percentage of Consolidated Operating Revenue
Regulated Operations 66 % 80 % 87 %
ALLETE Clean Energy (a)
22 % 8 % 6 %
Corporate and Other (b)
12 % 12 % 7 %
100 % 100 % 100 %
(a) Consolidated operating revenue for 2023 includes the sales of ALLETE Clean Energy’s Northern Wind and Red Barn projects.
(b) Consolidated operating revenue for 2023 and 2022 includes revenue from New Energy, which was acquired in the second quarter of 2022. (See Note. 5 Acquisitions.)
For a detailed discussion of results of operations and trends, see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations. For business segment information, see Note 1. Operations and Significant Accounting Policies and Note 14. Business Segments.
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS
Electric Sales / Customers
Regulated Utility Kilowatt-hours Sold
Year Ended December 31 2023 % 2022 % 2021 %
Millions
Retail and Municipal
Residential 1,089 8 1,148 9 1,135 7
Commercial 1,347 11 1,359 11 1,359 9
Industrial 7,044 55 6,745 52 7,196 47
Municipal 466 4 540 4 590 4
Total Retail and Municipal 9,946 78 9,792 76 10,280 67
Other Power Suppliers 2,819 22 3,149 24 5,102 33
Total Regulated Utility Kilowatt-hours Sold 12,765 100 12,941 100 15,382 100
Industrial Customers. In 2023, industrial customers represented 55 percent of total regulated utility kWh sales. Our industrial customers are primarily in the taconite mining, paper, pulp and secondary wood products, and pipeline industries. Cliffs idled all production at its Northshore mine in 2022 and resumed partial pellet plant production in April 2023. (See Outlook - Regulated Operations - Industrial Customers - Taconite.)
Industrial Customer Kilowatt-hours Sold
Year Ended December 31 2023 % 2022 % 2021 %
Millions
Taconite 4,935 70 4,713 70 5,281 73
Paper, Pulp and Secondary Wood Products 669 10 735 11 702 10
Pipelines and Other Industrial 1,440 20 1,297 19 1,213 17
Total Industrial Customer Kilowatt-hours Sold 7,044 100 6,745 100 7,196 100
Six taconite facilities served by Minnesota Power made up approximately 70 percent of 2022 iron ore pellet production in the U.S. according to data from the Minnesota Department of Revenue 2023 Mining Tax Guide. These taconite facilities are owned by Cliffs and USS Corporation. (See Large Power Customer Contracts.) Sales to taconite customers represented 4,935 million kWh, or 70 percent of total industrial customer kWh sales in 2023. Taconite, an iron bearing rock of relatively low iron content, is abundantly available in northern Minnesota and an important domestic source of raw material for the steel industry. Taconite processing plants use large quantities of electric power to grind the iron-bearing rock, and agglomerate and pelletize the iron particles into taconite pellets.
Minnesota Power’s taconite customers are capable of producing approximately 41 million tons of taconite pellets annually. Taconite pellets produced in Minnesota are primarily shipped to North American steel making facilities that are part of the integrated steel industry, which continue to lead the world in environmental performance among steelmaking countries. According to the U.S. Department of Energy, steel production in the U.S. is the most energy efficient of any major steel producing country. Steel produced from these North American facilities is used primarily in the manufacture of automobiles, appliances, tubular applications for all industries, and in the construction industry. Steel is also a critical component of the clean energy transformation underway today. The demand for more renewable energy and the need for additional infrastructure to transport green energy from the point of generation to the end user both require steel. Historically, approximately 10 percent of Minnesota taconite production has been exported outside of North America.
There has been a general historical correlation between U.S. steel production and Minnesota taconite production. The American Iron and Steel Institute, an association of North American steel producers, reported that U.S. raw steel production operated at approximately 75 percent of capacity in 2023 (78 percent in 2022 and 82 percent in 2021). The World Steel Association, an association of steel producers, national and regional steel industry associations, and steel research institutes representing approximately 85 percent of world steel production, projected U.S. steel consumption in 2024 will increase by approximately 2 percent compared to 2023.
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Industrial Customers (Continued)
The following table reflects Minnesota Power’s taconite customers’ production levels for the past ten years:
Minnesota Power Taconite Customer Production
Year Tons (Millions)
2023* 35
2022 32
2021 39
2020 30
2019 37
2018 39
2017 38
2016 28
2015 31
2014 39
Source: Minnesota Department of Revenue 2023 Mining Tax Guide for years 2014 - 2022.
* Preliminary data from the Minnesota Department of Revenue.
Minnesota Power’s taconite customers may experience annual variations in production levels due to such factors as economic conditions, short-term demand changes or maintenance outages. We estimate that a one million ton change in Minnesota Power’s taconite customers’ production would impact our annual earnings per share by approximately $0.05, net of expected power marketing sales at current prices. Changes in wholesale electric prices or customer contractual demand nominations could impact this estimate. Minnesota Power proactively sells power in the wholesale power markets that is temporarily not required by industrial customers to optimize the value of its generating facilities. Long-term reductions in taconite production or a permanent shut down of a taconite customer may lead Minnesota Power to file a general rate case to recover lost revenue.
In addition to serving the taconite industry, Minnesota Power serves a number of customers in the paper, pulp and secondary wood products industry, which represented 669 million kWh, or 10 percent of total industrial customer kWh sales in 2023. Minnesota Power also has an agreement to provide steam for one paper and pulp customer for use in the customer’s operations. The major paper and pulp mills we serve reported operating at similar levels in 2023 compared to 2022. ST Paper completed start-up of operations and is now a Large Power Customer as of the first quarter of 2023. On January 3, 2024, ST Paper announced it had entered into an asset purchase agreement to sell the Duluth Mill to Sofidel (See Outlook - Regulated Operations - Industrial Customers - Paper, Pulp and Secondary Wood Products - ST Paper.)
Large Power Customer Contracts. Minnesota Power had eight Large Power Customer contracts as of December 31, 2023, each serving requirements of 10 MW or more of customer load. Certain facilities with common ownership are served under combined contracts. The customers as of December 31, 2023 consisted of six taconite facilities owned by Cliffs and USS Corporation as well as four paper and pulp mills. Minnesota Power also serves Northshore Mining through a PSA with its affiliate Silver Bay Power, in addition to the load served through its Large Power Contract with United Taconite and Northshore Mining. (See Silver Bay Power PSA.)
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Large Power Customer Contracts (Continued)
Large Power Customer contracts require Minnesota Power to have a certain amount of generating capacity available. In turn, each Large Power Customer is required to pay a minimum monthly demand charge that covers the fixed costs associated with having this capacity available to serve the customer, including a return on common equity. Most contracts allow customers to establish the level of megawatts subject to a demand charge on a three- to four-month basis and require that a portion of their megawatt needs be committed on a take-or-pay basis for at least a portion of the term of the agreement. In addition to the demand charge, each Large Power Customer is billed an energy charge for each kWh used that recovers the variable costs incurred in generating electricity. Five of the Large Power Customer contracts have interruptible service which provides a discounted demand rate in exchange for the ability to interrupt the customers during system emergencies. Minnesota Power also provides incremental production service for customer demand levels above the contractual take-or-pay levels. There is no demand charge for this service and energy is priced at an increment above Minnesota Power’s cost. Incremental production service is interruptible.
All contracts with Large Power Customers continue past the contract termination date unless the required advance notice of cancellation has been given. The required advance notice of cancellation varies from two to four years. Such contracts reduce the impact on earnings that otherwise would result from significant reductions in kWh sales to such customers. Large Power Customers are required to take all of their purchased electric service requirements from Minnesota Power for the duration of their contracts. The rates and corresponding revenue associated with capacity and energy provided under these contracts are subject to change through the same regulatory process governing all retail electric rates. (See Regulatory Matters - Electric Rates.)
Minnesota Power, as permitted by the MPUC, requires its taconite-producing Large Power Customers to pay weekly for electric usage based on monthly energy usage estimates. These customers receive estimated bills or make weekly prepayments based on Minnesota Power’s estimate of the customer’s energy usage, forecasted energy prices and fuel adjustment clause estimates. Minnesota Power’s taconite producing Large Power Customers have generally predictable energy usage on a week-to-week basis and any differences that occur are trued-up the following month.
Contract Status for Minnesota Power Large Power Customers
As of December 31, 2023
Customer Industry Location Ownership Earliest
Termination Date
Cliffs - Minorca Mine (a)
Taconite Virginia, MN Cliffs December 31, 2027
Hibbing Taconite (a)(d)
Taconite Hibbing, MN 85.3% Cliffs
14.7% USS Corporation December 31, 2027
United Taconite and Northshore Mining (a)
Taconite Eveleth, MN and Babbitt, MN Cliffs December 31, 2027
USS Corporation
(USS - Minnesota Ore) (a)(b)(d)
Taconite Mtn. Iron, MN and Keewatin, MN USS Corporation December 31, 2027
Boise, Inc. (a)
Paper International Falls, MN Packaging Corporation of America December 31, 2027
UPM Blandin Paper Grand Rapids, MN UPM-Kymmene Corporation December 31, 2029
Sappi Cloquet LLC (a)
Paper and Pulp Cloquet, MN Sappi Limited December 31, 2027
ST Paper Duluth (c)
Paper Duluth, MN ST Paper LLC February 28, 2029
(a)The contract will terminate four years from the date of written notice from either Minnesota Power or the customer. No notice of contract cancellation has been given by either party. Thus, the earliest date of cancellation is December 31, 2027.
(b)USS Corporation owns both the Minntac Plant in Mountain Iron, MN, and the Keewatin Taconite Plant in Keewatin, MN.
(c)In January 2024, ST Paper announced it had entered into an asset purchase agreement to sell its paper mill in Duluth, Minnesota to Sofidel. (See Outlook - Regulated Operations - Industrial Customers - Paper, Pulp and Secondary Wood Products.)
(d)In December 2023, USS Corporation announced it entered into a definitive agreement in which Nippon Steel will acquire all of USS Corporation’s stock. (See Outlook - Regulated Operations - Industrial Customers - Taconite.)
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Silver Bay Power PSA. Minnesota Power has a PSA with Silver Bay Power through 2031 to supply its full energy requirements. Silver Bay Power supplies approximately 90 MW of load to Northshore Mining, an affiliate of Silver Bay Power.
Residential and Commercial Customers. In 2023, residential and commercial customers represented 19 percent of total regulated utility kWh sales.
Municipal Customers. In 2023, municipal customers represented 4 percent of total regulated utility kWh sales.
Minnesota Power’s wholesale electric contracts with 14 non-affiliated municipal customers in Minnesota have termination dates ranging from 2029 through 2037, with a majority of contracts expiring in 2029. One of these wholesale contracts includes a termination clause requiring a 3-year notice to terminate. (See Note 4. Regulatory Matters.)
Other Power Suppliers. The Company also enters into off-system sales with Other Power Suppliers. These sales are at market based prices into the MISO market on a daily basis or through bilateral agreements of various durations.
Our PSAs are detailed in Note 9. Commitments, Guarantees and Contingencies, with additional disclosure provided in the following paragraphs.
Minnkota Power PSA. Minnesota Power has a PSA with Minnkota Power where Minnesota Power is selling a portion of its entitlement from Square Butte to Minnkota Power, resulting in Minnkota Power’s net entitlement increasing and Minnesota Power’s net entitlement decreasing until Minnesota Power’s share is eliminated at the end of 2025. Of Minnesota Power’s 50 percent output entitlement, it sold approximately 37 percent to Minnkota Power in 2023 (32 percent in 2022 and 28 percent in 2021). Minnkota Power’s net entitlement increases to approximately 41 percent in 2024, 46 percent in 2025 and 50 percent in 2026. (See Power Supply - Long-Term Purchased Power.)
Hibbing Public Utilities. In April 2022, Minnesota Power entered into a long-term Power Purchase and Market Energy Service Agreement with Hibbing Public Utilities for the period of June 1, 2022, through May 31, 2027. The agreement replaced the previous wholesale electric contract between Hibbing Public Utilities and Minnesota Power.
Seasonality
The operations of our industrial customers, which make up a large portion of our electric sales, are not typically subject to significant seasonal variations. (See Electric Sales / Customers.) As a result, Minnesota Power is generally not subject to significant seasonal fluctuations in electric sales; however, Minnesota Power and SWL&P electric and natural gas sales to other customers may be affected by seasonal differences in weather. In general, peak electric sales occur in the winter and summer months with fewer electric sales in the spring and fall months. Peak sales of natural gas generally occur in the winter months. Additionally, our regulated utilities have historically generated fewer sales and less revenue when weather conditions are milder in the winter and summer.
Power Supply
In order to meet its customers’ electric requirements, Minnesota Power utilizes a mix of its own generation and purchased power. Since 2020, approximately 50 percent of Minnesota Power’s power supply for its retail and municipal customers in Minnesota has been provided by renewable energy sources. This was enabled by the completion of the 250 MW Nobles 2 wind energy facility in December 2020 and the GNTL in June 2020, which is used to deliver 250 MW of hydroelectric energy from Manitoba Hydro. Minnesota Power’s remaining operating coal-fired facilities are Boswell Units 3 and 4, which Minnesota Power plans to cease coal operations at by 2030 and 2035, respectively. (See Regulatory Matters.) Renewable energy percentages may vary year to year based on weather, system demand and transmission constraints.
The following table reflects Minnesota Power’s generating capabilities as of December 31, 2023, and total electrical supply for 2023. Minnesota Power had an annual net peak load of 1,551 MW on August 3, 2023.
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Power Supply (Continued)
Year Ended
Unit Year Net December 31, 2023
Regulated Utility Power Supply No. Installed Capability Generation and Purchases
MW MWh %
Coal-Fired
Boswell Energy Center (a)
3 1973 352
in Cohasset, MN 4 1980 468 (b)
820 4,458,923 33.8
Total Coal-Fired 820 4,458,923 33.8
Biomass Co-Fired / Natural Gas
Hibbard Renewable Energy Center in Duluth, MN 3 & 4 1949, 1951 60 68,189 0.5
Laskin Energy Center in Hoyt Lakes, MN 1 & 2 1953 98 110,290 0.8
Total Biomass Co-Fired / Natural Gas 158 178,479 1.3
Hydro (c)
Group consisting of ten stations in MN Multiple Multiple 120 434,133 3.3
Wind (d)
Taconite Ridge Energy Center in Mtn. Iron, MN Multiple 2008 25 47,361 0.4
Bison Wind Energy Center in Oliver and Morton Counties, ND Multiple 2010-2014 497 1,269,120 9.6
Total Wind 522 1,316,481 10.0
Solar (e)
Group consisting of two solar arrays in MN Multiple Multiple 10 15,844 0.1
Total Generation 1,630 6,403,860 48.5
Long-Term Purchased Power
Lignite Coal - Square Butte near Center, ND (f)
1,377,198 10.4
Wind - Oliver Wind I and II in Oliver County, ND 357,541 2.7
Wind - Nobles 2 in Nobles County, MN (g)
953,506 7.2
Hydro - Manitoba Hydro in Manitoba, Canada 1,460,000 11.1
Solar - Purchases from five solar arrays in MN 28,227 0.2
Total Long-Term Purchased Power 4,176,472 31.6
Other Purchased Power (h)
2,625,816 19.9
Total Purchased Power
6,802,288 51.5
Total Regulated Utility Power Supply
13,206,148 100.0
(a) Minnesota Power anticipates ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. (See Regulatory Matters.)
(b)Boswell Unit 4 net capability shown above reflects Minnesota Power’s ownership percentage of 80 percent. WPPI Energy owns 20 percent of Boswell Unit 4. (See Note 3. Jointly-Owned Facilities and Assets.)
(c)Hydro consists of 10 stations with 34 generating units.
(d)Taconite Ridge consists of 10 WTGs and Bison consists of 165 WTGs.
(e)Solar includes the 10 MW Camp Ripley Solar Array near Little Falls, MN, and a 40 kW community solar garden in Duluth, MN.
(f)Minnesota Power has a PSA with Minnkota Power whereby Minnesota Power is selling a portion of its entitlement from Square Butte to Minnkota Power. (See Electric Sales / Customers - Minnkota Power PSA.)
(g)See Item 1. Business - Corporate and Other - Investment in Nobles 2.
(h)Includes short-term market purchases in the MISO market and from Other Power Suppliers.
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Power Supply (Continued)
Fuel. Minnesota Power purchases low-sulfur, sub-bituminous coal from the Powder River Basin region located in Montana and Wyoming. Coal consumption in 2023 for electric generation at Minnesota Power’s coal-fired generating stations was 2.7 million tons (2.7 million tons in 2022; 2.7 million tons in 2021). As of December 31, 2023, Minnesota Power had coal inventories of 0.7 million tons (0.8 million tons as of December 31, 2022). Minnesota Power has coal supply agreements providing for the purchase of a significant portion of its coal requirements through December 2025. In 2024, Minnesota Power expects to obtain coal under these coal supply agreements and in the spot market. Minnesota Power continues to explore other future coal supply options and believes that adequate supplies of low-sulfur, sub-bituminous coal will continue to be available.
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.
Coal Delivered to Minnesota Power
Year Ended December 31 2023 2022 2021
Average Price per Ton $41.23 $39.98 $39.51
Average Price per MBtu $2.30 $2.25 $2.18
Long-Term Purchased Power. Minnesota Power has contracts to purchase capacity and energy from various entities, including output from certain coal, wind, hydro and solar generating facilities.
Our PPAs are detailed in Note 9. Commitments, Guarantees and Contingencies, with additional disclosure provided in the following paragraph.
Square Butte PPA. Under the PPA with Square Butte that extends through 2026, Minnesota Power is entitled to 50 percent of the output of Square Butte’s 455 MW coal-fired generating unit. (See Note 9. Commitments, Guarantees and Contingencies.) BNI Energy mines and sells lignite coal to Square Butte. This lignite supply is sufficient to provide fuel for the anticipated useful life of the generating unit. Square Butte’s cost of lignite consumed in 2023 was approximately $2.36 per MBtu ($2.05 per MBtu in 2022; $1.94 per MBtu in 2021). (See Electric Sales / Customers - Minnkota Power PSA.)
Manitoba Hydro. Minnesota Power has two long-term PPAs with Manitoba Hydro. The first PPA provides for Minnesota Power to purchase 250 MW of capacity and energy from Manitoba Hydro through May 2035. The second PPA provides for Minnesota Power to purchase up to 133 MW of energy from Manitoba Hydro through June 2040. A third PPA, which expired in April 2022 was an energy-only agreement, which primarily consisted of surplus hydro energy on Manitoba Hydro’s system that was delivered to Minnesota Power on a non-firm basis.
Wind Energy. Minnesota Power has a long-term PPA with Nobles 2 that provides for Minnesota Power to purchase the energy and associated capacity from a 250 MW wind energy facility in southwestern Minnesota through 2040. The agreement provides for the purchase of output from the facility at fixed energy prices. There are no fixed capacity charges, and Minnesota Power will only pay for energy as it is delivered. (See Corporate and Other - Investment in Nobles 2.) Minnesota Power also has two long-term wind energy PPAs with an affiliate of NextEra Energy, Inc. to purchase the output from Oliver Wind I (50 MW) and Oliver Wind II (48 MW) located in North Dakota.
Solar Energy. Minnesota Power purchases solar energy from approximately 20 MW of solar energy facilities located in Minnesota that are owned by an ALLETE subsidiary, and a 1 MW community solar garden in northeastern Minnesota, which is owned and operated by a third party.
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Transmission and Distribution
We have electric transmission and distribution lines of 500 kV (232 miles), 345 kV (241 miles), 250 kV (466 miles), 230 kV (715 miles), 161 kV (43 miles), 115 kV (1,380 miles) and less than 115 kV (6,415 miles). We own and operate 162 substations with a total capacity of 9,980 megavolt-amperes. Some of our transmission and distribution lines interconnect with other utilities, and we own some of our transmission lines jointly with other utilities. (See Note 3. Jointly-Owned Facilities and Assets and Outlook - Regulated Operations - Transmission.)
Great Northern Transmission Line. As a condition of the 250 MW long-term PPA entered into with Manitoba Hydro, construction of additional transmission capacity was required. As a result, Minnesota Power constructed the GNTL, an approximately 220-mile 500-kV transmission line between Manitoba and Minnesota’s Iron Range that was proposed by Minnesota Power and Manitoba Hydro in order to strengthen the electric grid, enhance regional reliability and promote a greater exchange of sustainable energy. In June 2020, Minnesota Power placed the GNTL into service with project costs of approximately $310 million incurred by Minnesota Power. Total project costs, including those costs contributed by a subsidiary of Manitoba Hydro, totaled approximately $660 million. The 250 MW PPA with Manitoba Hydro commenced when the GNTL was placed into service.
Investment in ATC
Our wholly-owned subsidiary, ALLETE Transmission Holdings, owns approximately 8 percent of ATC, a Wisconsin-based utility that owns and maintains electric transmission assets in portions of Wisconsin, Michigan, Minnesota and Illinois. We account for our investment in ATC under the equity method of accounting. As of December 31, 2023, our equity investment in ATC was $179.7 million ($165.4 million as of December 31, 2022). (See Note 6. Equity Investments.)
ATC’s authorized return on equity is 10.02 percent, or 10.52 percent including an incentive adder for participation in a regional transmission organization, based on a 2020 FERC order which is subject to various outstanding legal challenges related to the return on equity calculation and refund period ordered by the FERC. On August 9, 2022, the U.S. Court of Appeals for the District of Columbia Circuit vacated and remanded the 2020 FERC order back to the FERC. As a result of this decision, ATC recorded a reserve in the third quarter of 2022 for anticipated refunds to its customers for approximately $31 million of which our share was approximately $2.4 million pre-tax. We cannot predict the return on equity the FERC will ultimately authorize in the remanded proceeding.
In addition, the FERC issued a Notice of Proposed Rulemaking in April 2021 to limit the 50 basis point incentive adder for participation in a regional transmission organization to only the first three years of membership in such an organization. If this proposal is adopted, our equity in earnings from ATC would be reduced by approximately $1 million pre-tax annually.
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.
Properties
Our Regulated Operations businesses own office and service buildings, an energy control center, repair shops, electric plants, transmission and distribution facilities and storerooms in various localities in Minnesota, Wisconsin and North Dakota. All of the electric plants are subject to mortgages, which collateralize the outstanding first mortgage bonds of Minnesota Power and SWL&P. Most of the generating plants and substations are located on real property owned by Minnesota Power or SWL&P, subject to the lien of a mortgage, whereas most of the transmission and distribution lines are located on real property owned by others with appropriate easement rights or necessary permits from governmental authorities. WPPI Energy owns 20 percent of Boswell Unit 4. WPPI Energy has the right to use our transmission line facilities to transport its share of Boswell generation. (See Note 3. Jointly-Owned Facilities and Assets.)
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Regulatory Matters
We are subject to the jurisdiction of various regulatory authorities and other organizations. Regulatory matters and proceedings are detailed in Note 4. Regulatory Matters, with a summary included in the following paragraphs.
Electric Rates. All rates and contract terms in our Regulated Operations are subject to approval by applicable regulatory authorities. Minnesota Power and SWL&P design their retail electric service rates based on cost of service studies under which allocations are made to the various classes of customers as approved by the MPUC or the PSCW. Nearly all retail sales include billing adjustment clauses, which may adjust electric service rates for changes in the cost of fuel and purchased energy, recovery of current and deferred conservation improvement program expenditures and recovery of certain transmission, renewable and environmental investments.
Minnesota Public Utilities Commission. The MPUC has regulatory authority over Minnesota Power’s retail service area in Minnesota, retail rates, retail services, capital structure, issuance of securities and other matters. Minnesota Power’s retail base rates through 2021 were based on a 2018 MPUC retail rate order that allowed for a 9.25 percent return on common equity and a 53.81 percent equity ratio. Interim rates were implemented in Minnesota Power’s 2022 general rate case beginning in January 2022, and the resolution of Minnesota Power’s 2022 general rate case changed the allowed return on equity to 9.65 percent and the equity ratio to 52.50 percent beginning October 1, 2023. (See 2022 Minnesota General Rate Case.) As authorized by the MPUC, Minnesota Power also recognizes revenue under cost recovery riders for transmission and renewable investments.
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. On December 7, 2023, the MPUC accepted the filing as complete and approved an annual interim rate increase of approximately $64 million, net of rider revenue, incorporated into base rates starting January 1, 2024, subject to refund. We cannot predict the level of final rates that may be authorized by the MPUC.
2022 Minnesota General Rate Case. On November 1, 2021, Minnesota Power filed a retail rate increase request with the MPUC seeking an average increase of approximately 18 percent for retail customers. The rate filing sought a return on equity of 10.25 percent and a 53.81 percent equity ratio. On an annualized basis, the requested final rate increase would have generated approximately $108 million in additional revenue.
In an order dated February 28, 2023, the MPUC made determinations regarding Minnesota Power’s general rate case including allowing a return on common equity of 9.65 percent and a 52.50 percent equity ratio. We expect additional revenue from base rates of approximately $60 million and an additional $10 million in revenue recognized under cost recovery riders on an annualized basis. On March 20, 2023, Minnesota Power filed a petition for reconsideration with the MPUC requesting reconsideration and clarification of certain decisions in the MPUC’s order. Minnesota Power’s petition included requesting reconsideration of the ratemaking treatment of Taconite Harbor and Minnesota Power’s prepaid pension asset as well as clarification on interim rate treatment for sales to certain customers that did not operate during 2022. The MPUC denied the requests for reconsideration in an order dated May 15, 2023, and provided clarification in support of the interim rate refund treatment for sales to certain customers that did not operate during 2022.
On June 14, 2023, Minnesota Power appealed to the Minnesota Court of Appeals (Court) specific aspects of the MPUC’s rate case orders. Minnesota Power is appealing the ratemaking treatment of Taconite Harbor and Minnesota Power’s prepaid pension asset. We are unable to predict the outcome of this proceeding.
In an order dated September 29, 2023, the MPUC approved Minnesota Power’s final rates, which were implemented beginning on October 1, 2023. The MPUC order also approved Minnesota Power’s interim rate refund plan. Interim rates were collected through the third quarter of 2023 with reserves recorded as necessary. Minnesota Power recorded a reserve for an interim rate refund of approximately $39 million pre-tax as of September 30, 2023 (approximately $18 million as of December 31, 2022). The reserve was refunded to customers during the fourth quarter of 2023.
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Regulatory Matters (Continued)
Minnesota Power Land Sales. In August 2020, Minnesota Power filed a petition with the MPUC for approval to sell land that surrounds several reservoirs on its hydroelectric system and is no longer required to maintain its operations. The land had an estimated value of approximately $100 million, and Minnesota Power proposed to credit ratepayers the net proceeds from the sales in a future rate case or through its renewable resources rider to mitigate future rate increases. In an order dated November 18, 2021, the MPUC authorized the land sales and directed the net proceeds to be refunded to ratepayers subject to certain conditions and required compliance filings. As of December 31, 2023, we have a regulatory liability recorded of $30.2 million related to these sales.
2021 Integrated Resource Plan. On February 1, 2021, Minnesota Power filed its latest IRP, which was approved by the MPUC in an order dated January 9, 2023. The approved IRP, which reflects a joint agreement reached with various stakeholders, outlines Minnesota Power’s clean-energy transition plans through 2035. These plans include expanding its renewable energy supply, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. As part of these plans, Minnesota Power anticipates adding up to 700 MW of new wind and solar energy resources, and ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably. Minnesota Power is expected to file its next IRP by March 1, 2025.
Minnesota Power has a vision to deliver 100 percent carbon-free energy to customers by 2050, continuing its commitment to climate, customers and communities through its EnergyForward strategy. This vision builds on Minnesota Power’s achievement, in 2020, of now providing 50 percent renewable energy to its customers.
Public Service Commission of Wisconsin. The PSCW has regulatory authority over SWL&P’s retail sales of electricity, natural gas and water, issuances of securities and other matters. The resolution of SWL&P’s 2022 general rate case changed the allowed return on equity to 10.00 percent and maintained an equity ratio of 55.00 percent beginning January 1, 2023. (See 2022 Wisconsin General Rate Case.) SWL&P’s retail rates through 2022 were based on a December 2018 order by the PSCW that allowed for a return on equity of 10.40 percent and a 55.00 percent equity ratio.
2022 Wisconsin General Rate Case. In 2022, SWL&P filed a rate increase request with the PSCW seeking an average increase of 3.60 percent for retail customers. The filing sought an overall return on equity of 10.40 percent and a 55.00 percent equity ratio. On an annualized basis, the requested final rate increase would have generated an estimated $4.3 million in additional revenue. In an order dated December 20, 2022, the PSCW approved an annual increase of $3.3 million reflecting a return on equity of 10.00 percent and 55.00 percent equity ratio. Final rates went into effect January 1, 2023.
North Dakota Public Service Commission. The NDPSC has jurisdiction over site and route permitting of generation and transmission facilities in North Dakota.
Federal Energy Regulatory Commission. The FERC has jurisdiction over the licensing of hydroelectric projects, the establishment of rates and charges for transmission of electricity in interstate commerce, electricity sold at wholesale (including the rates for Minnesota Power’s municipal and wholesale customers), natural gas transportation, certain accounting and recordkeeping practices, certain activities of our regulated utilities and the operations of ATC. FERC jurisdiction also includes enforcement of NERC mandatory electric reliability standards. Violations of FERC rules are subject to enforcement action by the FERC including financial penalties up to $1 million per day per violation.
Regional Organizations
Midcontinent Independent System Operator, Inc. Minnesota Power, SWL&P and ATC are members of MISO, a regional transmission organization. While Minnesota Power and SWL&P retain ownership of their respective transmission assets, their transmission networks are under the regional operational control of MISO. Minnesota Power and SWL&P take and provide transmission service under the MISO open access transmission tariff. In cooperation with stakeholders, MISO manages the delivery of electric power across 15 states and the Canadian province of Manitoba.
North American Electric Reliability Corporation. The NERC has been certified by the FERC as the national electric reliability organization. The NERC ensures the reliability of the North American bulk power system. The NERC oversees six regional entities that establish requirements, approved by the FERC, for reliable operation and maintenance of power generation facilities and transmission systems. Minnesota Power is subject to these reliability requirements and can incur significant penalties for noncompliance.
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Regional Organizations (Continued)
Midwest Reliability Organization (MRO). Minnesota Power and ATC are members of the MRO, one of the six regional entities overseen by the NERC. The MRO's primary responsibilities are to: ensure compliance with mandatory reliability standards by entities which own, operate or use the interconnected, international bulk power system; conduct assessments of the grid's ability to meet electricity demand in the region; and analyze regional system events. The MRO region spans the Canadian provinces of Saskatchewan and Manitoba, and all or parts of 16 states.
Minnesota Legislation
Renewable and Carbon-Free Energy Requirements. 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 energy 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. Minnesota Power is also working with various stakeholders and participating in the regulatory process to implement this legislation.
Since 2020, approximately 50 percent of Minnesota Power’s power supply for its retail and municipal customers in Minnesota has been provided by renewable energy sources. Minnesota Power’s plans include expanding its renewable energy supply to 70 percent renewable energy by 2030. Minnesota Power has also set a target to achieve an 80 percent reduction in carbon emissions by 2035 compared to 2005 levels. (See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Outlook - EnergyForward.)
Minnesota Solar Energy Standard. Minnesota law requires at least 1.5 percent of total retail electric sales, excluding sales to certain customers, to be generated by solar energy. At least 10 percent of the 1.5 percent mandate must be met by solar energy generated by or procured from solar photovoltaic devices with a nameplate capacity of 40 kW or less and community solar garden subscriptions. Minnesota Power has met both parts of the solar mandate to date.
Competition
Retail electric energy sales in Minnesota and Wisconsin are made to customers in assigned service territories. As a result, most retail electric customers in Minnesota do not have the ability to choose their electric supplier. Large energy users of 2 MW and above that are located outside of a municipality are allowed to choose a supplier upon MPUC approval. Minnesota Power served eight Large Power Customers under contracts of at least 10 MW in 2023, none of which have engaged in a competitive rate process. (See Electric Sales / Customers.) No other large commercial or small industrial customers in Minnesota Power’s service territory have sought a provider outside Minnesota Power’s service territory. Retail electric and natural gas customers in Wisconsin do not have the ability to choose their energy supplier. In both states, however, electricity may compete with other forms of energy. Customers may also choose to generate their own electricity, or substitute other forms of energy for their manufacturing processes.
In 2023, 4 percent of total regulated utility kWh sales were to municipal customers in Minnesota. These customers have the right to seek an energy supply from any wholesale electric service provider upon contract expiration. Minnesota Power’s wholesale electric contract with the Nashwauk Public Utilities Commission is effective through 2037. Minnesota Power’s wholesale electric contracts with 13 other non-affiliated municipal customers are effective through 2029. (See Electric Sales / Customers.)
The FERC has continued with its efforts to promote a competitive wholesale market through open-access electric transmission and other means. As a result, our electric sales to Other Power Suppliers and our purchases to supply our retail and wholesale load are made in a competitive market.
ALLETE, Inc. 2023 Form 10-K
REGULATED OPERATIONS (Continued)
Franchises
Minnesota Power holds franchises to construct and maintain an electric distribution and transmission system in 95 cities. The remaining cities, villages and towns served by Minnesota Power do not require a franchise to operate. SWL&P serves customers under electric, natural gas or water franchises in 1 city and 14 villages and towns.
ALLETE CLEAN ENERGY
ALLETE Clean Energy focuses on developing, acquiring, and operating clean and renewable energy projects. ALLETE Clean Energy currently owns and operates, in 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 engages in the development of wind energy facilities to operate under long-term PSAs or for sale to others upon completion. (See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Outlook - ALLETE Clean Energy.)
ALLETE Clean Energy believes the market for renewable energy in North America is robust, driven by several factors including environmental regulation, tax incentives such as the extension of production tax credit and investment tax credits, societal expectations and continual technology advances. State renewable portfolio standards, state or federal regulations to limit GHG emissions and the extension of production tax credit and investment tax credits are examples of environmental regulation or public policy that we believe will drive renewable energy development.
ALLETE Clean Energy’s strategy includes the safe, reliable, optimal and profitable operation of its existing facilities. This includes a strong safety culture, the continuous pursuit of operational efficiencies at existing facilities and cost controls. ALLETE Clean Energy generally acquires facilities in liquid power markets and its strategy includes the exploration of PSA extensions upon expiration of existing contracts, production tax credit requalification of existing facilities or the sale of facilities.
ALLETE Clean Energy manages risk by having a diverse portfolio of assets, which includes PSA expiration, technology and geographic diversity. The current operating portfolio is subject to typical variations in seasonal wind with higher wind resources typically available in the winter months. The majority of its planned maintenance leverages this seasonality and is performed during lower wind periods. ALLETE Clean Energy’s current operating portfolio is as follows:
Region Wind Energy Facility Capacity MW MW PSA Expiration
East Armenia Mountain 101
PSA 1 50% 2031
PSA 2 50% 2024
Midwest Lake Benton 104 100% 2028
Storm Lake I 108 100% 2027
Storm Lake II 77
Merchant 90% n/a
PSA 10% 2032
Other 17 100% 2028
South Caddo 303
Merchant 27% n/a
PSA 1 66% 2034
PSA 2 7% 2034
Diamond Spring 303
PSA 1 58% 2035
PSA 2 25% 2032
PSA 3 16% 2035
West Condon 50 100% 2028
Glen Ullin 106 100% 2039
South Peak 80 100% 2035
The majority of ALLETE Clean Energy’s wind operations are located on real property owned by others with easement rights or necessary consents of governmental authorities. One of ALLETE Clean Energy’s wind energy facilities is encumbered by liens against its assets securing financing. ALLETE Clean Energy’s Glen Ullin, South Peak, Diamond Spring and Caddo wind energy facilities are subject to tax equity financing structures. (See Note 1. Operations and Significant Accounting Policies.)
ALLETE, Inc. 2023 Form 10-K
CORPORATE AND OTHER
New Energy
In April 2022, a wholly-owned subsidiary of ALLETE acquired 100 percent of the membership interests of New Energy for a purchase price of $165.5 million. New Energy, which is headquartered in Annapolis, Maryland, is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. New Energy is a leading developer of community, commercial and industrial, and small utility-scale renewable energy projects that has completed more than 500 MW in its history, totaling more than $1.2 billion of capital. New Energy currently has a robust project pipeline with greater than 2,000 MW of renewable projects in development across over 20 different states. New Energy is involved in greenfield development as well as acquiring and completing mid-stage and late-stage renewable energy projects. New Energy will continue its current strategy of developing and operating renewable energy projects.
Investment in Nobles 2
Our subsidiary, ALLETE South Wind, owns a 49 percent equity interest in 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. As of December 31, 2023, our equity investment in Nobles 2 was $151.5 million ($157.3 million at December 31, 2022). (See Note 6. Equity Investments.)
South Shore Energy
South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary, is developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting in 2028 pursuant to a capacity dedication agreement. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $700 million, of which South Shore Energy will be responsible for approximately 20 percent. South Shore Energy’s portion of NTEC project costs incurred through December 31, 2023, is approximately $9 million.
BNI Energy
BNI Energy is a supplier of lignite coal in North Dakota, producing approximately 4 million tons annually and has an estimated 650 million tons of lignite coal reserves. Two electric generating cooperatives, Minnkota Power and Square Butte, consume virtually all of BNI Energy’s production of lignite under cost-plus fixed fee coal supply agreements extending through December 31, 2037. (See Item 1. Business - Regulated Operations - Power Supply - Long-Term Purchased Power and Note 9. Commitments, Guarantees and Contingencies.) The mining process disturbs and reclaims between 200 and 250 acres per year. Laws require that the reclaimed land be at least as productive as it was prior to mining. As of December 31, 2023, BNI Energy’s total reclamation liability is estimated at $82.1 million, which is included in Other Non-Current Liabilities on the Consolidated Balance Sheet at its present value. These costs are included in the cost-plus fixed fee contract, for which an asset reclamation cost receivable was included in Other Non-Current Assets on the Consolidated Balance Sheet. The asset reclamation obligation is guaranteed by surety bonds and a letter of credit. (See Note 9. Commitments, Guarantees and Contingencies.)
ALLETE Properties
ALLETE Properties represents our legacy Florida real estate investment. ALLETE Properties’ major project in Florida is Town Center at Palm Coast, which consists of approximately 200 acres of land as well as various residential units and non-residential square footage. In addition to the Town Center at Palm Coast project, ALLETE Properties has approximately 500 acres of other land available for sale. (See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Outlook - Corporate and Other - ALLETE Properties.)
Seller Financing. ALLETE Properties occasionally provides seller financing to qualified buyers. As of December 31, 2023, outstanding finance receivables were $2.9 million, net of reserves, with maturities through 2027. These finance receivables accrue interest at market-based rates and are collateralized by the financed properties.
ALLETE, Inc. 2023 Form 10-K
CORPORATE AND OTHER (Continued)
ALLETE Properties (Continued)
Regulation. A substantial portion of our development properties in Florida are subject to federal, state and local regulations, and restrictions that may impose significant costs or limitations on our ability to develop the properties. Much of our property is vacant land and some is located in areas where development may affect the natural habitats of various protected wildlife species or in sensitive environmental areas such as wetlands.
Non-Rate Base Generation and Miscellaneous
Corporate and Other also includes 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.
As of December 31, 2023, non-rate base generation consists of 29 MW of natural gas and hydro generation at Rapids Energy Center in Grand Rapids, Minnesota, which is primarily dedicated to the needs of one customer, UPM Blandin, and approximately 20 MW of solar energy facilities located in Sylvan, Hoyt Lakes, and Duluth, Minnesota, which sell energy generated to Minnesota Power.
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. (See Note 9. Commitments, Guarantees and Contingencies.)
HUMAN CAPITAL MANAGEMENT
The Company’s key human capital management objectives are to attract, recognize and retain high quality talent, align with strategic business objectives and support the Company’s values. To support these objectives, the Company’s programs are designed to develop talent; reward and support employees through competitive compensation programs and benefit plans; enhance the Company’s culture through efforts aimed at making the workplace more engaging, safe and inclusive; and acquire talent and leverage internal opportunities to create a high-performing, diverse workforce. Our management, the ALLETE Board of Directors Executive Compensation and Human Capital Committee, and our Board of Directors as a whole play key roles in reviewing and overseeing our human capital practices.
As of December 31, 2023, ALLETE had 1,560 employees, of which 1,513 were full-time. We also respect employees’ freedom of association and their right to collectively organize. As of December 31, 2023, Minnesota Power and SWL&P have an aggregate of 479 employees covered under collective bargaining agreements, of which most are members of the 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 129 employees that are members of IBEW Local 1593. The current labor agreement with IBEW Local 1593 expires on March 31, 2026.
ALLETE, Inc. 2023 Form 10-K
HUMAN CAPITAL MANAGEMENT (Continued)
ALLETE’s Human Rights Policy confirms our commitment to the advancement and protection of human rights, consistent with U.S. human rights laws and the general principles in the International Labour Organization Convention.
Integrity. Integrity is a foundational, shared value at ALLETE, is important to ALLETE’s business and operations, and enables our success. The Company has a written Code of Business Conduct that applies to all of our employees, directors of ALLETE, contractors, vendors, and others who do business with or on behalf of ALLETE.
Health and Safety. The success of our business is fundamentally connected to the well-being of our people. Our journey to zero injury starts with a culture that is open and transparent. We encourage all employees to report injuries, near misses, and good catches, so that we can learn and share with others throughout the Company in an effort to improve safety performance. Leaders have regular safety conversations with employees, where hazard identification and controls are discussed to ensure work is being performed safely. To monitor progress, the Company uses leading and lagging indicators to analyze injury trends, safety participation and other data, such as data from our Company-wide safety perception survey to make better decision on safety practices.
Talent Attraction, Retention and Development. For more than a century, ALLETE has been successful because of our ability to attract and retain high-quality people who demonstrate our shared values. We engage in workforce planning, and succession planning, while building a robust talent pipeline and monitoring turnover.
We recognize and support the growth and development of our employees and offer opportunities to participate in internal and external learning programs. Our internal talent development programs provide employees with the resources they need to develop proficiency in their role, help achieve their career goals and build leadership skills. We are focusing initiatives on programs to expand the diversity of new hires and updating on-the-job trainings-including apprenticeships and scholarships aimed at bridging opportunity gaps-as we recognize the importance of a strong talent pipeline. In addition to role specific training, targeted training also includes respect in the workplace, cyber awareness, safety, integrity and leadership development.
Compensation and Benefits. Our competitive compensation package gives employees flexibility, choices and opportunities. Competitive compensation is important for the Company to attract and retain a qualified workforce to successfully manage our business and achieve our business objectives. We also strive to ensure pay equity among diverse employees performing equal or substantially similar work. Periodically, we review the median pay of our male and female employees as well as employees from diverse backgrounds.
Diversity, Equity and Inclusion. Increasing diversity enriches our workforce culture at ALLETE. Our employees are operating in an increasingly diverse society. In order to be accountable to our employees and stakeholders, we strive to have a workforce that reflects the diversity of the communities we serve, promotes inclusivity and is equitable.
At ALLETE, we want to ensure that we have a workplace culture where we treat each other with fairness, dignity and respect. The Company has a respect in the workplace initiative, which includes education as well as ongoing discussions focused on building respectful relationships and managing bias. We continue our efforts in crafting a framework to strengthen ALLETE’s diversity, equity and inclusion efforts in the areas of: workforce, supply chain, communications, customers, and ALLETE as a community citizen. ALLETE continues to take tangible steps toward advancing diversity, equity and inclusion by continuing to raise awareness, furthering intentional external relationships/partnerships, increasing supplier diversity, focus on underrepresented groups through grants/scholarships and other Company and employee giving.
Yellow Ribbon Program. ALLETE and its subsidiaries are dedicated to supporting veterans, military members and their families. An employee effort grew out of that spirit of commitment to veterans and led the state of Minnesota to designate ALLETE/Minnesota Power and ALLETE Clean Energy as Yellow Ribbon Companies. The mission of ALLETE’s Yellow Ribbon Program is to contribute to the Company’s unique culture by proactively recruiting and retaining the best and supporting an environment in which military-connected employees can thrive.
AVAILABILITY OF INFORMATION
ALLETE makes its SEC filings, including its annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and any amendments to those reports filed or furnished pursuant to Section 13(e) or 15(d) of the Securities Exchange Act of 1934, available free of charge on ALLETE’s website, www.allete.com, as soon as reasonably practicable after they are electronically filed with or furnished to the SEC.
ALLETE, Inc. 2023 Form 10-K
INFORMATION ABOUT OUR EXECUTIVE OFFICERS
As of February 20, 2024, these are the executive officers of ALLETE:
Executive Officers Initial Effective Date
Bethany M. Owen, Age 58
Chair, President and Chief Executive Officer May 11, 2021
President and Chief Executive Officer February 3, 2020
President January 31, 2019
Senior Vice President and Chief Legal and Administrative Officer November 26, 2016
Patrick L. Cutshall, Age 58
Vice President and Corporate Treasurer December 18, 2017
Nicole R. Johnson, Age 49
Vice President and President of ALLETE Clean Energy August 22, 2022
Vice President and Chief Administrative Officer June 28, 2019
Steven W. Morris, Age 62
Senior Vice President and Chief Financial Officer February 9, 2022
Vice President and Chief Accounting Officer October 28, 2021
Vice President, Controller and Chief Accounting Officer December 24, 2016
Joshua J. Skelton, Age 44
Vice President and Chief Operating Officer of Minnesota Power August 22, 2022
Margaret A. Thickens, Age 57
Vice President, Chief Legal Officer and Corporate Secretary February 13, 2019
All of the executive officers have been employed by us for more than five years in executive or management positions. Prior to election to the position listed above, the following executives held other positions with the Company during the past five years.
Ms. Johnson was Vice President - Human Resources.
Mr. Skelton was Chief Operating Officer of Minnesota Power, Vice President Generation Operations and ALLETE Safety.
There are no family relationships between any of the executive officers. All officers and directors are elected or appointed annually.
The present term of office of the executive officers listed in the preceding table extends to the first meeting of our Board of Directors after the next annual meeting of shareholders. Both meetings are scheduled for May 14, 2024.
ALLETE, Inc. 2023 Form 10-K

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ITEM 1A. RISK FACTORS
Item 1A. Risk Factors
The risks and uncertainties discussed below could materially affect our business operations, financial position, results of operations and cash flows, and should be carefully considered by stakeholders. The risks and uncertainties in this section are not the only ones we face; additional risks and uncertainties that we are not presently aware of, or that we currently consider immaterial, may also affect our business operations, financial position, results of operations and cash flows. Accordingly, the risks described below should be carefully considered together with other information set forth in this report and in future reports that we file with the SEC.
Regulated Operations Risks
Our results of operations could be negatively impacted if our taconite, paper and pipeline customers experience an economic downturn, incur work stoppages, fail to compete effectively, experience decreased demand, fail to economically obtain raw materials, fail to renew or obtain necessary permits, or experience a decline in prices for their product.
Minnesota Power’s Large Power Customers (see Item 1. Business - Regulated Operations - Electric Sales / Customers) and Silver Bay Power accounted for 24 percent of our 2023 consolidated operating revenue (29 percent in 2022 and 32 percent in 2021) and 36 percent of Regulated Operations operating revenue (36 percent in 2022 and 37 percent in 2021). Minnesota Power’s taconite customers, which are currently owned by only two entities at the end of 2023, accounted for approximately 21 percent of consolidated operating revenue and 32 percent of Regulated Operations operating revenue in 2023. This concentrated ownership presents customer concentration risk for the Company, and could lead to further capacity consolidation for both steel blast furnaces and related Minnesota iron ore production. These customers are also involved in cyclical industries that by their nature are adversely impacted by economic downturns and are subject to strong competition in the marketplace. The North American paper and pulp industry also faces declining demand due to the impact of electronic substitution for print and changing customer needs. As a result, certain paper and pulp customers have reduced their existing operations or idled facilities in recent years and have pursued or are pursuing product changes in response to declining demand. Additionally, the taconite industry could be impacted by changing technology in the steel industry such as the adoption of electric arc furnaces for steelmaking, which could result in declining demand for taconite and the electricity used during its production.
Minnesota Power also serves two pipeline customers that accounted for 2 percent of our 2023 consolidated operating revenue (2 percent in 2022 and in 2021) and 3 percent of Regulated Operations revenue in 2023 (2 percent in 2022 and 2021). These customers are involved in an industry that is seeing increased environmental pressure for construction of new or expanded pipeline infrastructure for the transportation of fossil fuels. Changes in regulatory rulings or permit proceedings could result in changes to operations of the pipeline network in our service territory.
Accordingly, if our industrial customers experience an economic downturn, incur a work stoppage (including strikes, lock-outs or other events), fail to compete effectively, experience decreased demand, fail to economically obtain raw materials or operate their facilities, fail to renew or obtain necessary permits, or experience a decline in demand or prices for their product, there could be adverse effects on their operations and, consequently, this could have a negative impact on our results of operations as we are unable to remarket at similar prices the energy that would otherwise have been sold to such customers.
We may not be able to successfully implement our strategic objectives of growing load at our utilities if current or potential industrial or municipal customers are unable to successfully implement expansion plans, including the inability to obtain necessary governmental permits and approvals.
As part of our long-term strategy, we pursue new wholesale and retail loads in and around our service territories. Currently, there are several companies in northeastern Minnesota that are in the process of developing natural resource-based projects that represent long-term growth potential and load diversity for our Regulated Operations businesses. These projects may include construction of new facilities and restarts of old facilities, both of which require permitting and approvals to be obtained before the projects can be successfully implemented. If a project does not obtain any necessary governmental (including environmental) permits and approvals or if these customers are unable to successfully implement expansion plans, our long-term strategy and thus our results of operations could be adversely impacted.
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
Regulated Operations Risks (Continued)
Our businesses, investments and customers are subject to an extensive legal and regulatory framework under federal and state laws as well as regulations imposed by other organizations that may have a negative impact on our business and results of operations.
Our businesses, investments and customers are subject to an extensive legal and regulatory framework imposed under federal and state law including regulations administered by the FERC, MPUC, MPCA, PSCW, NDPSC and EPA as well as regulations administered by other organizations including the NERC. These laws and regulations relate to allowed rates of return, capital structure, financings, rate and cost structure, acquisition and disposal of assets and facilities, construction and operation of generation, transmission and distribution facilities (including the ongoing maintenance and reliable operation of such facilities), recovery of purchased power costs and capital investments, approval of integrated resource plans and present or prospective wholesale and retail competition, renewable portfolio standards that require utilities to obtain specified percentages of electric supply from eligible renewable generation sources, among other things. Energy policy initiatives at the state or federal level could increase or accelerate renewable and carbon-free energy standards or incentives for distributed generation, municipal utility ownership, or local initiatives could introduce generation or distribution requirements that could change the current integrated utility model. (See Item 1. Business - Regulated Operations - Minnesota Legislation.) Our transmission systems and electric generation facilities are subject to the NERC mandatory reliability standards, including cybersecurity standards. Compliance with these standards may lead to increased operating costs and capital expenditures which are subject to regulatory approval for recovery. If it was determined that we were not in compliance with these mandatory reliability standards or other statutes, rules and orders, we could incur substantial monetary penalties and other sanctions, which could adversely affect our results of operations.
These laws and regulations significantly influence our operations and may affect our ability to recover costs from our customers. We are required to have numerous permits, licenses, approvals and certificates from the agencies and other organizations that regulate our business. We believe we have obtained the necessary permits, licenses, approvals and certificates for our existing operations and that our business is conducted in accordance with applicable laws; however, we are unable to predict the impact on our operating results from the future regulatory activities of any of these agencies and other organizations. Changes in regulations, timing of approvals, the adoption of new regulations or the expansion of jurisdiction by these agencies and other organizations could have an adverse impact on our business and results of operations. In addition, our ability to manage changing regulations could be impacted by our rights and obligations under joint ownership agreements.
Our ability to obtain rate adjustments to maintain reasonable rates of return depends upon regulatory action under applicable statutes and regulations, and we cannot provide assurance that rate adjustments will be obtained or reasonable authorized rates of return on capital will be earned. Minnesota Power and SWL&P, from time to time, file general rate cases with, or otherwise seek cost recovery authorization from, federal and state regulatory authorities. If Minnesota Power and SWL&P do not receive an adequate amount of rate relief in general rate cases, including if rates are reduced, if increased rates are not approved or recovered on a timely basis, if fuel adjustment clause recoveries or cost recovery for other items are not granted at the requested level, or costs are otherwise unable to be recovered through rates, we may experience an adverse impact on our financial position, results of operations and cash flows. We are unable to predict the impact on our business and results of operations from future legislation or regulatory activities of any of these agencies or organizations.
Our regulated operations present certain environmental risks that could adversely affect our financial position and results of operations, including effects of environmental laws and regulations, physical risks associated with climate change and initiatives designed to reduce the impact of GHG emissions.
We are subject to extensive environmental laws and regulations affecting many aspects of our past, present and future operations, including air quality, water quality and usage, waste management, reclamation, hazardous wastes, avian mortality and natural resources. These laws and regulations, or new laws and regulations that may be passed, can result in increased capital expenditures and increased operating and other costs as a result of compliance, remediation, containment and monitoring obligations, particularly with regard to laws relating to emissions, coal ash and water discharge at generating facilities.
These laws and regulations could restrict the output of some existing facilities, limit the use of some fuels in the production of electricity, require the installation of additional pollution control equipment, require participation in environmental emission allowance trading, and lead to other environmental considerations and costs, which could have an adverse impact on our business, operations and results of operations.
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
Regulated Operations Risks (Continued)
These laws and regulations generally require us to obtain and comply with a wide variety of environmental licenses, permits, inspections and other approvals. Violations of these laws and regulations could expose us to regulatory and legal proceedings, disputes with, and legal challenges by, governmental authorities and private parties, as well as potential significant civil fines criminal penalties and other sanctions.
Existing environmental regulations may be revised and new environmental regulations may be adopted or become applicable to us. Revised or additional regulations which result in increased compliance costs or additional operating restrictions, particularly if those costs are not fully recoverable from customers, could have an adverse effect on our results of operations.
There is significant uncertainty regarding if and when new laws, regulations or administrative policies will be adopted to reduce or limit GHG and the impact any such laws or regulations would have on us. In 2023, our operating coal-fired generating facilities consisted of the 352 MW Boswell Unit 3 and the 468 MW Boswell Unit 4. (See Item 7. Management Discussion and Analysis of Financial Condition and Results of Operation - Outlook - EnergyForward.) Any future limits on GHG emissions at the federal or state level, or action taken by regulators, before these facilities are retired or become coal-free may require us to incur significant capital expenditures and increases in operating costs, or could result in early closure of coal-fired generating facilities, stranded assets, an impairment of assets, denial of full recovery of decommissioning costs in excess of amounts previously collected, or otherwise adversely affect our results of operations, particularly if resulting expenditures and costs are not fully recoverable from customers.
Our regulated operations may be adversely impacted by the physical and financial risks associated with climate change. See Entity-wide Risks for additional discussion of risks related to GHG and climate change.
We cannot predict the amount or timing of all future expenditures related to environmental matters because of uncertainty as to applicable regulations or requirements. There is also uncertainty in quantifying liabilities under environmental laws that impose joint and several liability on all potentially responsible parties. Violations of certain environmental statutes, rules and regulations could expose ALLETE to third party disputes and potentially significant monetary penalties, as well as other sanctions for noncompliance.
The operation and maintenance of our regulated electric generation, transmission and distribution facilities are subject to operational risks that could adversely affect our financial position, results of operations and cash flows.
The operation of generating facilities involves many risks, including start-up operational risks, breakdown or failure of facilities, the dependence on a specific fuel source, inadequate fuel supply, availability of fuel transportation, and the impact of unusual or adverse weather conditions or other natural events, as well as the risk of performance below expected levels of output or efficiency. A significant portion of our facilities contain older generating equipment, which, even if maintained in accordance with good engineering practices, may require significant capital expenditures to continue operating at peak efficiency. Generation, transmission and distribution facilities and equipment are also likely to require periodic upgrades and improvements due to changing environmental standards and technological advances. Our ability to manage and operate certain facilities could also be impacted by our rights and obligations under the joint ownership agreements. We could be subject to costs associated with any unexpected failure to produce or deliver power, including failure caused by breakdown, forced outage or limited availability of fuel or fuel transportation, as well as the repair of damage to facilities due to breakdown, storms, natural disasters, wars, sabotage, terrorist acts and other catastrophic events. This could also lead to requiring additional purchased power to meet requirements of serving our retail load, which for Minnesota Power is subject to recovery under the fuel adjustment clause. Should these costs be denied or are otherwise unable to be recovered, our financial position, results of operations and cash flows could be adversely impacted.
Our ability to successfully and timely complete capital repairs or improvements to existing regulated facilities or in the development of new electric generation and transmission facilities or other capital projects is contingent upon many variables.
We expect to incur significant capital expenditures in making capital repairs or improvements to our existing electric generation and transmission facilities and in the development and construction of new electric generation and transmission facilities. Should any such efforts be unsuccessful, not completed in a timely manner, if we are unable to obtain the necessary permits, land rights and regulatory approvals, or if there are increases in the costs for or limited availability of key materials, supplies, labor and services, we could be subject to additional costs or impairments, and projects may be delayed or canceled which could have an adverse impact on our financial position, results of operation and cash flows.
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
Regulated Operations Risks (Continued)
Our regulated electric operations may not have access to adequate and reliable transmission and distribution facilities necessary to deliver electricity to our customers.
We depend on our own transmission and distribution facilities, as well as facilities owned by other utilities, to deliver the electricity sold to our customers, and to other energy suppliers. If transmission capacity is inadequate or transmission and distribution facilities we rely on are damaged, our ability to sell and deliver electricity may be limited. We may have to forgo sales or may have to buy more expensive wholesale electricity that is available in a capacity-constrained area. The ability to restore adequate capacity or repair damaged infrastructure may be impacted by the availability of key materials, supplies, labor and services, which if unavailable may prolong the impact of capacity constraints or damaged facilities. In addition, any infrastructure failure or damage that interrupts or impairs delivery of electricity to our customers could negatively impact the satisfaction of our customers, which could have an adverse impact on our business and results of operations.
The price of electricity may be volatile and fuel may be volatile and availability may be limited.
Volatility in market prices for electricity and volatility and limited availability of fuel could adversely impact our financial position and results of operations and may result from:
•severe or unexpected weather conditions and natural disasters;
•seasonality;
•changes in electricity usage;
•transmission or transportation constraints, inoperability or inefficiencies;
•availability of competitively priced alternative energy sources;
•changes in supply and demand for energy;
•changes in power production capacity;
•outages at our generating facilities or those of our competitors;
•availability of fuel and transportation of fuel;
•changes in production and storage levels of natural gas, lignite, coal, crude oil and refined products;
•wars, sabotage, terrorist acts, cybersecurity attacks or other catastrophic events; and
•federal, state, local and foreign energy, environmental, or other regulation and legislation.
Volatility in market prices for our fuel and purchase power costs impacts our sales to retail, municipal and Other Power Suppliers. Fluctuations in our fuel and purchased power costs related to our retail and municipal customers are passed on to customers through the fuel adjustment clause; however, our results of operations and cash flows may be adversely impacted if increased fuel adjustment clause rates are not approved or recovered on a timely basis, if cost recovery is not granted at the requested level, or costs are otherwise unable to be recovered through the fuel adjustment clause.
Wholesale prices for electricity have also declined in recent years primarily due to the extension of renewable tax credits and additional renewable generation commencing operations. If there are reductions in demand from current customers, we lose retail customers, or we lose municipal customers that do not renew existing contracts, we will market any available power to Other Power Suppliers in an effort to mitigate any earnings impact. Sales to Other Power Suppliers are sold at market-based prices into the MISO market on a daily basis or through bilateral agreements of various durations. Due to wholesale prices for electricity being below our rates for retail and municipal customers, we do not expect that our power marketing efforts would fully offset the reduction in earnings resulting from the lower demand from existing customers or the loss of customers. (See Item 1. Business - Regulated Operations - Electric Sales / Customers.)
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
Regulated Operations Risks (Continued)
Demand for energy may decrease.
Our results of operations are impacted by the demand for energy in our service territories, our municipal customers and other power suppliers. There could be lower demand for energy due to a loss of customers as a result of economic conditions, customers constructing or installing their own generation facilities, higher costs and rates charged to customers, eligible municipal and other power suppliers choosing an alternative energy provider, or loss of service territory or franchises. Further, energy conservation and technological advances that increased energy efficiency may temporarily or permanently reduce the demand for energy products. In addition, we are impacted by state and federal regulations requiring mandatory conservation measures, which reduce the demand for energy products. Continuing technology improvements and regulatory developments may make customer and third party-owned generation technologies such as rooftop solar systems, WTGs, microturbines and battery storage systems more cost effective and feasible for certain customers. If customers utilize their own generation, demand for energy from us would decline. There may not be future economic growth opportunities that would enable us to replace the lost energy demand from these customers. Therefore, a decrease in demand for energy could adversely impact our financial position, results of operations and cash flows.
ALLETE Clean Energy / Corporate and Other Risks
The inability to successfully manage and grow our businesses could adversely affect our results of operations.
The Company's strategy includes adding customers, new geographies, and growth through acquisitions or project development with long-term PSAs in place for the output or to be sold upon completion. This strategy depends, in part, on the Company’s ability to successfully identify and evaluate acquisition or development opportunities and consummate acquisitions on acceptable terms and obtain all required permits and approvals. The Company may compete with other companies for these acquisition and development opportunities, which may increase the Company’s cost of making acquisitions and the Company may be unsuccessful in pursuing these acquisition opportunities. Other companies may be able to pay more for acquisitions and may be able to identify, evaluate, bid for and purchase a greater number of assets than the Company’s financial or human resources permit. New laws and regulations promoting renewable energy generation may result in increased competition. Our ALLETE Clean Energy business is experiencing return pressures from increased competition, and lower forward price curves, as a growing amount of investment capital is being directed into wind energy generation opportunities. In addition, current and potential new project developments at our businesses can be negatively affected by a lower ALLETE stock price, which may result in such projects not being accretive, or otherwise unable to satisfy our financial objectives criteria to proceed. Additionally, tax law changes may adversely impact the economic characteristics of potential acquisitions or investments. If the Company is unable to execute its strategy of growth through acquisitions, project development for others, or the addition of new customers and geographies, it may impede our long-term objectives and business strategy.
Acquisitions and operations of recently acquired entities are subject to uncertainties. If we are unable to successfully integrate and manage New Energy, or future acquisitions and strategic investments, this could have an adverse impact on our results of operations. Our actual results may also differ from our expectations due to factors such as the ability to obtain timely regulatory or governmental approvals, integration and operational issues and the ability to retain management and other key personnel.
Our results of operations could be adversely affected by changes in governmental incentives or policies that support renewable energy or changes in taxes, tariffs, duties or other assessments on renewable energy or the equipment necessary to generate and deliver it.
Any reductions or modifications to, or the elimination of, governmental incentives or policies that support renewable energy, or the imposition of additional or increased sourcing of components subject to taxes, tariffs, duties or other assessments on renewable energy or the equipment necessary to generate and deliver it, could result in, among other items, the lack of a satisfactory market for the development or financing of new renewable energy projects and reduced project returns on current or future projects.
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
ALLETE Clean Energy / Corporate and Other Risks (Continued)
The U.S. government currently imposes anti-dumping and countervailing duties on certain imported photovoltaic (PV) cells and modules from China and Taiwan. Such duties can change over time pursuant to annual reviews conducted by the U.S. Department of Commerce (DOC). On August 18, 2023, the U.S. DOC issued a final affirmative determination that imports of certain PV cells and modules assembled and completed in Cambodia, Malaysia, Thailand, and Vietnam are circumventing anti-dumping and countervailing duties. Duties will not be collected on imports before June 2024 as a result of a temporary duty suspension ordered by the U.S. President. Our operating results could be adversely impacted if this U.S. DOC circumvention determination results in duties assessed on future purchases made by our businesses after the current moratorium ends, or if additional anti-dumping and countervailing duties are imposed by the U.S. government on products purchased by our businesses.
The generation of electricity from wind and solar energy facilities depends heavily on suitable meteorological conditions.
Although our electric generation facilities are located in diverse geographic regions to reduce the potential impact that may be caused by unfavorable weather in a particular region, suitable meteorological conditions are variable and difficult to predict. If wind or solar conditions are unfavorable or meteorological conditions are unsuitable, electricity generation and revenue from wind and solar energy facilities may be substantially below our expectations. The electricity produced, production tax credits received, and revenues generated by a wind or solar energy facility are highly dependent on suitable wind conditions and associated weather conditions, which are variable and beyond our control. We base our decisions about which wind and solar projects to build or acquire as well as our electricity generation estimates, in part, on the findings of long-term wind and other meteorological studies conducted on the project site and its region; however, the unpredictable nature of wind and solar conditions, weather and meteorological conditions can result in material deviations from these studies and our expectations. Furthermore, components of our systems could be damaged by severe weather, such as hailstorms, lightning or tornadoes. In addition, replacement and spare parts for key components may be difficult or costly to acquire or may be unavailable. Unfavorable wind and solar conditions, weather or changes to meteorological patterns could impair the effectiveness of our electric generation facility assets, reduce their output beneath their rated capacity or require shutdown of key equipment, impeding operation of our wind energy facilities or lead to an impairment of assets.
The construction, operation and maintenance of our electric generation facilities or investment in facilities are subject to operational risks that could adversely affect our financial position, results of operations and cash flows.
The construction and operation of generating facilities involves many risks, including the performance by key contracted suppliers and maintenance providers; increases in the costs for or limited availability of key materials, supplies, labor and services; start-up operations risks; breakdown or failure of facilities; curtailment of facilities by counterparties or due to inadequate transmission capacity; the dependence on the availability of wind resources; or the impact of unusual, adverse weather conditions or other natural events, as well as the risk of performance below expected levels of output or efficiency. Some of our facilities contain older generating equipment, which even if maintained in accordance with good engineering practices, may require significant capital expenditures to continue operating at peak efficiency. We could be subject to costs associated with any unexpected failure to produce and deliver power, including failure caused by breakdown or forced outage, as well as the repair of damage to facilities due to storms, natural disasters, wars, sabotage, terrorist acts and other catastrophic events.
The price of electricity may be volatile, which may impact results of operations at ALLETE Clean Energy wind energy facilities under contracts with commercial and industrial (C&I) customers.
Unusual, adverse weather conditions or other natural events and different settlement prices between hub and node can cause volatility in market prices for electricity and adversely affect our financial position, results of operations and cash flows. ALLETE Clean Energy’s power sales agreements with C&I customers at its Diamond Spring and Caddo wind energy facilities are contracts for differences where power is delivered to the market, a fixed price is paid by the customers to ALLETE Clean Energy, and differences between the market price and the fixed price are paid to or received from the customers. Certain contracts also settle with the market at the hub price whereas ALLETE Clean Energy settles with the customer at the node price which can vary significantly based on multiple factors. These settlement provisions can result in an adverse impact on our financial position, results of operations and cash flows when market prices are volatile, or lead to potential impairment of property, plant and equipment if these conditions persist for an extended period of time.
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
ALLETE Clean Energy / Corporate and Other Risks (Continued)
As contracts with counterparties expire, we may not be able to replace them with agreements on similar terms or divest the related assets at a profit.
ALLETE Clean Energy is party to PSAs that expire in various years between 2024 and 2039. These PSA expirations are prior to the end of the estimated useful lives of the respective wind energy facilities. If, for any reason, ALLETE Clean Energy is unable to enter into new agreements with existing or new counterparties on similar terms once the current agreements expire, sell energy in the wholesale market resulting in similar revenue, or enter into a contract to sell the facility at a profit, our financial position, results of operations and cash flows could be adversely affected, which includes potential impairment of property, plant and equipment.
Counterparties to turbine and other generation supply, service and maintenance, or power sale agreements may not fulfill their obligations.
Our businesses are party to turbine and other generation supply agreements, service and maintenance agreements, and PSAs under various durations with a limited number of creditworthy counterparties. If, for any reason, any of the counterparties under these agreements do not fulfill their related contractual obligations, and we are unable to mitigate non-performance by a key supplier or maintenance provider or remarket PSA energy resulting in similar revenue, our financial position, results of operations and cash flows could be adversely affected.
ALLETE has a significant amount of goodwill. A determination that goodwill has been impaired could result in a significant non-cash charge to earnings.
We had approximately $155 million of goodwill recorded on our Consolidated Balance Sheet as of December 31, 2023, related to New Energy. If we change our business strategy, fail to deliver on our projected results or if market or other conditions adversely affect the operations of New Energy, we may be required to record an impairment charge. Declines in projected operating cash flows at New Energy could also result in an impairment charge. An impairment charge would result in a non-cash charge to earnings that could have an adverse effect on our results of operations.
BNI Energy may be adversely impacted by its exposure to customer concentration, and environmental laws and regulations.
BNI Energy sells lignite coal to two electric generating cooperatives, Minnkota Power and Square Butte, and could be adversely impacted if these customers were unable or unwilling to fulfill their related contractual obligations, or change the way in which they operate their generating facilities. In addition, BNI Energy and its customers may be adversely impacted by existing or new environmental laws and regulations which could have an adverse effect on our financial position, results of operations and cash flows. In addition, insurance companies have decreased the available coverage for policy holders in the mining industry, impacting the availability of coverage, and leading to higher deductibles and premiums.
Real estate market conditions where our legacy Florida real estate investment is located may deteriorate.
The Company’s strategy related to the real estate assets of ALLETE Properties incorporates the possibility of a bulk sale of its entire portfolio, in addition to sales over time, however, adverse market conditions could impact the timing of land sales, which could result in little to no sales, while still incurring operating expenses such as community development district assessments and property taxes, resulting in net operating losses at ALLETE Properties. Furthermore, weak market conditions could put the properties at risk for an impairment charge. An impairment charge would result in a non-cash charge to earnings that could have an adverse effect on our results of operations.
Entity-wide Risks
We could be materially adversely affected by health epidemics, pandemics and other outbreaks.
Health epidemics, pandemics and other outbreaks, as well as the related federal and state government responses, can have widespread impacts on the economy and on our employees, customers, contractors and suppliers, such as those experienced from the COVID-19 pandemic. There may be uncertainty regarding the length of time an epidemic, pandemic or other outbreak will last, how they will evolve, or the extent and duration of any measures attempted to try and contain them.
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
Entity-wide Risks (Continued)
A disruption of economic activity or an extended disruption of economic activity may lead to adverse impacts on our taconite, paper, pulp and secondary wood products, and pipeline customers’ operations including reduced production or the temporary idling or indefinite shutdown of facilities, which would result in lower sales and revenue from these customers. A disruption in capital markets could lead to increased borrowing costs or adversely impact our ability to access capital markets or other financing sources, which would adversely affect our ability to maintain our businesses or to implement our business plans. An epidemic, pandemic or other outbreak may also result in a disruption to our supply chains which could adversely impact our operations and capital projects resulting in project and operational delays, project cancellations, lower returns on projects and cost increases.
Despite any efforts made to mitigate the impacts on the Company of an epidemic, pandemic or other outbreak, their ultimate impact also depends on factors beyond our control, including their duration and severity as well as governmental and third-party actions taken to contain their spread and mitigate their public health effects. As a result, we cannot predict the ultimate impact of an epidemic, pandemic or other outbreak, such as the ongoing COVID-19 pandemic and whether it will have a material impact on our liquidity, financial position, results of operations and cash flows.
We rely on access to financing sources and capital markets. If we do not have access to capital on acceptable terms or are unable to obtain capital when needed, our ability to execute our business plans, make capital expenditures or pursue other strategic actions that we may otherwise rely on for future growth would be adversely affected.
We rely on access to financing sources and the capital markets, on acceptable terms and at reasonable costs, as sources of liquidity for capital requirements not satisfied by our cash flows from operations. Rising interest rates, inflation and market disruptions or a downgrade of our credit ratings may increase the cost of borrowing or adversely affect our ability to access and finance in the capital markets or to access other financing sources such as tax equity financing. Such disruptions or causes of a downgrade could include but are not limited to: weakening of the Company’s cash flow metrics; a loss of, or a reduction in sales to, our taconite, paper and pipeline customers if we are unable to offset the related lost margins; weaker operating performance; adverse regulatory outcomes; disproportionate increase in the contribution to net income from ALLETE Clean Energy and our Corporate and Other businesses as compared to that from our Regulated Operations; deteriorating economic or capital market conditions; or volatility in commodity prices.
If we are not able to access capital on acceptable terms in sufficient amounts and when needed, or at all, the ability to maintain our businesses or to implement our business plans would be adversely affected. This would include our ability to make the significant capital expenditures planned in order to achieve Minnesota Power’s clean-energy transition plans. (See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Capital Requirements.)
A deterioration in general economic conditions, an inflationary environment or supply chain disruptions may have adverse impacts on our financial position, results of operations and cash flows.
If economic conditions deteriorate, we experience an inflationary environment or supply chains are disrupted on a national, regional or global level, it may have a negative impact on our customers and the Company’s financial position, results of operations and cash flows. This impact may include volatility and unpredictability in the demand for the products and services offered by our businesses, the loss of existing customers, tempered growth strategies, customer production cutbacks, customer bankruptcies and increases in costs for or limited availability of key materials, supplies, labor and services for our operations and capital projects. An uncertain economy could also adversely affect expenses including pension costs, interest costs, and uncollectible accounts, or lead to reductions in the value of certain real estate and other investments.
Our utility infrastructure and generating facilities, ongoing and future capital and development projects, and other operations require components, supplies, materials, labor and services sourced from suppliers or providers who, in turn, may source components from their suppliers. A shortage of key components, supplies, materials, labor or services in which an alternative supplier or provider is not identified could significantly impact project plans or our operations. Such impacts could include project delays, including potential for project cancellation, lower project returns, increased costs or the inability to provide service to customers, which could adversely impact our results of operations, financial condition or cash flows.
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
Entity-wide Risks (Continued)
Our businesses, investments and customers are subject to extensive state and federal legislation and regulation, compliance with which could have an adverse effect on our businesses.
Our businesses, investments and customers are subject to, and affected by, extensive state and federal legislation and regulation. If it was determined that our businesses failed to comply with applicable laws and regulations, we could become subject to fines or penalties or be required to implement additional compliance measures or actions, the cost of which could be material. If we are unable to obtain all required permits and approvals for our development projects, it could negatively impact our ability to execute on our EnergyForward strategy. Adoption of new laws, rules, regulations, principles, or practices by federal and state agencies, or changes to or a failure to comply with current laws, rules, regulations, principles, or practices and their interpretations, could have an adverse effect on our financial position, results of operations and cash flows.
The inability to attract and retain a qualified workforce including, but not limited to, executive officers, key employees and employees with specialized skills, could have an adverse effect on our operations.
The success of our business heavily depends on the leadership of our executive officers and key employees to implement our business strategy. The inability to maintain a qualified workforce, including, but not limited to, executive officers, key employees and employees with specialized skills, may negatively affect our ability to service our existing or new customers, or successfully manage our business or achieve our business objectives. Personnel costs may increase due to competitive pressures, inflation or terms of collective bargaining agreements with union employees.
Market performance and other changes could decrease the value of pension and other postretirement benefit plan assets, which may result in significant additional funding requirements and increased annual expenses.
The performance of the capital markets impacts the values of the assets that are held in trust to satisfy future obligations under our pension and other postretirement benefit plans. We have significant obligations to these plans and the trusts hold significant assets. These assets are subject to market fluctuations and will yield uncertain returns, which may fall below our projected rates of return. A decline in the market value of the pension and other postretirement benefit plan assets would increase the funding requirements under our benefit plans if asset returns do not recover. Additionally, our pension and other postretirement benefit plan liabilities are sensitive to changes in interest rates. As interest rates decrease, the liabilities increase, potentially increasing benefit expense and funding requirements. Our pension and other postretirement benefit plan costs are generally recoverable in our electric rates as allowed by our regulators or through our cost-plus fixed fee coal supply agreements at BNI Energy; however, there is no certainty that regulators will continue to allow recovery of these rising costs in the future.
We are exposed to significant reputational risk.
The Company could suffer negative impacts to its reputation as a result of operational incidents, violations of corporate compliance policies, such as our code of business conduct, by employees, directors of ALLETE, contractors, vendors and others who do business with or on behalf of ALLETE, regulatory violations, operations that produce or enable the production of GHG emissions or other events which may result in negative customer perception, increased regulatory oversight, and negative consequences to our credit ratings and ability to access capital, each of which could have an adverse effect on our financial position, results of operations and cash flows.
We are subject to physical and financial risks associated with climate change and other catastrophic events, such as natural disasters and acts of war.
Catastrophic events at or near Company facilities and equipment on which the Company depends upon or that otherwise impact the Company such as fires, wildfires, including the impact to Company facilities and operations or potential liability if caused by Company equipment, earthquakes, explosions, and floods, severe weather, such as ice storms, hailstorms, or tornadoes or similar occurrences, as well as acts of war, could adversely affect the Company’s facilities, operations, financial position, results of operations and cash flows. Although the Company has contingency plans and employs crisis management to respond and recover operations in the event of a severe disruption resulting from a catastrophic event, these measures may not be successful. Furthermore, despite these measures, if a catastrophic event were to occur, our financial position, results of operations and cash flows could be adversely affected.
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
Entity-wide Risks (Continued)
The scientific community generally accepts that emissions of GHG are linked to global climate change. Physical risks of climate change, such as more frequent, longer duration or more extreme weather events, changes in temperature and precipitation patterns, increased risk of wildfires, changes to ground and surface water availability, and other related phenomena, could affect some, or all, of our operations. Severe weather or other natural disasters could be destructive, which could result in increased costs or limit the availability of key materials, supplies, labor and services used in our operations or to respond to damaged facilities. An extreme weather event can also directly affect our capital assets, causing disruption in service to customers due to facility outages, downed wires and poles or damage to other operating equipment.
Climate-related risks that could adversely affect our financial position and results of operations include effects of environmental- or economic-based laws, regulations, incentives or initiatives designed to reduce the quantity or impact of GHG emissions, the ability of our regulated businesses to obtain rate adjustments to recover costs and investments to implement clean-energy transition plans, or disruptions to the economy or energy markets caused by climate change. This includes the risk of laws or regulations that create mandates that do not allow for a transition that protects the safety, reliability or affordability of energy for our customers, are implemented before cost-effective technology is developed and regulatory policy is established, or require the electric sector to decarbonize faster than other sectors and ahead of our current vision to deliver 100 percent carbon-free energy to customers by 2050. Additionally, restrictions on land use, wildlife impacts, and other environmental regulations could affect the siting, construction and operation of new or existing generation and transmission facilities needed to transition to lower-carbon generation sources.
These all have the potential to adversely affect our business and operations.
We are vulnerable to acts of terrorism or cybersecurity attacks.
Our operations may be targets of terrorist activities or cybersecurity attacks, which could disrupt our ability to provide utility service at our regulated utilities, develop or operate our renewable energy projects at ALLETE Clean Energy, or operate our other businesses. The impacts may also impair the fulfillment of critical business functions, negatively impact our reputation, subject us to litigation or increased regulation, or compromise sensitive, confidential and other data.
There have been cybersecurity attacks on U.S. energy infrastructure in the past and there may be such attacks in the future. Our generation, transmission and distribution facilities, information technology systems and other infrastructure facilities and systems could be direct targets of, or otherwise be materially adversely affected by such activities. Hacking, computer viruses, terrorism, theft and sabotage could impact our systems and facilities, or those of third parties on which we rely, which may disrupt our operations.
Our businesses require the continued operation of sophisticated custom-developed, purchased, and leased information technology systems and network infrastructure as well as the collection and retention of personally identifiable information of our customers, shareholders and employees. Although we maintain security measures designed to prevent cybersecurity incidents and protect our information technology and control systems, network infrastructure and other assets, our technology systems, or those of third parties on which we rely, may be vulnerable to disability, failures or unauthorized access due to hacking, viruses, acts of war or terrorism as well as other causes. If those technology systems fail or are breached and not recovered in a timely manner, we may be unable to perform critical business functions including effectively maintaining certain internal controls over financial reporting, our reputation may be negatively impacted, we may become subject to litigation or increased regulation, and sensitive, confidential and other data could be compromised. If our business were impacted by terrorist activities or cybersecurity attacks, such impacts could have an adverse effect on our financial position, results of operations and cash flows.
We maintain insurance against some, but not all, of the risks and uncertainties we face.
We maintain insurance against some, but not all, of the risks and uncertainties we face. The occurrence of these risks and uncertainties, if not fully covered by insurance, could have a material effect on our financial position, results of operations and cash flows.
ALLETE, Inc. 2023 Form 10-K
Item 1A. Risk Factors (Continued)
Entity-wide Risks (Continued)
Government challenges to our tax positions, as well as tax law changes and the inherent difficulty in quantifying potential tax effects of our operations and business decisions, could adversely affect our results of operations and liquidity.
We are required to make judgments regarding the potential tax effects of various financial transactions and our ongoing operations in order to estimate our obligations to taxing authorities. The obligations, which include income taxes and taxes other than income taxes, involve complex matters that ultimately could be litigated. We also estimate our ability to use tax benefits, including those in the form of carryforwards and tax credits that are recorded as deferred tax assets on our Consolidated Balance Sheet. A disallowance of some or all of these tax benefits could have an adverse impact on our financial position, results of operations and cash flows.
We are currently utilizing, and plan to utilize in the future, our carryforwards and tax credits to reduce our income tax obligations. If we cannot generate enough taxable income in the future to utilize all of our carryforwards and tax credits before they expire, we may incur adverse charges to earnings.
If federal or state tax authorities deny any deductions or tax credits, negatively change existing tax laws or policies, or fail to extend or renew policies beneficial to the Company, such as those for renewable energy production tax credits, our financial position, results of operations and cash flows may be adversely impacted.
Our business, financial position, results of operations, and cash flows could be materially affected by adverse results of litigation.
We are involved in litigation arising in the normal course of business. Unfavorable resolution of legal or administrative proceedings in which we are involved or other future legal or administrative proceedings may have an adverse effect on our business, financial position, results of operations and cash flows.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
Item 1B. Unresolved Staff Comments
None.
ALLETE, Inc. 2023 Form 10-K

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ITEM 2. PROPERTIES
Item 2. Properties
A discussion of our properties is included in Item 1. Business and is incorporated by reference herein.

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ITEM 3. LEGAL PROCEEDINGS
Item 3. Legal Proceedings
Discussions of material regulatory and environmental proceedings are included in Note 4. Regulatory Matters and Note 9. Commitments, Guarantees and Contingencies, and are incorporated by reference herein.
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.

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ITEM 4. MINE SAFETY DISCLOSURE
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-K.
Part II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Our common stock is listed on the NYSE under the symbol ALE. We have paid dividends, without interruption, on our common stock since 1948. A quarterly dividend of $0.705 per share on our common stock is payable on March 1, 2024, to the shareholders of record on February 15, 2024. The timing and amount of future dividends will depend upon earnings, cash requirements, the financial condition of the Company, applicable government regulations and other factors deemed relevant by the ALLETE Board of Directors. As of February 1, 2024, there were approximately 19,000 common stock shareholders of record.
We do not have a publicly announced stock repurchase program and we did not repurchase any equity securities during the quarter ended December 31, 2023.
ALLETE, Inc. 2023 Form 10-K
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities (Continued)
Performance Graph.
The following graph compares ALLETE’s cumulative Total Shareholder Return on its common stock with the cumulative return of the S&P 500 Index and the Philadelphia Utility Index. The S&P 500 Index is a capitalization-weighted index of 500 stocks designed to measure performance of the broad domestic economy through changes in the aggregate market value of 500 stocks representing all major industries. Because this composite index has a broad industry base, its performance may not closely track that of a composite index comprised solely of electric utilities. The Philadelphia Utility Index is a capitalization-weighted index of 20 utility companies involved in the generation of electricity.
The calculations assume a $100 investment on December 31, 2018, and reinvestment of dividends.
2018 2019 2020 2021 2022 2023
ALLETE $100 $110 $87 $97 $98 $98
S&P 500 Index $100 $131 $156 $200 $164 $207
Philadelphia Utility Index $100 $127 $130 $154 $155 $141
ALLETE, Inc. 2023 Form 10-K

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ITEM 6. SELECTED FINANCIAL DATA
Item 6. [Reserved]

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion should be read in conjunction with our Consolidated Financial Statements and notes to those statements 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-K 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-K under the headings: “Forward-Looking Statements” located on page 7 and “Risk Factors” located in Item 1A. The risks and uncertainties described in this 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.
Overview
Basis of Presentation. We present two reportable segments: Regulated Operations and ALLETE Clean Energy. Our segments were determined in accordance with the guidance on segment reporting. We measure performance of our operations through budgeting and monitoring of contributions to consolidated net income by each business segment.
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 4. 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 Other is 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 December 31, 2023, unless otherwise indicated. All subsidiaries are wholly-owned unless otherwise specifically indicated. References in this report to “we,” “us” and “our” are to ALLETE and its subsidiaries, collectively.
ALLETE, Inc. 2023 Form 10-K
2023 Financial Overview
The following net income discussion summarizes a comparison of the year ended December 31, 2023, to the year ended December 31, 2022.
Net income attributable to ALLETE in 2023 was $247.1 million, or $4.30 per diluted share, compared to $189.3 million, or $3.38 per diluted share, in 2022. 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 9. Commitments, Guarantees and Contingencies.) This increase was partially offset by the impact of unusually low wind resources at ALLETE Clean Energy and warmer winter weather impacting our Regulated Operations in 2023. Earnings per share dilution in 2023 was $0.11 due to additional shares of common stock outstanding in 2023 compared to 2022.
Regulated Operations net income attributable to ALLETE was $147.2 million in 2023, compared to $149.9 million in 2022. Net income at Minnesota Power was lower than 2022 primarily due to higher operating and maintenance, depreciation and interest expenses, and lower kWh sales to residential and commercial customers in 2023 compared to 2022 due to warmer winter weather. These decreases were partially offset by higher kWh sales to industrial customers in 2023 and lower property tax expense resulting from the favorable impact of an updated estimate for property taxes payable in 2023. Net income at SWL&P was higher than 2022 primarily due to the implementation of new rates from its most recent rate case in 2023. (See Note 4. Regulatory Matters.) Our after-tax equity earnings in ATC were higher than 2022 reflecting period over period changes in ATC’s estimate of a refund liability related to the appeals court decision on MISO return on equity complaints in 2022. (See Note 6. Equity Investments.)
ALLETE Clean Energy net income attributable to ALLETE was $71.7 million in 2023 compared to $16.3 million in 2022. Net income in 2023 reflected a $44.3 million after-tax gain recognized for a favorable arbitration ruling involving a subsidiary of ALLETE Clean Energy. Net income in 2023 also included the gain on sale of the Red Barn project in 2023 of $4.3 million after-tax and higher interest income related to interest awarded as part of the arbitration ruling. These increases were partially offset by lower wind resources and availability at its wind energy facilities in 2023 as well as a network outage located near its Caddo wind energy facility resulting in lower earnings. Net income in 2022 included reserves for an anticipated loss on the sale of ALLETE Clean Energy’s project to repower and sell its Northern Wind project as well as earnings from the legacy Northern Wind facilities, which were decommissioned in April 2022 as part of the project.
Corporate and Other net income attributable to ALLETE was $28.2 million in 2023 compared to $23.1 million in 2022. Net income in 2023 reflects higher earnings from New Energy in 2023 compared to 2022 as a result of more renewable development projects closing during 2023, income in 2023 from net losses attributable to non-controlling interest for tax equity financed solar energy facilities and the impact of purchase price accounting in 2022. Net income from New Energy in 2023 was $17.6 million. Net income from New Energy in 2022 was $7.8 million, which included a $8.3 million after-tax expense as a result of purchase price accounting related to projects under development at the time of acquisition. Net income in 2023 also reflects earnings from Minnesota solar projects placed into service in the fourth quarter of 2022 and second quarter of 2023, and a $3.8 million after-tax expense for the consolidated income tax impact resulting from the gain on the favorable arbitration ruling. Net income in 2022 included transaction costs of $2.7 million after-tax related to the acquisition of New Energy in April 2022.
ALLETE, Inc. 2023 Form 10-K
2023 Compared to 2022
(See Note 14. Business Segments for financial results by segment.)
Regulated Operations
Year Ended December 31 2023 2022
Millions
Operating Revenue - Utility $1,238.3 $1,259.3
Fuel, Purchased Power and Gas - Utility 484.3 545.5
Transmission Services - Utility 88.2 76.7
Operating and Maintenance 247.1 239.3
Depreciation and Amortization 179.2 171.9
Taxes Other than Income Taxes 44.5 57.4
Operating Income 195.0 168.5
Interest Expense (63.9) (58.1)
Equity Earnings 23.1 19.3
Other Income 15.4 9.8
Income Before Income Taxes 169.6 139.5
Income Tax Expense (Benefit) 22.4 (10.4)
Net Income Attributable to ALLETE $147.2 $149.9
Operating Revenue - Utility decreased $21.0 million from 2022 primarily due to lower kWh sales, fuel adjustment clause recoveries and gas sales, partially offset by higher cost recovery rider revenue, FERC formula-based rates and transmission revenue.
Lower kWh sales reduced revenue $32.5 million from 2022 reflecting lower sales to residential, commercial and municipal customers as well as lower sales to other power suppliers, partially offset by higher sales to industrial customers. Sales to residential, commercial and municipal customers decreased from 2022 primarily due to warmer weather in the winter months in 2023 compared to 2022. Heating degree days for Duluth, Minnesota, were down 13 percent in 2023 compared to 2022. Sales to municipal customers also decreased as a result of a new contract entered into with Hibbing Public Utilities in 2022 with sales under the new contract now classified under other power suppliers. Sales to industrial customers increased primarily due to higher sales to taconite customers as well as sales to ST Paper, which became a Large Power Customer in 2023, higher sales to Cenovus Energy, which restarted its refinery in Superior, Wisconsin, in 2023, and higher sales to pipeline and other customers. (See Outlook - Regulated Operations - Industrial Customers - ST Paper and Cenovus Energy.) Sales to other power suppliers, which are sold at market-based prices into the MISO market on a daily basis or through PSAs of various durations, decreased in 2023 compared to 2022 primarily due to fewer market sales and lower market prices in 2023 compared to 2022.
Kilowatt-hours Sold
2023 2022 Quantity
Variance %
Variance
Millions
Regulated Utility
Retail and Municipal
Residential 1,089 1,148 (59) (5.1)
Commercial 1,347 1,359 (12) (0.9)
Industrial 7,044 6,745 299 4.4
Municipal 466 540 (74) (13.7)
Total Retail and Municipal 9,946 9,792 154 1.6
Other Power Suppliers 2,819 3,149 (330) (10.5)
Total Regulated Utility Kilowatt-hours Sold 12,765 12,941 (176) (1.4)
Revenue from electric sales to taconite and mining customers accounted for 32 percent of regulated operating revenue in 2023 (32 percent in 2022). Revenue from electric sales to paper, pulp and secondary wood product customers accounted for 5 percent of regulated operating revenue in 2023 (5 percent in 2022). Revenue from electric sales to pipelines and other industrial customers accounted for 11 percent of regulated operating revenue in 2023 (10 percent in 2022).
ALLETE, Inc. 2023 Form 10-K
2023 Compared to 2022 (Continued)
Regulated Operations (Continued)
Fuel adjustment clause revenue decreased $20.6 million primarily due to lower fuel and purchased power costs attributable to retail and municipal customers. (See Fuel, Purchased Power and Gas - Utility.)
Revenue from gas sales at SWL&P decreased $4.6 million reflecting fewer gas sales resulting from warmer winter weather and lower gas prices in 2023 compared to 2022. (See Fuel, Purchased Power and Gas - Utility.)
Cost recovery rider revenue increased $18.2 million primarily due to fewer production tax credits generated by Minnesota Power. If production tax credits are generated at a level below those assumed in Minnesota Power’s retail rates, an increase in cost recovery rider revenue is recognized to offset the impact of lower production tax credits on income tax expense.
Revenue from wholesale customers under FERC formula-based rates increased $9.6 million primarily due to higher rates reflecting higher expenses billable under wholesale customer contracts.
Transmission revenue increased $9.2 million primarily due to higher MISO-related revenue.
Operating Expenses decreased $47.5 million from 2022.
Fuel, Purchased Power and Gas - Utility expense decreased $61.2 million, or 11 percent, from 2022 primarily due to lower kWh sales, purchased power prices and fuel costs as well as lower gas sales and prices.
Transmission Services - Utility expense increased $11.5 million, or 15 percent, from 2022 primarily due to higher MISO-related expense.
Operating and Maintenance expense increased $7.8 million, or 3 percent, from 2022 primarily due to higher salaries and wages, vegetation management costs, and materials purchased for use in generation facilities and field operations. These increases were partially offset by lower contract and professional services as well as lower benefit costs.
Depreciation and Amortization expense increased $7.3 million, or 4 percent, from 2022 primarily due to a higher plant in service balance in 2023.
Taxes Other than Income Taxes decreased $12.9 million, or 22 percent, from 2022 primarily due to lower property tax expense resulting from the favorable impact of an updated estimate for 2022 property tax expense recorded in 2023.
Interest Expense increased $5.8 million, or 10 percent, from 2022 primarily due to higher interest rates and interest on Minnesota Power’s reserve for interim rate refunds in 2023.
Equity Earnings increased $3.8 million from, or 20 percent, 2022 primarily due to period over period changes in ATC’s estimate of a refund liability related to the appeals court decision on MISO return on equity complaints in 2022. (See Note 6. Equity Investments.)
Other Income increased $5.6 million from 2022 reflecting year over year differences in various individually immaterial items.
Income Tax Expense increased $32.8 million from 2022. The effective tax rate in 2023 was an income tax expense compared to a benefit in 2022 primarily due to lower production tax credits and higher pre-tax income.
ALLETE, Inc. 2023 Form 10-K
2023 Compared to 2022 (Continued)
ALLETE Clean Energy
Year Ended December 31 2023 2022
Millions
Operating Revenue
Contracts with Customers - Non-utility $413.4 $110.7
Other - Non-utility (a)
5.1 7.6
Cost of Sales - Non-utility 342.2 56.7
Operating and Maintenance 52.1 47.3
Depreciation and Amortization 57.5 58.6
Taxes Other than Income Taxes 10.0 10.7
Operating Loss (43.3) (55.0)
Interest Expense (0.8) (2.3)
Other Income (b)
68.0 10.8
Income (Loss) Before Income Taxes 23.9 (46.5)
Income Tax Expense (Benefit) 2.7 (15.4)
Net Income (Loss) 21.2 (31.1)
Net Loss Attributable to Non-Controlling Interest (b)
(50.5) (47.4)
Net Income Attributable to ALLETE $71.7 $16.3
(a)Represents non-cash amortization of differences between contract prices and estimated market prices on assumed PSAs.
(b)See Note 1. Operations and Significant Accounting Policies.
Operating Revenue increased $300.2 million from 2022 primarily due to the sales of ALLETE Clean Energy’s Northern Wind and Red Barn projects in 2023. This increase was partially offset by lower wind resources and availability at wind energy facilities in all regions in 2023 compared to 2022. Wind availability was down across the nation much of the year and, consequently, ALLETE Clean Energy revenue was negatively impacted in 2023. Operating revenue in 2023 was also negatively impacted by a forced outage in the fourth quarter of 2023 to a substation and the transmission lines feeding that substation located near ALLETE Clean Energy’s Caddo wind energy facility. This forced outage increased congestion experienced by the Caddo wind energy facility resulting in lower kWh sales and pricing. In 2022, operating revenue also included revenue from the legacy Northern Wind facilities, which were decommissioned in April 2022 as part of ALLETE Clean Energy’s Northern Wind project.
Year Ended December 31,
2023 2022
Production and Operating Revenue kWh Revenue kWh Revenue
Millions
Wind Energy Regions
East 224.0 $21.2 266.6 $24.3
Midwest (a)
560.9 18.4 775.9 27.0
South 1,720.8 16.8 2,047.1 15.4
West 714.1 13.6 829.5 18.1
Total Wind Energy Facilities 3,219.8 70.0 3,919.1 84.8
Sale of Wind Energy Facility - 348.5 - 33.5
Total Production and Operating Revenue 3,219.8 $418.5 3,919.1 $118.3
(a)The Chanarambie and Viking wind energy facilities were decommissioned in the second quarter of 2022 as part of ALLETE Clean Energy’s Northern Wind project.
ALLETE, Inc. 2023 Form 10-K
2023 Compared to 2022 (Continued)
ALLETE Clean Energy (Continued)
Cost of Sales - Non-utility increased $285.5 million from 2022 reflecting the sales of ALLETE Clean Energy’s Northern Wind and Red Barn projects in 2023. Cost of Sales - Non-utility in 2022 reflected reserves in 2022 related to ALLETE Clean Energy’s project to repower and sell its Northern Wind project resulting from inflationary increases and significant cost pressures. In addition, 2022 included a $10.2 million reserve in the second quarter related to the sale of the Northern Wind project, which was fully offset by a gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the wind energy facilities. (See Other Income.)
Operating and Maintenance expense increased $4.8 million, or 10 percent, from 2022 primarily due to higher contract and professional services in 2023. Arbitration-related costs incurred in 2023 for arbitration proceedings involving a subsidiary of ALLETE Clean Energy were fully offset by the recovery of $3.6 million for arbitration-related costs that were awarded as part of a favorable arbitration ruling. (See Note 9. Commitments, Guarantees and Contingencies.)
Other Income increased $57.2 million from 2022 primarily due to a $58.4 million gain recognized for a favorable arbitration ruling 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 9. Commitments, Guarantees and Contingencies.) Other Income in 2022 reflected a gain on removal of the PSA liability for the Northern Wind project upon decommissioning of the wind energy facilities in 2022. (See Cost of Sales - Non-utility.)
Income Tax Expense increased $18.1 million from 2022 primarily due to higher pre-tax income in 2023 compared to 2022.
Net Loss Attributable to Non-Controlling Interest increased $3.1 million from 2022 reflecting a higher production tax credit rate, as determined by the Internal Revenue Service, in 2023 compared to 2022. This increase was partially offset by lower wind resources at our tax equity financed wind energy facilities.
Corporate and Other
Operating Revenue increased $29.9 million, or 15 percent, from 2022 reflecting higher revenue from New Energy, which was acquired in April 2022, and higher revenue at BNI Energy, which operates under cost-plus fixed fee contracts, as a result of higher expenses in 2023 compared to 2022.
Net Income Attributable to ALLETE was $28.2 million in 2023 compared to $23.1 million in 2022. Net income in 2023 reflects higher earnings from New Energy in 2023 compared to 2022 as a result of more renewable development projects closing during 2023, income in 2023 from net losses attributable to non-controlling interest for tax equity financed solar energy facilities and the impact of purchase price accounting in 2022. Net income from New Energy in 2023 was $17.6 million. Net income from New Energy in 2022 was $7.8 million, which included a $8.3 million after-tax expense as a result of purchase price accounting related to projects under development at the time of acquisition. Net income in 2023 also reflects earnings from Minnesota solar projects placed into service in the fourth quarter of 2022 and second quarter of 2023, and a $3.8 million after-tax expense for the consolidated income tax impact resulting from the gain on the favorable arbitration ruling. Net income in 2022 included transaction costs of $2.7 million after-tax related to the acquisition of New Energy in April 2022.
Income Taxes - Consolidated
For the year ended December 31, 2023, the effective tax rate was an expense of 13.5 percent (benefit of 31.2 percent for the year ended December 31, 2022). The effective tax rate for 2023 an expense compared to a benefit in 2022 primarily due to higher pre-tax income and lower production tax credits. (See Note 11. Income Tax Expense.)
ALLETE, Inc. 2023 Form 10-K
2022 Compared to 2021
The comparison of the results of operations for the years ended December 31, 2022 and 2021 is included in Management's Discussion in the Annual Report on Form 10-K for the year ended December 31, 2022.
Critical Accounting Policies
The preparation of financial statements and related disclosures in conformity with GAAP requires management to make various estimates and assumptions that affect amounts reported in the Consolidated Financial Statements. These estimates and assumptions may be revised, which may have a material effect on the Consolidated Financial Statements. Actual results may differ from these estimates and assumptions. These policies are discussed with the Audit Committee of our Board of Directors on a regular basis. We believe the following policies are most critical to our business and the understanding of our results of operations.
Regulatory Accounting. Our regulated utility operations are subject to accounting standards for the effects of certain types of regulation. These standards require us to reflect the effect of regulatory decisions in our financial statements. 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. This assessment considers factors such as, but not limited to, changes in the regulatory environment and recent rate orders to other regulated entities under the same jurisdiction. If future recovery or refund of costs becomes no longer probable, the assets and liabilities would be recognized in current period net income or other comprehensive income. (See Note 4. Regulatory Matters.)
Pension and Postretirement Health and Life Actuarial Assumptions. We account for our pension and other postretirement benefit obligations in accordance with the accounting standards for defined benefit pension and other postretirement plans. These standards require the use of several important assumptions, including the expected long-term rate of return on plan assets, the discount rate and mortality assumptions, among others, in determining our obligations and the annual cost of our pension and other postretirement benefits. In establishing the expected long-term rate of return on plan assets, we determine the long-term historical performance of each asset class and adjust these for current economic conditions while utilizing the target allocation of our plan assets to forecast the expected long-term rate of return. Our pension asset allocation as of December 31, 2023, was approximately 57 percent equity securities, 40 percent fixed income and 3 percent real estate. Our postretirement health and life asset allocation as of December 31, 2023, was approximately 67 percent equity securities, and 33 percent fixed income. Equity securities consist of a mix of market capitalization sizes with domestic and international securities. In 2023, we used weighted average expected long-term rates of return of 6.83 percent in our actuarial determination of our pension expense and 6.33 percent in our actuarial determination of our other postretirement expense. The actuarial determination uses an asset smoothing methodology for actual returns to reduce the volatility of varying investment performance over time. We review our expected long-term rate of return assumption annually and will adjust it to respond to changing market conditions. A one-quarter percent decrease in the expected long-term rate of return would increase the annual expense for pension and other postretirement benefits by approximately $2.1 million, pre-tax.
The discount rate is computed using a bond matching study which utilizes a portfolio of high quality bonds that produce cash flows similar to the projected costs of our pension and other postretirement plans. In 2023, we used weighted average discount rates of 5.70 percent and 5.89 percent in our actuarial determination of our pension and other postretirement expense, respectively. We review our discount rates annually and will adjust them to respond to changing market conditions. A one-quarter percent decrease in the discount rate would increase the annual expense for pension and other postretirement benefits by approximately $0.4 million, pre-tax.
The mortality assumptions used to calculate our pension and other postretirement benefit obligations as of December 31, 2023, considered a modified PRI-2012 mortality table and MP-2021 mortality projection scale. (See Note 12. Pension and Other Postretirement Benefit Plans.)
Valuation of Business Combinations and Resulting Goodwill. When we acquire a business, the assets acquired and liabilities assumed are recorded at their respective fair values as of the acquisition date. Determining the fair value of intangible assets acquired as part of a business combination requires us to make significant estimates. These estimates may include the amount and timing of projected future cash flows, the discount rate used to discount those cash flows to present value, the assessment of the asset’s life cycle, and the consideration of legal, technical, regulatory, economic and competitive risks.
ALLETE, Inc. 2023 Form 10-K
Critical Accounting Policies (Continued)
Goodwill. Goodwill is the excess of the purchase price (consideration transferred) over the estimated fair value of the net assets of the acquired businesses. In accordance with GAAP, goodwill is not amortized. The Company assesses whether there has been an impairment of goodwill annually in the fourth quarter and whenever an event occurs or circumstances change that would indicate the carrying amount may be impaired. Impairment testing for goodwill is done at the reporting unit level. An impairment loss is recognized when the carrying amount of the reporting unit’s net assets exceeds the estimated fair value of the reporting unit. The test for impairment requires us to make several estimates about fair value, most of which are based on projected future cash flows. Our estimates associated with the goodwill impairment test are considered critical due to the amount of goodwill recorded on our Consolidated Balance Sheet and the judgment required in determining fair value. The fair value of the New Energy reporting unit was determined using a discounted cash flow model, using significant assumptions which included a discount rate of 14 percent, cash flow forecasts through 2028, industry average gross margins, and a terminal growth rate of 3.5 percent. Any forecast contains a degree of uncertainty, and changes in the forecasted cash flows and other assumptions could significantly increase or decrease the calculated fair value of New Energy. The results of our annual impairment test are discussed in Note 1. Operations and Significant Accounting Policies and Note 7. Fair Value in this Form 10-K. Goodwill was $154.9 million as of December 31, 2023.
Impairment of Long-Lived Assets. We review our long-lived assets for indicators of impairment in accordance with the accounting standards for property, plant and equipment on a quarterly basis.
In accordance with the accounting standards for property, plant and equipment, if indicators of impairment exist, we test our long-lived assets for recoverability by comparing the carrying amount of the asset to the undiscounted future net cash flows expected to be generated by the asset. Cash flows are assessed at the lowest level of identifiable cash flows. The undiscounted future net cash flows are impacted by trends and factors known to us at the time they are calculated and our expectations related to: management’s best estimate of future sales prices; holding period and timing of sales; method of disposition; and future expenditures necessary to maintain the operations. (See Note 1. Operations and Significant Accounting Policies.)
Taxation. We are required to make judgments regarding the potential tax effects of various financial transactions and our ongoing operations to estimate our obligations to taxing authorities. These tax obligations include income taxes and taxes other than income taxes. Judgments related to income taxes require the recognition in our financial statements of the largest tax benefit of a tax position that is “more-likely-than-not” to be sustained on audit. Tax positions that do not meet the “more-likely-than-not” criteria are reflected as a tax liability in accordance with the accounting standards for uncertainty in income taxes. We record a valuation allowance against our deferred tax assets to the extent it is more-likely-than-not that some portion or all of the deferred tax assets will not be realized.
We are subject to income taxes in various jurisdictions. We make assumptions and judgments each reporting period to estimate our income tax assets, liabilities, benefits and expenses. Judgments and assumptions are supported by historical data and reasonable projections. Our assumptions and judgments include the application of tax statutes and regulations, and projections of future federal taxable income, state taxable income, and state apportionment to determine our ability to utilize NOL and credit carryforwards prior to their expiration. Significant changes in assumptions regarding future federal and state taxable income or a change in tax rates could require new or increased valuation allowances which could result in a material impact on our results of operations.
ALLETE, Inc. 2023 Form 10-K
Outlook
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, 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.
In August 2022, the Inflation Reduction Act was signed into law. We believe our businesses will benefit from certain provisions of the legislation including from the extension and transferability of production tax credits and investment tax credits, among others. We are planning to sell certain tax credits generated in 2023 and beyond. We do not currently anticipate any impact from the new alternative minimum tax. We will continue to assess the impact of the law as additional implementation guidance becomes available.
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. Minnesota Power has a vision of delivering 100 percent carbon-free energy by 2050. (See EnergyForward.) We will monitor and review proposed environmental regulations and may challenge those that add considerable cost with limited environmental benefit. Minnesota Power will continue to pursue customer growth opportunities and cost recovery rider approvals for transmission, renewable and environmental investments, as well as work with regulators to earn a fair rate of return.
Regulatory Matters. Entities within our Regulated Operations segment are under the jurisdiction of the MPUC, FERC, PSCW and NDPSC. See Note 4. Regulatory Matters for discussion of regulatory matters within these jurisdictions.
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 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. We cannot predict the level of final rates that may be authorized by the MPUC.
Wisconsin Retail Rates. SWL&P expects to file its next general rate case with the PSCW in the first quarter of 2024.
ALLETE, Inc. 2023 Form 10-K
Outlook (Continued)
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 55 percent of our regulated utility kWh sales in 2023 (52 percent in 2022 and 47 percent in 2021) were made to our industrial customers. We expect industrial sales of approximately 7.0 million MWh in 2024 (7.0 million MWh in 2023 and 6.7 million in 2022). (See Item 1. Business - Regulated Operations - Electric Sales / Customers.)
Taconite. Minnesota Power’s taconite customers are capable of producing up to approximately 41 million tons of taconite pellets annually. Taconite pellets produced in Minnesota are primarily shipped to North American steel making facilities that are part of the integrated steel industry, which continue to lead the world in environmental performance among steelmaking countries. According to the U.S. Department of Energy, steel production in the U.S. is the most energy efficient of any major steel producing country. Steel produced from these North American facilities is used primarily in the manufacture of automobiles, appliances, tubular applications for all industries, and in the construction industry. Steel is also a critical component of the clean energy transformation underway today. Meeting the demand for more renewable energy and the need for additional infrastructure to transport green energy from the point of generation to the end user both require steel. Historically, approximately 10 percent of Minnesota taconite production has been exported outside of North America.
There has been a general historical correlation between U.S. steel production and Minnesota taconite production. The American Iron and Steel Institute, an association of North American steel producers, reported that U.S. raw steel production operated at approximately 75 percent of capacity in 2023 (78 percent in 2022 and 82 percent in 2021). The World Steel Association, an association of steel producers, national and regional steel industry associations, and steel research institutes representing approximately 85 percent of world steel production, projected U.S. steel consumption in 2024 will increase by approximately 2 percent compared to 2023.
Minnesota Power’s taconite customers may experience annual variations in production levels due to such factors as economic conditions, short-term demand changes or maintenance outages. The Minnesota Department of Revenue Mineral Tax Office expects taconite production from our taconite customers to be approximately 35 million tons in 2024. We estimate that a one million ton change in Minnesota Power’s taconite customers’ production would impact our annual earnings per share by approximately $0.05, net of expected power marketing sales at current prices. Changes in wholesale electric prices or customer contractual demand nominations could impact this estimate. Minnesota Power proactively sells power in the wholesale power markets that is temporarily not required by industrial customers to optimize the value of its generating facilities. Long-term reductions in taconite production or a permanent shut down of a taconite customer may lead Minnesota Power to file a general rate case to recover lost revenue.
USS Corporation. USS Corporation has announced plans to invest approximately $150 million to construct a system dedicated to producing direct reduced-grade (DR-grade) pellets at its Keetac plant. USS Corporation broke ground on the project in the third quarter of 2022, and is expected to begin producing DR-grade pellets in 2024. This will enable the existing pelletizing plant to not only create DR-grade pellets for use as a feedstock for a direct reduced iron (DRI) or hot briquetted iron (HBI) process that ultimately supplies electric arc furnace steelmaking but also maintains the optionality to continue producing blast furnace-grade pellets. USS Corporation’s Minntac and Keetac plants are Large Power industrial customers of Minnesota Power. USS Corporation has the capability to produce approximately 15 million and 5 million tons annually at its Minntac and Keetac plants, respectively.
In the third quarter of 2023, USS Corporation disclosed it had commenced a formal review process to evaluate strategic alternatives for the company after receiving multiple unsolicited proposals that ranged from the acquisition of certain production assets to consideration for the whole company. 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. USS Corporation expects the transaction to close in the second or third quarter 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.
Cleveland-Cliffs, Inc. (Cliffs). In 2020, Cliffs announced that it had completed the previously announced acquisition of substantially all of the operations of ArcelorMittal USA LLC and its subsidiaries. Cliffs had stated that upon closure of the acquisition, Cliffs would be the largest flat-rolled steel producer and the largest iron ore pellet producer in North America. The acquisition included ArcelorMittal’s Minorca mine in Virginia, Minnesota, and its ownership share of Hibbing Taconite in Hibbing, Minnesota, which are both large industrial customers of Minnesota Power. Cliffs is Minnesota Power’s largest customer. The acquisition has increased customer concentration risk for the Company and could lead to further capacity consolidation for both steel blast furnaces and related Minnesota iron ore production.
ALLETE, Inc. 2023 Form 10-K
Outlook (Continued)
Industrial Customers (Continued)
Cliffs completed construction of a hot briquetted iron production plant in Toledo, Ohio, in 2020, which has utilized direct reduced-grade pellets from Northshore Mining. In October 2021, Cliffs indicated it plans to move direct reduced-grade pellet production to its Minorca mine and that Northshore Mining would become a “swing facility” due to the higher royalty rates at that mine. (See Northshore Mining.)
Northshore Mining. Cliffs idled all production at its Northshore mine in 2022. Northshore Mining resumed partial pellet plant production in April 2023. Cliffs indicated it will continue to utilize Northshore Mining as a swing facility. Northshore Mining has the capability to produce approximately 6 million tons annually. Minnesota Power has a PSA through 2031 with Silver Bay Power, which provides the majority of the electric service requirements for Northshore Mining.
Hibbing Taconite. Hibbing Taconite is a joint venture between subsidiaries of Cliffs (85.3 percent ownership) and USS Corporation (14.7 percent ownership). The joint venture is managed by Cliffs and is also a Large Power Customer of Minnesota Power. On May 25, 2023, the Minnesota Executive Council approved state mineral leases near Nashwauk, Minnesota, with Cliffs, the majority owner of Hibbing Taconite. Cliffs has stated that these leases will provide Hibbing Taconite with more than two decades of additional mineral reserves. Prior to the leases being awarded, Hibbing Taconite had proven mineral reserves to support its operations through 2026. Hibbing Taconite has the capability of producing 8 million tons of taconite annually.
Minnesota Sulfate Wild Rice Water Quality Standard. On April 29, 2021, the EPA identified rivers and lakes in Minnesota in which wild rice grows that have sulfate levels that exceed Minnesota’s sulfate limit for wild rice waters. On September 1, 2021, three additional wild rice waters with sulfate levels that exceed Minnesota’s sulfate limit were identified. The EPA directed the MPCA to add these rivers and lakes to its list of impaired waters which can be used to set limits in discharge permits for industrial activities such as mining. Minnesota Power’s taconite customers could be adversely impacted if they are required to significantly reduce sulfate discharges.
Paper, Pulp and Secondary Wood Products. The North American paper and pulp industry continues to face declining demand due to the impact of electronic substitution for print and changing customer needs. As a result, certain paper and pulp customers have reduced their existing operations in recent years and have pursued or are pursuing product changes in response to the declining demand. The resulting reduction in production capacity outside of Minnesota for certain paper grades has solidified our paper customers’ operations, at least for the near term, and as such we expect operating levels in 2024 at the major paper and pulp mills we serve to be at similar levels as in 2023.
ST Paper. In May 2021, ST Paper announced it had completed the purchase of the Duluth Mill from Verso Corporation. In January 2022, Minnesota Power entered into an electric service agreement with ST Paper that would begin Large Power Customer service with a minimum term of six years upon start-up of operations. ST Paper completed start-up of operations and became a Large Power Customer as of the first quarter of 2023. On January 3, 2024, ST Paper announced it had entered into an asset purchase 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.
Pipeline and Other Industries.
Cenovus Energy. In 2018, a fire at Cenovus Energy’s refinery in Superior, Wisconsin, which was owned by Husky Energy at that time, disrupted operations at the facility. Under normal operating conditions, SWL&P provides approximately 14 MW of average monthly demand to the refinery in addition to water service. In April 2023, Cenovus Energy announced that it had commenced restart of the facility.
ALLETE, Inc. 2023 Form 10-K
Outlook (Continued)
EnergyForward. Minnesota Power is executing EnergyForward, its strategy assuring reliability, protecting affordability and further improving environmental performance. The plan includes completed and planned investments in wind, solar, natural gas and hydroelectric power, construction of additional transmission capacity, the installation of emissions control technology and the idling and retirement of certain coal-fired generating facilities. Minnesota Power has a vision to deliver 100 percent carbon-free energy to customers, continuing its commitment to climate, customers and communities through its EnergyForward strategy. This vision builds on Minnesota Power’s recent achievement of now providing 50 percent renewable energy to its customers. In 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. Minnesota Power is working with various stakeholders and participating in the regulatory process to implement this legislation. (See Item 1. Business - Regulated Operations - Minnesota Legislation.)
2021 Integrated Resource Plan (IRP). On February 1, 2021, Minnesota Power filed its latest IRP, which was approved by the MPUC in an order dated January 9, 2023. The approved IRP, which reflects a joint agreement reached with various stakeholders, outlines Minnesota Power’s clean-energy transition plans through 2035. These plans include expanding its renewable energy supply, achieving coal-free operations at its facilities by 2035, and investing in a resilient and flexible transmission and distribution grid. As part of these plans, Minnesota Power anticipates adding up to 700 MW of new wind and solar energy resources, and ceasing coal operations at Boswell Units 3 and 4 by 2030 and 2035, respectively. Minnesota Power’s plans recognize that advances in technology will play a significant role in completing its transition to carbon-free energy supply, reliably and affordably. Minnesota Power is expected to file its next IRP by March 1, 2025.
In recent years, Minnesota Power has transformed its energy supply from more than a 95 percent reliance on coal to become a leader in the nation’s clean-energy transformation. Since 2013, the company has closed or converted seven of its nine coal-fired units and added nearly 900 megawatts of renewable energy sources. Additionally, Minnesota Power has been a leader in energy conservation, surpassing the state’s conservation goals each year for the past decade.
Nemadji Trail Energy Center (NTEC). In 2017, Minnesota Power submitted a resource package to the MPUC which included requesting approval of a natural gas capacity dedication and other affiliated interest agreements for NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting in 2028 pursuant to the capacity dedication agreement.
Renewable Energy. Minnesota Power continues to execute its renewable energy strategy and reached its goal of supplying 50 percent of its energy by renewable energy sources. Minnesota Power also has a vision of delivering 100 percent carbon-free energy by 2050. (See EnergyForward.)
Minnesota Power has approved cost recovery riders for certain renewable investments and expenditures as well as investments and expenditures related to compliance with the Minnesota Solar Energy Standard. The cost recovery riders allow Minnesota Power to charge retail customers on a current basis for the costs of certain renewable and solar investments and expenditures plus a return on the capital invested. (See Note 4. Regulatory Matters.)
Wind Energy. Minnesota Power’s wind energy facilities consist of Bison (497 MW) located in North Dakota, and Taconite Ridge (25 MW) located in northeastern Minnesota. Minnesota Power also has two long-term wind energy PPAs with an affiliate of NextEra Energy, Inc. to purchase the output from Oliver Wind I (50 MW) and Oliver Wind II (48 MW) located in North Dakota.
Minnesota Power uses the 465-mile, 250-kV DC transmission line that runs from Center, North Dakota, to Duluth, Minnesota, to transport wind energy from North Dakota while gradually phasing out coal-based electricity delivered to its system over this transmission line from Square Butte’s lignite coal-fired generating unit. Minnesota Power is currently pursuing a modernization and capacity upgrade of its DC transmission system to continue providing reliable operations and additional system capabilities. (See Transmission.)
Wind Energy Request For Proposals. On December 15, 2023, Minnesota Power issued 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.
ALLETE, Inc. 2023 Form 10-K
Outlook (Continued)
EnergyForward (Continued)
Nobles 2 PPA. Minnesota Power has a long-term PPA with Nobles 2 that provides for Minnesota Power to purchase the energy and associated capacity from a 250 MW wind energy facility in southwestern Minnesota through 2040. The agreement provides for the purchase of output from the facility at fixed energy prices. There are no fixed capacity charges, and Minnesota Power will only pay for energy as it is delivered. (See Corporate and Other - Investment in Nobles 2.)
Manitoba Hydro. Minnesota Power has two long-term PPAs with Manitoba Hydro. The first PPA provides for Minnesota Power to purchase 250 MW of capacity and energy from Manitoba Hydro through May 2035. The second PPA provides for Minnesota Power to purchase up to 133 MW of energy from Manitoba Hydro through June 2040. (See Note 9. Commitments, Guarantees and Contingencies.)
Solar Energy. Minnesota Power’s solar energy facilities consist of a 10 MW solar energy facility at the Camp Ripley Minnesota Army National Guard base and training facility near Little Falls, Minnesota, and a 40 kW solar array located in Duluth, Minnesota. Minnesota Power also purchases solar energy from approximately 20 MW of solar energy facilities located in Minnesota that are owned by an ALLETE subsidiary, and a 1 MW community solar garden in northeastern Minnesota, which is owned and operated by a third party. SWL&P owns and operates a 470 kW solar array as part of a community solar garden in Superior, Wisconsin, that went into service in 2023.
Solar Energy Request For Proposals. On October 2, 2023, Minnesota Power issued 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.
Transmission. We continue to make investments in transmission opportunities that strengthen or enhance the transmission grid or take advantage of our geographical location between sources of renewable energy and end users. These include investments to enhance our own transmission facilities and investments in other transmission assets (individually or in combination with others) and our investment in ATC. See also Item 1. Business - Regulated Operations - Transmission and Distribution.
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. 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 2029, 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 2025, subject to MPUC approval, 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. 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, subject to final application and review process. In addition, this project received $15 million in state funding as part of an energy and climate budget bill passed by the Minnesota Legislature in 2023.
ALLETE, Inc. 2023 Form 10-K
Outlook (Continued)
Transmission (Continued)
Northland Reliability Project. Minnesota Power and Great River Energy announced in July 2022 their intent to build a 180-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. Subject to regulatory approvals, the transmission line is expected to be in service in 2030.
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. The project is in its early stages and is expected to cost between $600 million and $700 million. The MPUC will determine the final route for the Minnesota portion as well as cost recovery for Minnesota Power’s approximately $20 million estimated share of the project. Subject to regulatory approvals, the transmission line is expected to be in service in 2027.
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 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.
Portions of our ALLETE Clean Energy business are experiencing return pressures that are impacting our earnings per share growth from increased competition, congestion and lower forward price curves, as a growing amount of investment capital is being directed into wind generation opportunities. In addition, current and potential new project developments can be negatively affected by a lower ALLETE stock price, which may result in such projects not being accretive, or otherwise unable to satisfy our financial objectives criteria to proceed. In response to these market pressures, we are actively evaluating additional growth opportunities to deliver more comprehensive clean energy solutions for customers at ALLETE Clean Energy, which may include wind, solar, storage solutions, and related energy infrastructure investments and services. We believe that the renewable energy industry is entering a new phase of growth and that we are well-positioned to serve customers and drive future growth at ALLETE. ALLETE Clean Energy will continue to optimize its existing wind energy facility portfolio, advance and expand its project pipeline, and explore other renewable energy opportunities to further enhance its service offerings, growth and profitability.
In May 2021, ALLETE Clean Energy announced that it acquired the rights to the approximately 92 MW Red Barn wind development project and the approximately 68 MW Whitetail renewable development project in southwestern Wisconsin. ALLETE Clean Energy signed an asset sale agreement for the Red Barn wind project with Wisconsin Public Service Corporation and Madison Gas and Electric Company in 2021. The sale of Red Barn wind project closed in the second quarter of 2023 at which time ALLETE Clean Energy received cash proceeds of approximately $160 million and recorded a gain on sale of $4.3 million after-tax.
ALLETE, Inc. 2023 Form 10-K
Outlook (Continued)
ALLETE Clean Energy
Since September 20, 2023, a substation and the transmission lines feeding that substation located near ALLETE Clean Energy’s Caddo wind energy facility, and operated by another party, have experienced a forced outage. This forced outage has increased congestion experienced by the Caddo wind energy facility and is expected to have a negative impact on ALLETE Clean Energy’s results in the first quarter of 2024. We will continue to monitor this development for timing of repairs and impact going forward.
ALLETE Clean Energy manages risk by having a diverse portfolio of assets, which includes PSA expiration, technology and geographic diversity. The current operating portfolio is subject to typical variations in seasonal wind with higher wind resources typically available in the winter months. The majority of its planned maintenance leverages this seasonality and is performed during lower wind periods. ALLETE Clean Energy’s current operating portfolio is as follows:
Region Wind Energy Facility Capacity MW MW PSA Expiration
East Armenia Mountain 101
PSA 1 50% 2031
PSA 2 50% 2024
Midwest Lake Benton 104 100% 2028
Storm Lake I 108 100% 2027
Storm Lake II 77
Merchant 90% n/a
PSA 1 10% 2032
Other 17 100% 2028
South Caddo 303
Merchant 27% n/a
PSA 1 66% 2034
PSA 2 7% 2034
Diamond Spring 303
PSA 1 58% 2035
PSA 2 25% 2032
PSA 3 16% 2035
West Condon 50 100% 2028
Glen Ullin 106 100% 2039
South Peak 80 100% 2035
Non-cash amortization to revenue recognized by ALLETE Clean Energy relates to the amortization of differences between contract prices and estimated market prices on assumed PSAs. As part of wind energy facility acquisitions, ALLETE Clean Energy assumed various PSAs that were above or below estimated market prices at the time of acquisition; the resulting differences between contract prices and estimated market prices are amortized to revenue over the remaining PSA term. Non-cash amortization is expected to be approximately $5 million in 2024, $6 million in 2025 through 2027, and decreasing thereafter through 2032.
Corporate and Other.
New Energy. New Energy is a renewable energy development company with a primary focus on solar and storage facilities while also offering comprehensive operations, maintenance and asset management services. New Energy is a leading developer of community, commercial and industrial, and small utility-scale renewable energy projects that has completed more than 500 MW in its history, totaling more than $1.2 billion of capital. New Energy currently has a robust project pipeline with greater than 2,000 MW of renewable projects in development across over 20 different states. New Energy adds value through cost effective development and economies of scale on project implementation, bringing national capabilities to regional co-development partners. New Energy is involved in greenfield development as well as acquiring and completing mid-stage and late-stage renewable energy projects.
Investment in Nobles 2. Our subsidiary, ALLETE South Wind, owns a 49 percent equity interest in 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. (See Note 6. Equity Investments.)
ALLETE, Inc. 2023 Form 10-K
Outlook (Continued)
Corporate and Other (Continued)
South Shore Energy. South Shore Energy, ALLETE’s non-rate regulated, Wisconsin subsidiary, is developing NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy. Minnesota Power is expected to purchase approximately 20 percent of the facility's output starting in 2028 pursuant to a capacity dedication agreement. Construction of NTEC is subject to obtaining additional permits from local, state and federal authorities. The total project cost is estimated to be approximately $700 million, of which South Shore Energy will be responsible for approximately 20 percent. South Shore Energy’s portion of NTEC project costs incurred through December 31, 2023, is approximately $9 million.
BNI Energy. In 2023, BNI Energy sold 4.0 million tons of coal (3.7 million tons in 2022) and anticipates 2024 sales will be similar to 2023. BNI Energy operates under cost-plus fixed fee agreements extending through December 31, 2037.
ALLETE Properties. Our strategy incorporates the possibility of a bulk sale of the entire ALLETE Properties portfolio. Proceeds from a bulk sale would be strategically deployed to support growth initiatives at our Regulated Operations and ALLETE Clean Energy. ALLETE Properties also continues to pursue sales of individual parcels over time and will continue to maintain key entitlements and infrastructure.
Income Taxes
ALLETE’s aggregate federal and multi-state statutory tax rate is approximately 28 percent for 2023. ALLETE also has tax credits and other tax adjustments that reduce the combined statutory rate to the effective tax rate. These tax credits and adjustments historically have included items such as production tax credits, excess deferred taxes, non-controlling interests in subsidiaries, as well as other items. The annual effective rate can also be impacted by such items as changes in income before income taxes, state and federal tax law changes that become effective during the year, business combinations, tax planning initiatives and resolution of prior years’ tax matters. We expect our effective tax rate to be an expense of approximately 5 percent for 2024 primarily due to federal production tax credits as a result of wind energy generation and non-controlling interests in subsidiaries. We also expect that our effective tax rate will be lower than the combined statutory rate over the next 10 years due to production tax credits attributable to our wind energy generation.
Liquidity and Capital Resources
Liquidity Position. ALLETE is well-positioned to meet its liquidity needs. As of December 31, 2023, we had cash and cash equivalents of $71.9 million, $369.7 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.
Capital Structure. ALLETE’s capital structure for each of the last three years is as follows:
As of December 31 2023 % 2022 % 2021 %
Millions
ALLETE Equity $2,809.6 54 $2,691.9 51 $2,404.3 49
Non-Controlling Interest in Subsidiaries 597.0 11 656.4 12 533.2 11
Short-Term and Long-Term Debt (a)
1,799.4 35 1,929.1 37 1,986.4 40
Redeemable Non-Controlling Interest 0.5 - - - - -
$5,206.5 100 $5,277.4 100 $4,923.9 100
(a) Excludes unamortized debt issuance costs.
ALLETE, Inc. 2023 Form 10-K
Liquidity and Capital Resources(Continued)
Cash Flows. Selected information from ALLETE’s Consolidated Statement of Cash Flows is as follows:
Year Ended December 31 2023 2022 2021
Millions
Cash, Cash Equivalents and Restricted Cash at Beginning of Period $40.2 $47.7 $65.2
Cash Flows from (used in)
Operating Activities 585.3 221.3 263.5
Investing Activities (283.6) (384.0) (485.2)
Financing Activities (262.5) 155.2 204.2
Change in Cash, Cash Equivalents and Restricted Cash 39.2 (7.5) (17.5)
Cash, Cash Equivalents and Restricted Cash at End of Period $79.4 $40.2 $47.7
Operating Activities. Cash provided by operating activities was higher in 2023 compared to 2022. Cash provided by operating activities in 2023 reflected cash proceeds from the sales of ALLETE Clean Energy’s Northern Wind and Red Barn projects which were sold to third parties in 2023, cash received from the favorable arbitration award by a subsidiary of ALLETE Clean Energy, and lower payments for inventories compared to 2022 primarily related to the Northern Wind and Red Barn projects. Cash provided by operating activities in 2023 also increased due to the timing of recovery under Minnesota Power’s fuel adjustment clause.
Cash provided by operating activities was lower in 2022 compared to 2021. Cash provided by operating activities in 2022 reflected higher payments for inventories, net of customer deposits received, compared to 2021 primarily related to ALLETE Clean Energy’s Northern Wind and Red Barn projects. This decrease was partially offset by the timing of recovery under the fuel adjustment clause.
Investing Activities. Cash used in investing activities was lower in 2023 compared to 2022. Cash used for investing activities in 2023 reflected higher additions to property, plant and equipment compared to 2022. Cash used for investing activities in 2022 reflected cash payments for the acquisition of New Energy.
Cash used in investing activities was lower in 2022 compared to 2021. Cash used for investing activities in 2022 reflected lower additions to property, plant and equipment and lower payments for equity method investments compared to 2021. These decreases were partially offset by cash payments for the acquisition of New Energy.
Financing Activities. Cash used in financing activities in 2023 reflected lower proceeds from the issuance of common stock and the issuance of long-term debt, and lower proceeds from the issuance of non-controlling interest in subsidiaries compared to 2022.
Cash provided by financing activities was lower in 2022 compared to 2021 primarily due to higher repayments of short-term and long-term debt and higher dividends on common stock in 2022. These decreases were partially offset by higher proceeds from the issuance of common stock, higher proceeds from issuance of short-term and long-term debt, and higher proceeds from non-controlling interest in 2022.
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 December 31, 2023, we had consolidated bank lines of credit aggregating $423.1 million ($475.7 million as of December 31, 2022), most of which expire in January 2027. We had $19.4 million outstanding in standby letters of credit and $34.1 million outstanding draws under our lines of credit as of December 31, 2023 ($32.8 million in standby letters of credit and $31.3 million outstanding draws as of December 31, 2022). We also have other credit facility agreements in place that provide the ability to issue up to $252.0 million in standby letters of credit. As of December 31, 2023, we had $130.5 million outstanding in standby letters of credit under these agreements.
In addition, as of December 31, 2023, we had 2.6 million original issue shares of our common stock available for issuance through Invest Direct 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.
ALLETE, Inc. 2023 Form 10-K
Liquidity and Capital Resources (Continued)
Securities. We entered into a distribution agreement with Lampert Capital Markets, in 2008, as amended most recently in 2020, with respect to the issuance and sale of up to an aggregate of 13.6 million shares of our common stock, without par value, of which 2.1 million shares remain available for issuance as of December 31, 2023. For the year ended December 31, 2023, no shares of common stock were issued under this agreement (none in 2022; 0.8 million shares for net proceeds of $51.0 million in 2021).
During the year ended December 31, 2023, we issued 0.3 million shares of common stock through Invest Direct, the Employee Stock Purchase Plan and the Retirement Savings and Stock Ownership Plan, resulting in net proceeds of $14.9 million (0.3 million shares for net proceeds of $16.2 million in 2022; 0.3 million shares for net proceeds of $18.9 million in 2021). See Note 10. Common Stock and Earnings Per Share for additional detail regarding ALLETE’s equity securities.
Financial Covenants. See Note 8. Short-Term and Long-Term Debt for information regarding our financial covenants.
Pension and Other Postretirement Benefit Plans. Management considers various factors when making funding decisions, such as regulatory requirements, actuarially determined minimum contribution requirements and contributions required to avoid benefit restrictions for the defined benefit pension plans. For the year ended December 31, 2023, we made $17.3 million in cash contributions to the defined benefit pension plans. On January 12, 2024, we contributed $25.0 million in cash to the defined benefit pension plans, and expect to make $2.0 million in additional cash contributions to the defined benefit pension plans in 2024. We do not expect to make any contributions to the defined benefit postretirement health and life plans in 2024. (See Note 10. Common Stock and Earnings Per Share and Note 12. Pension and Other Postretirement Benefit Plans.)
Off-Balance Sheet Arrangements. Off-balance sheet arrangements are discussed in Note 9. Commitments, Guarantees and Contingencies.
Contractual Obligations and Commercial Commitments. ALLETE has contractual obligations and other commitments that will need to be funded in the future, in addition to its capital expenditure programs. Material contractual obligations and other commitments are as follows:
Long-Term Debt. ALLETE has material long-term debt obligations, including long-term debt due within one year. These obligations include the principal amount of bonds, notes and loans which are recorded on the Consolidated Balance Sheet, plus interest. (See Note 8. Short-Term and Long-Term Debt.)
Pension and Other Postretirement Benefit Plans. Pension and other postretirement benefit plan obligations include the current estimate of future benefit payments. Pension contributions are dependent on several factors including realized asset performance, future discount rate and other actuarial assumptions, Internal Revenue Service and other regulatory requirements, and contributions required to avoid benefit restrictions for the pension plans. Funding for the other postretirement benefit plans is impacted by realized asset performance, future discount rate and other actuarial assumptions, and utility regulatory requirements. Our obligations are estimates and will change based on actual market performance, changes in interest rates and any changes in governmental regulations. (See Note 12. Pension and Other Postretirement Benefit Plans.)
Operating and Finance Lease Obligations. ALLETE has certain operating and finance lease obligations for the minimum payments required under various lease agreements which are recorded on the Consolidated Balance Sheet. (See Note 1. Operations and Significant Accounting Policies.)
Easement Obligations. ALLETE has easement obligations for the minimum payments required under our land easement agreements at our wind energy facilities. (See Note 9. Commitments, Guarantees and Contingencies.)
PPA Obligations. PPA obligations represent our Square Butte, Manitoba Hydro and other PPAs. (See Note 9. Commitments, Guarantees and Contingencies.)
Other Purchase Obligations. ALLETE has other purchase obligations covering our minimum purchase commitments under coal supply and rail contracts, and long-term service agreements for wind energy facilities. (See Note 9. Commitments, Guarantees and Contingencies.)
ALLETE, Inc. 2023 Form 10-K
Liquidity and Capital Resources (Continued)
Credit Ratings. Access to reasonably priced capital markets is dependent in part on credit and ratings. Our securities have been rated by S&P 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 Moody’s
Issuer Credit Rating BBB Baa1
Commercial Paper A-2 P-2
First Mortgage Bonds (a) A2
(a) Not rated by S&P.
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.
Common Stock Dividends. ALLETE is committed to providing a competitive dividend to its shareholders while at the same time funding its growth. ALLETE’s long-term objective is to maintain a dividend payout ratio similar to our peers and provide for future dividend increases. Our targeted payout range is between 60 percent and 70 percent. In 2023, we paid out 63 percent (77 percent in 2022; 78 percent in 2021) of our per share earnings in dividends. On January 26, 2024, our Board of Directors declared a dividend of $0.705 per share, which is payable on March 1, 2024, to shareholders of record at the close of business on February 15, 2024.
ALLETE, Inc. 2023 Form 10-K
Capital Requirements
ALLETE’s projected capital expenditures for the years 2024 through 2028 are presented in the following table. Actual capital expenditures may vary from the projections due to changes in forecasted plant maintenance, regulatory decisions or approvals, future environmental requirements, base load growth, capital market conditions or executions of new business strategies. Projected capital expenditures exclude amounts for projects that will be sold to third parties upon completion.
Capital Expenditures 2024 2025 2026 2027 2028 Total
Millions
Regulated Operations
High kV Transmission Expansion (a)
$45 $80 $215 $480 $705 $1,525
Solar RFP (b)
35 130 300 100 75 640
Wind RFP (b)
5 105 215 300 - 625
Storage (b)
- 10 10 10 100 130
Base & Other 225 215 235 270 190 1,135
Regulated Operations 310 540 975 1,160 1,070 4,055
ALLETE Clean Energy (c)
15 5 5 5 5 35
Corporate and Other
South Shore Energy (d)
40 55 40 40 10 185
Other 10 15 10 20 15 70
Total Capital Expenditures (e)
$375 $615 $1,030 $1,225 $1,100 $4,345
(a)This includes capital expenditures for the HVDC modernization, Northland Reliability, Duluth Loop and Big Stone South transmission projects. (See Outlook - Transmission.)
(b)These capital expenditures are part of Minnesota Power’s clean-energy transition plans, which include its vision to deliver 100 percent carbon-free energy to customers by 2050, as detailed in Minnesota Power’s latest IRP, which was approved by the MPUC in January 2023. These capital expenditures are dependent on successful requests for proposal by Minnesota Power. (See Outlook - EnergyForward.)
(c)Capital expenditures do not include costs related to developing projects that will be sold upon completion as these costs are accounted for as inventory and reflected in Inventories - Net on the Consolidated Balance Sheet.
(d)Our portion of estimated capital expenditures for construction of NTEC, an approximately 600 MW proposed combined-cycle natural gas-fired generating facility to be built in Superior, Wisconsin, which will be jointly owned by Dairyland Power Cooperative, Basin and South Shore Energy.
(e)These amounts do not include capital expenditures for projects considered to be in their preliminary stages.
We are well positioned to meet our financing needs due to adequate operating cash flows, available additional working capital and access to capital markets. We will finance capital expenditures from a combination of internally generated funds, debt and equity issuance proceeds. We intend to maintain a capital structure with capital ratios near current levels. (See Capital Structure.)
Environmental and Other 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 9. Commitments, Guarantees and Contingencies.)
Market Risk
Securities Investments.
Available-for-Sale Securities. As of December 31, 2023, our available-for-sale securities portfolio consisted primarily of securities held in other postretirement plans to fund employee benefits.
ALLETE, Inc. 2023 Form 10-K
Market Risk (Continued)
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. The following table presents the long-term debt obligations and the corresponding weighted average interest rate as of December 31, 2023:
Expected Maturity Date
Interest Rate Sensitive
Financial Instruments 2024 2025 2026 2027 2028 Thereafter Total Fair Value
Long-Term Debt
Fixed Rate - Millions $94.1 $216.9 $80.2 $162.5 $55.8 $1,144.8 $1,754.3 $1,625.5
Average Interest Rate - % 3.4 3.4 3.5 4.5 3.6 4.2 4.1
Variable Rate - Millions $17.3 $27.8 - - - - $45.1 $45.1
Average Interest Rate - % 8.9 3.9 - - - - 5.8
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 December 31, 2023, an increase of 100 basis points in interest rates would impact the amount of pre-tax interest expense by $0.5 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 December 31, 2023.
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.
Recently Adopted Accounting Pronouncements.
New accounting pronouncements are discussed in Note 1. Operations and Significant Accounting Policies.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Item 7A. Quantitative and Qualitative Disclosures about Market Risk
See Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Market Risk for information related to quantitative and qualitative disclosure about market risk.
ALLETE, Inc. 2023 Form 10-K

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Item 8. Financial Statements and Supplementary Data
See our Consolidated Financial Statements as of December 31, 2023 and 2022, and for the years ended December 31, 2023, 2022 and 2021, and supplementary data, which are indexed in Item 15(a).

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
Not applicable.

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ITEM 9A. CONTROLS AND PROCEDURES
Item 9A. Controls and Procedures
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
As of December 31, 2023, 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.
Management’s Report on Internal Control Over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f) or 15d-15(f). Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the Internal Control - Integrated Framework (framework) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the framework, our management concluded that our internal control over financial reporting was effective as of December 31, 2023.
The effectiveness of the Company’s internal control over financial reporting as of December 31, 2023, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report which is included herein.
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.

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ITEM 9B. OTHER INFORMATION
Item 9B. Other Information
Trading Plans. For the three months ended December 31, 2023, no director or officer of the Company adopted, modified 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.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Item 10. Directors, Executive Officers and Corporate Governance
Unless otherwise stated, the information required by this Item is incorporated by reference herein from our Proxy Statement for the 2024 Annual Meeting of Shareholders (2024 Proxy Statement) under the following headings:
•Directors. The information regarding directors will be included in the “Election of Directors” section;
•Audit Committee Financial Expert. The information regarding the Audit Committee financial expert will be included in the “Corporate Governance” section and the “Audit Committee Report” section;
•Audit Committee Members. The identity of the Audit Committee members will be included in the “Corporate Governance” section and the “Audit Committee Report” section;
•Executive Officers. The information regarding executive officers is included in Part I of this Form 10-K; and
•Section 16(a) Delinquency. If applicable, information regarding Section 16(a) delinquencies will be included in a “Delinquent Section 16(a) Reports” section.
Our 2024 Proxy Statement will be filed with the SEC within 120 days after the end of our 2023 fiscal year.
Code of Ethics. We have adopted a written Code of Ethics that applies to all of our employees, including our Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer. A copy of our Code of Ethics is available on our website at www.allete.com and print copies are available without charge upon request to ALLETE, Inc., Attention: Secretary, 30 West Superior St., Duluth, Minnesota 55802. Any amendment to the Code of Ethics or any waiver of the Code of Ethics will be disclosed on our website at www.allete.com promptly following the date of such amendment or waiver.
Corporate Governance. The following documents are available on our website at www.allete.com and print copies are available upon request:
•Corporate Governance Guidelines;
•Audit Committee Charter;
•Executive Compensation and Human Capital Committee Charter; and
•Corporate Governance and Nominating Committee Charter.
Any amendment to these documents will be disclosed on our website at www.allete.com promptly following the date of such amendment.

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ITEM 11. EXECUTIVE COMPENSATION
Item 11. Executive Compensation
The information required by this Item is incorporated by reference herein from the “Compensation Discussion and Analysis,” the “Compensation Committee Report,” the “Director Compensation” and the “Pay Versus Performance” sections in our 2024 Proxy Statement.
Information concerning the Company’s policy regarding incentive-based compensation received by current and former officers in the event of a required accounting restatement is included in Exhibit 97 to this Form 10-K.
ALLETE, Inc. 2023 Form 10-K

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
The information required by this Item is incorporated by reference herein from the “Ownership of ALLETE Common Stock - Securities Owned by Certain Beneficial Owners” and the “Ownership of ALLETE Common Stock - Securities Owned by Directors and Management” sections in our 2024 Proxy Statement.
Securities Authorized for Issuance Under Equity Compensation Plans
The following table sets forth the shares of ALLETE common stock available for issuance under the Company's equity compensation plans as of December 31, 2023:
Plan Category Number of Securities to be Issued Upon Exercise of Outstanding Options, Warrants, and Rights (a)
Weighted-Average Exercise Price of Outstanding Options, Warrants, and Rights (b)
Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans (c)
Equity Compensation Plans Approved by Security Holders 189,646 - 917,149
Equity Compensation Plans Not Approved by Security Holders - - -
Total 189,646 - 917,149
(a) Includes the following as of December 31, 2023: (i) 29,751 securities representing the performance shares (including accrued dividends) granted under the executive long-term incentive compensation plan that vested but were not paid as of December 31, 2023; (ii) 81,747 securities representing the target number of performance share awards (including accrued dividends) granted under the executive long-term incentive compensation plan that were unvested; and (iii) 78,148 director deferred stock units (including accrued dividends) under the non-employee director compensation deferral plan. With respect to unvested performance share awards, the actual number of shares to be issued will vary from 0 percent to 200 percent of the target level depending upon the achievement of total shareholder return objectives established for such awards. For additional information about the performance shares, including payout calculations, see our 2024 Proxy Statement.
(b) Earned performance share awards are paid in shares of ALLETE common stock on a one-for-one basis. Accordingly, these awards do not have a weighted-average exercise price.
(c) Excludes the number of securities shown in the first column as to be issued upon exercise of outstanding options, warrants, and rights. The amount shown is comprised of: (i) 593,992 shares available for issuance under the executive long-term incentive compensation plan in the form of options, rights, restricted stock units, performance share awards, and other grants as approved by the Executive Compensation Committee of the Company’s Board of Directors; (ii) 274,834 shares available for issuance under the Non-Employee Director Stock Plan as payment for a portion of the annual retainer payable to non-employee Directors; and (iii) 48,323 shares available for issuance under the ALLETE and Affiliated Companies Employee Stock Purchase Plan.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Item 13. Certain Relationships and Related Transactions, and Director Independence
The information required by this Item is incorporated by reference herein from the “Corporate Governance” section in our 2024 Proxy Statement.
We have adopted a Related Person Transaction Policy which is available on our website at www.allete.com. Print copies are available without charge, upon request. Any amendment to this policy will be disclosed on our website at www.allete.com promptly following the date of such amendment.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. Principal Accountant Fees and Services
Our independent registered public accounting firm is PricewaterhouseCoopers LLP, Minneapolis, MN, PCAOB ID: 238.
The information required by this Item is incorporated by reference herein from the “Audit Committee Report” section in our 2024 Proxy Statement.
ALLETE, Inc. 2023 Form 10-K
Part IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Item 15. Exhibits and Financial Statement Schedules
(a) Certain Documents Filed as Part of this Form 10-K.
(1) Financial Statements Page
ALLETE
Report of Independent Registered Public Accounting Firm
Consolidated Balance Sheet as of December 31, 2023 and 2022
For the Years Ended December 31, 2023, 2022 and 2021
Consolidated Statement of Income
Consolidated Statement of Comprehensive Income
Consolidated Statement of Cash Flows
Consolidated Statement of Equity
Notes to Consolidated Financial Statements
(2) Financial Statement Schedules
Schedule II - ALLETE Valuation and Qualifying Accounts and Reserves
All other schedules have been omitted either because the information is not required to be reported by ALLETE or because the information is included in the Consolidated Financial Statements or the notes.
(3) Exhibits including those incorporated by reference.
Exhibit Number
*3(a)1
- Articles of Incorporation, amended and restated as of May 8, 2001 (filed as Exhibit 3(b) to the March 31, 2001, Form 10-Q, File No. 1-3548).
*3(a)2
- Amendment to Articles of Incorporation, dated as of September 20, 2004 (filed as Exhibit 3 to the September 21, 2004, Form 8-K, File No. 1-3548).
*3(a)3
- Amendment to Articles of Incorporation, dated as of May 12, 2009 (filed as Exhibit 3 to the June 30, 2009, Form 10-Q, File No. 1-3548).
*3(a)4
- Amendment to Articles of Incorporation, dated as of May 11, 2010 (filed as Exhibit 3(a) to the May 14, 2010, Form 8-K, File No. 1-3548).
*3(a)5
- Amendment to Certificate of Assumed Name, filed with the Minnesota Secretary of State on May 8, 2001 (filed as Exhibit 3(a) to the March 31, 2001, Form 10-Q, File No. 1-3548).
*3(b)
Bylaws, as amended effective April 13, 2020 (filed as Exhibit 3 to the April 14, 2020, Form 8-K, File No. 1-3548).
*4(a)1 - Mortgage and Deed of Trust, dated as of September 1, 1945, between Minnesota Power & Light Company (now ALLETE) and The Bank of New York Mellon (formerly Irving Trust Company) and Janet Lee (successor to Richard H. West), Trustees (filed as Exhibit 7(c), File No. 2-5865).
*4(a)2 - Supplemental Indentures to ALLETE’s Mortgage and Deed of Trust:
Number Dated as of Reference File Exhibit
First March 1, 1949 2-7826 7(b)
Second July 1, 1951 2-9036 7(c)
Third March 1, 1957 2-13075 2(c)
Fourth January 1, 1968 2-27794 2(c)
Fifth April 1, 1971 2-39537 2(c)
Sixth August 1, 1975 2-54116 2(c)
Seventh September 1, 1976 2-57014 2(c)
Eighth September 1, 1977 2-59690 2(c)
Ninth April 1, 1978 2-60866 2(c)
Tenth August 1, 1978 2-62852 2(d)2
Eleventh December 1, 1982 2-56649 4(a)3
Twelfth April 1, 1987 33-30224 4(a)3
Thirteenth March 1, 1992 33-47438 4(b)
Fourteenth June 1, 1992 33-55240 4(b)
Fifteenth July 1, 1992 33-55240 4(c)
Sixteenth July 1, 1992 33-55240 4(d)
ALLETE, Inc. 2023 Form 10-K
Exhibit Number
Seventeenth February 1, 1993 33-50143 4(b)
Eighteenth July 1, 1993 33-50143 4(c)
Nineteenth
February 1, 1997
1-3548 (1996 Form 10-K)
4(a)3
Twentieth
November 1, 1997
1-3548 (1997 Form 10-K)
4(a)3
Twenty-first
October 1, 2000
333-54330
4(c)3
Twenty-second
July 1, 2003
1-3548 (June 30, 2003, Form 10-Q)
Twenty-third
August 1, 2004
1-3548 (Sept. 30, 2004, Form 10-Q)
4(a)
Twenty-fourth
March 1, 2005
1-3548 (March 31, 2005, Form 10-Q)
Twenty-fifth
December 1, 2005
1-3548 (March 31, 2006, Form 10-Q)
Twenty-sixth
October 1, 2006
1-3548 (2006 Form 10-K)
4(a)3
Twenty-seventh
February 1, 2008
1-3548 (2007 Form 10-K)
4(a)3
Twenty-eighth
May 1, 2008
1-3548 (June 30, 2008, Form 10-Q)
Twenty-ninth
November 1, 2008
1-3548 (2008 Form 10-K)
4(a)3
Thirtieth
January 1, 2009
1-3548 (2008 Form 10-K)
4(a)4
Thirty-first
February 1, 2010
1-3548 (March 31, 2010, Form 10-Q)
Thirty-second
August 1, 2010
1-3548 (Sept. 30, 2010, Form 10-Q)
Thirty-third
July 1, 2012
1-3548 (July 2, 2012, Form 8-K)
Thirty-fourth
April 1, 2013
1-3548 (April 2, 2013, Form 8-K)
Thirty-fifth
March 1, 2014
1-3548 (March 31, 2014, Form 10-Q)
Thirty-sixth
June 1, 2014
1-3548 (June 30, 2014, Form 10-Q)
Thirty-seventh
September 1, 2014
1-3548 (Sept. 30, 2014, Form 10-Q)
Thirty-eighth
September 1, 2015
1-3548 (Sept. 30, 2015, Form 10-Q)
4(a)
Thirty-ninth
April 1, 2018
1-3548 (March 31, 2018, Form 10-Q)
Fortieth
March 1, 2019
1-3548 (March 31, 2019, Form 10-Q)
4(a)
Forty-first
August 1, 2020
1-3548 (Sept. 30, 2020, Form 10-Q)
4(a)
Forty-second
September 1, 2021
1-3548 (Sept. 30, 2021, Form 10-Q)
Forty-third
August 1, 2022
1-3548 (Sept. 30, 2022, Form 10-Q)
Forty-fourth
April 1, 2023
1-3548 (June 30, 2023, Form 10-Q)
*4(b)1 - Mortgage and Deed of Trust, dated as of March 1, 1943, between Superior Water, Light and Power Company and Chemical Bank & Trust Company and Howard B. Smith, as Trustees, both succeeded by U.S. Bank National Association, as Trustee (filed as Exhibit 7(c), File No. 2-8668).
*4(b)2 - Supplemental Indentures to Superior Water, Light and Power Company’s Mortgage and Deed of Trust:
Number Dated as of Reference File Exhibit
First March 1, 1951 2-59690 2(d)(1)
Second March 1, 1962 2-27794 2(d)1
Third July 1, 1976 2-57478 2(e)1
Fourth March 1, 1985 2-78641 4(b)
Fifth December 1, 1992 1-3548 (1992 Form 10-K) 4(b)1
Sixth
March 24, 1994
1-3548 (1996 Form 10-K)
4(b)1
Seventh
November 1, 1994
1-3548 (1996 Form 10-K)
4(b)2
Eighth
January 1, 1997
1-3548 (1996 Form 10-K)
4(b)3
Ninth
October 1, 2007
1-3548 (2007 Form 10-K)
4(c)3
Tenth
October 1, 2007
1-3548 (2007 Form 10-K)
4(c)4
Eleventh
December 1, 2008
1-3548 (2008 Form 10-K)
4(c)3
Twelfth
December 2, 2013
1-3548 (2013 Form 10-K)
4(c)3
Thirteenth
May 29, 2018
1-3548 (June 30, 2018, Form 10-Q)
Fourteenth
June 14, 2021
1-3548 (June 30, 2021, Form 10-Q)
4(a)
Fifteenth
June 14, 2021
1-3548 (June 30, 2021, Form 10-Q)
4(b)
*4(c)
- Note Purchase and Guarantee Agreement dated as of November 5, 2015, among Armenia Mountain Wind LLC, AMW I Holding, LLC and the purchasers named therein (filed as Exhibit 4 to the November 12, 2015, Form 8-K, File No. 1-3548).
ALLETE, Inc. 2023 Form 10-K
Exhibit Number
*4(d)
- Note Purchase Agreement, dated December 8, 2016, between ALLETE and Hartford Investment Management Company, Northwestern Mutual Investment Management Company, The Northwestern Mutual Life Insurance Company and Nationwide Life insurance Company (filed as Exhibit 4 to the December 12, 2016, Form 8-K, File No. 1-3548).
*4(e)
- Note Purchase Agreement, dated September 10, 2020, between ALLETE and the purchasers named therein (filed as Exhibit 4 to the September 30, 2020, Form 10-Q, File No. 1-3548).
*4(f)
- Description of Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934 (filed as Exhibit 4(h) to the 2019 Form 10-K, File No. 1-3548).
*10(a)
- Power Purchase and Sale Agreement, dated as of May 29, 1998, between Minnesota Power, Inc. (now ALLETE) and Square Butte Electric Cooperative (filed as Exhibit 10 to the June 30, 1998, Form 10-Q, File No. 1-3548).
*10(b)1
- Amended and Restated Credit Agreement dated as of January 10, 2019 among ALLETE, as Borrower, the lenders party thereto, JPMorgan Chase Bank, N.A., as Administrative Agent, and J.P. Morgan Chase Bank, N.A., as Sole Lead Arranger and Sole Book Runner (filed as Exhibit 10(b)2 to the 2018 Form 10-K, File No. 1-3548).
*10(b)2
- First Amendment to Credit Agreement dated May 15, 2019, among ALLETE, as Borrower, the lenders party thereto, and JPMorgan Chase Bank, N.A., as Administrative Agent (filed as Exhibit 4 to the June 30, 2019, Form 10-Q, File No. 1-3548).
*10(b)3
- Second Amendment to Credit Agreement dated November 23, 2021, among ALLETE, as Borrower, the lenders party thereto, and JPMorgan Chase Bank, N.A., as Administrative Agent. (filed as Exhibit 10(b)3 to the 2021 Form 10-K, File No. 1-3548).
*10(b)4
- Third Amendment to Credit Agreement dated as of October 17, 2023, among ALLETE, as Borrower, the lenders party thereto, and JPMorgan Chase Bank, N.A., as Administrative Agent. (filed as Exhibit 10 to the Sept. 30, 2023, Form 10-Q, File No. 1-3548).
*10(c)1
- Financing Agreement between Collier County Industrial Development Authority and ALLETE dated as of July 1, 2006 (filed as Exhibit 10(b)1 to the June 30, 2006, Form 10-Q, File No. 1-3548).
*10(c)2
- Amended and Restated Letter of Credit Agreement, dated as of June 3, 2011, among ALLETE, the participating banks and Wells Fargo Bank, National Association, as Administrative Agent and Issuing Bank (filed as Exhibit 10(b) to the June 30, 2011, Form 10-Q, File No. 1-3548).
*10(c)3
- First Amendment to Amended and Restated Letter of Credit Agreement, dated as of June 1, 2013, between ALLETE and Wells Fargo Bank, National Association, as Issuing Bank, Administrative Agent and Sole Participating Bank (filed as Exhibit 10(b) to the June 30, 2013, Form 10-Q, File No. 1-3548).
*10(d)
- Agreement dated December 16, 2005, among ALLETE, Wisconsin Public Service Corporation and WPS Investments, LLC (filed as Exhibit 10(g) to the 2009 Form 10-K, File No. 1-3548).
*+10(e)1
- ALLETE Executive Annual Incentive Plan, as amended and restated, effective January 1, 2011 (filed as Exhibit 10(h)1 to the 2010 Form 10-K, File No. 1-3548).
*+10(e)2
- ALLETE Executive Annual Incentive Plan Form of Award Effective 2020 (filed as Exhibit 10(e)8 to the 2019 Form 10-K, File No. 1-3548).
*+10(e)3
- ALLETE Executive Annual Incentive Plan Form of Award Effective 2021 (filed as Exhibit 10(e)8 to the 2020 Form 10-K, File No. 1-3548).
*+10(e)4
- ALLETE Executive Annual Incentive Plan Form of Award Effective 2022 (filed as Exhibit 10(e)9 to the 2021 Form 10-K, File No. 1-3548).
*+10(e)5
- ALLETE Executive Annual Incentive Plan Form of Award Effective 2023 (filed as Exhibit 10(e)8 to the 2022 Form 10-K, File No. 1-3548).
*+10(e)6
- ALLETE Executive Annual Incentive Plan Form of Award ALLETE Clean Energy Effective 2023 (filed as Exhibit 10(e)9 to the 2022 Form 10-K, File No. 1-3548).
+10(e)7
- ALLETE Executive Annual Incentive Plan, as amended and restated, effective December 21, 2023.
+10(e)8
- ALLETE Executive Annual Incentive Plan Form of Award Effective 2024.
+10(e)9
- ALLETE Executive Annual Incentive Plan Form of Award ALLETE Clean Energy Effective 2024.
*+10(f)1
- ALLETE and Affiliated Companies Supplemental Executive Retirement Plan (SERP I), as amended and restated, effective January 1, 2009 (filed as Exhibit 10(i)4 to the 2008 Form 10-K, File No. 1-3548).
*+10(f)2
- Amendment to the ALLETE and Affiliated Companies Supplemental Executive Retirement Plan (SERP I), effective January 1, 2011 (filed as Exhibit 10(i)2 to the 2010 Form 10-K, File No. 1-3548).
*+10(f)3
- ALLETE and Affiliated Companies Supplemental Executive Retirement Plan II (SERP II), as amended and restated, effective January 1, 2021 (filed as Exhibit 10(f)5 to the 2021 Form 10-K, File No. 1-3548).
+10(f)4
- ALLETE and Affiliated Companies Supplemental Executive Retirement Plan II (SERP II), as amended and restated, effective October 27, 2023.
*+10(g)
- ALLETE Deferred Compensation Trust Agreement, as amended and restated, effective December 15, 2012 (filed as Exhibit 10(j) to the 2012 Form 10-K, File No. 1-3548).
*+10(h)1
- ALLETE Executive Long-Term Incentive Compensation Plan effective January 1, 2016 (filed November 6, 2015, as Exhibit 99 to Form S-8, File No. 333-207846).
*+10(h)2
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Cash Award Effective 2018 (filed as Exhibit 10(b) to the March 31, 2018, Form 10-Q, File No. 1-3548).
ALLETE, Inc. 2023 Form 10-K
Exhibit Number
*+10(h)3
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Restricted Stock Unit Grant Effective 2018 (filed as Exhibit 10(i)7 to the 2017 Form 10-K, File No. 1-3548).
*+10(h)4
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Performance Share Grant Effective 2018 (filed as Exhibit 10(i)8 to the 2017 Form 10-K, File No. 1-3548).
*+10(h)5
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Restricted Stock Unit Grant Effective 2019 (filed as Exhibit 10(i)10 to the 2018 Form 10-K, File No. 1-3548).
*+10(h)6
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Performance Share Grant Effective 2019 (filed as Exhibit 10(i)11 to the 2018 Form 10-K, File No. 1-3548).
*+10(h)7
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Restricted Stock Unit Grant Effective 2020 (filed as Exhibit 10(i)12 to the 2019 Form 10-K, File No. 1-3548).
*+10(h)8
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Performance Share Grant Effective 2020 (filed as Exhibit 10(i)13 to the 2019 Form 10-K, File No. 1-3548).
*+10(h)9
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Restricted Stock Unit Grant Effective 2021 (filed as Exhibit 10(i)14 to the 2020 Form 10-K, File No. 1-3548).
*+10(h)10
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Performance Share Grant Effective 2021 (filed as Exhibit 10(i)15 to the 2020 Form 10-K, File No. 1-3548).
*+10(h)11
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Restricted Stock Unit Grant Effective 2022 (filed as Exhibit 10(i)17 to the 2021 Form 10-K, File No. 1-3548).
*+10(h)12
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Performance Share Grant Effective 2022 (filed as Exhibit 10(i)18 to the 2021 Form 10-K, File No. 1-3548).
*+10(h)13
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Restricted Stock Unit Grant Effective 2023 (filed as Exhibit 10(h)16 to the 2022 Form 10-K, File No. 1-3548).
*+10(h)14
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Performance Share Grant Effective 2023 (filed as Exhibit 10(h)17 to the 2022 Form 10-K, File No. 1-3548).
+10(h)15
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Restricted Stock Unit Grant Effective 2024.
+10(h)16
- Form of ALLETE Executive Long-Term Incentive Compensation Plan Performance Share Grant Effective 2024.
*+10(i)1
- Amended and Restated ALLETE Non-Employee Director Stock Plan, effective May 15, 2013 (filed as Exhibit 10(a) to the June 30, 2013, Form 10-Q, File No. 1-3548).
*+10(i)2
- ALLETE Non-Employee Director Stock Plan (As Amended and Restated Effective May 10, 2022) (filed as Exhibit 99, File No. 333-265211).
*+10(j)3
- ALLETE Non-Employee Director Compensation Summary effective January 1, 2020 (filed as Exhibit 10(k)3 to the 2020 Form 10-K, File No. 1-3548).
*+10(j)4
- ALLETE Non-Employee Director Compensation Summary effective January 1, 2022 (filed as Exhibit 10(k)4 to the 2021 Form 10-K, File No. 1-3548).
*+10(j)5
- Amended and Restated ALLETE Non-Employee Director Stock Plan, effective May 10, 2022 (filed as Exhibit 99 to Form S-8, File No. 333-265211).
+10(j)6
- ALLETE Non-Employee Director Compensation Summary effective January 1, 2023 (filed as Exhibit 10(j)6 to the 2022 Form 10-K, File No. 1-3548).
*+10(k)1
- Minnesota Power (now ALLETE) Director Compensation Deferral Plan Amended and Restated, effective January 1, 1990 (filed as Exhibit 10(ac) to the 2002 Form 10-K, File No. 1-3548).
*+10(k)2
- Amendment to the Minnesota Power (now ALLETE) Director Compensation Deferral Plan, effective October 1, 2003 (filed as Exhibit 10(aa)2 to the 2003 Form 10-K, File No. 1-3548).
*+10(k)3
- Amendment to the ALLETE Director Compensation Deferral Plan, effective January 1, 2005 (filed as Exhibit 10(c) to the March 31, 2005, Form 10-Q, File No. 1-3548).
*+10(k)4
- Amendment to the ALLETE Director Compensation Deferral Plan, effective October 1, 2006 (filed as Exhibit 10(d) to the September 30, 2006, Form 10-Q, File No. 1-3548).
*+10(k)5
- Amendment to the ALLETE Director Compensation Deferral Plan, effective July 24, 2012 (filed as Exhibit 10(n)5 to the 2012 Form 10-K, File No. 1-3548).
*+10(l)1
- ALLETE Non-Employee Director Compensation Deferral Plan II, effective May 1, 2009 (filed as Exhibit 10(a) to the June 30, 2009, Form 10-Q, File No. 1-3548).
*+10(l)2
- ALLETE Non-Employee Director Compensation Deferral Plan II, as amended and restated, effective July 24, 2012 (filed as Exhibit 10(o)2 to the 2012 Form 10-K, File No. 1-3548).
*+10(m)
- ALLETE Non-Employee Director Compensation Trust Agreement, as amended and restated, effective December 15, 2012 (filed as Exhibit 10(p)2 to the 2012 Form 10-K, File No. 1-3548).
*+10(n)1
- ALLETE and Affiliated Companies Change in Control Severance Plan, as amended and restated, effective April 23, 2018 (filed as Exhibit 10(c) to the March 31, 2018, Form 10-Q, File No. 1-3548).
ALLETE, Inc. 2023 Form 10-K
Exhibit Number
+10(n)2
- ALLETE and Affiliated Companies Change in Control Severance Plan, as amended and restated, effective October 27, 2023.
- Subsidiaries of the Registrant.
- Consent of Independent Registered Public Accounting Firm.
31(a)
- Rule 13a-14(a)/15d-14(a) Certification by the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31(b)
- Rule 13a-14(a)/15d-14(a) Certification by the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
- Section 1350 Certification of Annual Report by the Chief Executive Officer and Chief Financial Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
- Mine Safety.
- Policy Relating to Recovery of Erroneously Awarded Compensation.
- ALLETE News Release dated February 20, 2024, announcing earnings for the year ended December 31, 2023. (This exhibit has been furnished and shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, nor shall it be deemed incorporated by reference in any filing under the Securities Act of 1933, except as shall be expressly set forth by specific reference in such filing.)
101.INS - XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH - XBRL Schema
101.CAL - XBRL Calculation
101.DEF - XBRL Definition
101.LAB - XBRL Label
101.PRE - XBRL Presentation
104 - Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, other long-term debt instruments are not filed as exhibits because the total amount of debt authorized under each omitted instrument does not exceed 10 percent of our total consolidated assets. We will furnish copies of these instruments to the SEC upon its request.
* Incorporated herein by reference as indicated.
+ Management contract or compensatory plan or arrangement pursuant to Item 15(b).