UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2022

OR

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ________________ to ___________________

Commission File Number	Registrant; State of Incorporation; Address; and Telephone Number	IRS Employer Identification No.
001-03016	WISCONSIN PUBLIC SERVICE CORPORATION	39-0715160

(A Wisconsin Corporation)

2830 South Ashland Avenue

P.O. Box 19001

Green Bay, WI 54307-9001

(800) 450-7260

Securities registered pursuant to Section 12(b) of the Act:

None

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

    Yes ☒    No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

    Yes ☒    No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer	☐	Accelerated filer	☐
Non-accelerated filer	☒	Smaller reporting company		☐
		Emerging growth company		☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

    Yes ☐    No ☒

Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date:

Common Stock, $4 par value,

23,896,962 shares outstanding at

June 30, 2022

All of the common stock of Wisconsin Public Service Corporation is held by Integrys Holding, Inc., a wholly owned subsidiary of WEC Energy Group, Inc.

WISCONSIN PUBLIC SERVICE CORPORATION

QUARTERLY REPORT ON FORM 10-Q

For the Quarter Ended June 30, 2022

TABLE OF CONTENTS

				Page
	CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION			1
PART I.	FINANCIAL INFORMATION			3
ITEM 1.	FINANCIAL STATEMENTS (UNAUDITED)			3
	Condensed Income Statements			3
	Condensed Balance Sheets			4
	Condensed Statements of Cash Flows			5
	Condensed Statements of Equity			6
	Notes to Condensed Financial Statements			7
			Page
	Note 1	General Information	7
	Note 2	Acquisition	7
	Note 3	Operating Revenues	8
	Note 4	Credit Losses	9
	Note 5	Regulatory Assets and Liabilities	10
	Note 6	Property, Plant, and Equipment	11
	Note 7	Common Equity	11
	Note 8	Short-Term Debt and Lines of Credit	12
	Note 9	Leases	12
	Note 10	Materials, Supplies, and Inventories	13
	Note 11	Income Taxes	13
	Note 12	Fair Value Measurements	14
	Note 13	Derivative Instruments	16
	Note 14	Guarantees	17
	Note 15	Employee Benefits	17
	Note 16	Goodwill	17
	Note 17	Segment Information	17
	Note 18	Commitments and Contingencies	19
	Note 19	Supplemental Cash Flow Information	23
	Note 20	Regulatory Environment	23
	Note 21	New Accounting Pronouncements	24
ITEM 2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS			25
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK			41
ITEM 4.	CONTROLS AND PROCEDURES			42
PART II.	OTHER INFORMATION			43
ITEM 1.	LEGAL PROCEEDINGS			43
ITEM 1A.	RISK FACTORS			43
ITEM 6.	EXHIBITS			43
SIGNATURE				44

06/30/2022 Form 10-Q i Wisconsin Public Service Corporation

GLOSSARY OF TERMS AND ABBREVIATIONS

The abbreviations and terms set forth below are used throughout this report and have the meanings assigned to them below:

Affiliates
ATC	American Transmission Company LLC
Integrys	Integrys Holding, Inc.
WE	Wisconsin Electric Power Company
WEC Energy Group	WEC Energy Group, Inc.
Federal and State Regulatory Agencies
CBP	United States Customs and Border Protection Agency
DOC	United States Department of Commerce
EPA	United States Environmental Protection Agency
PSCW	Public Service Commission of Wisconsin
SEC	United States Securities and Exchange Commission
WDNR	Wisconsin Department of Natural Resources
Accounting Terms
AFUDC	Allowance for Funds Used During Construction
ASU	Accounting Standards Update
FASB	Financial Accounting Standards Board
GAAP	United States Generally Accepted Accounting Principles
OPEB	Other Postretirement Employee Benefits
Environmental Terms
ACE	Affordable Clean Energy
BATW	Bottom Ash Transport Water
BTA	Best Technology Available
CAA	Clean Air Act
CASAC	Clean Air Scientific Advisory Committee
CO2	Carbon Dioxide
ELG	Steam Electric Effluent Limitation Guidelines
GHG	Greenhouse Gas
NAAQS	National Ambient Air Quality Standards
NOV	Notice of Violation
NOx	Nitrogen Oxide
WOTUS	Waters of the United States
WPDES	Wisconsin Pollutant Discharge Elimination System
Measurements
Dth	Dekatherm
MW	Megawatt
MWh	Megawatt-hour
µg/m3	Micrograms Per Cubic Meter
Other Terms and Abbreviations
AD/CVD	Antidumping and Countervailing Duties
AMI	Advanced Metering Infrastructure
Badger Hollow I	Badger Hollow Solar Park I
Chicago, IL-IN-WI	Chicago, Illinois, Indiana, and Wisconsin
COVID-19	Coronavirus Disease – 2019
D.C. Circuit Court of Appeals	United States Court of Appeals for the District of Columbia Circuit
Darien	Darien Solar-Battery Park
EGU	Electric Generating Unit
ESG Progress Plan	WEC Energy Group's Capital Investment Plan for Efficiency, Sustainability, and Growth for 2022-2026

06/30/2022 Form 10-Q ii Wisconsin Public Service Corporation

EV	Electric Vehicle
Exchange Act	Securities Exchange Act of 1934, as amended
Executive Order 13990	Executive Order 13990 of January 20, 2021 – Protecting Public Health and the Environment and Restoring Science To Tackle the Climate Crisis
FTR	Financial Transmission Right
ITC	Investment Tax Credit
LIBOR	London Interbank Offered Rate
MISO	Midcontinent Independent System Operator, Inc.
Paris	Paris Solar-Battery Park
PTC	Production Tax Credit
RICE	Reciprocating Internal Combustion Engine
RNG	Renewable Natural Gas
ROE	Return on Equity
S&P	Standard & Poor's
Supreme Court	United States Supreme Court
Tax Legislation	Tax Cuts and Jobs Act of 2017
UFLPA	Uyghur Forced Labor Prevention Act
West Riverside	West Riverside Energy Center
Whitewater	Whitewater Cogeneration Facility
WRO	Withhold Release Order

06/30/2022 Form 10-Q iii Wisconsin Public Service Corporation

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

In this report, we make statements concerning our expectations, beliefs, plans, objectives, goals, strategies, and future events or performance. These statements are "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Exchange Act. Readers are cautioned not to place undue reliance on these forward-looking statements. Forward-looking statements may be identified by reference to a future period or periods or by the use of terms such as "anticipates," "believes," "could," "estimates," "expects," "forecasts," "goals," "guidance," "intends," "may," "objectives," "plans," "possible," "potential," "projects," "seeks," "should," "targets," "will," or variations of these terms.

Forward-looking statements include, among other things, statements concerning management's expectations and projections regarding earnings, completion of capital projects, sales and customer growth, rate actions and related filings with regulatory authorities, environmental and other regulations, including associated compliance costs, legal proceedings, effective tax rates, pension and OPEB plans, fuel costs, sources of electric energy supply, coal and natural gas deliveries, remediation costs, climate-related matters, the ESG Progress Plan, liquidity and capital resources, and other matters.

Forward-looking statements are subject to a number of risks and uncertainties that could cause our actual results to differ materially from those expressed or implied in the statements. These risks and uncertainties include those described in risk factors as set forth in our 2021 Annual Report on Form 10-K, and those identified below:

•Factors affecting utility operations such as catastrophic weather-related damage, environmental incidents, unplanned facility outages and repairs and maintenance, and electric transmission or natural gas pipeline system constraints;

•Factors affecting the demand for electricity and natural gas, including political or regulatory developments, varying, adverse, or unusually severe weather conditions, including those caused by climate change, changes in economic conditions, customer growth and declines, commodity prices, energy conservation efforts, and continued adoption of distributed generation by customers;

•The timing, resolution, and impact of rate cases and negotiations, including recovery of deferred and current costs and the ability to earn a reasonable return on investment, and other regulatory decisions impacting our regulated operations;

•The impact of federal, state, and local legislative and/or regulatory changes, including changes in rate-setting policies or procedures, deregulation and restructuring of the electric and/or natural gas utility industries, transmission or distribution system operation, the approval process for new construction, reliability standards, pipeline integrity and safety standards, allocation of energy assistance, energy efficiency mandates, and tax laws, including those that affect our ability to use PTCs and ITCs;

•Federal, state, and local legislative and regulatory changes relating to the environment, including climate change and other environmental regulations impacting generation facilities and renewable energy standards, the enforcement of these laws and regulations, changes in the interpretation of regulations or permit conditions by regulatory agencies, and the recovery of associated remediation and compliance costs;

•The ability to obtain and retain customers, including wholesale customers, due to increased competition in our electric and natural gas markets from retail choice and alternative electric suppliers, and continued industry consolidation;

•The timely completion of capital projects within budgets and the ability to recover the related costs through rates;

•The risk of delays and shortages, and increased costs of equipment, materials, or other resources that are critical to our business operations and corporate strategy, as a result of supply chain disruptions (including disruptions from rail congestion), inflation, and other factors;

•The impact of health pandemics, including any new developments relating to the COVID-19 pandemic, on our business functions, financial condition, liquidity, and results of operations;

•Factors affecting the implementation of WEC Energy Group's CO2 emission and/or methane emission reduction goals and opportunities and actions related to those goals, including related regulatory decisions, the cost of materials, supplies, and labor,

06/30/2022 Form 10-Q 1 Wisconsin Public Service Corporation

technology advances, the feasibility of competing generation projects, and the ability to execute WEC Energy Group's capital plan;

•The financial and operational feasibility of taking more aggressive action to further reduce GHG emissions in order to limit future global temperature increases;

•The risks associated with inflation and changing commodity prices, including natural gas and electricity;

•The availability and cost of sources of natural gas and other fossil fuels, purchased power, materials needed to operate environmental controls at our electric generating facilities, or water supply due to high demand, shortages, transportation problems, nonperformance by electric energy or natural gas suppliers under existing power purchase or natural gas supply contracts, or other developments;

•Any impacts on the global economy, supply chains and fuel prices, generally, from the ongoing conflict between Russia and Ukraine and related sanctions;

•Changes in credit ratings, interest rates, and our ability to access the capital markets, caused by volatility in the global credit markets, our capitalization structure, and market perceptions of the utility industry or us;

•Changes in the method of determining LIBOR or the replacement of LIBOR with an alternative reference rate;

•Costs and effects of litigation, administrative proceedings, investigations, settlements, claims, and inquiries;

•The direct or indirect effect on our business resulting from terrorist attacks and cyber security intrusions, as well as the threat of such incidents, including the failure to maintain the security of personally identifiable information, the associated costs to protect our utility assets, technology systems, and personal information, and the costs to notify affected persons to mitigate their information security concerns and to comply with state notification laws;

•The risk of financial loss, including increases in bad debt expense, associated with the inability of our customers, counterparties, and affiliates to meet their obligations;

•Changes in the creditworthiness of the counterparties with whom we have contractual arrangements, including participants in the energy trading markets and fuel suppliers and transporters;

•The investment performance of our employee benefit plan assets, as well as unanticipated changes in related actuarial assumptions, which could impact future funding requirements;

•Factors affecting the employee workforce, including loss of key personnel, internal restructuring, work stoppages, and collective bargaining agreements and negotiations with union employees;

•Advances in technology, and related legislation or regulation supporting the use of that technology, that result in competitive disadvantages and create the potential for impairment of existing assets;

•The risk associated with the values of goodwill, other intangible assets, long-lived assets, and equity method investments, and their possible impairment;

•Potential business strategies to acquire and dispose of assets, which cannot be assured to be completed timely or within budgets;

•The timing and outcome of any audits, disputes, and other proceedings related to taxes;

•The effect of accounting pronouncements issued periodically by standard-setting bodies; and

•Other considerations disclosed elsewhere herein and in other reports we file with the SEC or in other publicly disseminated written documents.

Except as may be required by law, we expressly disclaim any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

06/30/2022 Form 10-Q 2 Wisconsin Public Service Corporation

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

WISCONSIN PUBLIC SERVICE CORPORATION

CONDENSED INCOME STATEMENTS (Unaudited)	Three Months Ended				Six Months Ended
	June 30				June 30
(in millions)	2022		2021		2022		2021
Operating revenues	$	418.5	$	341.2	$	897.4	$	746.5
Operating expenses
Cost of sales	184.7		113.6		412.2		281.7
Other operation and maintenance	94.4		96.4		178.1		191.8
Depreciation and amortization	49.5		46.6		99.2		92.6
Property and revenue taxes	10.7		10.0		21.6		20.2
Total operating expenses	339.3		266.6		711.1		586.3
Operating income	79.2		74.6		186.3		160.2
Other income, net	11.6		10.4		21.7		19.0
Interest expense	16.6		16.3		33.2		32.5
Other expense	(5.0)		(5.9)		(11.5)		(13.5)
Income before income taxes	74.2		68.7		174.8		146.7
Income tax expense	17.6		8.5		41.6		17.2
Net income	$	56.6	$	60.2	$	133.2	$	129.5

The accompanying Notes to Condensed Financial Statements are an integral part of these financial statements.

06/30/2022 Form 10-Q 3 Wisconsin Public Service Corporation

WISCONSIN PUBLIC SERVICE CORPORATION

CONDENSED BALANCE SHEETS (Unaudited)	June 30,		December 31,
(in millions, except share and per share amounts)	2022		2021
Assets
Current assets
Cash and cash equivalents	$	0.3	$	2.4
Accounts receivable and unbilled revenues, net of reserves of $10.8 and $11.1, respectively	248.3		226.6
Accounts receivable from related parties	35.9		26.1
Materials, supplies, and inventories	113.7		112.9
Derivative assets	32.2		22.2
Prepaid taxes	51.7		40.0
Other	8.6		12.3
Current assets	490.7		442.5
Long-term assets
Property, plant, and equipment, net of accumulated depreciation and amortization of $1,838.2 and $1,808.4, respectively	5,211.7		5,098.6
Regulatory assets	353.9		347.9
Goodwill	36.4		36.4
Pension and OPEB assets	279.1		260.7
Other	52.4		49.6
Long-term assets	5,933.5		5,793.2
Total assets	$	6,424.2	$	6,235.7
Liabilities and Equity
Current liabilities
Short-term debt	$	178.5	$	331.0
Accounts payable	184.7		130.8
Accounts payable to related parties	49.1		42.6
Other	116.5		81.4
Current liabilities	528.8		585.8
Long-term liabilities
Long-term debt	1,700.1		1,690.6
Deferred income taxes	832.8		782.2
Deferred ITCs	74.8		74.8
Regulatory liabilities	723.9		735.5
Environmental remediation liabilities	89.5		95.0
Other	132.9		128.8
Long-term liabilities	3,554.0		3,506.9
Commitments and contingencies (Note 18)
Common shareholder's equity
Common stock – $4 par value; 32,000,000 shares authorized; 23,896,962 shares issued and outstanding	95.6		95.6
Additional paid in capital	1,616.7		1,491.5
Retained earnings	629.1		555.9
Common shareholder's equity	2,341.4		2,143.0
Total liabilities and equity	$	6,424.2	$	6,235.7

The accompanying Notes to Condensed Financial Statements are an integral part of these financial statements.

06/30/2022 Form 10-Q 4 Wisconsin Public Service Corporation

WISCONSIN PUBLIC SERVICE CORPORATION

CONDENSED STATEMENTS OF CASH FLOWS (Unaudited)	Six Months Ended
	June 30
(in millions)	2022		2021
Operating activities
Net income	$	133.2	$	129.5
Reconciliation to cash provided by operating activities
Depreciation and amortization	99.2		92.6
Deferred income taxes and ITCs, net	43.2		37.1
Change in –
Accounts receivable and unbilled revenues, net	(40.4)		8.7
Materials, supplies, and inventories	(0.8)		3.5
Prepaid taxes	(11.7)		2.0
Other current assets	3.7		1.2
Accounts payable	49.5		(33.2)
Accrued taxes	(7.8)		15.6
Other current liabilities	40.2		1.4
Other, net	(54.0)		(16.9)
Net cash provided by operating activities	254.3		241.5
Investing activities
Capital expenditures	(185.4)		(172.2)
Reimbursement for ATC's construction costs	10.0		—
Proceeds from cash surrender value of life insurance	4.4		—
Payments for assets transferred from affiliates	—		(5.5)
Other, net	2.5		(0.4)
Net cash used in investing activities	(168.5)		(178.1)
Financing activities
Change in short-term debt	(152.5)		(4.0)
Payment of dividends to parent	(60.0)		(60.0)
Equity contribution from parent	125.0		—
Other, net	(0.4)		—
Net cash used in financing activities	(87.9)		(64.0)
Net change in cash and cash equivalents	(2.1)		(0.6)
Cash and cash equivalents at beginning of period	2.4		2.7
Cash and cash equivalents at end of period	$	0.3	$	2.1

The accompanying Notes to Condensed Financial Statements are an integral part of these financial statements.

06/30/2022 Form 10-Q 5 Wisconsin Public Service Corporation

WISCONSIN PUBLIC SERVICE CORPORATION

CONDENSED STATEMENTS OF EQUITY (Unaudited)
(in millions)	Common Stock		Additional Paid In Capital		Retained Earnings		Total Common Shareholder's Equity
Balance at December 31, 2021	$	95.6	$	1,491.5	$	555.9	$	2,143.0
Net income	—		—		76.6		76.6
Equity contribution from parent	—		125.0		—		125.0
Payment of dividends to parent	—		—		(30.0)		(30.0)
Stock-based compensation and other	—		0.2		—		0.2
Balance at March 31, 2022	$	95.6	$	1,616.7	$	602.5	$	2,314.8
Net income	—		—		56.6		56.6
Payment of dividends to parent	—		—		(30.0)		(30.0)
Balance at June 30, 2022	$	95.6	$	1,616.7	$	629.1	$	2,341.4

(in millions)	Common Stock		Additional Paid In Capital		Retained Earnings		Total Common Shareholder's Equity
Balance at December 31, 2020	$	95.6	$	1,436.4	$	584.7	$	2,116.7
Net income	—		—		69.3		69.3
Payment of dividends to parent	—		—		(30.0)		(30.0)
Stock-based compensation and other	—		0.1		—		0.1
Balance at March 31, 2021	$	95.6	$	1,436.5	$	624.0	$	2,156.1
Net income	—		—		60.2		60.2
Payment of dividends to parent	—		—		(30.0)		(30.0)
Stock-based compensation and other	—		0.1		—		0.1
Balance at June 30, 2021	$	95.6	$	1,436.6	$	654.2	$	2,186.4

The accompanying Notes to Condensed Financial Statements are an integral part of these financial statements.

06/30/2022 Form 10-Q 6 Wisconsin Public Service Corporation

WISCONSIN PUBLIC SERVICE CORPORATION

NOTES TO CONDENSED FINANCIAL STATEMENTS (Unaudited)

June 30, 2022

NOTE 1—GENERAL INFORMATION

Wisconsin Public Service Corporation serves approximately 458,600 electric customers and 339,000 natural gas customers.

As used in these notes, the term "financial statements" refers to the condensed financial statements. This includes the income statements, balance sheets, statements of cash flows, and statements of equity, unless otherwise noted. In this report, when we refer to "the Company," "us," "we," "our," or "ours," we are referring to Wisconsin Public Service Corporation.

Investments in companies not controlled by us, but over which we have significant influence regarding the operating and financial policies of the investee, are accounted for using the equity method.

We have prepared the unaudited interim financial statements presented in this Form 10-Q pursuant to the rules and regulations of the SEC and GAAP. Accordingly, these financial statements do not include all of the information and footnotes required by GAAP for annual financial statements. These financial statements should be read in conjunction with the financial statements and footnotes in our Annual Report on Form 10-K for the year ended December 31, 2021. Financial results for an interim period may not give a true indication of results for the year. In particular, the results of operations for the three and six months ended June 30, 2022, are not necessarily indicative of expected results for 2022 due to seasonal variations and other factors.

In management's opinion, we have included all adjustments, normal and recurring in nature, necessary for a fair presentation of our financial results.

NOTE 2—ACQUISITION

In accordance with Topic 805: Clarifying the Definition of a Business (ASU 2017-01), transactions are evaluated and are accounted for as acquisitions (or disposals) of assets or businesses, and transaction costs are capitalized in asset acquisitions.

Acquisition of Electric Generation Facility in Wisconsin

In November 2021, we, along with WE, signed an asset purchase agreement to acquire Whitewater, a commercially operational 236.5 MW dual-fueled (natural gas and low sulfur fuel oil) combined-cycle electrical generation facility in Whitewater, Wisconsin. WE currently purchases all of the capacity from this generation facility pursuant to a power purchase agreement. In December 2021, we, along with WE, filed an application with the PSCW for approval to acquire Whitewater. If approved, our share of the cost of this facility is estimated to be $36.3 million for 50% of the capacity. The transaction is expected to close in early 2023.

06/30/2022 Form 10-Q 7 Wisconsin Public Service Corporation

NOTE 3—OPERATING REVENUES

For more information about our operating revenues, see Note 1(d), Operating Revenues, in our 2021 Annual Report on Form 10-K.

Disaggregation of Operating Revenues

The following tables present our operating revenues disaggregated by revenue source for our utility segment. We do not have any revenues associated with our other segment. We disaggregate revenues into categories that depict how the nature, amount, timing, and uncertainty of revenues and cash flows are affected by economic factors. Revenues are further disaggregated by electric and natural gas operations and then by customer class. Each customer class within our electric and natural gas operations have different expectations of service, energy and demand requirements, and can be impacted differently by regulatory activities within their jurisdictions.

	Three Months Ended June 30				Six Months Ended June 30
(in millions)	2022		2021		2022		2021
Wisconsin Public Service Corporation
Electric utility	$	332.6	$	287.6	$	643.3	$	559.0
Natural gas utility	84.3		50.4		251.2		182.7
Total revenues from contracts with customers	416.9		338.0		894.5		741.7
Other operating revenues	1.6		3.2		2.9		4.8
Total operating revenues	$	418.5	$	341.2	$	897.4	$	746.5

Revenues from Contracts with Customers

Electric Utility Operating Revenues

The following table disaggregates electric utility operating revenues into customer class:

	Three Months Ended June 30				Six Months Ended June 30
(in millions)	2022		2021		2022		2021
Residential	$	111.3	$	102.8	$	228.4	$	204.7
Small commercial and industrial	104.3		93.4		201.6		177.5
Large commercial and industrial	79.4		63.7		142.7		118.9
Other	2.2		2.1		4.4		4.2
Total retail revenues	297.2		262.0		577.1		505.3
Wholesale	23.7		20.7		45.5		39.6
Resale	6.9		0.9		12.1		6.8
Other utility revenues	4.8		4.0		8.6		7.3
Total electric utility operating revenues	$	332.6	$	287.6	$	643.3	$	559.0

06/30/2022 Form 10-Q 8 Wisconsin Public Service Corporation

Natural Gas Utility Operating Revenues

The following table disaggregates natural gas utility operating revenues into customer class:

	Three Months Ended June 30				Six Months Ended June 30
(in millions)	2022		2021		2022		2021
Residential	$	46.9	$	41.2	$	149.0	$	108.5
Commercial and industrial	31.0		24.3		93.8		63.0
Total retail revenues	77.9		65.5		242.8		171.5
Transportation	4.5		4.4		10.7		10.2
Other utility revenues (1)	1.9		(19.5)		(2.3)		1.0
Total natural gas utility operating revenues	$	84.3	$	50.4	$	251.2	$	182.7

(1)Includes the revenues subject to our purchased gas recovery mechanism. The negative amount for the three months ended June 30, 2021 primarily relates to the approval by the PSCW to recover from customers, over the second quarter of 2021, the higher natural gas costs that were incurred as a result of the extreme winter weather conditions in February 2021. As these amounts were billed to customers, they were reflected in retail revenues with an offsetting decrease in other utility revenues.

Other Operating Revenues

Other operating revenues consist primarily of the following:

	Three Months Ended June 30				Six Months Ended June 30
(in millions)	2022		2021		2022		2021
Late payment charges	$	1.1	$	1.9	$	2.2	$	2.4
Alternative revenues (1)	0.3		1.2		0.5		2.3
Other	0.2		0.1		0.2		0.1
Total other operating revenues	$	1.6	$	3.2	$	2.9	$	4.8

(1)See Note 1(d), Operating Revenues, in our 2021 Annual Report on Form 10-K for more information on alternative revenues.

NOTE 4—CREDIT LOSSES

Our exposure to credit losses is related to our accounts receivable and unbilled revenue balances, which are generated from the sale of electricity and natural gas by our regulated utility operations. Our regulated utility operations are included in our utility segment. No accounts receivable and unbilled revenue balances were reported in the other segment at June 30, 2022 and December 31, 2021.

We evaluate the collectability of our accounts receivable and unbilled revenue balances considering a combination of factors. For some of our larger customers and also in circumstances where we become aware of a specific customer's inability to meet its financial obligations to us, we record a specific allowance for credit losses against amounts due in order to reduce the net recognized receivable to the amount we reasonably believe will be collected. For all other customers, we use the accounts receivable aging method to calculate an allowance for credit losses. Using this method, we classify accounts receivable into different aging buckets and calculate a reserve percentage for each aging bucket based upon historical loss rates. The calculated reserve percentages are updated on at least an annual basis, in order to ensure recent macroeconomic, political, and regulatory trends are captured in the calculation, to the extent possible. Risks identified that we do not believe are reflected in the calculated reserve percentages, are assessed on a quarterly basis to determine whether further adjustments are required.

We monitor our ongoing credit exposure through active review of counterparty accounts receivable balances against contract terms and due dates. Our activities include timely account reconciliation, dispute resolution and payment confirmation. To the extent possible, we work with customers with past due balances to negotiate payment plans, but will disconnect customers for non-payment as allowed by the PSCW, if necessary, and employ collection agencies and legal counsel to pursue recovery of defaulted receivables. For our larger customers, detailed credit review procedures may be performed in advance of any sales being made. We sometimes require letters of credit, parental guarantees, prepayments or other forms of credit assurance from our larger customers to mitigate credit risk.

06/30/2022 Form 10-Q 9 Wisconsin Public Service Corporation

We have included a table below that shows our gross third-party receivable balances and related allowance for credit losses.

(in millions)	June 30, 2022			December 31, 2021
Accounts receivable and unbilled revenues	$	259.1		$	237.7
Allowance for credit losses	10.8			11.1
Accounts receivable and unbilled revenues, net (1)	$	248.3		$	226.6
Total accounts receivable, net – past due greater than 90 days (1)	$	10.8		$	8.0
Past due greater than 90 days – collection risk mitigated by regulatory mechanisms (1)	96.3		%	97.3		%

(1)Our exposure to credit losses for certain regulated utility customers is mitigated by a regulatory mechanism we have in place. Specifically, our residential tariffs include a mechanism for cost recovery or refund of uncollectible expense based on the difference between actual uncollectible write-offs and the amounts recovered in rates. As a result, at June 30, 2022, $98.8 million, or 39.8%, of our net accounts receivable and unbilled revenues balance had regulatory protections in place to mitigate the exposure to credit losses.

A rollforward of the allowance for credit losses is included below:

	Three Months Ended June 30				Six Months Ended June 30
(in millions)	2022		2021		2022		2021
Balance at the beginning of the period	$	12.1	$	17.5	$	11.1	$	18.3
Provision for credit losses	2.0		2.1		4.0		2.5
Provision for credit losses deferred for future recovery or refund	(2.3)		(4.9)		(0.6)		(5.0)
Write-offs charged against the allowance	(2.4)		(2.2)		(6.3)		(4.3)
Recoveries of amounts previously written off	1.4		0.8		2.6		1.8
Balance at the end of the period	$	10.8	$	13.3	$	10.8	$	13.3

There was a $0.3 million decrease in the allowance for credit losses at June 30, 2022, compared to December 31, 2021. The decrease was driven by customer write-offs related to collection practices returning to pre-pandemic levels in 2021, including the restoration of our ability to disconnect customers. After a customer is disconnected for a period of time without payment on their account, we will write off that customer balance. Partially offsetting the decrease in the allowance for credit losses, we believe that the high energy costs that customers are seeing, which have been driven by high natural gas prices, contributed to higher past due accounts receivable balances and a related increase in the allowance for credit losses.

The decrease in the allowance for credit losses at June 30, 2021, compared to December 31, 2020, was driven by an improvement in past due accounts receivable balances, primarily related to residential customers. Most of the improvement occurred in the second quarter of 2021, which we believe was related to the start of normal collection practices.

NOTE 5—REGULATORY ASSETS AND LIABILITIES

The following regulatory assets and liabilities were reflected on our balance sheets at June 30, 2022 and December 31, 2021. For more information on our regulatory assets and liabilities, see Note 6, Regulatory Assets and Liabilities, in our 2021 Annual Report on Form 10-K.

(in millions)	June 30, 2022		December 31, 2021
Regulatory assets
Environmental remediation costs	$	118.0	$	120.1
Pension and OPEB costs	67.7		74.1
Income tax related items	56.1		54.5
Plant retirement related items	46.1		50.2
Asset retirement obligations	17.0		14.2
ReACT™	14.3		15.6
Energy costs recoverable through rate adjustments	10.4		—
Energy efficiency programs	9.0		6.1
Uncollectible expense	4.8		5.5
Other, net	10.5		7.6
Total regulatory assets	$	353.9	$	347.9

06/30/2022 Form 10-Q 10 Wisconsin Public Service Corporation

(in millions)	June 30, 2022		December 31, 2021
Regulatory liabilities
Income tax related items	$	344.7	$	352.7
Removal costs	191.5		189.9
Pension and OPEB benefits	115.8		116.5
Derivatives (1)	40.2		26.9
Earnings sharing mechanism (2)	15.3		26.7
Energy costs refundable through rate adjustments (3)	10.6		8.4
Electric transmission costs (2)	9.5		19.7
Other, net	6.9		3.1
Total regulatory liabilities	$	734.5	$	743.9
Balance sheet presentation
Other current liabilities	$	10.6	$	8.4
Regulatory liabilities	723.9		735.5
Total regulatory liabilities	$	734.5	$	743.9

(1)    For most energy-related physical and financial contracts that qualify as derivatives, the PSCW allows the effects of fair value accounting to be offset to regulatory assets and liabilities. See Note 13, Derivative Instruments, for more information on our derivative asset and liability balances.

(2)    The decrease in these regulatory liability balances was primarily related to the PSCW's approval of certain accounting treatments that allowed us to forego applying for a 2022 base rate increase, and instead maintain base rates consistent with 2021 levels. Among the accounting treatments approved was the amortization of certain regulatory liability balances in 2022, to offset a portion of our forecasted revenue deficiency. See Note 23, Regulatory Environment, in our 2021 Annual Report on Form 10-K for additional information on our 2022 base rates.

(3)    The increase in these regulatory liabilities was primarily related to lower natural gas costs incurred during 2022, compared to what was anticipated in rates.

NOTE 6—PROPERTY, PLANT, AND EQUIPMENT

As a result of a MISO ruling received in June 2021, retirement of the jointly-owned Columbia generating units 1 and 2 became probable. Columbia generating units 1 and 2 are expected to be retired by June 1, 2026. The retirement date for these plants was pushed back from the end of 2023 for unit 1 and the end of 2024 for unit 2. See Note 20, Regulatory Environment, for more information on the Columbia generating units' retirement. The net book value of our ownership share of unit 1 and unit 2 was $86.6 million and $185.6 million, respectively, at June 30, 2022. These amounts were classified as plant to be retired within property, plant, and equipment on our balance sheets. These units are included in rate base, and we continue to depreciate them on a straight-line basis using the composite depreciation rates approved by the PSCW.

NOTE 7—COMMON EQUITY

Various financing arrangements and regulatory requirements impose certain restrictions on our ability to transfer funds to the sole holder of our common stock, Integrys, in the form of cash dividends, loans, or advances. In addition, Wisconsin law prohibits us from making loans to or guaranteeing obligations of WEC Energy Group, Integrys, or their subsidiaries. See Note 11, Common Equity, in our 2021 Annual Report on Form 10-K for additional information on these and other restrictions.

We do not believe that these restrictions will materially affect our operations or limit any dividend payments in the foreseeable future.

06/30/2022 Form 10-Q 11 Wisconsin Public Service Corporation

NOTE 8—SHORT-TERM DEBT AND LINES OF CREDIT

The following table shows our short-term borrowings and their corresponding weighted-average interest rates:

(in millions, except percentages)	June 30, 2022			December 31, 2021
Commercial paper
Amount outstanding	$	178.5		$	331.0
Weighted-average interest rate on amounts outstanding	1.77		%	0.21		%

Our average amount of commercial paper borrowings based on daily outstanding balances during the six months ended June 30, 2022 was $158.6 million with a weighted-average interest rate during the period of 0.46%.

The information in the table below relates to our revolving credit facility used to support our commercial paper borrowing program, including available capacity under this facility:

(in millions)	Maturity	June 30, 2022
Revolving credit facility (1)	September 2026	$	400.0
Less:
Letters of credit issued inside credit facility		$	1.3
Commercial paper outstanding		178.5
Available capacity under existing credit facility		$	220.2

(1)In April 2022, we received approval from the PSCW to extend the maturity of this facility to September 2026.

NOTE 9—LEASES

We, along with WE and an unaffiliated utility, partnered to construct Paris, a utility-scale solar-powered electric generating facility with a battery energy storage system in Kenosha County, Wisconsin. We own 15% of Paris. Once fully constructed, we will own 30 MW of solar generation and 17 MW of battery storage of this project. The PSCW has approved the acquisition and construction of Paris, and commercial operation for the solar portion of the project is targeted in 2023.

Related to our investment in Paris, we, along with WE and an unaffiliated utility, entered into several land leases in Kenosha County, Wisconsin that commenced in the second quarter of 2022. Each lease has an initial construction term that ends upon achieving commercial operation, then automatically extends for 25 years with an option for an additional 25-year extension. We expect the optional extension to be exercised, and, as a result, the land leases are being amortized over the extended term of the leases. The lease payments will be recovered through rates.

Our total obligation under the land-related finance leases for Paris was approximately $8.8 million at June 30, 2022, and will decrease to zero over the remaining lives of the leases. Long-term lease liabilities related to our finance land leases for Paris were included in long-term debt on the balance sheet. Our finance lease right of use asset related to Paris was approximately $8.8 million as of June 30, 2022, and was included in property, plant, and equipment on our balance sheet.

In accordance with Accounting Standards Codification Subtopic 980-842, Regulated Operations – Leases (Subtopic 980-842), the expense recognition pattern associated with Paris leases resembles that of an operating lease, as amortization of the right of use assets has been modified from what would typically be recorded for a finance lease under Topic 842. The difference between the minimum lease payments and the sum of imputed interest and unadjusted amortization costs calculated under Topic 842 is deferred as a regulatory asset in accordance with Subtopic 980-842 on our balance sheet.

At June 30, 2022, our weighted-average discount rate for the Paris finance leases was 5.28%. We used the fully collateralized incremental borrowing rates based upon information available for similarly rated companies in determining the present value of lease payments.

06/30/2022 Form 10-Q 12 Wisconsin Public Service Corporation

Future minimum lease payments and the corresponding present value of our net minimum lease payments under the finance leases for Paris as of June 30, 2022, were as follows:

(in millions)
Six months ended December 31, 2022	$	0.1
2023	0.4
2024	0.4
2025	0.4
2026	0.4
2027	0.4
Thereafter	29.3
Total minimum lease payments	31.4
Less: Interest	(22.6)
Present value of minimum lease payments	8.8
Less: Short-term lease liabilities	—
Long-term lease liabilities	$	8.8

NOTE 10—MATERIALS, SUPPLIES, AND INVENTORIES

Our inventory consisted of:

(in millions)	June 30, 2022		December 31, 2021
Materials and supplies	$	56.0	$	50.5
Natural gas in storage	33.5		33.5
Fossil fuel	24.2		28.9
Total	$	113.7	$	112.9

Substantially all materials and supplies, natural gas in storage, and fossil fuel inventories are recorded using the weighted-average cost method of accounting.

NOTE 11—INCOME TAXES

The provision for income taxes differs from the amount of income tax determined by applying the applicable United States statutory federal income tax rate to income before income taxes as a result of the following:

	Three Months Ended June 30, 2022				Three Months Ended June 30, 2021
(in millions)	Amount		Effective Tax Rate		Amount		Effective Tax Rate
Statutory federal income tax	$	15.6	21.0	%	$	14.4	21.0	%
State income taxes net of federal tax benefit	4.6		6.2	%	4.3		6.2	%
Federal excess deferred tax amortization	(1.3)		(1.8)	%	(1.3)		(2.0)	%
Federal excess deferred tax amortization – Wisconsin unprotected	(1.0)		(1.3)	%	(8.4)		(12.2)	%
Other	(0.3)		(0.4)	%	(0.5)		(0.6)	%
Total income tax expense	$	17.6	23.7	%	$	8.5	12.4	%
	Six Months Ended June 30, 2022				Six Months Ended June 30, 2021
(in millions)	Amount		Effective Tax Rate		Amount		Effective Tax Rate
Statutory federal income tax	$	36.7	21.0	%	$	30.8	21.0	%
State income taxes net of federal tax benefit	11.0		6.3	%	9.2		6.3	%
Federal excess deferred tax amortization	(2.9)		(1.7)	%	(2.9)		(2.0)	%
Federal excess deferred tax amortization – Wisconsin unprotected	(2.2)		(1.2)	%	(18.9)		(12.9)	%
Other	(1.0)		(0.6)	%	(1.0)		(0.7)	%
Total income tax expense	$	41.6	23.8	%	$	17.2	11.7	%

06/30/2022 Form 10-Q 13 Wisconsin Public Service Corporation

The effective tax rates of 23.7% and 23.8% for the three and six months ended June 30, 2022, respectively, differ from the United States statutory federal income tax rate of 21%, primarily due to state income taxes. This item was partially offset by the impact of the protected deferred tax benefits associated with the Tax Legislation, as discussed in more detail below.

The effective tax rates of 12.4% and 11.7% for the three and six months ended June 30, 2021, respectively, differ from the United States statutory federal income tax rate of 21%, primarily due to the recognition of certain unprotected deferred tax benefits created as a result of the Tax Legislation. Effective January 1, 2020, in accordance with the rate order received from the PSCW in December 2019, we began amortizing the unprotected deferred tax benefits over periods ranging from two years to four years, to reduce near-term rate impacts to our customers. In addition, as discussed in more detail below, the impact of the protected deferred tax benefits associated with the Tax Legislation drove a decrease in the effective tax rate. These items were partially offset by state income taxes.

The Tax Legislation required us to remeasure the deferred income taxes at our utility segment and we began to amortize the resulting excess protected deferred income taxes beginning in 2018 in accordance with normalization requirements (see federal excess deferred tax amortization lines above).

See Note 23, Regulatory Environment, in our 2021 Annual Report on Form 10-K for additional information on unprotected tax benefits.

NOTE 12—FAIR VALUE MEASUREMENTS

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).

Fair value accounting rules provide a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are defined as follows:

Level 1 – Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 – Pricing inputs are observable, either directly or indirectly, but are not quoted prices included within Level 1. Level 2 includes those financial instruments that are valued using external inputs within models or other valuation methods.

Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methods that result in management's best estimate of fair value. Level 3 instruments include those that may be more structured or otherwise tailored to customers' needs.

Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. We use a mid-market pricing convention (the mid-point price between bid and ask prices) as a practical measure for valuing certain derivative assets and liabilities. We primarily use a market approach for recurring fair value measurements and attempt to use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.

When possible, we base the valuations of our derivative assets and liabilities on quoted prices for identical assets and liabilities in active markets. These valuations are classified in Level 1. The valuations of certain contracts not classified as Level 1 may be based on quoted market prices received from counterparties and/or observable inputs for similar instruments. Transactions valued using these inputs are classified in Level 2. Certain derivatives are categorized in Level 3 due to the significance of unobservable or internally-developed inputs. Our derivative instruments categorized as Level 3 consisted of FTRs at June 30, 2022 and December 31, 2021. These derivative instruments are valued using MISO auction prices.

06/30/2022 Form 10-Q 14 Wisconsin Public Service Corporation

The following tables summarize our financial assets and liabilities that were accounted for at fair value on a recurring basis, categorized by level within the fair value hierarchy:

	June 30, 2022
(in millions)	Level 1		Level 2		Level 3		Total
Derivative assets
Natural gas contracts	$	12.8	$	4.9	$	—	$	17.7
FTRs	—		—		10.3		10.3
Coal contracts	—		7.2		—		7.2
Total derivative assets	$	12.8	$	12.1	$	10.3	$	35.2
Derivative liabilities
Natural gas contracts	$	3.4	$	0.6	$	—	$	4.0

	December 31, 2021
(in millions)	Level 1		Level 2		Level 3		Total
Derivative assets
Natural gas contracts	$	6.5	$	3.0	$	—	$	9.5
FTRs	—		—		1.4		1.4
Coal contracts	—		15.3		—		15.3
Total derivative assets	$	6.5	$	18.3	$	1.4	$	26.2
Derivative liabilities
Natural gas contracts	$	1.4	$	0.2	$	—	$	1.6

The derivative assets and liabilities listed in the tables above include options, futures, physical commodity contracts, and other instruments used to manage market risks related to changes in commodity prices. They also include FTRs, which are used to manage electric transmission congestion costs in the MISO Energy and Operating Reserves Markets.

The following table summarizes the changes to derivatives classified as Level 3 in the fair value hierarchy:

	Three Months Ended June 30				Six Months Ended June 30
(in millions)	2022		2021		2022		2021
Balance at the beginning of the period	$	0.6	$	0.4	$	1.4	$	1.2
Purchases	11.6		3.0		11.6		3.1
Settlements	(1.9)		(0.6)		(2.7)		(1.5)
Balance at the end of the period	$	10.3	$	2.8	$	10.3	$	2.8

Fair Value of Financial Instruments

The following table shows the financial instruments included on our balance sheets that were not recorded at fair value:

	June 30, 2022				December 31, 2021
(in millions)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt (1)	$	1,659.2	$	1,454.5	$	1,659.3	$	1,903.2

(1)The carrying amount of long-term debt excludes finance lease obligations of $40.9 million and $31.3 million at June 30, 2022 and December 31, 2021, respectively.

The fair value of our long-term debt is categorized within Level 2 of the fair value hierarchy.

06/30/2022 Form 10-Q 15 Wisconsin Public Service Corporation

NOTE 13—DERIVATIVE INSTRUMENTS

We use derivatives as part of our risk management program to manage the risks associated with the price volatility of purchased power, generation, and natural gas costs for the benefit of our customers. Our approach is non-speculative and designed to mitigate risk. Our regulated hedging programs are approved by the PSCW.

We record derivative instruments on our balance sheets as an asset or liability measured at fair value unless they qualify for the normal purchases and sales exception and are so designated. We continually assess our contracts designated as normal and will discontinue the treatment of these contracts as normal if the required criteria are no longer met. Changes in the derivative's fair value are recognized currently in earnings unless specific hedge accounting criteria are met or we receive regulatory treatment for the derivative. For most energy-related physical and financial contracts in our regulated operations that qualify as derivatives, the PSCW allows the effects of fair value accounting to be offset to regulatory assets and liabilities.

None of our derivatives are designated as hedging instruments. On our balance sheets, we classify derivative assets and liabilities as current or long-term based on the maturities of the underlying contracts. Derivative assets and liabilities not shown separately on our balance sheets are included in the other current and other long-term line items. The following table shows our derivative assets and derivative liabilities.

	June 30, 2022				December 31, 2021
(in millions)	Derivative Assets		Derivative Liabilities		Derivative Assets		Derivative Liabilities
Current
Natural gas contracts (1)	$	17.2	$	3.4	$	9.2	$	1.5
FTRs	10.3		—		1.4		—
Coal contracts	4.7		—		11.6		—
Total current	32.2		3.4		22.2		1.5
Long-term
Natural gas contracts (1)	0.5		0.6		0.3		0.1
Coal contracts	2.5		—		3.7		—
Total long-term	3.0		0.6		4.0		0.1
Total	$	35.2	$	4.0	$	26.2	$	1.6

(1)Our natural gas derivative assets increased from December 31, 2021 to June 30, 2022 primarily due to the significant increase in natural gas prices.

Realized gains and losses on derivatives are primarily recorded in cost of sales upon settlement; however, they may be subsequently deferred for future rate recovery or refund as the gains and losses are included in our fuel and natural gas cost recovery mechanisms. Our estimated notional sales volumes and realized gains and losses were as follows:

	Three Months Ended June 30, 2022			Three Months Ended June 30, 2021
(in millions)	Volumes	Gains (Losses)		Volumes	Gains
Natural gas contracts	7.5 Dth	$	16.4	8.9 Dth	$	0.4
FTRs	2.0 MWh	(0.1)		1.7 MWh	4.5
Total		$	16.3		$	4.9
	Six Months Ended June 30, 2022			Six Months Ended June 30, 2021
(in millions)	Volumes	Gains		Volumes	Gains (Losses)
Natural gas contracts	19.1 Dth	$	21.6	22.5 Dth	$	(1.3)
FTRs	4.0 MWh	0.7		4.4 MWh	5.4
Total		$	22.3		$	4.1

On our balance sheets, the amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are not offset against the fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. At both June 30, 2022 and December 31, 2021, we had posted cash collateral of $6.3 million. These amounts were recorded on our balance sheets in other current assets. At June 30, 2022, we had also received cash collateral of $11.4 million. This amount was recorded on our balance sheet in other current liabilities.

06/30/2022 Form 10-Q 16 Wisconsin Public Service Corporation

The following table shows derivative assets and derivative liabilities if derivative instruments by counterparty were presented net on our balance sheets:

	June 30, 2022					December 31, 2021
(in millions)	Derivative Assets			Derivative Liabilities		Derivative Assets		Derivative Liabilities
Gross amount recognized on the balance sheet	$	35.2		$	4.0	$	26.2	$	1.6
Gross amount not offset on the balance sheet	(12.9)		(1)	(3.4)		(1.4)		(1.4)
Net amount	$	22.3		$	0.6	$	24.8	$	0.2

(1)    Includes cash collateral received of $9.5 million.

NOTE 14—GUARANTEES

As of June 30, 2022, we had $20.6 million of standby letters of credit issued by financial institutions for the benefit of third parties that have extended credit to us, which automatically renew each year unless proper termination notice is given. These amounts are not reflected on our balance sheets.

NOTE 15—EMPLOYEE BENEFITS

The following tables show the components of net periodic benefit cost (credit) for our benefit plans.

	Pension Benefits
	Three Months Ended June 30				Six Months Ended June 30
(in millions)	2022		2021		2022		2021
Service cost	$	1.9	$	2.3	$	4.5	$	5.3
Interest cost	5.6		5.5		11.3		11.0
Expected return on plan assets	(13.8)		(13.0)		(27.6)		(25.9)
Amortization of net actuarial loss	4.3		6.4		8.7		13.3
Net periodic benefit cost (credit)	$	(2.0)	$	1.2	$	(3.1)	$	3.7

	OPEB Benefits
	Three Months Ended June 30				Six Months Ended June 30
(in millions)	2022		2021		2022		2021
Service cost	$	0.9	$	0.9	$	2.0	$	2.1
Interest cost	1.1		1.1		2.2		2.1
Expected return on plan assets	(5.3)		(5.2)		(10.5)		(10.2)
Amortization of prior service credit	(2.5)		(2.6)		(5.1)		(5.2)
Amortization of net actuarial gain	(0.7)		(1.3)		(1.3)		(1.8)
Net periodic benefit credit	$	(6.5)	$	(7.1)	$	(12.7)	$	(13.0)

During the six months ended June 30, 2022, we made contributions and payments of $0.3 million related to our pension plans and $0.4 million related to our OPEB plans. We expect to make contributions and payments of $0.3 million related to our pension plans and $0.5 million related to our OPEB plans during the remainder of 2022, dependent upon various factors affecting us, including our liquidity position and possible tax law changes.

NOTE 16—GOODWILL

Goodwill represents the excess of the cost of an acquisition over the fair value of the identifiable net assets acquired. We had no changes to the carrying amount of goodwill during the six months ended June 30, 2022. We had no accumulated impairment losses related to our goodwill as of June 30, 2022.

NOTE 17—SEGMENT INFORMATION

We use net income to measure segment profitability and to allocate resources to our businesses. At June 30, 2022, we reported two segments, which are described below.

06/30/2022 Form 10-Q 17 Wisconsin Public Service Corporation

Our utility segment includes our electric and natural gas utility operations, which serve customers in northeastern and central Wisconsin. Our electric utility operations are engaged in the generation, distribution, and sale of electricity. Our natural gas utility operations are engaged in the purchase, distribution, and sale of natural gas to retail customers as well as the transportation of customer-owned natural gas.

Our other segment primarily consists of equity earnings from our investment in Wisconsin River Power Company.

All of our operations and assets are located within the United States. The following tables show summarized financial information for the three and six months ended June 30, 2022 and 2021, related to our reportable segments:

(in millions)	Utility		Other		Wisconsin Public Service Corporation
Three months ended June 30, 2022
Operating revenues	$	418.5	$	—	$	418.5
Other operation and maintenance	94.4		—		94.4
Depreciation and amortization	49.5		—		49.5
Other income, net	11.2		0.4		11.6
Interest expense	16.6		—		16.6
Income tax expense	17.5		0.1		17.6
Net income	56.3		0.3		56.6

(in millions)	Utility		Other		Wisconsin Public Service Corporation
Three months ended June 30, 2021
Operating revenues	$	341.2	$	—	$	341.2
Other operation and maintenance	96.4		—		96.4
Depreciation and amortization	46.6		—		46.6
Other income, net	9.9		0.5		10.4
Interest expense	16.3		—		16.3
Income tax expense	8.4		0.1		8.5
Net income	59.8		0.4		60.2

(in millions)	Utility		Other		Wisconsin Public Service Corporation
Six Months Ended June 30, 2022
Operating revenues	$	897.4	$	—	$	897.4
Other operation and maintenance	178.1		—		178.1
Depreciation and amortization	99.2		—		99.2
Other income, net	20.9		0.8		21.7
Interest expense	33.2		—		33.2
Income tax expense	41.4		0.2		41.6
Net income	132.6		0.6		133.2

(in millions)	Utility		Other		Wisconsin Public Service Corporation
Six Months Ended June 30, 2021
Operating revenues	$	746.5	$	—	$	746.5
Other operation and maintenance	191.8		—		191.8
Depreciation and amortization	92.6		—		92.6
Other income, net	18.1		0.9		19.0
Interest expense	32.5		—		32.5
Income tax expense	17.0		0.2		17.2
Net income	128.8		0.7		129.5

06/30/2022 Form 10-Q 18 Wisconsin Public Service Corporation

NOTE 18—COMMITMENTS AND CONTINGENCIES

We have significant commitments and contingencies arising from our operations, including those related to unconditional purchase obligations, environmental matters, and enforcement and litigation matters.

Unconditional Purchase Obligations

We have obligations to distribute and sell electricity and natural gas to our customers and expect to recover costs related to these obligations in future customer rates. In order to meet these obligations, we routinely enter into long-term purchase and sale commitments for various quantities and lengths of time. Our minimum future commitments related to these purchase obligations as of June 30, 2022, were approximately $1.0 billion.

Environmental Matters

Consistent with other companies in the energy industry, we face significant ongoing environmental compliance and remediation obligations related to current and past operations. Specific environmental issues affecting us include, but are not limited to, current and future regulation of air emissions such as sulfur dioxide, NOx, fine particulates, mercury, and GHGs; water intake and discharges; management of coal combustion products such as fly ash; and remediation of impacted properties, including former manufactured gas plant sites.

Air Quality

Cross State Air Pollution Rule – Good Neighbor Plan

The EPA issued a proposed rule that would update and expand the Cross-State Air Pollution Rule's ozone-season NOx program to address the 2015 ozone NAAQS, resulting in more stringent regulation of ozone-season NOx emissions from EGUs in 26 states, relying on authorization through the CAA's “good neighbor provision." As part of the proposed rule, expected to take effect in May 2023, the EPA would establish a new trading program that would impose lower NOx emissions budgets on states, at levels that the EPA projected would be achievable through full operation of existing EGU emissions control equipment beginning during ozone season 2023, and through installation of additional control equipment at both EGU and non-EGU stationary sources by the start of the 2026 ozone season, as well as planned plant retirements.

Based on a review of our existing units' 2020 and 2021 actual ozone season emissions and projected future emissions versus proposed NOx ozone season allocations, we anticipate that we should be able to comply with the expanded rule requirements without procuring additional allowances on the open market.

Our planned RICE units in Wisconsin are not subject to this rule as proposed as each unit is expected to be less than 25 MW. We note that, to the extent we use RICE engines for natural gas distribution operations, those engines may be subject to the emission limits and operational requirements of the rule beginning in 2026. In June 2022, we submitted comments on this proposed rule seeking clarification of its applicability, as well as other items, and we will closely monitor the final rule for any changes from the proposed rule.

National Ambient Air Quality Standards

Ozone

After completing its review of the 2008 ozone standard, the EPA released a final rule in October 2015, creating a more stringent standard than the 2008 NAAQS. The 2015 ozone standard lowered the 8-hour limit for ground-level ozone. In December 2020, the EPA completed its 5-year review of the ozone standard and issued a final decision to retain, without any changes, the existing 2015 standard. Under Executive Order 13990, the Biden Administration ordered that all agencies review existing regulations, orders, guidance documents, policies, and similar actions promulgated, issued, or adopted between January 20, 2017 and January 20, 2021. In October 2021, the EPA announced that it will reconsider the December 2020 decision to retain the 2015 ozone standards with no changes and that it is targeting the end of 2023 to complete this reconsideration.

The EPA issued final nonattainment area designations for the 2015 ozone standard in April 2018. The following counties within our service territory were designated as partial nonattainment: Door, Kenosha, Sheboygan, Manitowoc, and Northern Milwaukee/

06/30/2022 Form 10-Q 19 Wisconsin Public Service Corporation

Ozaukee. The area designations were challenged in the D.C. Circuit Court of Appeals in Clean Wisconsin et al. v. U.S. Environmental Protection Agency. A decision was issued in July 2020 remanding the rule to the EPA for further evaluation. As a result of the July 2020 remand, in June 2021, the EPA published its final action to revise the nonattainment area designations and/or boundaries for 13 counties associated with six nonattainment areas, including several in Illinois and Wisconsin. Under the new designations, all of Milwaukee and Ozaukee counties are now listed as nonattainment and portions of Racine, Waukesha, and Washington counties have been added to the nonattainment area. Additionally, the Chicago, IL-IN-WI nonattainment area now includes an expanded portion of Kenosha County, and the partial nonattainment areas of Sheboygan, Door, and Manitowoc counties were also expanded.

In April 2022, the EPA proposed to find that the Milwaukee and Chicago, IL-IN-WI nonattainment areas did not meet the marginal attainment deadline of August 2021, and will be adjusted to "moderate" nonattainment status for the 2015 standard. Accordingly, Wisconsin must submit State Implementation Plan revisions to address the reclassifications. A final rulemaking for the designations is expected in October 2022.

In February 2022, revisions to the Wisconsin Administrative Code to adopt the 2015 standard were finalized. The amended regulations adopted the standard and incorporated by reference the federal air pollution monitoring requirements related to the standard. We believe that we are well positioned to meet the requirements associated with the 2015 ozone standard and do not expect to incur significant costs to comply with the associated state and federal rules.

Particulate Matter

In December 2020, the EPA completed its 5-year review of the 2012 annual and 24-hour standards for fine particulate matter. The EPA determined that no revisions were necessary to the current annual standard of 12 µg/m3 or the 24-hour standard of 35 µg/m3. This determination was also subject to review under Executive Order 13990 and in June 2021, the EPA announced it would reconsider the December 2020 decision. Under the Biden Administration's policy review, the EPA concluded that the scientific evidence and information from the December 2020 determination supports revising the level of the annual standard for the particulate matter NAAQS to below the current level of 12 µg/m3, while retaining the 24-hour standard. In March 2022, the EPA’s CASAC sent a letter to the EPA finalizing its peer review of the particulate matter standards. Based on their review, the majority of the members of the CASAC found that lowering the annual standard to within a range of 8 to 10 µg/m3 was appropriate, while a minority of the members of the committee found that a range of 10 to 11 µg/m3 would be appropriate. Additionally, a majority of the CASAC members favored lowering the 24-hour standard, while a minority concurred with EPA’s preliminary conclusion to retain the 24-hour standard without revision. In May 2022, the EPA released its staff-written Policy Assessment for the reconsideration of the standard. Similar to the CASAC findings, the EPA staff found that conditions supported either an annual standard in the 10 to 12 µg/m3 range or in the 8 to 10 µg/m3 range.

A proposed rule is expected in August 2022, and a final rule is expected in spring 2023. All counties within our service territory are in attainment with the current 2012 standards. If the EPA lowers the annual standard to 10 or 11 µg/m3, our generating facilities within our service territory should remain in attainment. If the EPA lowers it to below 10 µg/m3, there could be some non-attainment areas that may affect permitting of some smaller ancillary equipment located at our facilities.

Climate Change

The ACE rule, which replaced the Clean Power Plan, was vacated by the D.C. Circuit Court of Appeals in January 2021. In October 2021, the Supreme Court agreed to review the D.C. Circuit Court's ruling vacating the EPA's ACE rule and in June 2022, the Supreme Court issued its decision. The Supreme Court found that the EPA may regulate GHGs under section 111 of the CAA but cannot rely on generation shifting to lower carbon emitting sources to do so. Based on an updated EPA regulatory timeline, we expect a new GHG replacement rule to be proposed in March 2023.

In January 2021, the EPA finalized a rule to revise the New Source Performance Standards for GHG emissions from new, modified, and reconstructed fossil-fueled power plants; however, it was vacated by the D.C. Circuit Court of Appeals in April 2021. Based on an updated EPA regulatory timeline, we expect a new rule to be proposed in March 2023. WEC Energy Group continues to move forward on the ESG Progress Plan, which is heavily focused on reducing GHG emissions.

The ESG Progress Plan includes the retirement of older, fossil-fueled generation, to be replaced with zero-carbon-emitting renewables and clean natural gas-fueled generation. We have already retired approximately 300 MW of coal-fired generation since the beginning of 2018. Through its ESG Progress Plan, WEC Energy Group expects to retire approximately 1,600 MW of additional fossil-fueled generation by the end of 2026, which includes the planned retirement by June 2026 of jointly-owned Columbia Units 1-2. See Note 20, Regulatory Environment, for more information on the timing of the retirements. In May 2021, WEC Energy

06/30/2022 Form 10-Q 20 Wisconsin Public Service Corporation

Group announced goals to achieve reductions in carbon emissions from its electric generation fleet by 60% by the end of 2025 and by 80% by the end of 2030, both from a 2005 baseline. WEC Energy Group expects to achieve these goals by making operating refinements, retiring less efficient generating units, and executing its capital plan. Over the longer term, the target for WEC Energy Group's generation fleet is net-zero CO2 emissions by 2050.

WEC Energy Group also continues to reduce methane emissions by improving its natural gas distribution systems, and has set a target across its natural gas distribution operations to achieve net-zero methane emissions by the end of 2030. WEC Energy Group plans to achieve its net-zero goal through an effort that includes both continuous operational improvements and equipment upgrades, as well as the use of RNG throughout its utility systems.

Water Quality

Clean Water Act Cooling Water Intake Structure Rule

In August 2014, the EPA issued a final regulation under Section 316(b) of the Clean Water Act that requires the location, design, construction, and capacity of cooling water intake structures at existing power plants to reflect the BTA for minimizing adverse environmental impacts. The federal rule became effective in October 2014 and applies to all of our existing generating facilities with cooling water intake structures.

In 2016, the WDNR initiated a state rulemaking process to incorporate the federal Section 316(b) requirements into the Wisconsin Administrative Code. This new state rule, NR 111, became effective in June 2020, and the WDNR will apply it when establishing BTA requirements for cooling water intake structures at existing facilities. These BTA requirements are incorporated into WPDES permits for our facilities.

We have received interim BTA determinations for Weston Units 2, 3, and 4. We believe that existing technology installed at the Weston facility will result in a final BTA determination during the WPDES permit reissuance in 2023.

As a result of past capital investments completed to address Section 316(b) compliance, we believe our fleet overall is well positioned to continue to meet this regulation and do not expect to incur significant additional compliance costs.

Steam Electric Effluent Limitation Guidelines

The EPA's final 2015 ELG rule took effect in January 2016 and was modified in 2020 to revise the treatment technology requirements related to BATW at existing facilities. This rule created new requirements for several types of power plant wastewaters. The new requirement that affects us relates to discharge limits for BATW. Our power plant facility already has advanced wastewater treatment technologies installed that meet many of the discharge limits established by this rule. There will, however, need to be facility modifications to meet water permit requirements for the BATW system at Weston Unit 3, which is expected to be completed by December 2023. Based on engineering cost estimates, we expect that compliance with the ELG rule will require approximately $10 million in capital investment. The BATW modification does not require PSCW approval prior to construction. All of these ELG required projects are either in-service or are on track for completion by the WPDES permit deadline in December 2023.

In July 2021, the EPA announced that it intends to initiate rulemaking to revise the ELG Rule as modified in 2020. The EPA has stated that the ELG Rule will continue to be implemented and enforced while the agency pursues this rulemaking process. The EPA plans to propose a revised rule in the fall of 2022.

Waters of the United States

In December 2021, the EPA and the United States Army Corps of Engineers together released a proposed rule to repeal the April 2020 Navigable Waters Protection Rule that defined WOTUS. The purpose of this proposed rule will be to restore regulations defining WOTUS that were in place prior to 2015 and to update certain provisions to be consistent with relevant Supreme Court decisions. The pre-2015 approach involves applying factors established through case law and agency precedents to determine whether a wetland or surface drainage feature is subject to federal jurisdiction. In January 2022, the Supreme Court granted certiorari in a case to evaluate the proper test for determining whether wetlands are WOTUS. At this point, our projects requiring federal permits are moving ahead, but we are monitoring to better understand potential future impacts. This case, once decided, should provide clarity regarding the definition of WOTUS. We will continue to monitor this litigation and any subsequent agency action.

06/30/2022 Form 10-Q 21 Wisconsin Public Service Corporation

Land Quality

Manufactured Gas Plant Remediation

We have identified sites at which we or a predecessor company owned or operated a manufactured gas plant or stored manufactured gas. We have also identified other sites that may have been impacted by historical manufactured gas plant activities. We are responsible for the environmental remediation of these sites, some of which are in the EPA Superfund Alternative Approach Program. We are also working with the state of Wisconsin in our investigation and remediation planning. These sites are at various stages of investigation, monitoring, remediation, and closure.

In addition, we are coordinating the investigation and cleanup of some of these sites subject to the jurisdiction of the EPA under what is called a "multisite" program. This program involves prioritizing the work to be done at the sites, preparation and approval of documents common to all of the sites, and use of a consistent approach in selecting remedies. At this time, we cannot estimate future remediation costs associated with these sites beyond those described below.

The future costs for detailed site investigation, future remediation, and monitoring are dependent upon several variables including, among other things, the extent of remediation, changes in technology, and changes in regulation. Historically, our regulators have allowed us to recover incurred costs, net of insurance recoveries and recoveries from potentially responsible parties, associated with the remediation of manufactured gas plant sites. Accordingly, we have established regulatory assets for costs associated with these sites.

We have established the following regulatory assets and reserves for manufactured gas plant sites:

(in millions)	June 30, 2022		December 31, 2021
Regulatory assets	$	118.0	$	120.1
Reserves for future environmental remediation	89.5		95.0

Enforcement and Litigation Matters

We are involved in legal and administrative proceedings before various courts and agencies with respect to matters arising in the ordinary course of business. Although we are unable to predict the outcome of these matters, management believes that appropriate reserves have been established and that final settlement of these actions will not have a material impact on our financial condition or results of operations.

Consent Decrees

Weston and Pulliam Power Plants

In November 2009, the EPA issued an NOV to us, which alleged violations of the CAA's New Source Review requirements relating to certain projects completed at the Weston and Pulliam power plants from 1994 to 2009. We entered into a Consent Decree with the EPA resolving this NOV. This Consent Decree was entered by the United States District Court for the Eastern District of Wisconsin in March 2013. With the retirement of Pulliam Units 7 and 8 in October 2018, we completed the mitigation projects required by the Consent Decree and received a completeness letter from the EPA in October 2018. We are working with the EPA on a closeout process for the Consent Decree and expect that process to be completed in 2023.

Joint Ownership Power Plants – Columbia and Edgewater

In December 2009, the EPA issued an NOV to Wisconsin Power and Light Company, the operator of the Columbia and Edgewater plants, and the other joint owners of these plants, including Madison Gas and Electric Company, WE (former co-owner of an Edgewater unit), and us. The NOV alleged violations of the CAA's New Source Review requirements related to certain projects completed at those plants. We, along with Wisconsin Power and Light Company, Madison Gas and Electric Company, and WE, entered into a Consent Decree with the EPA resolving this NOV. This Consent Decree was entered by the United States District Court for the Western District of Wisconsin in June 2013. As a result of the continued implementation of the Consent Decree related to the jointly owned Columbia and Edgewater plants, the Edgewater 4 generating unit was retired in September 2018. Wisconsin Power and Light Company expects to start the process to close out this Consent Decree in early 2023.

06/30/2022 Form 10-Q 22 Wisconsin Public Service Corporation

NOTE 19—SUPPLEMENTAL CASH FLOW INFORMATION

	Six Months Ended June 30
(in millions)	2022		2021
Cash paid for interest, net of amount capitalized	$	33.2	$	31.7
Cash paid (received) for income taxes, net	18.9		(35.1)
Significant non-cash investing and financing transactions:
Accounts payable related to construction costs	26.4		16.3
Liabilities accrued for software licensing agreement	1.5		—

NOTE 20—REGULATORY ENVIRONMENT

2023 and 2024 Rates

In April 2022, we filed a request with the PSCW to increase our retail electric and natural gas rates, effective January 1, 2023. The requested increase in electric rates was driven by capital investments in new wind, solar, and battery storage; capital investments in natural gas generation; and changes in wholesale business with other utilities. Many of these investments have already been approved by the PSCW. The requested increase in natural gas rates primarily related to capital investments that have been made to maintain and improve safety and reliability.

In July 2022, we updated our rate request to reflect recent developments that impacted our original proposal for rate increases in 2023. These recent developments included:

•Delays in the in-service dates of Darien and the battery portion of Paris due to supply chain disruptions.

•Wisconsin Power & Light Company's decision to delay the retirements of the jointly-owned Columbia units. The retirements of the Columbia units, which were originally planned for the end of 2023 and 2024, were delayed until 2026. We hold a 27.5% ownership interest in these units.

•The effect of anticipated increases in interest rates on borrowing costs.

The updated rate request proposal includes an aggregate increase of approximately $6 million from the original proposal and is reflected in the following table:

Proposed 2023 rate increase
Electric	$	79.4	million	/	6.6%
Gas	$	30.9	million	/	8.4%
Proposed ROE (1)	10.0%
Proposed common equity component average on a financial basis (1)	53.0%

(1)    The proposed ROE is consistent with our currently authorized ROE. Our common equity component average is currently 52.5%.

We are proposing to continue using an earnings sharing mechanism. Under the proposed earnings sharing mechanism, if we earn above our authorized ROE: (i) we would retain 100.0% of earnings for the first 25 basis points above the authorized ROE; (ii) 50.0% of the next 50 basis points would be required to be refunded to ratepayers; and (iii) 100.0% of any remaining excess earnings would be required to be refunded to ratepayers.

We are seeking a limited rate case re-opener for 2024 to address additional revenue requirements associated with generation projects that are expected to be placed into service in 2023 and 2024.

We expect a decision from the PSCW in the fourth quarter of 2022, with any rate adjustments expected to be effective January 1, 2023.

06/30/2022 Form 10-Q 23 Wisconsin Public Service Corporation

NOTE 21—NEW ACCOUNTING PRONOUNCEMENTS

Reference Rate Reform

In March 2020, the FASB issued ASU No. 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting, which provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions affected by reference rate reform if certain criteria are met. The amendments apply only to contracts, hedging relationships, and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. The amendments are effective for all entities as of March 12, 2020 through December 31, 2022. We are currently evaluating the impact this guidance may have on our financial statements and related disclosures.

Government Assistance

In November 2021, the FASB issued ASU No. 2021-10, Government Assistance (Topic 832). The amendments in this update increase the transparency surrounding government assistance by requiring disclosure of: (i) the types of assistance received; (ii) an entity’s accounting for the assistance; and (iii) the effect of the assistance on the entity’s financial statements. The update is effective for annual periods beginning after December 15, 2021. We plan to adopt this pronouncement for our fiscal year ending on December 31, 2022, and we are currently evaluating the impact this guidance may have on our financial statements and related disclosures.

06/30/2022 Form 10-Q 24 Wisconsin Public Service Corporation

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

CORPORATE DEVELOPMENTS

The following discussion should be read in conjunction with the accompanying unaudited financial statements and related notes and our 2021 Annual Report on Form 10-K.

Introduction

We are an electric and natural gas utility and an indirect wholly owned subsidiary of WEC Energy Group. We derive revenues primarily from the distribution and sale of electricity and natural gas to retail customers in Wisconsin. We also provide wholesale electric service to numerous utilities and cooperatives for resale. We conduct our business primarily through our utility reportable segment. See Note 17, Segment Information, for more information on our reportable business segments.

Corporate Strategy

Our goal is to continue to build and sustain long-term value for our customers and WEC Energy Group's shareholders by focusing on the fundamentals of our business: environmental stewardship; reliability; operating efficiency; financial discipline; exceptional customer care; and safety. WEC Energy Group's capital investment plan for efficiency, sustainability and growth, referred to as its ESG Progress Plan, provides a roadmap to achieve this goal. It is an aggressive plan to cut emissions, maintain superior reliability, deliver significant savings for customers, and grow WEC Energy Group's and our investment in the future of energy.

Throughout its strategic planning process, WEC Energy Group takes into account important developments, risks and opportunities, including new technologies, customer preferences and affordability, energy resiliency efforts, and sustainability. WEC Energy Group published the results of a priority sustainability issue assessment in 2020, identifying the issues that are most important to the company and its stakeholders over the short and long terms. This risk and priority assessment has formed WEC Energy Group's direction as a company.

Creating a Sustainable Future

WEC Energy Group's ESG Progress Plan includes the retirement of older, fossil-fueled generation, to be replaced with zero-carbon-emitting renewables and clean natural gas-fired generation at its electric utilities, including us. When taken together, the retirements and new investments should better balance supply with demand, while maintaining reliable, affordable energy for our customers. The retirements will contribute to meeting WEC Energy Group's and our goals to reduce CO2 emissions from electric generation.

In May 2021, WEC Energy Group announced goals to achieve reductions in carbon emissions from its electric generation fleet by 60% by the end of 2025 and by 80% by the end of 2030, both from a 2005 baseline. WEC Energy Group expects to achieve these goals by making operating refinements, retiring less efficient generating units and executing its capital plan. Over the longer term, the target for its generation fleet is net-zero CO2 emissions by 2050.

As part of the path toward these goals, by the end of 2030, WEC Energy Group expects to use coal as a backup fuel only, and WEC Energy Group believes it will be in a position to eliminate coal as an energy source by the end of 2035.

WEC Energy Group already has retired more than 1,800 MWs of coal-fired generation since the beginning of 2018, which included the 2018 retirement of the Pulliam power plant as well as the jointly-owned Edgewater Unit 4 generating units. Through the ESG Progress Plan, WEC Energy Group expects to retire approximately 1,600 MW of additional fossil-fueled generation by the end of 2026, which includes the planned retirement in 2026 of the jointly-owned Columbia Units 1-2. See Note 20, Regulatory Environment, for information on the delay of these planned retirements.

In addition to retiring these older, fossil-fueled plants, WEC Energy Group expects to invest approximately $3.5 billion from 2022-2026 in regulated renewable energy in Wisconsin. WEC Energy Group's plan is to replace a portion of the retired capacity by building and owning zero-carbon-emitting renewable generation facilities that are anticipated to include the following new investments made by either us or WE based on specific customer needs:

•1,400 MW of utility-scale solar (amount does not include WE's Badger Hollow Solar Park II, which is currently under construction);

06/30/2022 Form 10-Q 25 Wisconsin Public Service Corporation

•800 MW of battery storage; and

•100 MW of wind.

WEC Energy Group also plans on investing in a combination of clean, natural gas-fired generation, made by either us or WE based on specific customer needs, including:

•100 MW of RICE natural gas-fueled generation;

•the planned purchase of 200 MW of capacity in West Riverside — a combined-cycle natural gas plant recently completed by Alliant Energy in Wisconsin; and

•the planned purchase of Whitewater, a natural gas-fired combined-cycle electric generating facility with a capacity of 236.5 MW.

The new investments discussed above are in addition to the renewable projects currently underway. For more details, see Liquidity and Capital Resources – Cash Requirements – Significant Capital Projects.

In addition, we invested in 200 MW of utility-scale solar. We partnered with an unaffiliated utility to construct two solar projects now in service in Wisconsin: Two Creeks Solar Park and Badger Hollow I. We own 100 MW of each project for a total of 200 MW.

In August 2021, the PSCW approved pilot programs for us to install and maintain EV charging equipment for customers at their homes or businesses. The programs provide direct benefits to customers by removing cost barriers associated with installing EV equipment. In October 2021, subject to the receipt of any necessary regulatory approvals, WEC Energy Group pledged to expand the EV charging network within its utilities' electric service territories. In doing so, WEC Energy Group joined a coalition of utility companies in a unified effort to make EV charging convenient and widely available throughout the Midwest. The coalition WEC Energy Group joined is planning to help build and grow EV charging corridors, enabling the general public to safely and efficiently charge their vehicles.

WEC Energy Group also continues to reduce methane emissions by improving its natural gas distribution system, and has set a target across its natural gas distribution operations to achieve net-zero methane emissions by the end of 2030. WEC Energy Group plans to achieve its net-zero goal through an effort that includes both continuous operational improvements and equipment upgrades, as well as the use of RNG throughout its utility systems. In 2022, we received approval from the PSCW for an RNG pilot associated with our natural gas distribution system.

As part of WEC Energy Group's effort to look for new opportunities in sustainable energy, it is testing the effects of blending hydrogen, a clean generating fuel, with natural gas at one of its RICE generating units in the Upper Peninsula of Michigan. WEC Energy Group is partnering with the Electric Power Research Institute in this research that could help create another viable option for decarbonizing the economy. The project is being carried out in 2022, and the results will be shared across the industry.

Reliability

We have made significant reliability-related investments in recent years, and in accordance with the ESG Progress Plan, expect to continue strengthening and modernizing our generation fleet, as well as our electric and natural gas distribution networks to further improve reliability.

For more details, see Liquidity and Capital Resources – Cash Requirements – Significant Capital Projects.

Operating Efficiency

We continually look for ways to optimize the operating efficiency of our company and will continue to do so under the ESG Progress Plan. For example, we are making progress on our AMI program, replacing aging meter-reading equipment on both our network and customer property. An integrated system of smart meters, communication networks, and data management programs enables two-way communication between us and our customers. This program reduces the manual effort for disconnects and reconnects and enhances outage management capabilities.

WEC Energy Group continues to focus on integrating the resources of its businesses and finding the best and most efficient processes.

06/30/2022 Form 10-Q 26 Wisconsin Public Service Corporation

Financial Discipline

A strong adherence to financial discipline is essential to meeting our earnings projections and maintaining a strong balance sheet, stable cash flows, and quality credit ratings.

We follow an asset management strategy that focuses on investing in and acquiring assets consistent with our strategic plans, as well as disposing of assets, including property, plants, and equipment, that are no longer strategic to operations, are not performing as intended, or have an unacceptable risk profile. See Note 2, Acquisition, for more information on our acquisition of Whitewater.

Exceptional Customer Care

Our approach is driven by an intense focus on delivering exceptional customer care every day. We strive to provide the best value for our customers by demonstrating personal responsibility for results, leveraging our capabilities and expertise, and using creative solutions to meet or exceed our customers’ expectations.

A multiyear effort is driving a standardized, seamless approach to digital customer service across all of the WEC Energy Group companies. It has moved all utilities, including us, to a common platform for all customer-facing self-service options. Using common systems and processes reduces costs, provides greater flexibility and enhances the consistent delivery of exceptional service to customers.

Safety

Safety is one of our core values and a critical component of our culture. We are committed to keeping our employees and the public safe through a comprehensive corporate safety program that focuses on employee engagement and elimination of at-risk behaviors.

Under our "Target Zero" mission, we have an ultimate goal of zero incidents, accidents, and injuries. Management and union leadership work together to reinforce the Target Zero culture. We set annual goals for safety results as well as measurable leading indicators, in order to raise awareness of at-risk behaviors and situations and guide injury-prevention activities. All employees are encouraged to report unsafe conditions or incidents that could have led to an injury. Injuries and tasks with high levels of risk are assessed, and findings and best practices are shared across the WEC Energy Group companies.

Our corporate safety program provides a forum for addressing employee concerns, training employees and contractors on current safety standards, and recognizing those who demonstrate a safety focus.

RESULTS OF OPERATIONS

THREE MONTHS ENDED JUNE 30, 2022

Earnings

Our earnings for the second quarter of 2022 were $56.6 million, compared with $60.2 million for the same quarter in 2021. See below for additional information on the $3.6 million decrease in earnings.

Non-GAAP Financial Measures

The discussion below addresses the contribution of our utility segment to net income. The discussion includes financial information prepared in accordance with GAAP, as well as electric margins and natural gas margins, which are not measures of financial performance under GAAP. Electric margins (electric revenues less fuel and purchased power costs) and natural gas margins (natural gas revenues less cost of natural gas sold) are non-GAAP financial measures because they exclude other operation and maintenance expense, depreciation and amortization, and property and revenue taxes.

We believe that electric and natural gas margins provide a useful basis for evaluating utility operations since the majority of prudently incurred fuel and purchased power costs, as well as prudently incurred natural gas costs, are passed through to customers in current rates. As a result, management uses electric and natural gas margins internally when assessing the operating performance of our utility segment as these measures exclude the majority of revenue fluctuations caused by changes in these expenses.

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Similarly, the presentation of electric and natural gas margins herein is intended to provide supplemental information for investors regarding our operating performance.

Our electric margins and natural gas margins may not be comparable to similar measures presented by other companies. Furthermore, these measures are not intended to replace operating income as determined in accordance with GAAP as an indicator of operating performance. Our utility segment operating income for the three months ended June 30, 2022 and 2021 was $79.2 million and $74.6 million, respectively. The discussion below includes a table that provides the calculation of electric margins and natural gas margins, along with a reconciliation to the most directly comparable GAAP measure, operating income.

Utility Segment Contribution to Net Income

The following table compares our utility segment's contribution to net income for the second quarter of 2022, with the same quarter in 2021, including favorable or better, "B", and unfavorable or worse, "W", variances.

	Three Months Ended June 30
(in millions)	2022		2021		B (W)
Electric revenues	$	333.8	$	290.4	$	43.4
Fuel and purchased power	128.9		90.4		(38.5)
Total electric margins	204.9		200.0		4.9
Natural gas revenues	84.7		50.8		33.9
Cost of natural gas sold	55.8		23.2		(32.6)
Total natural gas margins	28.9		27.6		1.3
Total electric and natural gas margins	233.8		227.6		6.2
Other operation and maintenance	94.4		96.4		2.0
Depreciation and amortization	49.5		46.6		(2.9)
Property and revenue taxes	10.7		10.0		(0.7)
Operating income	79.2		74.6		4.6
Other income, net	11.2		9.9		1.3
Interest expense	16.6		16.3		(0.3)
Income before income taxes	73.8		68.2		5.6
Income tax expense	17.5		8.4		(9.1)
Net income	$	56.3	$	59.8	$	(3.5)

The following table shows a breakdown of other operation and maintenance:

	Three Months Ended June 30
(in millions)	2022		2021		B (W)
Operation and maintenance not included in line items below	$	55.9	$	48.2	$	(7.7)
Transmission (1)	33.3		37.9		4.6
Regulatory amortizations and other pass through expenses (2)	10.6		10.3		(0.3)
Earnings sharing mechanism (3)	(5.4)		—		5.4
Total other operation and maintenance	$	94.4	$	96.4	$	2.0

(1)Represents transmission expense that we are authorized to collect in rates. The PSCW has approved escrow accounting for ATC and MISO network transmission expenses. As a result, we defer as a regulatory asset or liability, the difference between actual transmission costs and those included in rates until recovery or refund is authorized in a future rate proceeding. During the second quarter of 2022 and 2021, $39.0 million and $37.3 million, respectively, of costs were billed to us by transmission providers.

During the second quarter of 2022 we amortized $4.8 million of the regulatory liabilities associated with our transmission escrow to offset certain 2022 revenue deficiencies, as approved by the PSCW in order to forego filing for a 2022 base rate increase. This amortization drove the decrease in transmission expense during the second quarter of 2022, compared with the same quarter in 2021. See Note 23, Regulatory Environment, in our 2021 Annual Report on Form 10-K for additional information on 2022 base rates.

06/30/2022 Form 10-Q 28 Wisconsin Public Service Corporation

(2)Regulatory amortizations and other pass through expenses are substantially offset in margins and therefore do not have a significant impact on net income.

(3)Represents amortization of a certain portion of our regulatory liability associated with our 2020 earnings sharing mechanism to offset certain 2022 revenue deficiencies, as approved by the PSCW in order to forego filing for a 2022 base rate increase. See Note 23, Regulatory Environment, in our 2021 Annual Report on Form 10-K for additional information on 2022 base rates.

The following tables provide information on delivered sales volumes by customer class and weather statistics:

	Three Months Ended June 30
	MWh (in thousands)
Electric Sales Volumes	2022	2021	B (W)
Customer class
Residential	696.0	701.8	(5.8)
Small commercial and industrial	985.9	973.4	12.5
Large commercial and industrial	1,005.3	982.3	23.0
Other	5.2	5.4	(0.2)
Total retail	2,692.4	2,662.9	29.5
Wholesale	408.5	431.6	(23.1)
Resale	89.6	42.8	46.8
Total sales in MWh	3,190.5	3,137.3	53.2

	Three Months Ended June 30
	Therms (in millions)
Natural Gas Sales Volumes	2022	2021	B (W)
Customer class
Residential	41.3	34.5	6.8
Commercial and industrial	35.2	26.7	8.5
Total retail	76.5	61.2	15.3
Transportation	109.6	107.1	2.5
Total sales in therms	186.1	168.3	17.8

	Three Months Ended June 30
	Degree Days
Weather (1)	2022	2021	B (W)
Heating (963 Normal)	908	854	6.3	%
Cooling (144 Normal)	249	242	2.9	%

(1)Normal degree days are based on a 20-year moving average of monthly temperatures from the Green Bay, Wisconsin weather station.

Electric Revenues

Electric revenues increased $43.4 million during the second quarter of 2022, compared with the same quarter in 2021. To the extent that changes in fuel and purchased power costs are passed through to customers, the changes are offset by comparable changes in revenues. See the discussion of electric utility margins below for more information related to the recovery of fuel and purchased power costs and the remaining drivers of the changes in electric revenues.

Electric Utility Margins

Electric utility margins increased $4.9 million during the second quarter of 2022, compared with the same quarter in 2021. The significant factor impacting the higher electric utility margins was an $8.5 million increase in margins related to the impact of unprotected excess deferred taxes during the second quarter of 2021, which we agreed to return to customers in our PSCW-approved rate order. This increase in margins is offset in income taxes.

This increase in margins was partially offset by a $4.1 million quarter-over-quarter negative impact from actual fuel and purchased power costs compared with costs collected in rates. Under the Wisconsin fuel rules, our margins are impacted by under- or over-

06/30/2022 Form 10-Q 29 Wisconsin Public Service Corporation

collections of certain fuel and purchased power costs that are within a 2% price variance from the costs included in rates, and the remaining variance beyond the 2% price variance is generally deferred for future recovery or refund to customers.

Natural Gas Revenues

Natural gas revenues increased $33.9 million during the second quarter of 2022, compared with the same quarter in 2021. Because prudently incurred natural gas costs are passed through to our customers in current rates, the changes are offset by comparable changes in revenues. The average per-unit cost of natural gas increased 69% during the second quarter of 2022, compared with the same quarter in 2021. The remaining drivers of changes in natural gas revenues are described in the discussion of natural gas utility margins below.

Natural Gas Utility Margins

Natural gas utility margins increased $1.3 million during the second quarter of 2022, compared with the same quarter in 2021. The most significant factor impacting the higher natural gas utility margins was an increase from higher sales volumes, driven by the continued economic recovery in Wisconsin from the COVID-19 pandemic.

Other Operating Expenses (includes other operation and maintenance, depreciation and amortization, and property and revenue taxes)

Other operating expenses at the utility segment increased $1.6 million during the second quarter of 2022, compared with the same quarter in 2021. The significant factors impacting the increase in operating expenses were:

•A $4.4 million increase in electric and natural gas distribution expenses, primarily driven by higher storm restoration expense during the second quarter of 2022, and higher costs to maintain system reliability.

•A $2.9 million increase in depreciation and amortization, driven by assets being placed into service as we continue to execute on our capital plan.

•A $2.4 million increase in other operating and maintenance expense related to our power plants, driven by the timing of a planned outage at Weston and reductions in refined coal credits during the second quarter of 2022.

•A $1.7 million increase in benefits, primarily driven by higher stock-based compensation and pension costs, partially offset by lower deferred compensation costs.

These increases in other operating expenses were substantially offset by:

•A $5.4 million decrease in expense driven by the amortization of a certain portion of our regulatory liability associated with our 2020 earnings sharing mechanism, as discussed in the notes under the other operation and maintenance table above.

•A $4.6 million decrease in transmission expense driven by the amortization of a certain portion of our regulatory liabilities associated with transmission escrow balances, as discussed in the notes under the other operation and maintenance table above.

Other Income, Net

Other income, net increased $1.3 million during the second quarter of 2022, compared with the same quarter in 2021, driven by higher net credits from the non-service components of our net periodic pension and OPEB costs. See Note 15, Employee Benefits, for more information on our benefit costs. This increase was partially offset by lower AFUDC-Equity, driven by Badger Hollow I being placed in service in November 2021.

Income Tax Expense

Income tax expense increased $9.1 million during the second quarter of 2022, compared with the same quarter in 2021. The increase in income tax expense was due to an approximate $9 million negative impact related to lower quarter-over-quarter amortization of the unprotected excess deferred tax benefits from the Tax Legislation in connection with the rate order approved by the PSCW, effective January 1, 2020. The impact due to the benefit from the amortization of the unprotected excess deferred tax

06/30/2022 Form 10-Q 30 Wisconsin Public Service Corporation

benefits from the Tax Legislation did not impact earnings as there was an offsetting impact in operating income. See Note 11, Income Taxes, for additional information on unprotected tax benefits.

Other Segment Contribution to Net Income

	Three Months Ended June 30
(in millions)	2022		2021		B (W)
Net income	$	0.3	$	0.4	$	(0.1)

SIX MONTHS ENDED JUNE 30, 2022

Earnings

Our earnings for the six months ended June 30, 2022 were $133.2 million, compared to $129.5 million for the same period in 2021. See below for additional information on the $3.7 million increase in earnings.

Expected 2022 Annual Effective Tax Rate

We expect our 2022 annual effective tax rate to be between 23% and 24%. Our effective tax rate calculations are revised every quarter based on the best available year-end tax assumptions, adjusted in the following year after returns are filed. Tax accrual estimates are trued-up to the actual amounts claimed on the tax returns and further adjusted after examinations by taxing authorities, as needed.

Non-GAAP Financial Measures

The discussion below addresses the contribution of our utility segment to net income. The discussion includes financial information prepared in accordance with GAAP, as well as electric margins and natural gas margins, which are not measures of financial performance under GAAP. Electric margins (electric revenues less fuel and purchased power costs) and natural gas margins (natural gas revenues less cost of natural gas sold) are non-GAAP financial measures because they exclude other operation and maintenance expense, depreciation and amortization, and property and revenue taxes.

We believe that electric and natural gas margins provide a useful basis for evaluating utility operations since the majority of prudently incurred fuel and purchased power costs, as well as prudently incurred natural gas costs, are passed through to customers in current rates. As a result, management uses electric and natural gas margins internally when assessing the operating performance of our utility segment as these measures exclude the majority of revenue fluctuations caused by changes in these expenses. Similarly, the presentation of electric and natural gas margins herein is intended to provide supplemental information for investors regarding our operating performance.

Our electric margins and natural gas margins may not be comparable to similar measures presented by other companies. Furthermore, these measures are not intended to replace operating income as determined in accordance with GAAP as an indicator of operating performance. Our utility segment operating income for the six months ended June 30, 2022 and 2021 was $186.3 million and $160.2 million, respectively. The discussion below includes a table that provides the calculation of electric margins and natural gas margins, along with a reconciliation to the most directly comparable GAAP measure, operating income.

06/30/2022 Form 10-Q 31 Wisconsin Public Service Corporation

Utility Segment Contribution to Net Income

	Six Months Ended June 30
(in millions)	2022		2021		B (W)
Electric revenues	$	645.4	$	563.1	$	82.3
Fuel and purchased power	235.5		169.0		(66.5)
Total electric margins	409.9		394.1		15.8
Natural gas revenues	252.0		183.4		68.6
Cost of natural gas sold	176.7		112.7		(64.0)
Total natural gas margins	75.3		70.7		4.6
Total electric and natural gas margins	485.2		464.8		20.4
Other operation and maintenance	178.1		191.8		13.7
Depreciation and amortization	99.2		92.6		(6.6)
Property and revenue taxes	21.6		20.2		(1.4)
Operating income	186.3		160.2		26.1
Other income, net	20.9		18.1		2.8
Interest expense	33.2		32.5		(0.7)
Income before income taxes	174.0		145.8		28.2
Income tax expense	41.4		17.0		(24.4)
Net income	$	132.6	$	128.8	$	3.8

The following table shows a breakdown of other operation and maintenance:

	Six Months Ended June 30
(in millions)	2022		2021		B (W)
Operation and maintenance not included in line items below	$	101.7	$	96.9	$	(4.8)
Transmission (1)	66.6		75.9		9.3
Regulatory amortizations and other pass through expenses (2)	20.6		19.0		(1.6)
Earnings sharing mechanism (3)	(10.8)		—		10.8
Total other operation and maintenance	$	178.1	$	191.8	$	13.7

(1)Represents transmission expense that we are authorized to collect in rates. The PSCW has approved escrow accounting for ATC and MISO network transmission expenses. As a result, we defer as a regulatory asset or liability, the difference between actual transmission costs and those included in rates until recovery or refund is authorized in a future rate proceeding. During the six months ended June 30, 2022 and 2021, $77.0 million and $75.7 million, respectively, of costs were billed to us by transmission providers.

During the six months ended June 30, 2022, we amortized $9.5 million of the regulatory liabilities associated with our transmission escrow to offset certain 2022 revenue deficiencies, as approved by the PSCW in order to forego filing for a 2022 base rate increase. This amortization drove the decrease in transmission expense during the six months ended June 30, 2022, compared with the same period in 2021.

(2)Regulatory amortizations and other pass through expenses are substantially offset in margins and therefore do not have a significant impact on net income.

(3)Represents amortization of a certain portion of our regulatory liability associated with our 2020 earnings sharing mechanism to offset certain 2022 revenue deficiencies, as approved by the PSCW in order to forego filing for a 2022 base rate increase.

06/30/2022 Form 10-Q 32 Wisconsin Public Service Corporation

The following tables provide information on delivered sales volumes by customer class and weather statistics:

	Six Months Ended June 30
	MWh (in thousands)
Electric Sales Volumes	2022	2021	B (W)
Customer class
Residential	1,487.3	1,460.4	26.9
Small commercial and industrial	1,979.6	1,941.4	38.2
Large commercial and industrial	1,976.1	1,939.8	36.3
Other	12.7	13.0	(0.3)
Total retail	5,455.7	5,354.6	101.1
Wholesale	803.0	844.8	(41.8)
Resale	181.1	132.9	48.2
Total sales in MWh	6,439.8	6,332.3	107.5

	Six Months Ended June 30
	Therms (in millions)
Natural Gas Sales Volumes	2022	2021	B (W)
Customer Class
Residential	172.0	150.3	21.7
Commercial and industrial	123.8	101.8	22.0
Total retail	295.8	252.1	43.7
Transportation	262.4	250.9	11.5
Total sales in therms	558.2	503.0	55.2

	Six Months Ended June 30
	Degree Days
Weather (1)	2022	2021	B (W)
Heating (4,610 Normal)	4,751	4,336	9.6	%
Cooling (144 Normal)	249	242	2.9	%

(1)Normal degree days are based on a 20-year moving average of monthly temperatures from the Green Bay, Wisconsin weather station.

Electric Revenues

Electric revenues increased $82.3 million during the six months ended June 30, 2022, compared with the same period in 2021. To the extent that changes in fuel and purchased power costs are passed through to customers, the changes are offset by comparable changes in revenues. See the discussion of electric utility margins below for more information related to the recovery of fuel and purchased power costs and the remaining drivers of the changes in electric revenues.

Electric Utility Margins

Electric utility margins increased $15.8 million during the six months ended June 30, 2022, compared with the same period in 2021. The significant factors impacting the higher electric utility margins were:

•A $21.0 million increase in margins related to the impact of unprotected excess deferred taxes during the six months ended June 30, 2021, which we agreed to return to customers in our PSCW-approved rate order. This increase in margins is offset in income taxes.

•A $5.8 million net increase in margins related to higher retail sales volumes, driven by the impact of favorable weather during the six months ended June 30, 2022, compared with the same period in 2021. As measured by heating degree days, the six months ended June 30, 2022 were 9.6% colder than the same period in 2021.

These increases in margins were partially offset by a $10.7 million period-over-period negative impact from actual fuel and purchased power costs compared with costs collected in rates. Under the Wisconsin fuel rules, our margins are impacted by under-

06/30/2022 Form 10-Q 33 Wisconsin Public Service Corporation

or over-collections of certain fuel and purchased power costs that are within a 2% price variance from the costs included in rates, and the remaining variance beyond the 2% price variance is generally deferred for future recovery or refund to customers.

Natural Gas Revenues

Natural gas revenues increased $68.6 million during the six months ended June 30, 2022, compared with the same period in 2021. Because prudently incurred natural gas costs are passed through to our customers in current rates, the changes are offset by comparable changes in revenues. The average per-unit cost of natural gas increased 33% during the six months ended June 30, 2022, compared with the same period in 2021. The remaining drivers of changes in natural gas revenues are described in the discussion of natural gas utility margins below.

Natural Gas Utility Margins

Natural gas utility margins increased $4.6 million during the six months ended June 30, 2022, compared with the same period in 2021. The most significant factor impacting the higher natural gas utility margins was an increase from higher sales volumes, primarily driven by the continued economic recovery in Wisconsin from the COVID-19 pandemic, as well as colder weather during the six months ended June 30, 2022, compared with the same period in 2021.

Other Operating Expenses (includes other operation and maintenance, depreciation and amortization, and property and revenue taxes)

Other operating expenses at the utility segment decreased $5.7 million during the six months ended June 30, 2022, compared with the same period in 2021. The significant factors impacting the decrease in operating expenses were:

•A $10.8 million decrease in expense driven by the amortization of a certain portion of our regulatory liability associated with our 2020 earnings sharing mechanism, as discussed in the notes under the other operation and maintenance table above.

•A $9.3 million decrease in transmission expense driven by the amortization of a certain portion of our regulatory liabilities associated with transmission escrow balances, as discussed in the notes under the other operation and maintenance table above.

•A $2.6 million decrease related to a gain on land sales during the six months ended June 30, 2022, compared with the same period in 2021.

These decreases in operating expenses were partially offset by:

•A $7.6 million increase in electric and natural gas distribution expenses, primarily driven by higher storm restoration expense during the six months ended June 30, 2022, and higher costs to maintain system reliability.

•A $6.6 million increase in depreciation and amortization, driven by assets being placed into service as we continue to execute on our capital plan.

•A $2.6 million increase in other operating and maintenance expense related to our power plants, driven by the timing of a planned outage at Weston and reductions in refined coal credits during the six months ended June 30, 2022.

Other Income, Net

Other income, net increased $2.8 million during the six months ended June 30, 2022, compared with the same period in 2021, driven by higher net credits from the non-service components of our net periodic pension and OPEB costs. This increase was partially offset by lower AFUDC-Equity, driven by Badger Hollow I being placed in service in November 2021.

Interest Expense

Interest expense increased $0.7 million during the six months ended June 30, 2022, compared with the same period in 2021. This increase was primarily due to the AFUDC-Debt, driven by Badger Hollow I being placed in service in November 2021.

06/30/2022 Form 10-Q 34 Wisconsin Public Service Corporation

Income Tax Expense

Income tax expense increased $24.4 million during the six months ended June 30, 2022, compared with the same period in 2021. This increase was primarily due to an approximate $21 million negative impact related to lower period-over-period amortization of the unprotected excess deferred tax benefits from the Tax Legislation in connection with the rate order approved by the PSCW, effective January 1, 2020. The impact due to the benefit from the amortization of the unprotected excess deferred tax benefits from the Tax Legislation did not impact earnings as there was an offsetting impact in operating income.

Other Segment Contribution to Operating Income

	Six Months Ended June 30
(in millions)	2022		2021		B (W)
Net income	$	0.6	$	0.7	$	(0.1)

LIQUIDITY AND CAPITAL RESOURCES

Overview

We expect to maintain adequate liquidity to meet our cash requirements for the operation of our business and implementation of our corporate strategy through the internal generation of cash from operations and access to the capital markets.

Cash Flows

The following table summarizes our cash flows during the six months ended June 30:

(in millions)	2022		2021		Change in 2022 Over 2021
Cash provided by (used in):
Operating activities	$	254.3	$	241.5	$	12.8
Investing activities	(168.5)		(178.1)		9.6
Financing activities	(87.9)		(64.0)		(23.9)

Operating Activities

Net cash provided by operating activities increased $12.8 million during the six months ended June 30, 2022, compared with the same period in 2021, driven by:

•A $66.8 million increase in cash from higher overall collections from customers as a result of an increase in retail sales volumes during the six months ended June 30, 2022, compared with the same period in 2021. This increase was driven by colder weather and the continued economic recovery from the COVID-19 pandemic.

•A $48.1 million increase in cash related to lower payments for other operation and maintenance expenses, driven by the timing of payments for accounts payable.

•A $23.1 million increase in cash due to realized gains on derivative instruments and higher collateral received from counterparties during the six months ended June 30, 2022, both driven by higher natural gas prices.

These increases in net cash provided by operating activities were partially offset by:

•A $69.9 million decrease in cash related to higher payments for fuel and purchased power at our plants during the six months ended June 30, 2022, compared with the same period in 2021. Our plants incurred higher fuel costs during the six months ended June 30, 2022, compared with the same period in 2021, as a result of an increase in the price of natural gas.

•A $54.0 million decrease in cash related to higher cash paid for income taxes, driven by the monetization of fewer tax credits during the six months ended June 30, 2022, compared with the same period in 2021.

06/30/2022 Form 10-Q 35 Wisconsin Public Service Corporation

Investing Activities

Net cash used in investing activities decreased $9.6 million during the six months ended June 30, 2022, compared with the same period in 2021, driven by:

•Proceeds of $10.0 million received for reimbursement of ATC's construction costs during the six months ended June 30, 2022. There were no proceeds received for reimbursement during the six months ended June 30, 2021.

•Payments of $5.5 million to affiliates for assets transferred related to a customer billing system during the six months ended June 30, 2021. There were no payments to affiliates for assets transferred during the six months ended June 30, 2022.

•Proceeds of $4.4 million received for the cash surrender of life insurance during the six months ended June 30, 2022.

Partially offsetting this decrease in net cash used in investing activities was a $13.2 million increase in cash paid for capital expenditures during the six months ended June 30, 2022, compared with the same period in 2021, which is discussed in more detail below.

Capital Expenditures

Capital expenditures for the six months ended June 30 were as follows:

(in millions)	2022		2021		Change in 2022 Over 2021
Capital expenditures	$	185.4	$	172.2	$	13.2

The increase in cash paid for capital expenditures during the six months ended June 30, 2022, compared with the same period in 2021, was driven by higher payments for capital expenditures related to Paris and other renewable energy projects and the new natural gas-fired generation facility being constructed at the Weston power plants. These increases were partially offset by lower payments for capital expenditures related to upgrades to our natural gas and electric distribution systems.

See Capital Resources and Requirements – Capital Requirements – Significant Capital Projects for more information.

Financing Activities

Net cash used in financing activities increased $23.9 million during the six months ended June 30, 2022, compared with the same period in 2021, driven by a $148.5 million decrease in cash related to higher net repayments of commercial paper during the six months ended June 30, 2022. This increase in net cash used in financing activities was partially offset by a $125.0 million equity contribution received from our parent during the six months ended June 30, 2022, to balance our capital structure. We did not receive any equity contributions during the same period in 2021.

For more information on our financing activities, see Note 8, Short-Term Debt and Lines of Credit.

Cash Requirements

We require funds to support and grow our business. Our significant cash requirements primarily consist of capital and investment expenditures, payments to retire and pay interest on long-term debt, the payment of common stock dividends to our parent, and the funding of our ongoing operations. See the discussion below and Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources – Cash Requirements in our 2021 Annual Report on Form 10-K for additional information regarding our significant cash requirements.

06/30/2022 Form 10-Q 36 Wisconsin Public Service Corporation

Significant Capital Projects

We have several capital projects that will require significant capital expenditures over the next three years and beyond. All projected capital requirements are subject to periodic review and may vary significantly from estimates, depending on a number of factors. These factors include environmental requirements, regulatory restraints and requirements, changes in tax laws and regulations, acquisition and development opportunities, market volatility, economic trends, supply chain disruptions, the COVID-19 pandemic, inflation, and interest rates. Our estimated capital expenditures and acquisitions for the next three years are reflected below. These amounts include anticipated expenditures for environmental compliance and certain remediation issues. For a discussion of certain environmental matters affecting us, see Note 18, Commitments and Contingencies.

(in millions)
2022	$	627.2	(1)
2023	537.3
2024	621.6
Total	$	1,786.1

(1)This includes actual capital expenditures already incurred in 2022, as well as estimated capital expenditures for the remainder of the year.

We continue to upgrade our electric and natural gas distribution systems to enhance reliability. These upgrades include addressing our aging infrastructure and system hardening and the AMI program. AMI is an integrated system of smart meters, communication networks, and data management systems that enable two-way communication between utilities and customers.

WEC Energy Group is committed to investing in solar, wind, battery storage, and clean natural gas-fired generation. Below are examples of projects that are proposed or currently underway.

•We, along with WE and an unaffiliated utility, received PSCW approval to acquire and construct Paris, a utility-scale solar-powered electric generating facility with a battery energy storage system. The project will be located in Kenosha County, Wisconsin and once fully constructed, we will own 30 MW of solar generation and 17 MW of battery storage of this project. Our share of the cost of this project is estimated to be approximately $65 million, with construction of the solar portion expected to be completed in 2023.

•We, along with WE, received approval to accelerate capital investments in two wind parks. Our share of the investment is expected to be approximately $69 million to repower major components of Crane Creek Wind Park, which is expected to be completed by the end of 2022.

•In March 2021, we, along with WE and an unaffiliated utility, filed an application with the PSCW for approval to acquire and construct Darien, a utility-scale solar-powered electric generating facility with a battery energy storage system. The project will be located in Rock and Walworth counties, Wisconsin and once fully constructed, we will own 37 MW of solar generation and 12 MW of battery storage of this project. If approved, our share of the cost of this project is estimated to be approximately $65 million, with construction of the solar portion expected to be completed in 2024.

•We, along with an unaffiliated utility, received PSCW approval to acquire the Red Barn Wind Park, a utility-scale wind-powered electric generating facility. The project will be located in Grant County, Wisconsin and once constructed, we will own 82 MW of this project. Our share of the cost of this project is estimated to be approximately $160 million, with construction expected to be completed by the end of 2022.

•In April 2021, we, along with WE and an unaffiliated utility, filed an application with the PSCW for approval to acquire the Koshkonong Solar-Battery Park, a utility-scale solar-powered electric generating facility with a battery energy storage system. The project will be located in Dane County, Wisconsin and once fully constructed, we will own 45 MW of solar generation and 25 MW of battery storage of this project. If approved, our share of the cost of this project is estimated to be approximately $97 million, with construction of the solar portion expected to be completed in 2025.

•We, along with WE, received PSCW approval to construct a natural gas-fired generation facility at our existing Weston power plant site in northern Wisconsin. The new facility will consist of seven RICE units. Once constructed, we will own 64 MW of this project. Our share of the cost of this project is estimated to be approximately $85 million, with construction expected to be completed in 2023.

06/30/2022 Form 10-Q 37 Wisconsin Public Service Corporation

•In November 2021, we, along with WE, signed an asset purchase agreement to acquire Whitewater, a commercially operational 236.5 MW dual-fueled (natural gas and low sulfur fuel oil) combined-cycle electrical generation facility in Whitewater, Wisconsin. In December 2021, we, along with WE, filed an application with the PSCW for approval to acquire Whitewater. If approved, our share of the cost of this facility is estimated to be $36.3 million for 50% of the capacity, with the transaction expected to close in early 2023.

•In January 2022, we, along with an unaffiliated utility, filed an application with the PSCW for approval to acquire a portion of West Riverside's nameplate capacity. We are also requesting approval to assign the option to purchase part of West Riverside to WE. If approved, we or WE would acquire 100 MW of capacity, in the first of two potential option exercises. West Riverside is a combined-cycle natural gas plant recently completed by an unaffiliated utility in Rock County, Wisconsin. If approved, and we don't assign the option to WE, our share of the cost of this ownership interest would be approximately $91 million, with the transaction expected to close in the second quarter of 2023. In addition, we could exercise and request approval to assign to WE a second option to acquire an additional 100 MW of capacity.

In March 2022, the DOC opened an investigation into whether new tariffs should be imposed on solar panels and cells imported from multiple southeast Asian countries. See Factors Affecting Results, Liquidity, and Capital Resources – Regulatory, Legislative, and Legal Matters – United States Department of Commerce Complaint and Factors Affecting Results, Liquidity, and Capital Resources – Regulatory, Legislative, and Legal Matters – Uyghur Forced Labor Prevention Act for information on the potential impacts to our solar projects as a result of the DOC investigation and CBP actions related to solar panels, respectively. The expected in-service dates identified above already reflect some of these impacts.

Long-Term Debt

There were no material changes in our outstanding long-term debt during the six months ended June 30, 2022.

Common Stock Dividends

During the six months ended June 30, 2022, we paid common stock dividends of $60.0 million to the sole holder of our common stock, Integrys.

Other Significant Cash Requirements

See Note 18, Commitments and Contingencies, for information regarding our minimum future commitments related to purchase obligations for the procurement of fuel, power, and gas supply, as well as the related storage and transportation. There were no material changes to our other significant commitments outside the ordinary course of business during the six months ended June 30, 2022.

Off-Balance Sheet Arrangements

We are a party to various financial instruments with off-balance sheet risk as a part of our normal course of business, including financial guarantees and letters of credit that support construction projects, commodity contracts, and other payment obligations. We believe that these agreements do not have, and are not reasonably likely to have, a current or future material effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures, or capital resources. For additional information, see Note 8, Short-Term Debt and Lines of Credit, and Note 14, Guarantees.

Sources of Cash

Liquidity

We anticipate meeting our short-term and long-term cash requirements to operate our business and implement our corporate strategy through internal generation of cash from operations, equity contributions from our parent, and access to the capital markets, which allows us to obtain external short-term borrowings, including commercial paper, and intermediate or long-term debt securities. Cash generated from operations is primarily driven by sales of electricity and natural gas to our utility customers, reduced by costs of operations. Our access to the capital markets is critical to our overall strategic plan and allows us to supplement cash

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flows from operations with external borrowings to manage seasonal variations, working capital needs, commodity price fluctuations, unplanned expenses, and unanticipated events.

We maintain a bank back-up credit facility, which provides liquidity support for our obligations with respect to commercial paper and for general corporate purposes. We review our bank back-up credit facility needs on an ongoing basis and expect to be able to maintain adequate credit facilities to support our operations.

The amount, type, and timing of any financings in 2022, as well as in subsequent years, will be contingent on investment opportunities and our cash requirements and will depend upon prevailing market conditions, regulatory approvals, and other factors. We plan to maintain a capital structure consistent with that approved by the PSCW. For more information on our approved capital structure, see Item 1. Business – D. Regulation in our 2021 Annual Report on Form 10-K.

The issuance of our securities is subject to the approval of the PSCW. Additionally, with respect to the public offering of securities, we file registration statements with the SEC under the Securities Act of 1933, as amended (1933 Act). The amounts of securities authorized by the PSCW, as well as the securities registered under the 1933 Act, are closely monitored and appropriate filings are made to ensure flexibility in the capital markets.

At June 30, 2022, our current liabilities exceeded our current assets by $38.1 million. We do not expect this to have any impact on our liquidity as we currently believe that our cash and cash equivalents, our available capacity of $220.2 million under our existing revolving credit facility, cash generated from ongoing operations, and access to the capital markets are adequate to meet our short-term and long-term cash requirements.

See Note 8, Short-Term Debt and Lines of Credit, for more information about our credit facility and commercial paper.

Investments in Outside Trusts

We maintain investments in outside trusts to fund the obligation to provide pension and certain OPEB benefits to current and future retirees. These trusts had investments consisting of fixed income and equity securities that are subject to the volatility of the stock market and interest rates. For more information, see Investments in Outside Trusts in Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources – Sources of Cash in our 2021 Annual Report on Form 10-K.

Debt Covenants

Certain of our short-term debt agreements contain financial covenants that we must satisfy, including a debt to capitalization ratio. At June 30, 2022, we were in compliance with all such covenants. We expect to be in compliance with all such debt covenants for the foreseeable future. See Note 13, Short-Term Debt and Lines of Credit, in our 2021 Annual Report on Form 10-K, for more information regarding our debt covenants.

Credit Rating Risk

Cash collateral postings and prepayments made with external parties, including postings related to exchange-traded contracts, and cash collateral posted by external parties were immaterial as of June 30, 2022. From time to time, we may enter into commodity contracts that could require collateral or a termination payment in the event of a credit rating change to below BBB- at S&P Global Ratings, a division of S&P Global Inc., and/or Baa3 at Moody’s Investors Service, Inc. We also have other commodity contracts that, in the event of a credit rating downgrade, could result in a reduction of our unsecured credit granted by counterparties.

In addition, access to capital markets at a reasonable cost is determined in large part by credit quality. Any credit ratings downgrade could impact our ability to access capital markets.

Subject to other factors affecting the credit markets as a whole, we believe our current ratings should provide a significant degree of flexibility in obtaining funds on competitive terms. However, these security ratings reflect the views of the rating agency only. An explanation of the significance of these ratings may be obtained from the rating agency. Such ratings are not a recommendation to buy, sell, or hold securities. Any rating can be revised upward or downward or withdrawn at any time by a rating agency.

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FACTORS AFFECTING RESULTS, LIQUIDITY, AND CAPITAL RESOURCES

The following is a discussion of certain factors that may affect our results of operations, liquidity, and capital resources. This discussion should be read together with the information in Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations – Factors Affecting Results, Liquidity, and Capital Resources in our 2021 Annual Report on Form 10-K, which provides a more complete discussion of factors affecting us, including market risks and other significant risks, competitive markets, environmental matters, critical accounting policies and estimates, and other matters.

COVID-19 Pandemic

We have taken steps to mitigate the impact of the global COVID-19 pandemic. However, the extent to which the COVID-19 pandemic could continue to impact our results of operations and liquidity is largely dependent upon the ability of our customers to resume or maintain normal operations. Adverse impacts to us and our subsidiaries from a prolonged COVID-19 pandemic environment could include a decrease in revenues, increased bad debt expense, increases in past due accounts receivable balances, and access to the capital markets at unfavorable terms or rates.

We will continue to monitor COVID-19 pandemic-related developments affecting our workforce, customers, and suppliers and will implement additional actions that we determine to be necessary in order to mitigate any additional impacts. We cannot predict the full extent of the impacts of COVID-19, which will depend on, among other things, its duration through new variants, the rate and the effectiveness of both vaccinations and treatments, future regulatory and governmental actions, and the ability to maintain normal business activity.

Regulatory, Legislative, and Legal Matters

Uyghur Forced Labor Prevention Act

The CBP issued a WRO in June 2021, applicable to certain silica-based products originating from the Xinjiang Uyghur Autonomous Region of China (Xinjiang), such as polysilicon, included in the manufacturing of solar panels. In June 2022, the WRO was superseded by the implementation of the UFLPA, which was signed into law by President Biden in December 2021. The UFLPA establishes a rebuttable presumption that any imports wholly or partially manufactured in Xinjiang are prohibited from entering the United States. While our suppliers were able to provide the CBP sufficient documentation to meet WRO compliance requirements, and we expect the same will be true for UFLPA purposes, we cannot currently predict what, if any, impact the UFLPA will have on the overall supply of solar panels into the United States and the related timing and cost of our solar projects included in WEC Energy Group's capital plan.

United States Department of Commerce Complaint

In August 2021, a group of anonymous domestic solar manufacturers filed a petition (AD/CVD) with the DOC seeking to impose new tariffs on solar panels and cells imported from several countries, including Malaysia, Vietnam, and Thailand. The petitioners claimed that Chinese solar manufacturers are shifting products to these countries to avoid the tariffs required on products imported from China. In November 2021, the DOC rejected this petition. In denying the petition, the DOC cited the anonymous group’s refusal of the DOC’s request to provide more detail and identify its members due to concerns about retribution from the dominant Chinese solar industry.

In February 2022, a California based company filed a petition (AD/CVD) with the DOC seeking to impose new tariffs on solar panels and cells imported from multiple countries, including Malaysia, Vietnam, Thailand, and Cambodia. While the petition is similar to the one rejected by the DOC in November 2021, there are notable differences. The group added Cambodia to the petition and is requesting that the DOC conduct a country-wide inquiry into each of the four countries. In March 2022, the DOC decided to act on the February petition and investigate the claim. A DOC decision is expected by January 2023. If the DOC determines that the petition has merit, it would be able to apply any final tariffs retroactively to November 4, 2021. If imposed, the new tariffs are expected to further disrupt the supply of solar modules to the United States, and could impact the cost and timing of our solar projects.

In June 2022, the Biden Administration used its executive powers to issue a 24-month tariff moratorium on solar panels manufactured in Cambodia, Malaysia, Thailand, and Vietnam. The moratorium comes as a direct response to concerns raised about the adverse impact from the ongoing DOC complaint on the U.S. solar industry. As the DOC will continue its investigation discussed above, companies may still be subject to tariffs after the moratorium ends; however, U.S. companies will reportedly be exempt from

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any retroactive tariffs that previously could have applied. The Biden Administration also announced that it will invoke the Defense Production Act to accelerate the production of solar panels in the U.S. The Biden Administration's actions did not address whether WROs applied to panels under previous complaints would be affected.

Infrastructure Investment and Jobs Act

In November 2021, President Biden signed into law the Infrastructure Investment and Jobs Act, which provides for approximately $1.2 trillion of federal spending over the next five years, including approximately $85 billion for investments in power, utilities, and renewables infrastructure across the United States. We expect funding from this Act will support the work we are doing to reduce GHG emissions, increase EV charging, and strengthen and protect the energy grid. Funding in the Act should also help to expand emerging technologies, like hydrogen and carbon management, as we continue the transition to a clean energy future. We believe the Infrastructure Investment and Jobs Act will accelerate investment in projects that will help us meet our net zero emission goals to the benefit of our customers, the communities we serve, and our company.

Environmental Matters

See Note 18, Commitments and Contingencies, for a discussion of certain environmental matters affecting us, including rules and regulations relating to air quality, water quality, land quality, and climate change.

Market Risks and Other Significant Risks

We are exposed to market and other significant risks as a result of the nature of our business and the environment in which we operate. These risks include, but are not limited to, the inflation and supply chain disruptions described below. In addition, there is continuing uncertainty over the impact that the ongoing conflict between Russia and Ukraine will have on the global economy, supply chains, and fuel prices. See Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations – Factors Affecting Results, Liquidity, and Capital Resources – Market Risks and Other Significant Risks in our 2021 Annual Report on Form 10-K for a discussion of market and other significant risks applicable to us.

Inflation and Supply Chain Disruptions

We continue to monitor the impact of inflation and supply chain disruptions. We monitor the costs of medical plans, fuel, transmission access, construction costs, regulatory and environmental compliance costs, and other costs in order to minimize inflationary effects in future years, to the extent possible, through pricing strategies, productivity improvements, and cost reductions. We monitor the global supply chain, and related disruptions, in order to ensure we are able to procure the necessary materials and other resources necessary to both maintain our energy services in a safe and reliable manner and to grow our infrastructure in accordance with WEC Energy Group's capital plan. For additional information concerning risks related to inflation and supply chain disruptions, see the two risk factors below that are disclosed in Part I of our 2021 Annual Report on Form 10-K.

•Item 1A. Risk Factors – Risks Related to the Operation of Our Business – Our operations and corporate strategy may be adversely affected by supply chain disruptions and inflation.

•Item 1A. Risk Factors – Risks Related to Economic and Market Volatility – Fluctuating commodity prices could negatively impact our electric and natural gas utility operations.

For additional information concerning risk factors, including market risks, see the Cautionary Statement Regarding Forward-Looking Information at the beginning of this report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

There have been no material changes related to market risk from the disclosures presented in our 2021 Annual Report on Form 10-K. In addition to the Form 10-K disclosures, see Management's Discussion and Analysis of Financial Condition and Results of Operations – Factors Affecting Results, Liquidity, and Capital Resources – COVID-19 Pandemic and Market Risks and Other Significant Risks in Item 2 of Part I of this report, as well as Note 12, Fair Value Measurements, Note 13, Derivative Instruments, and Note 14, Guarantees, in this report for information concerning our market risk exposures.

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ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

Our management, with the participation of our principal executive officer and principal financial officer, has evaluated the effectiveness of our disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Based upon such evaluation, our principal executive officer and principal financial officer have concluded that, as of the end of such period, our disclosure controls and procedures are effective: (i) in recording, processing, summarizing, and reporting, on a timely basis, information required to be disclosed by us in the reports that we file or submit under the Exchange Act; and (ii) to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.

Changes in Internal Control Over Financial Reporting

There were no changes in our internal control over financial reporting (as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) during the second quarter of 2022 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The following should be read in conjunction with Item 3. Legal Proceedings in Part I of our 2021 Annual Report on Form 10-K. See Note 18, Commitments and Contingencies, and Note 20, Regulatory Environment, in this report for additional information on material legal proceedings and matters related to us.

In addition to those legal proceedings discussed in Note 18, Commitments and Contingencies, and Note 20, Regulatory Environment, we are currently, and from time to time, subject to claims and suits arising in the ordinary course of business. Although the results of these additional legal proceedings cannot be predicted with certainty, management believes, after consultation with legal counsel, that the ultimate resolution of these proceedings will not have a material effect on our financial statements.

ITEM 1A. RISK FACTORS

There were no material changes from the risk factors disclosed in Item 1A. Risk Factors in Part I of our 2021 Annual Report on Form 10-K.

ITEM 6. EXHIBITS

Number	Exhibit
31	Rule 13a-14(a) / 15d-14(a) Certifications
	31.1	Certification Pursuant to Rule 13a-14(a) or 15d-14(a), as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
	31.2	Certification Pursuant to Rule 13a-14(a) or 15d-14(a), as Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32	Section 1350 Certifications
	32.1	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
	32.2	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101	Interactive Data Files
	101.INS	Inline 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	Inline XBRL Taxonomy Extension Schema
	101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase
	101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase
	101.LAB	Inline XBRL Taxonomy Extension Label Linkbase
	101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

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SIGNATURE

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

		WISCONSIN PUBLIC SERVICE CORPORATION
		(Registrant)
		/s/ WILLIAM J. GUC
Date:	August 4, 2022	William J. Guc
		Vice President, Controller, and Assistant Corporate Secretary
		(Duly Authorized Officer and Chief Accounting Officer)

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