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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)


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

For the quarterly period ended ~~March~~June 3130, 2024


☐			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: 001-31387


Northern States Power Company
(Exact Name of Registrant as Specified in its Charter)

Minnesota

41-1967505

(State or Other Jurisdiction of Incorporation or Organization)

(I.R.S. Employer Identification No.)

414 Nicollet Mall

Minneapolis

Minnesota

55401

(Address of Principal Executive Offices)

(Zip Code)


	(612)	330-5500
(Registrant’s Telephone Number, Including Area Code)


N/A
(Former name, former address and former fiscal year, if changed since last report)

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

Title of each class

Trading Symbol(s)

Name of each exchange on which registered

N/A

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.

Class						Outstanding at ~~April~~August 251, 2024
Common Stock, $0.01 par value						1,000,000 shares

Northern States Power Company meets the conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q and is therefore filing this Form 10-Q with the reduced disclosure format specified in General Instruction H(2) to such Form 10-Q.

TABLE OF CONTENTS

PART I	FINANCIAL INFORMATION
Item 1 —	Financial Statements (Unaudited)	4
	Consolidated Statements of Income	4
	Consolidated Statements of Comprehensive Income	5
	Consolidated Statements of Cash Flows	6
	Consolidated Balance Sheets	7
	Consolidated Statements of Common Stockholder’s Equity	8
	Notes to Consolidated Financial Statements	98
Item 2 —	Management’s Discussion and Analysis of Financial Condition and Results of Operations	1820
Item 4 —	Controls and Procedures	2123
PART II	OTHER INFORMATION
Item 1 —	Legal Proceedings	2123
Item 1A —	Risk Factors	2123
Item 5 —	Other Information	2123
Item 6 —	Exhibits	2124
SIGNATURES		2225

This Form 10-Q is filed by NSP-Minnesota. NSP-Minnesota is a wholly owned subsidiary of Xcel Energy Inc. Additional information on Xcel Energy is available in various filings with the SEC. This report should be read in its entirety.

Definitions of Abbreviations

Xcel Energy Inc.’s Subsidiaries and Affiliates (current and former)
NSP-Minnesota			Northern States Power Company, a Minnesota corporation
NSP System			The electric production and transmission system of NSP-Minnesota and NSP-Wisconsin operated on an integrated basis and managed by NSP-Minnesota
NSP-Wisconsin			Northern States Power Company, a Wisconsin corporation
PSCo			Public Service Company of Colorado
SPS			Southwestern Public Service Company
Utility subsidiaries			NSP-Minnesota, NSP-Wisconsin, PSCo and SPS
Xcel Energy			Xcel Energy Inc. and its subsidiaries
Federal and State Regulatory Agencies
D.C. Circuit			United States Court of Appeals for the District of Columbia Circuit
DOC			Minnesota Department of Commerce
EPA			United States Environmental Protection Agency
FERC			Federal Energy Regulatory Commission
MPUC			Minnesota Public Utilities Commission
NDPSC			North Dakota Public Service Commission
OAG			Minnesota Office of Attorney General
SEC			Securities and Exchange Commission
SDPUC			South Dakota Public Utilities Commission
Other
ALJ			Administrative Law Judge
C&I			Commercial and Industrial
CCR			Coal combustion residuals
CCR Rule			Final rule (40 CFR 257.50 - 257.107) published by the EPA regulating the management, storage and disposal of CCRs as nonhazardous waste
CEO			Chief executive officer
CERCLA			Comprehensive Environmental Response, Compensation, and Liability Act
CFO			Chief financial officer
CSPV			Crystalline Silicon Photovoltaic
CUB			Citizens Utility Board
ETR			Effective tax rate
FTR			Financial transmission right
GAAP			United States generally accepted accounting principles
GE			General Electric Company
IPP			Independent power producing entity
MGP			Manufactured gas plant
MISO			Midcontinent Independent System Operator, Inc.
NAV			Net asset value
NOx			Nitrogen Oxides
O&M			Operating and maintenance
PFAS			Per- and Polyfluoroalkyl Substances
PPA			Power purchase agreement
PTC			Production tax credit
RFP			Request for proposal
ROE			Return on equity
RTO			Regional Transmission Organization
SMMPA			Southern Minnesota Municipal Power Agency
Measurements
MW			Megawatts


Forward-Looking Statements

Except for the historical statements contained in this report, the matters discussed herein are forward-looking statements that are subject to certain risks, uncertainties and assumptions. Such forward-looking statements, including those relating to future sales, future expenses, future tax rates, future operating performance, estimated base capital expenditures and financing plans, projected capital additions and forecasted annual revenue requirements with respect to rider filings, expected rate increases to customers, expectations and intentions regarding regulatory proceedings, expected pension contributions, and expected impact on our results of operations, financial condition and cash flows of ~~resettlement~~legal ~~calculations~~proceeding ~~and credit losses relating to certain energy transactions~~outcomes, as well as assumptions and other statements are intended to be identified in this document by the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “objective,” “outlook,” “plan,” “project,” “possible,” “potential,” “should,” “will,” “would” and similar expressions. Actual results may vary materially. Forward-looking statements speak only as of the date they are made, and we expressly disclaim any obligation to update any forward-looking information. The following factors, in addition to those discussed in NSP-Minnesota’s Annual Report on Form 10-K for the fiscal year ended Dec. 31, 2023 and subsequent filings with the SEC, could cause actual results to differ materially from management expectations as suggested by such forward-looking information: operational safety, including our nuclear generation facilities and other utility operations; successful long-term operational planning; commodity risks associated with energy markets and production; rising energy prices and fuel costs; qualified employee workforce and third-party contractor factors; violations of our Codes of Conduct; our ability to recover costs; changes in regulation; reductions in our credit ratings and the cost of maintaining certain contractual relationships; general economic conditions, including recessionary conditions, inflation rates, monetary fluctuations, supply chain constraints and their impact on capital expenditures and/or the ability of NSP-Minnesota to obtain financing on favorable terms; availability or cost of capital; our customers’ and counterparties’ ability to pay their debts to us; assumptions and costs relating to funding our employee benefit plans and health care benefits; tax laws; uncertainty regarding epidemics, the duration and magnitude of business restrictions including shutdowns (domestically and globally), the potential impact on the workforce, including shortages of employees or third-party contractors due to quarantine policies, vaccination requirements or government restrictions, impacts on the transportation of goods and the generalized impact on the economy; effects of geopolitical events, including war and acts of terrorism; cybersecurity threats and data security breaches; seasonal weather patterns; changes in environmental laws and regulations; climate change and other weather events; natural disaster and resource depletion, including compliance with any accompanying legislative and regulatory changes; costs of potential regulatory penalties and wildfire damages in excess of liability insurance coverage; regulatory changes and/or limitations related to the use of natural gas as an energy source; challenging labor market conditions and our ability to attract and retain a qualified workforce; and our ability to execute on our strategies or achieve expectations related to environmental, social and governance matters including as a result of evolving legal, regulatory and other standards, processes, and assumptions, the pace of scientific and technological developments, increased costs, the availability of requisite financing, and changes in carbon markets.

Table of Contents

PART I — FINANCIAL INFORMATION


ITEM 1 — FINANCIAL STATEMENTS

NSP-MINNESOTA AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

(amounts in millions)

	Three Months Ended March 31
	Three Months Ended June 30				Six Months Ended June 30
	2024		2023		2024		2023
Operating revenues
Electric, non-affiliates	$	1,~~133~~117	$	1,~~131~~076	$	2,250	$	2,207
Electric, affiliates	~~122~~120		~~125~~113		242		238
Natural gas	~~273~~90		~~400~~98		363		498
Other	83		1012		11		22
Total operating revenues	1,~~536~~330		1,~~666~~299		2,866		2,965
Operating expenses
Electric fuel and purchased power	~~459~~464		~~505~~518		923		1,023
Cost of natural gas sold and transported	~~139~~23		~~297~~45		162		342
Cost of sales — other	4—		7		4		14
Operating and maintenance expenses	~~295~~328		~~325~~326		623		651
Conservation program expenses	4842		3125		90		56
Depreciation and amortization	~~268~~272		~~262~~202		540		464
Taxes (other than income taxes)	6852		7832		120		110
Total operating expenses	1,~~281~~181		1,~~505~~155		2,462		2,660
Operating income	~~255~~149		~~161~~144		404		305
Other income, net	53		—2		8		2
Allowance for funds used during construction — equity	1113		89		24		17
Interest charges and financing costs
Interest charges and other financing costs	8891		7783		179		160
Allowance for funds used during construction — debt	(56)		(5)		(11)		(10)
Total interest charges and financing costs	8385		7278		168		150
Income before income taxes	~~188~~80		9777		268		174
Income tax benefit	(2351)		(4250)		(74)		(92)
Net income	$	~~211~~131	$	~~139~~127	$	342	$	266

See Notes to Consolidated Financial Statements

Table of Contents

NSP-MINNESOTA AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

(amounts in millions)

	Three Months Ended March 31
	Three Months Ended June 30				Six Months Ended June 30
	2024		2023		2024		2023
Net income	$	~~211~~131	$	~~139~~127	$	342	$	266
Other comprehensive income
Derivative instruments:
Net fair value increase (decrease), net of tax	12		(3)
Net fair value increase, net of tax	—		6		12		3
Total other comprehensive income	12—		~~(3)~~6		12		3
Total comprehensive income	$	~~223~~131	$	~~136~~133	$	354	$	269

See Notes to Consolidated Financial Statements

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NSP-MINNESOTA AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(amounts in millions)

	Three Months Ended March 31
	Six Months Ended June 30
	2024		2023
Operating activities
Net income	$	~~211~~342	$	~~139~~266
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	~~270~~544		~~264~~466
Nuclear fuel amortization	2053		2953
Deferred income taxes	~~112~~160		(3065)
Allowance for equity funds used during construction	(1124)		(817)
Provision for bad debts	68		813
Changes in operating assets and liabilities:
Accounts receivable	16		~~(18)~~43
Accrued unbilled revenues	13(10)		~~112~~81
Inventories	151		6835
Other current assets	(7446)		~~(29)~~2
Accounts payable	~~(21)~~23		(~~133~~81)
Net regulatory assets and liabilities	(729)		~~157~~192
Other current liabilities	(~~170~~270)		4495
Pension and other employee benefit obligations	(4243)		(2219)
Other, net	1215		69
Net cash provided by operating activities	~~350~~740		~~587~~1,073
Investing activities
Capital/construction expenditures	(~~612~~1,308)		(~~532~~1,103)
Purchase of investment securities	(~~189~~469)		(~~236~~416)
Proceeds from the sale of investment securities	~~179~~450		~~228~~398
Investments in utility money pool arrangement	(~~317~~357)		(569)
Repayments from utility money pool arrangement	~~129~~414		—5
Other, net	(23)		(2)
Net cash used in investing activities	(~~812~~1,273)		(~~547~~1,187)
Financing activities
Repayments of short-term borrowings, net	(165)		(87207)
Borrowings under utility money pool arrangement	100		—189
Repayments under utility money pool arrangement	(100)		—(189)
Proceeds from issuance of long-term debt	~~688~~687		—783
Capital contributions from parent	347		151
Repayment of long-term debt	—		(400)
Dividends paid to parent	(121)		(122)
Capital contributions from parent	499		251
Net cash provided by (used in) financing activities	749		(58)
Dividends paid to parent	(222)		(254)
Net change in cash, cash equivalents and restricted cash	287		(18)
Net cash provided by financing activities	799		173
Net change in cash, cash equivalents and restricted cash	266		59
Cash, cash equivalents and restricted cash at beginning of period	34		65
Cash, cash equivalents and restricted cash at end of period	$	~~321~~300	$	47124
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	$	(69149)	$	(69137)
Cash received from (paid for) income taxes, net; includes proceeds from tax credit transfers	76		(5)
Cash received from income taxes, net; includes proceeds from tax credit transfers	193		43
Supplemental disclosure of non-cash investing and financing transactions:
Accrued property, plant and equipment additions	$	~~149~~217	$	~~170~~158
Inventory transfers to property, plant and equipment	921		926
Operating lease right-of-use assets	—39		29
Allowance for equity funds used during construction	1124		817

See Notes to Consolidated Financial Statements

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NSP-MINNESOTA AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (UNAUDITED)

(amounts in millions, except share and per share data)

	March 31, 2024		Dec. 31, 2023
	June 30, 2024		Dec. 31, 2023
Assets
Current assets
Cash and cash equivalents	$	~~321~~300	$	34
Accounts receivable, net	~~471~~462		490
Accounts receivable from affiliates	1219		15
Investments in money pool arrangements	~~245~~—		57
Accrued unbilled revenues	~~277~~301		290
Inventories	~~332~~334		356
Regulatory assets	~~354~~364		250
Derivative instruments	3483		50
Prepayments and other	~~161~~135		87
Total current assets	21,~~207~~998		1,629
Property, plant and equipment, net	19,~~097~~572		18,757
Other assets
Nuclear decommissioning fund and other investments	3,~~403~~443		3,262
Regulatory assets	~~817~~807		837
Derivative instruments	7173		61
Operating lease right-of-use assets	~~417~~435		439
Other	1118		16
Total other assets	4,~~719~~776		4,615
Total assets	$	26,~~023~~346	$	25,001
Liabilities and Equity
Current liabilities
Short-term debt	—		165
Accounts payable	~~531~~589		579
Accounts payable to affiliates	6156		89
Regulatory liabilities	~~326~~362		300
Taxes accrued	~~274~~175		223
Accrued interest	9092		79
Dividends payable to parent	~~101~~103		121
Derivative instruments	3738		44
Operating lease liabilities	9394		91
Other	~~149~~146		351
Total current liabilities	1,~~662~~655		2,042
Deferred credits and other liabilities
Deferred income taxes	2,~~147~~210		1,992
Deferred investment tax credits	1413		14
Regulatory liabilities	2,~~225~~206		2,097
Asset retirement obligations	2,~~689~~775		2,658
Derivative instruments	9091		86
Pension and employee benefit obligations	~~128~~131		168
Operating lease liabilities	~~347~~363		372
Other	2827		35
Total deferred credits and other liabilities	7,~~668~~816		7,422
Commitments and contingencies
Capitalization
Long-term debt	8,~~019~~020		7,330
Common stock — 5,000,000 shares authorized of $0.01 par value; 1,000,000 shares outstanding at March 31, 2024 and Dec. 31, 2023, respectively	—		—
Common stock — 5,000,000 shares authorized of $0.01 par value; 1,000,000 shares outstanding at June 30, 2024 and Dec. 31, 2023, respectively	—		—
Additional paid in capital	6,~~031~~184		5,686
Retained earnings	2,~~651~~679		2,541
Accumulated other comprehensive loss	(8)		(20)
Total common stockholder's equity	8,~~674~~855		8,207
Total liabilities and equity	$	26,~~023~~346	$	25,001

See Notes to Consolidated Financial Statements

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NSP-MINNESOTA AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER’S EQUITY (UNAUDITED)

(amounts in millions, except share data)

	Common Stock Issued					Retained Earnings		Accumulated Other Comprehensive Loss		Total Common Stockholder's Equity
	Shares	Par Value		Additional PaidIn Capital
Three Months Ended March 31, 2024 and 2023
Three Months Ended June 30, 2024 and 2023
Balance at Dec. 31, 2022	1,000,000	$	—	$	5,374	$	2,480	$	(18)	$	7,836
Net income						139				139
Other comprehensive loss								(3)		(3)
Dividends declared to parent						(132)				(132)
Contribution of capital by parent				110						110
Balance at March 31, 2023	1,000,000	$	—	$	5,484	$	2,487	$	(21)	$	7,950
Net income						127				127
Other comprehensive loss								6		6
Dividends declared to parent						(112)				(112)
Contribution of capital by parent				101						101
Balance at June 30, 2023	1,000,000	$	—	$	5,585	$	2,502	$	(15)	$	8,072
Balance at March 31, 2024	1,000,000	$	—	$	6,031	$	2,651	$	(8)	$	8,674
Net income						131				131
Dividends declared to parent						(103)				(103)
Contribution of capital by parent				153						153
Balance at June 30, 2024	1,000,000	$	—	$	6,184	$	2,679	$	(8)	$	8,855
	Common Stock Issued					Retained Earnings		Accumulated Other Comprehensive Loss		Total Common Stockholder's Equity
	Shares	Par Value		Additional PaidIn Capital
Six Months Ended June 30, 2024 and 2023
Balance at Dec. 31, 2022	1,000,000	$	—	$	5,374	$	2,480	$	(18)	$	7,836
Net income						266				266
Other comprehensive income								3		3
Dividends declared to parent						(244)				(244)
Contribution of capital by parent				211						211
Balance at June 30, 2023	1,000,000	$	—	$	5,585	$	2,502	$	(15)	$	8,072
Balance at Dec. 31, 2023	1,000,000	$	—	$	5,686	$	2,541	$	(20)	$	8,207
Net income						~~211~~342				~~211~~342
Other comprehensive income								12		12
Dividends declared to parent						(~~101~~204)				(~~101~~204)
Contribution of capital by parent				~~345~~498						~~345~~498
Balance at March 31, 2024	1,000,000	$	—	$	6,031	$	2,651	$	(8)	$	8,674
Balance at June 30, 2024	1,000,000	$	—	$	6,184	$	2,679	$	(8)	$	8,855
See Notes to Consolidated Financial Statements

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NSP-MINNESOTA AND SUBSIDIARIES

Notes to Consolidated Financial Statements (UNAUDITED)

In the opinion of management, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly, in accordance with GAAP, the financial position of NSP-Minnesota and its subsidiaries as of ~~March~~June 3130, 2024 and Dec. 31, 2023; the results of NSP-Minnesota’s operations, including the components of net income, ~~and~~ comprehensive income, ~~cash flows~~ and changes in stockholder’s equity for the three and six months ended ~~March~~June 3130, 2024 and 2023; and NSP-Minnesota’s cash flows for the six months ended June 30, 2024 and 2023.

All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after ~~March~~June 3130, 2024 up to the date of issuance of these consolidated financial statements. These statements contain all necessary adjustments and disclosures resulting from that evaluation. The Dec. 31, 2023 balance sheet information has been derived from the audited 2023 consolidated financial statements included in the NSP-Minnesota Annual Report on Form 10-K for the year ended Dec. 31, 2023.

Notes to the consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with GAAP on an annual basis have been condensed or omitted pursuant to such rules and regulations. For further information, refer to the consolidated financial statements and notes thereto included in the NSP-Minnesota Annual Report on Form 10-K for the year ended Dec. 31, 2023, filed with the SEC on Feb. 21, 2024. Due to the seasonality of NSP-Minnesota’s electric and natural gas sales, interim results are not necessarily an appropriate base from which to project annual results.


1. Summary of Significant Accounting Policies

The significant accounting policies set forth in Note 1 to the consolidated financial statements in the NSP-Minnesota Annual Report on Form 10-K for the year ended Dec. 31, 2023 appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.


2. Accounting Pronouncements

Recently Issued

Segment Reporting — In November 2023, the FASB issued ASU 2023-07 – Segment Reporting (Topic 280) – Improvements to Reportable Segment Disclosures, which extends the existing requirements for annual disclosures to quarterly periods, and requires that both annual and quarterly disclosures present segment expenses using line items consistent with information regularly provided to the chief operating decision maker. The ASU is effective for annual periods beginning after Dec. 15, 2023 and quarterly periods beginning after Dec. 15, 2024, and ~~Xcel~~NSP-Minnesota ~~Energy~~ does not expect implementation of the new disclosure guidance to have a material impact to its consolidated financial statements.

Income Taxes — In December 2023, the FASB issued ASU 2023-09 – Income Taxes (Topic 740) – Improvements to Income Tax Disclosures, with new disclosure requirements including presentation of prescribed line items in the effective tax rate reconciliation and disclosures regarding state and local tax payments. The ASU is effective for annual periods beginning after Dec. 15, 2024, and ~~Xcel~~NSP-Minnesota ~~Energy~~ does not expect implementation of the new disclosure guidance to have a material impact to its consolidated financial statements.

Climate-Related Disclosures — In March 2024, the SEC issued Final Rule 33-11275 – The Enhancement and Standardization of Climate-Related Disclosures for Investors. This rule requires registrants to provide standardized disclosures in Form 10-K related to climate-related risks, Scope 1 and 2 greenhouse gas emissions, as well as to include in a footnote to the consolidated financial statements the financial impact of severe weather events and other natural conditions. The rule requires implementation in phases between 2025 and 2033. In April 2024, the SEC announced that it would voluntarily stay its final climate disclosure rules pending judicial review. ~~Xcel~~ ~~Energy~~NSP-Minnesota does not expect implementation of the new guidance to have a material impact on the consolidated financial statements.


3. Selected Balance Sheet Data

(Millions of Dollars)	~~March~~June 3130, 2024		Dec. 31, 2023
Accounts receivable, net
Accounts receivable	$	~~516~~501	$	538
Less allowance for bad debts	(4539)		(48)
Accounts receivable, net	$	~~471~~462	$	490

(Millions of Dollars)	~~March~~June 3130, 2024		Dec. 31, 2023
Inventories
Materials and supplies	$	~~222~~226	$	219
Fuel	~~104~~98		105
Natural gas	610		32
Total inventories	$	~~332~~334	$	356

(Millions of Dollars)

~~March~~June 3130, 2024

Dec. 31, 2023

Property, plant and equipment, net

Electric plant

21,~~437~~780

21,206

Natural gas plant

2,~~273~~312

2,256

Common and other property

1,~~316~~346

1,301

Plant to be retired (a)

~~589~~575

604

Construction work in progress

1,~~315~~607

1,085

Total property, plant and equipment

2627,~~930~~620

26,452

Less accumulated depreciation

(8,~~204~~451)

(8,044)

Nuclear fuel

3,~~379~~444

3,337

Less accumulated amortization

(3,~~008~~041)

(2,988)

Property, plant and equipment, net

19,~~097~~572

18,757

(a)Amounts include Sherco 1 and 3 and A.S. King. Balance is presented net of accumulated depreciation.


4. Borrowings and Other Financing Instruments

Short-Term Borrowings

NSP-Minnesota meets its short-term liquidity requirements primarily through the issuance of commercial paper and borrowings under its credit facility and the money pool.

Money Pool — Xcel Energy and its utility subsidiaries have established a money pool arrangement that allows for short-term investments in and borrowings between the utility subsidiaries. Xcel Energy may make investments in the utility subsidiaries at market-based interest rates; however, the money pool arrangement does not allow the utility subsidiaries to make investments in Xcel Energy.

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Money pool borrowings:

(Amounts in Millions, Except Interest Rates)	Three Months Ended ~~March~~June 3130, 2024			Year Ended Dec. 31, 2023
Borrowing limit	$	250		$	250
Amount outstanding at period end	—			—
Average amount outstanding	11—			17
Maximum amount outstanding	~~100~~N/A			135
Weighted average interest rate, computed on a daily basis	~~5.33~~N/A		%	4.97		%
Weighted average interest rate at period end	N/A			N/A

Commercial Paper — Commercial paper outstanding:

(Amounts in Millions, Except Interest Rates)	Three Months Ended ~~March~~June 3130, 2024			Year Ended Dec. 31, 2023
Borrowing limit	$	700		$	700
Amount outstanding at period end	—			165
Average amount outstanding	~~195~~—			92
Maximum amount outstanding	~~400~~N/A			441
Weighted average interest rate, computed on a daily basis	~~5.49~~N/A		%	4.99		%
Weighted average interest rate at period end	N/A			5.47

Letters of Credit — NSP-Minnesota uses letters of credit, generally with terms of one year, to provide financial guarantees for certain obligations. There were $12 million and $15 million of letters of credit outstanding under the credit facility at ~~both~~June ~~March 31~~30, 2024 and Dec. 31, 2023, respectively. Amounts approximate their fair value and are subject to fees.

Revolving Credit Facility — In order to issue its commercial paper, NSP-Minnesota must have a revolving credit facility equal to or greater than the commercial paper borrowing limit and cannot issue commercial paper exceeding available capacity under this credit facility. The credit facility provides short-term financing in the form of notes payable to banks, letters of credit and back-up support for commercial paper borrowings.

NSP-Minnesota has the right to request an extension of the revolving credit facility termination date for two additional one-year periods. All extension requests are subject to majority bank group approval.

At ~~March~~June 3130, 2024, NSP-Minnesota had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)						Drawn (b)						Available
$	700					$	1512					$	~~685~~688

(a)Expires in September 2027.

(b)Includes outstanding commercial paper and letters of credit.

All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity under the credit facility. NSP-Minnesota had no direct advances on the credit facility outstanding at ~~March~~June 3130, 2024 and Dec. 31, 2023.

Bilateral Credit Agreement — In April 2024, NSP-Minnesota’s uncommitted bilateral credit agreement was renewed for an additional one-year term. The credit agreement is limited in use to support letters of credit.

As of ~~March~~June 3130, 2024, NSP-Minnesota had $6570 million of outstanding letters of credit under the $75 million bilateral credit agreement.

Long-Term Borrowings

During the ~~three~~six months ended ~~March~~June 3130, 2024, NSP-Minnesota issued $700 million of 5.40% first mortgage bonds due March 15, 2054.


5. Revenues

Revenue is classified by the type of goods/services rendered and market/customer type. NSP-Minnesota’s operating revenues consisted of the following:

	Three Months Ended March 31, 2024
	Three Months Ended June 30, 2024
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	~~368~~350	$	~~138~~37	$	7—	$	~~513~~387
C&I	~~522~~571		9025		—		~~612~~596
Other	910		—		13		1013
Total retail	~~899~~931		~~228~~62		83		~~1,135~~996
Wholesale	7557		—		—		7557
Transmission	6356		—		—		6356
Interchange	122		—		—		122
Interchange and other	115		11		—		126
Other	3		17		—		20
Total revenue from contracts with customers	1,159		73		3		1,235
Total revenue from contracts with customers	1,162		245		8		1,415
Alternative revenue and other	78		17		—		95
Alternative revenue and other	93		28		—		121
Total revenues	$	1,237	$	90	$	3	$	1,330
Total revenues	$	1,255	$	273	$	8	$	1,536

	Three Months Ended March 31, 2023
	Three Months Ended June 30, 2023
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	~~358~~317	$	~~207~~42	$	910	$	~~574~~369
C&I	~~543~~517		~~173~~40		—		~~716~~557
Other	89		—		12		911
Total retail	~~909~~843		~~380~~82		1012		~~1,299~~937
Wholesale	~~104~~80		—		—		~~104~~80
Transmission	6466		—		—		6466
Interchange and other	~~126~~108		23		—		~~128~~111
Total revenue from contracts with customers	1,~~203~~097		~~382~~85		1012		1,~~595~~194
Alternative revenue and other	5392		1813		—		71105
Total revenues	$	1,~~256~~189	$	~~400~~98	$	1012	$	1,~~666~~299



	Six Months Ended June 30, 2024
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	718	$	175	$	7	$	900
C&I	1,093		115		—		1,208
Other	19				4		23
Total retail	1,830		290		11		2,131
Wholesale	132		—		—		132
Transmission	119		—		—		119
Interchange and other	240		28		—		268

Total revenue from contracts with customers	2,321		318		11		2,650
Alternative revenue and other	171		45		—		216
Total revenues	$	2,492	$	363	$	11	$	2,866

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	Six Months Ended June 30, 2023
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	675	$	249	$	19	$	943
C&I	1,060		213		—		1,273
Other	17		—		3		20
Total retail	1,752		462		22		2,236
Wholesale	184		—		—		184
Transmission	130		—		—		130
Interchange and other	234		5		—		239

Total revenue from contracts with customers	2,300		467		22		2,789
Alternative revenue and other	145		31		—		176
Total revenues	$	2,445	$	498	$	22	$	2,965


6. Income Taxes

Reconciliation between the statutory rate and ETR:

	Three Months Ended March 31
	Six Months Ended June 30
	2024		2023
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	7.0		7.0
(Decreases) increases:
Wind PTCs (a)	(3549.19)		(6574.17)
Plant regulatory differences (b)	(5.24)		(6.27)
Other tax credits, net operating loss & tax credit allowances	(1.01)		(1.35)
Other (net)	1.1		1.3
Other, net	0.8		2.0
Effective income tax rate	(1227.26)	%	(4352.39)	%

(a)Wind PTCs net of estimated transfer discounts are credited to customers (reduction to revenue) and do not materially impact net income.

(b)Plant regulatory differences primarily relate to the credit of excess deferred taxes to customers ~~through the average rate assumption method~~. Income tax benefits associated with the credit are offset by corresponding revenue reductions.

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7. Fair Value of Financial Assets and Liabilities

Fair Value Measurements

Accounting guidance for fair value measurements and disclosures provides a hierarchical framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value.

•Level 1 — Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. The types of assets and liabilities included in Level 1 are actively traded instruments with observable actual trading prices.

•Level 2 — Pricing inputs are other than actual trading prices in active markets, but are either directly or indirectly observable as of the reporting date. The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts, or priced with models using highly observable inputs.

•Level 3 — Significant inputs to pricing have little or no observability as of the reporting date. The types of assets and liabilities included in Level 3 include those valued with models requiring significant judgment or estimation.

Specific valuation methods include:

Investments in equity securities and other funds — Equity securities are valued using quoted prices in active markets. The fair values for commingled funds are measured using NAVs. The investments in commingled funds may be redeemed for NAV with proper notice. Private equity commingled funds require approval of the fund for any unscheduled redemption, and such redemptions may be approved or denied by the fund at its sole discretion. Unscheduled distributions from real estate commingled funds may be redeemed with proper notice, however, withdrawals may be delayed or discounted as a result of fund illiquidity.

Investments in debt securities — Fair values for debt securities are determined by a third party pricing service using recent trades and observable spreads from benchmark interest rates for similar securities.

Interest rate derivatives — Fair values of interest rate derivatives are based on broker quotes that utilize current market interest rate forecasts.

Commodity derivatives — Methods used to measure the fair value of commodity derivative forwards and options utilize forward prices and volatilities, as well as pricing adjustments for specific delivery locations, and are generally assigned a Level 2 classification.

When contracts relate to inactive delivery locations or extend to periods beyond those readily observable on active exchanges, the significance of the use of less observable inputs on a valuation is evaluated and may result in Level 3 classification.

Electric commodity derivatives held by NSP-Minnesota include transmission congestion instruments, generally referred to as FTRs. FTRs purchased from an RTO are financial instruments that entitle or obligate the holder to monthly revenues or charges based on transmission congestion across a given transmission path.

The values of these instruments are derived from, and designed to offset, the costs of transmission congestion. In addition to overall transmission load, congestion is also influenced by the operating schedules of power plants and the consumption of electricity pertinent to a given transmission path. Unplanned plant outages, scheduled plant maintenance, changes in the relative costs of fuels used in generation, weather and overall changes in demand for electricity can each impact the operating schedules of the power plants on the transmission grid and the value of these instruments.

FTRs are recognized at fair value and adjusted each period prior to settlement. Given the limited observability of certain variables underlying the reported auction values of FTRs, these fair value measurements have been assigned a Level 3 classification.

Net congestion costs, including the impact of FTR settlements are shared through fuel and purchased energy cost recovery mechanisms. As such, the fair value of the unsettled instruments (i.e., derivative asset or liability) is offset/deferred as a regulatory asset or liability.

Non-Derivative Fair Value Measurements

The Nuclear Regulatory Commission requires NSP-Minnesota to maintain a portfolio of investments to fund the costs of decommissioning its nuclear generating plants. Assets of the nuclear decommissioning fund are legally restricted for the purpose of decommissioning these facilities. The fund contains cash equivalents, debt securities, equity securities and other investments. NSP-Minnesota uses the MPUC approved asset allocation for the investment targets by asset class for the qualified trust.

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NSP-Minnesota recognizes the costs of funding the decommissioning over the lives of the nuclear plants, assuming rate recovery of all costs. Realized and unrealized gains on fund investments over the life of the fund are deferred as an offset of NSP-Minnesota’s regulatory asset for nuclear decommissioning costs. Consequently, any realized and unrealized gains and losses on securities in the nuclear decommissioning fund are deferred as a component of the associated nuclear decommissioning costs.

Unrealized gains for the nuclear decommissioning fund were $1.3 billion and $1.2 billion as of ~~March~~June 3130, 2024 and Dec. 31, 2023, and unrealized losses were $3440 million and $29 million as of ~~March~~June 3130, 2024 and Dec. 31, 2023, respectively.

Non-derivative instruments with recurring fair value measurements in the nuclear decommissioning fund:

	March 31, 2024
	June 30, 2024
			Fair Value
(Millions of Dollars)	Cost		Level 1		Level 2		Level 3		NAV		Total
Nuclear decommissioning fund (a)
Cash equivalents	$	5743	$	5743	$	—	$	—	$	—	$	5743
Commingled funds	~~718~~713		—		—		—		1,~~042~~036		1,~~042~~036
Debt securities	~~804~~834		—		~~781~~801		914		—		~~790~~815
Equity securities	~~511~~517		1,~~457~~493		21		—		—		1,~~459~~494
Total	$	2,~~090~~107	$	1,~~514~~536	$	~~783~~802	$	914	$	1,~~042~~036	$	3,~~348~~388

(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $55 million of other investments, including the rabbi trust.


	Dec. 31, 2023
			Fair Value
(Millions of Dollars)	Cost		Level 1		Level 2		Level 3		NAV		Total
Nuclear decommissioning fund (a)
Cash equivalents	$	41	$	41	$	—	$	—	$	—	$	41
Commingled funds	721		—		—		—		1,049		1,049
Debt securities	784		—		771		9		—		780
Equity securities	508		1,339		2		—		—		1,341
Total	$	2,054	$	1,380	$	773	$	9	$	1,049	$	3,211

(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $51 million of other investments, including the rabbi trust.

11For the three and six months ended June 30, 2024 and 2023, there were no transfers of Level 3 investments between levels.

~~Table~~Contractual maturity dates of ~~Contents~~debt securities in the nuclear decommissioning fund as of June 30, 2024:

For the three months ended March 31, 2024 and 2023, there were no Level 3 nuclear decommissioning fund investments or transfer of amounts between levels.


	Final Contractual Maturity
(Millions of Dollars)	Due in 1 Year or Less		Due in 1 to 5 Years		Due in 5 to 10 Years		Due after 10 Years		Total
Debt securities	$	5	$	289	$	266	$	255	$	815

Contractual maturity dates of debt securities in the nuclear decommissioning fund as of March 31, 2024:

	Final Contractual Maturity
(Millions of Dollars)	Due in 1 Year or Less		Due in 1 to 5 Years		Due in 5 to 10 Years		Due after 10 Years		Total
Debt securities	$	6	$	276	$	257	$	251	$	790

Derivative Activities and Fair Value Measurements

NSP-Minnesota enters into derivative instruments, including forward contracts, futures, swaps and options, for trading purposes and to manage risk in connection with changes in interest rates and utility commodity prices.

Interest Rate Derivatives — NSP-Minnesota enters into contracts that effectively fix the interest rate on a specified principal amount of a hypothetical future debt issuance. These financial swaps net settle based on changes in a specified benchmark interest rate, acting as a hedge of changes in market interest rates that will impact specified anticipated debt issuances. These derivative instruments are designated as cash flow hedges for accounting purposes, with changes in fair value prior to occurrence of the hedged transactions recorded as other comprehensive income.

As of ~~March~~June 3130, 2024, accumulated other comprehensive loss related to interest rate derivatives included immaterial net losses expected to be reclassified into earnings during the next 12 months as the hedged transactions impact earnings. As of ~~March~~June 3130, 2024, NSP-Minnesota had no unsettled interest rate derivatives.

See Note 10 for the financial impact of qualifying interest rate cash flow hedges on NSP-Minnesota’s accumulated other comprehensive loss included in the consolidated statements of common stockholder’s equity and in the consolidated statements of comprehensive income.

Wholesale and Commodity Trading — NSP-Minnesota conducts various wholesale and commodity trading activities, including the purchase and sale of electric capacity, energy, energy-related instruments and natural gas-related instruments, including derivatives. NSP-Minnesota is allowed to conduct these activities within guidelines and limitations as approved by its risk management committee, comprised of management personnel not directly involved in the activities governed by this policy.

Results of derivative instrument transactions entered into for trading purposes are presented in the consolidated statements of income as electric revenues, net of any sharing with customers. These activities are not intended to mitigate commodity price risk associated with regulated electric and natural gas operations. Sharing of these margins is determined through state regulatory proceedings as well as the operation of the FERC-approved joint operating agreement.

Commodity Derivatives — NSP-Minnesota enters into derivative instruments to manage variability of future cash flows from changes in commodity prices in its electric and natural gas operations. This could include the purchase or sale of energy or energy-related products, natural gas to generate electric energy, natural gas for resale and FTRs.

The most significant derivative positions outstanding at ~~March~~June 3130, 2024 for this purpose relate to FTR instruments administered by MISO. These instruments are intended to offset the impacts of transmission system congestion.

When NSP-Minnesota enters into derivative instruments that mitigate commodity price risk on behalf of electric and natural gas customers, the instruments are not typically designated as qualifying hedging transactions. The classification of unrealized losses or gains on these instruments as a regulatory asset or liability, if applicable, is based on approved regulatory recovery mechanisms.

As of ~~March~~June 3130, 2024, NSP-Minnesota had no commodity contracts designated as cash flow hedges.

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Gross notional amounts of commodity forwards, options and FTRs:

(Amounts in Millions) (a)(b)	~~March~~June 3130, 2024	Dec. 31, 2023
Megawatt hours of electricity	2458	38
Million British thermal units of natural gas	6162	64

(a)Not reflective of net positions in the underlying commodities.

(b)Notional amounts for options included on a gross basis but weighted for the probability of exercise.

Consideration of Credit Risk and Concentrations — NSP-Minnesota continuously monitors the creditworthiness of counterparties to its interest rate derivatives and commodity derivative contracts prior to settlement and assesses each counterparty’s ability to perform on the transactions set forth in the contracts. Impact of credit risk was immaterial to the fair value of unsettled commodity derivatives presented on the consolidated balance sheets.

NSP-Minnesota’s most significant concentrations of credit risk with particular entities or industries are contracts with counterparties to its wholesale, trading and non-trading commodity activities.

As of ~~March~~June 3130, 2024, ~~four~~three of NSP-Minnesota’s ten most significant counterparties for these activities, comprising $2321 million, or 2119%, of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings.

Three of the ten most significant counterparties, comprising $3125 million, or 2823%, of this credit exposure, were not rated by these external ratings agencies, but based on NSP-Minnesota’s internal analysis, had credit quality consistent with investment grade.

~~Three~~Four of these significant counterparties, comprising $5561 million or 5056% of this credit exposure, had credit quality less than investment grade, based on internal analysis.

~~Five~~Four of these significant counterparties are municipal or cooperative electric entities, RTOs or other utilities.

Credit Related Contingent Features — Contract provisions for derivative instruments that NSP-Minnesota enters into, including those accounted for as normal purchase and normal sale contracts and therefore not reflected on the consolidated balance sheets, may require the posting of collateral or settlement of the contracts for various reasons, including if the applicable utility subsidiary’s credit ratings are downgraded below its investment grade credit rating by any of the major credit rating agencies.

As of ~~March~~June 3130, 2024 and Dec. 31, 2023, there were $1417 million and $12 million, respectively, of derivative liabilities with such underlying contract provisions.

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Certain contracts also contain cross default provisions that may require the posting of collateral or settlement of the contracts if there was a failure under other financing arrangements related to payment terms or other covenants.

As of ~~both~~June ~~March 31~~30, 2024 and Dec. 31, 2023, there were approximately $8486 million and $80 million, respectively of derivative liabilities with such underlying contract provisions.

Certain derivative instruments are also subject to contract provisions that contain adequate assurance clauses. These provisions allow counterparties to seek performance assurance, including cash collateral, in the event that a given utility subsidiary’s ability to fulfill its contractual obligations is reasonably expected to be impaired. NSP-Minnesota had no collateral posted related to adequate assurance clauses in derivative contracts as of ~~March~~June 3130, 2024 and Dec. 31, 2023.

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Recurring Derivative Fair Value Measurements

Impact of derivative activity:

	Pre-Tax Fair Value Gains (Losses) Recognized During the Period in:
(Millions of Dollars)	Accumulated Other Comprehensive Loss		Regulatory Assets and Liabilities
Three Months Ended March 31, 2024
Three Months Ended June 30, 2024
Other derivative instruments:
Electric commodity	$	—	$	—
Natural gas commodity	—		—
Total	$	—	$	—
Six Months Ended June 30, 2024
Derivatives designated as cash flow hedges:
Interest rate	$	16	$	—
Total	$	16	$	—
Other derivative instruments:
Electric commodity	$	—	$	1
Natural gas commodity	—		3
Total	$	—	$	4
Three Months Ended March 31, 2023
Three Months Ended June 30, 2023
Derivatives designated as cash flow hedges:
Interest rate	$	~~(4)~~8	$	—
Total	$	~~(4)~~8	$	—
Derivatives designated as cash flow hedges:
Electric commodity	$	—	$	(11)
Total	$	—	$	(11)
Six Months Ended June 30, 2023
Derivatives designated as cash flow hedges:
Interest rate	$	4	$	—
Total	$	4	$	—
Other derivative instruments:
Electric commodity	$	—	$	(1728)
Natural gas commodity	—$	—	2$	2
Total	$	—	$	(1526)

	Pre-Tax Losses Reclassified into Income During the Period from:			Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Regulatory Assets and Liabilities
Three Months Ended March 31, 2024
Three Months Ended June 30, 2024
Other derivative instruments:
Commodity trading	$	—		$	1(14)	(a)
Electric commodity	42		(b)	—
Total	$	2		$	(14)
Six Months Ended June 30, 2024
Other derivative instruments:
Commodity trading	$	—		$	(13)	(a)
Electric commodity	6		(b)	—
Natural gas commodity	—			(5)		(c)(d)
Total	$	46		$	(418)
Three Months Ended March 31, 2023
Three Months Ended June 30, 2023
Other derivative instruments:
Electric commodity	7		(b)	—
Total	$	7		$	—
Six Months Ended June 30, 2023
Other derivative instruments:
Commodity trading	$	—		$	(1)	(a)
Electric commodity	1421		(b)	—
Natural gas commodity	—			(5)		(c)(d)
Total	$	1421		$	(6)

(a)Recorded to electric revenues. Presented amounts do not reflect non-derivative transactions or margin sharing with customers.

(b)Recorded to electric fuel and purchased power. These derivative settlement gains and losses are shared with electric customers through fuel and purchased energy cost-recovery mechanisms, and reclassified out of income as regulatory assets or liabilities, as appropriate. FTR settlements are shared with customers and do not have a material impact on net income. Presented amounts reflect changes in fair value between auction and settlement dates, but exclude the original auction fair value.

(c)Recorded to cost of natural gas sold and transported. These losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset, as appropriate.

(d)Relates primarily to option premium amortization.

NSP-Minnesota had no derivative instruments designated as fair value hedges during the ~~three~~six months ended ~~March~~June 3130, 2024 and 2023.

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Derivative assets and liabilities measured at fair value on a recurring basis were as follows:

	March 31, 2024												Dec. 31, 2023
	June 30, 2024												Dec. 31, 2023
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative assets
Other derivative instruments:
Commodity trading	$	85	$	3435	$	3022	$	7262	$	(4344)	$	2918	$	7	$	32	$	32	$	71	$	(42)	$	29
Electric commodity	—		—		965		965		(43)		562		—		—		23		23		(7)		16
Natural gas commodity	—		—3		—		—3		—		—3		—		5		—		5		—		5
Total current derivative assets	$	85	$	3438	$	3987	$	81130	$	(47)	$	3483	$	7	$	37	$	55	$	99	$	(49)	$	50
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	75	$	4746	$	5157	$	~~105~~108	$	(3435)	$	7173	$	7	$	43	$	45	$	95	$	(34)	$	61
Total noncurrent derivative assets	$	75	$	4746	$	5157	$	~~105~~108	$	(3435)	$	7173	$	7	$	43	$	45	$	95	$	(34)	$	61

	March 31, 2024												Dec. 31, 2023
	June 30, 2024												Dec. 31, 2023
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative liabilities
Derivatives designated as cash flow hedges:
Interest rate	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	7	$	—	$	7	$	—	$	7
Other derivative instruments:
Commodity trading	$	76	$	6465	$	56	$	7677	$	(45)	$	3132	$	6	$	60	$	5	$	71	$	(43)	$	28
Electric commodity	—		—		43		43		(43)		—		—		—		7		7		(7)		—
Natural gas commodity	—		—		—		—		—		—		—		3		—		3		—		3
Total current derivative liabilities	$	76	$	6465	$	9	$	80	$	(4948)	3132		$	6	$	70	$	12	$	88	$	(50)	38
PPAs (b)											6												6
Current derivative instruments											$	3738											$	44
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	11	$	5156	$	42	$	~~104~~109	$	(3537)	$	6972	$	14	$	49	$	37	$	100	$	(36)	$	64
Total noncurrent derivative liabilities	$	11	$	5156	$	42	$	~~104~~109	$	(3537)	6972		$	14	$	49	$	37	$	100	$	(36)	64
PPAs (b)											2119												22
Noncurrent derivative instruments											$	9091											$	86

(a)NSP-Minnesota nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At ~~March~~June 3130, 2024 and Dec. 31, 2023, derivative assets and liabilities include no obligations to return cash collateral. At both ~~March~~June 3130, 2024 and Dec. 31, 2023 derivative assets and liabilities include rights to reclaim cash collateral of $3 million. Counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.

(b)NSP-Minnesota currently applies the normal purchase exception to qualifying PPAs. Balance relates to specific contracts that were previously recognized at fair value prior to applying the normal purchase exception, and are being amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities.

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Changes in Level 3 commodity derivatives:

	Three Months Ended March 31
	Three Months Ended June 30
(Millions of Dollars)	2024		2023
Balance at April 1	$	39	$	46
Purchases (a)	72		97
Settlements (a)	(27)		(15)
Net transactions recorded during the period:
Gains recognized in earnings (b)	3		12
Net gains (losses) recognized as regulatory assets and liabilities (a)	6		(23)
Balance at June 30	$	93	$	117
	Six Months Ended June 30
(Millions of Dollars)	2024		2023
Balance at Jan. 1	$	51	$	107
Settlements (a)	(15)		(13)
Purchases (a)	72		97
Settlements (a)	(42)		(28)
Net transactions recorded during the period:
Losses recognized in earnings (b)	—		(14)
Gains (losses) recognized in earnings (b)	3		(2)
Net gains (losses) recognized as regulatory assets and liabilities (a)	39		(3457)
Balance at March 31	$	39	$	46
Balance at June 30	$	93	$	117

(a)Relates primarily to FTR instruments administered by MISO.

(b)Relates to commodity trading and is subject to substantial offsetting losses and gains on derivative instruments categorized as levels 1 and 2 in the consolidated income statement. See above tables for the income statement impact of derivative activity, including commodity trading gains and losses.

Fair Value of Long-Term Debt

As of ~~March~~June 3130, 2024, other financial instruments for which the carrying amount did not equal fair value:

March 31, 2024

Dec. 31, 2023

June 30, 2024

Dec. 31, 2023

(Millions of Dollars)

Carrying Amount

Fair Value

Carrying Amount

Fair Value

Long-term debt, including current portion

8,~~019~~020

6,~~993~~847

7,330

6,561

Fair value of NSP-Minnesota’s long-term debt is estimated based on recent trades and observable spreads from benchmark interest rates for similar securities. Fair value estimates are based on information available to management as of ~~March~~June 3130, 2024 and Dec. 31, 2023, and given the observability of the inputs, fair values presented for long-term debt were assigned as Level 2.


8. Benefit Plans and Other Postretirement Benefits

Components of Net Periodic Benefit Cost

	Three Months Ended March 31
	Three Months Ended June 30
	2024		2023		2024		2023
(Millions of Dollars)	Pension Benefits				Postretirement HealthCare Benefits
Service cost	$	56	$	5	$	—	$	—
Interest cost (a)	98		9		1—		1
Expected return on plan assets (a)	(1112)		(11)		—		—
Amortization of net loss (a)	3		3		—		—
Net periodic benefit cost	6		6		1		1
Settlement charge (b)	31		—		—		—
Effects of regulation	3		1		—		—
Net periodic benefit cost	36		6		—		1
Net benefit cost recognized for financial reporting	$	9	$	7	$	1	$	1
Effects of regulation	(32)		3		—		—
Net benefit cost recognized for financial reporting	$	4	$	9	$	—	$	1
	Six Months Ended June 30
	2024		2023		2024		2023
(Millions of Dollars)	Pension Benefits				Postretirement HealthCare Benefits
Service cost	$	11	$	10	$	—	$	—
Interest cost (a)	17		18		1		1
Expected return on plan assets (a)	(23)		(23)		—		—
Amortization of net loss (a)	6		6		—		—
Settlement charge (b)	31		—		—		—
Net periodic benefit cost	42		11		1		1
Effects of regulation	(29)		5		—		—
Net benefit cost recognized for financial reporting	$	13	$	16	$	1	$	1

(a)The components of net periodic cost other than the service cost component are included in the line item “Other income, net” in the consolidated statements of income or capitalized on the consolidated balance sheets as a regulatory asset.

(b)A settlement charge is required when the amount of lump-sum distributions during the year is greater than the sum of the service and interest cost components of the annual net periodic pension cost. In the second quarter of 2024, as a result of lump-sum distributions during the 2024 plan year, NSP-Minnesota recorded a pension settlement charge of $31 million, which was not recognized in earnings due to the effects of rate making.

In January 2024, contributions totaling $100 million were made across Xcel Energy’s pension plans, of which $41 million was attributable to NSP-Minnesota. Xcel Energy does not expect additional pension contributions during 2024.

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9. Commitments and Contingencies

Legal

NSP-Minnesota is involved in various litigation matters in the ordinary course of business. The assessment of whether a loss is probable or is a reasonable possibility, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. Management maintains accruals for losses probable of being incurred and subject to reasonable estimation. Management is sometimes unable to estimate an amount or range of a reasonably possible loss in certain situations, including but not limited to when (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories.

In such cases, there is considerable uncertainty regarding the timing or ultimate resolution, including a possible eventual loss. For current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, would have a material effect on NSP-Minnesota’s consolidated financial statements. Legal fees are generally expensed as incurred.

Rate Matters and Other

NSP-Minnesota is involved in various regulatory proceedings arising in the ordinary course of business. Until resolution, typically in the form of a rate order, uncertainties may exist regarding the ultimate rate treatment for certain activities and transactions. Amounts have been recognized for probable and reasonably estimable losses that may result. Unless otherwise disclosed, any reasonably possible range of loss in excess of any recognized amount is not expected to have a material effect on the consolidated financial statements.

Sherco — In 2018, NSP-Minnesota and SMMPA (Co-owner of Sherco Unit 3) reached a settlement with GE related to a 2011 incident, which damaged the turbine at Sherco Unit 3 and resulted in an extended outage ~~for repair~~. NSP-Minnesota notified the MPUC of its proposal to refund settlement proceeds to customers through the fuel clause adjustment.

In March 2019, the MPUC approved NSP-Minnesota’s settlement refund proposal. Additionally, the MPUC decided to withhold any decision as to NSP-Minnesota’s prudence in connection with the incident at Sherco Unit 3 until after conclusion of an appeal pending between GE and NSP-Minnesota’s insurers. In February 2020, the Minnesota Court of Appeals affirmed the district court’s judgment in favor of GE.

In January 2021, the OAG and DOC recommended that NSP-Minnesota refund approximately $17 million of replacement power costs previously recovered through the FCA. NSP-Minnesota responded that it acted prudently in connection with the Sherco Unit 3 outage, the MPUC has previously disallowed $22 million of related costs and no additional refund or disallowance is appropriate.

In July 2022, the MPUC referred the matter to the Office of Administrative Hearings to conduct a contested case on the prudence of the replacement power costs incurred by NSP-Minnesota. In 2023, NSP-Minnesota and various parties filed recommendations, including the DOC which recommended a $56 million customer refund. The Xcel Large Industrial customer group recommended a refund of $72 million. ~~A final decision by the MPUC is expected in mid-2024. A loss related to this matter is deemed remote.~~

15In May 2024, the ALJ recommended a customer refund of $34 million (less a portion of the proceeds received from the settlement with GE). The ALJ indicated that consideration of the $22 million of previously disallowed costs was not in the scope of their recommendation. Xcel Energy has recorded an estimate for a customer refund in this matter. A final decision by the MPUC is expected in late 2024.

~~Table~~Minnesota 2023 Fuel Clause Adjustment — In March 2024, NSP-Minnesota filed its annual fuel clause adjustment true-up petition to the MPUC, with a proposed refund of ~~Contents~~$126 million for fuel over-recoveries in 2023. In April 2024, the DOC recommended the MPUC approve the non-nuclear aspects of the petition.

In May 2024, the DOC and Minnesota OAG filed comments relating to an outage at the Prairie Island generating station that lasted from October 2023 through February 2024. The DOC recommended that NSP-Minnesota refund $20 million of replacement power costs for 2023 as well as a future refund of replacement power costs for 2024 once those costs are known. The OAG recommended that NSP-Minnesota refund $18 million of replacement power costs for 2023 and did not address 2024.

In July 2024, NSP-Minnesota filed reply comments in the 2023 proceeding in support of its position that no customer refund for replacement power costs is warranted. A final decision by the MPUC is expected in late 2024.

Environmental

New and changing federal and state environmental mandates can create financial ~~liabilities~~obligations for NSP-Minnesota, which are normally recovered through the regulated rate process.

Site Remediation

Various federal and state environmental laws impose liability where hazardous substances or other regulated materials have been released to the environment. NSP-Minnesota may sometimes pay all or a portion of the cost to remediate sites where past activities of their predecessors or other parties have caused environmental contamination.

Environmental contingencies could arise from various situations, including sites of former MGPs; and third-party sites, such as landfills, for which NSP-Minnesota is alleged to have sent wastes to that site.

MGP, Landfill and Disposal Sites

NSP-Minnesota is investigating, remediating or performing post-closure actions at seven MGP, landfill or other disposal sites across its service territories.

NSP-Minnesota has recognized approximately $1 million of costs/liabilities ~~from~~for ~~final~~ resolution of these issues,; however, the ~~outcome~~final outcomes and timing are unknown. In addition, there may be regulatory recovery, insurance recovery and/or recovery from other potentially responsible parties, offsetting a portion of costs incurred.

~~Environmental Requirements —~~ Water and Waste

Coal Ash Regulation — NSP-Minnesota’s ~~operations~~is ~~are~~ subject to ~~federal~~the ~~and~~CCR ~~state~~Rule, ~~regulations~~which ~~that~~imposes ~~impose~~ requirements for handling, storage, treatment and disposal of ~~solid~~coal ~~waste,~~ash ~~including the CCR Rule. As a specific requirement of the CCR Rule, utilities must complete groundwater sampling around their applicable landfills~~ and ~~surface~~other ~~impoundments~~solid ~~as well as perform corrective actions where offsite groundwater has been impacted~~waste.

IfIn ~~certain~~May ~~impacts~~2024, final amendments to ~~groundwater~~the ~~are~~CCR ~~detected,~~Rule ~~utilities~~were ~~are~~published. ~~required~~These toinclude ~~perform~~legacy ~~additional~~CCR ~~groundwater~~surface ~~investigations~~impoundments at inactive facilities and~~/or~~ ~~perform~~previously ~~corrective~~exempt ~~actions~~areas ~~beginning~~where ~~with~~CCR anwas ~~Assessment~~placed directly on land at CCR-regulated facilities, including areas of ~~Corrective~~beneficial ~~Measures~~use.

NSP-Minnesota is conducting groundwater sampling and monitoring and implementing assessment of corrective measures at certain CCR landfills and surface impoundments. No results above the groundwater protection standards in the rule were identified. 17

~~Federal~~Table Clean Water Act Section 316(b) — The Federal Clean Water Act requires the EPA to regulate cooling water intake structures to assure they reflect the best technology available for minimizing impingement and entrainment of ~~aquatic species.~~ Contents

As a specific requirement of the CCR Rule, utilities must complete facility evaluations and groundwater sampling around their subject landfills, surface impoundments and certain other areas where coal ash was placed on land, as well as perform corrective actions where offsite groundwater has been impacted.

If certain impacts to groundwater are detected, utilities may be required to perform additional groundwater investigations and/or perform corrective actions, typically beginning with an Assessment of Corrective Measures.

NSP-Minnesota expects to incur $6 million for investigations through 2028 to perform required reporting and assess whether corrective actions are necessary. Asset retirement obligations have been recorded for each of these activities, and amounts are expected to be recoverable through regulatory mechanisms.

NSP-Minnesota has also identified coal ash that is expected to be required to be removed from certain closed coal-fueled generating facilities at estimated costs totaling approximately $60 million. Asset retirement obligations have been recorded, with the costs expected to be recoverable through regulatory mechanisms.

NSP-Minnesota continues to evaluate the 2024 updates to the CCR rule, the interpretations of those updates and how they will apply to specific sites. Assessment of the recent updates to the CCR Rule and corresponding site investigation activities may result in updates to estimated costs as well as identification of additional required corrective actions.

Clean Water Act Section 316(b) — The Federal Clean Water Act requires the EPA to regulate cooling water intake structures to assure they reflect the best technology available for minimizing impingement and entrainment of aquatic species.

NSP-Minnesota estimates capital expenditures of approximately $45 million may be required to comply with the requirements. NSP-Minnesota anticipates these costs will be recoverable through regulatory mechanisms.

~~Environmental Requirements —~~ Air

Clean Air Act NOx Allowance Allocations — In June 2023, the EPA published final regulations for ozone under the “Good Neighbor” provisions of the Clean Air Act. The final rule applies to generation facilities in Minnesota, as well as other states outside of our service territory. The rule establishes an allowance trading program for NOx that will impact NSP-Minnesota fossil fuel-fired electric generating facilities. Subject facilities will have to secure additional allowances, install NOx controls and/or develop a strategy of operations that utilizes the existing allowance allocations. Guidelines are also established for allowance banking and emission limit backstops.

While the financial impacts of the final rule are uncertain and dependent on market forces and anticipated generation, NSP-Minnesota anticipates the annual costs could be significant, but would be recoverable through regulatory mechanisms.

NSP-Minnesota has joined other companies in litigation challenging the EPA’s disapproval of Minnesota’s state implementation plan. Currently, the regulation is under a judicial stay for Minnesota. The regulation may become applicable in the future, depending on the outcome of the litigation and the status of the stay of the final rule, which was granted by the U.S. Supreme Court in June 2024.

Leases

NSP-Minnesota evaluates contracts that may contain leases, including PPAs and arrangements for the use of office space, land for solar developments and other facilities, vehicles and equipment. A contract contains a lease if it conveys the exclusive right to control the use of a specific asset.

Components of lease expense:

	Three Months Ended March 31
	Three Months Ended June 30
(Millions of Dollars)	2024		2023
Operating leases
PPA capacity payments	$	2325	$	2524
Other operating leases (a)	53		45
Total operating lease expense (b)	$	28	$	29

(a)Includes immaterial short-term lease expense for both 2024 and 2023.

(b)PPA capacity payments are included in electric fuel and purchased power on the consolidated statements of income. Expense for other operating leases is included in O&M expense and electric fuel and purchased power.

Commitments under operating leases as of March 31, 2024:



	Six Months Ended June 30
(Millions of Dollars)	2024		2023
Operating leases
PPA capacity payments	$	48	$	49
Other operating leases (a)	8		9
Total operating lease expense (b)	$	56	$	58

(Millions of Dollars)	PPA OperatingLeases		Other OperatingLeases		TotalOperatingLeases
Total minimum obligation	$	377	$	174	$	551
Interest component of obligation	(32)		(79)		(111)
Present value of minimum obligation	$	345	$	95	440
Less current portion					(93)
Noncurrent operating lease liabilities					$	347

(a)Includes immaterial short-term lease expense for both 2024 and 2023.

16(b)PPA capacity payments are included in electric fuel and purchased power on the consolidated statements of income. Expense for other operating leases is included in O&M expense and electric fuel and purchased power.

~~Table~~Commitments under operating leases as of ~~Contents~~June 30, 2024:


(Millions of Dollars)	PPA Operating Leases		Other Operating Leases		Total Operating Leases
Total minimum obligation	$	352	$	262	$	614
Interest component of obligation	(29)		(128)		(157)
Present value of minimum obligation	$	323	$	134	457
Less current portion					(94)
Noncurrent operating lease liabilities					$	363

Variable Interest Entities

Under certain PPAs, NSP-Minnesota purchases power from IPPs for which NSP-Minnesota is required to reimburse fuel costs, or to participate in tolling arrangements under which NSP-Minnesota procures the natural gas required to produce the energy that it purchases. NSP-Minnesota has determined that certain IPPs are VIEs, however NSP-Minnesota is not subject to risk of loss from the operations of these entities, and no significant financial support is required other than contractual payments for energy and capacity.

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NSP-Minnesota evaluated each of these VIEs for possible consolidation, including review of qualitative factors such as the length and terms of the contract, control over O&M, control over dispatch of electricity, historical and estimated future fuel and electricity prices and financing activities. NSP-Minnesota concluded that these entities are not required to be consolidated in its consolidated financial statements because NSP-Minnesota does not have the power to direct the activities that most significantly impact the entities’ economic performance.

NSP-Minnesota had approximately 1,347 MW of capacity under long-term PPAs at both ~~March~~June 3130, 2024 and Dec. 31, 2023, with entities that have been determined to be VIEs. These agreements have expiration dates through 2039.


10. Other Comprehensive Loss

Changes in accumulated other comprehensive loss, net of tax:

	Three Months Ended March 31, 2024						Three Months Ended March 31, 2023
	Three Months Ended June 30, 2024						Three Months Ended June 30, 2023
(Millions of Dollars)	Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total		Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total
Accumulated other comprehensive loss at Jan. 1	$	(18)	$	(2)	$	(20)	$	(16)	$	(2)	$	(18)
Accumulated other comprehensive loss at April 1	$	(6)	$	(2)	$	(8)	$	(19)	$	(2)	$	(21)
Gains reclassified from net accumulated other comprehensive income:
Other comprehensive gain before reclassifications	12—		—		12—		—6		—		—6
Losses reclassified from net accumulated other comprehensive loss:
Net current period other comprehensive income	—		—		—		6		—		6
Interest rate derivatives (a)	—		—		—		(3)		—		(3)
Accumulated other comprehensive loss at June 30	$	(6)	$	(2)	$	(8)	$	(13)	$	(2)	$	(15)
Net current period other comprehensive income (loss)	12		—		12		(3)		—		(3)
Accumulated other comprehensive loss at March 31	$	(6)	$	(2)	$	(8)	$	(19)	$	(2)	$	(21)

(a)Included in interest charges.



	Six Months Ended June 30, 2024						Six Months Ended June 30, 2023
(Millions of Dollars)	Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total		Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total
Accumulated other comprehensive loss at Jan. 1	$	(18)	$	(2)	$	(20)	$	(16)	$	(2)	$	(18)
Gains reclassified from net accumulated other comprehensive income:
Other comprehensive gain before reclassifications	12		—		12		3		—		3


Net current period other comprehensive income	12		—		12		3		—		3
Accumulated other comprehensive loss at June 30	$	(6)	$	(2)	$	(8)	$	(13)	$	(2)	$	(15)


11. Segment Information

NSP-Minnesota evaluates performance based on profit or loss generated from the product or service provided. These segments are managed separately because the revenue streams are dependent upon regulated rate recovery, which is separately determined for each segment.

NSP-Minnesota has the following reportable segments:

•Regulated Electric — The regulated electric utility segment generates electricity which is transmitted and distributed in Minnesota, North Dakota and South Dakota. In addition, this segment includes sales for resale and provides wholesale transmission service to various entities in the United States. The regulated electric utility segment also includes NSP-Minnesota’s wholesale commodity and trading operations.

•Regulated Natural Gas — The regulated natural gas utility segment transports, stores and distributes natural gas in portions of Minnesota and North Dakota.

NSP-Minnesota also presents All Other, which includes operating segments with revenues below the necessary quantitative thresholds. Those operating segments primarily include appliance repair services revenues/commissions, non-utility real estate activities and revenues associated with processing solid waste into refuse-derived fuel.

Asset and capital expenditure information is not provided for NSP-Minnesota’s reportable segments. As an integrated electric and natural gas utility, NSP-Minnesota operates significant assets that are not dedicated to a specific business segment. Reporting assets and capital expenditures by business segment would require arbitrary and potentially misleading allocations, which may not necessarily reflect the assets that would be required for the operation of the business segments on a stand-alone basis.

Certain costs, such as common depreciation, common O&M expenses and interest expense are allocated based on cost causation allocators across each segment. In addition, a general allocator is used for certain general and administrative expenses, including office supplies, rent, property insurance and general advertising.

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NSP-Minnesota’s segment information:

	Three Months Ended March 31
	Three Months Ended June 30
(Millions of Dollars)	2024		2023
Regulated Electric
Total revenues (a)	$	1,~~255~~237	$	1,~~256~~189
Net income	~~145~~122		~~111~~134
Regulated Natural Gas
Operating revenues (b)	$	273	$	400
Total revenues (b)	$	90	$	98
Intersegment revenue	1		1
Net income (loss)	4		(9)
Total revenues	$	274	$	401
Net income	51		30
All Other
Total revenues	$	83	$	1012
Net income (loss)	15		(2)
Net income	5		2
Consolidated Total
Operating revenues (a)(b)	$	1,537	$	1,667
Total revenues (a)(b)	$	1,330	$	1,299
Reconciling eliminations	(1)		(1)
Net income	131		127
Total operating revenues	$	1,536	$	1,666
Net income	211		139

(a)~~Operating~~Total revenues include $~~122~~120 million and $~~125~~113 million of affiliate electric revenue for the three months ended ~~March~~June 3130, 2024 and 2023.

(b)~~Operating~~Total revenues include an immaterial amount of affiliate gas revenue for the three months ended ~~March~~June 3130, 2024 and 2023.


	Six Months Ended June 30
(Millions of Dollars)	2024		2023
Regulated Electric


Total revenues (a)	$	2,492	$	2,445
Net income	267		245
Regulated Natural Gas
Operating revenues (b)	$	363	$	498
Intersegment revenue	1		1
Total revenues	$	364	$	499
Net income	55		21
All Other
Total revenues	$	11	$	22
Net income	20		—
Consolidated Total
Total revenues	$	2,867	$	2,966
Reconciling eliminations	(1)		(1)
Total operating revenues (a)(b)	$	2,866	$	2,965
Net income	342		266

(a)Total revenues include $242 million and $238 million of affiliate electric revenue for the six months ended June 30, 2024 and 2023.

(b)Operating revenues include an immaterial amount of affiliate gas revenue for the six months ended June 30, 2024 and 2023.

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

Discussion of financial condition and liquidity for NSP-Minnesota is omitted per conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q for wholly owned subsidiaries. It is replaced with management’s narrative analysis of the results of operations set forth in General Instruction H(2)(a) of Form 10-Q for wholly owned subsidiaries (reduced disclosure format).

Non-GAAP Financial Measures

The following discussion includes financial information prepared in accordance with GAAP, as well as certain non-GAAP financial measures such as ongoing earnings. Generally, a non-GAAP financial measure is a measure of a company’s financial performance, financial position or cash flows that adjusts measures calculated and presented in accordance with GAAP.

NSP-Minnesota’s management uses non-GAAP measures for financial planning and analysis, for reporting of results to the Board of Directors, in determining performance-based compensation, and communicating its earnings outlook to analysts and investors. Non-GAAP financial measures are intended to supplement investors’ understanding of our performance and should not be considered alternatives for financial measures presented in accordance with GAAP. These measures are discussed in more detail below and may not be comparable to other companies’ similarly titled non-GAAP financial measures.


Results of Operations

NSP-Minnesota’s net income was $~~211~~342 million for the ~~three~~six months ended ~~March~~June 3130, 2024 compared with $~~139~~266 million for the prior year. ~~The~~Year-to-date ~~change~~earnings ~~was~~primarily ~~driven~~reflect by increased recovery of electric and natural gas infrastructure investments and lower O&M expenses, partially offset by higher ~~interest~~depreciation ~~expenses~~ and ~~depreciation.~~interest expenses.

Electric Revenue

Electric revenues are impacted by fluctuations in the price of natural gas, coal and uranium, regulatory outcomes, market prices and seasonality. In addition, electric customers receive a credit for PTCs generated, which reduce electric revenue and income taxes. ~~In the first quarter, electric revenues decreased $1 million.~~

(Millions of Dollars)	~~Three~~Six Months Ended ~~March~~June 30, 2024 vs. 2023
Recovery of lower electric fuel and purchased power expenses	$	(46)
Regulatory rate outcomes	$	122
PTCs flowed back to customers	(6)
Conservation and demand side management	35
Interchange agreement revenue from NSP-Wisconsin	(3)
Non-fuel riders	29
Regulatory rate outcomes	28
Recovery of lower electric fuel and purchased power expenses	(84)
Conservation and demand side management	18
PTCs flowed back to customers	(8)
Non-fuel riders	14
Sales and demand (a)	(7)
Sales and demand (a)	8
Estimated impact of weather (net of sales true-up)	(5)
Other (net)	(14)
Other, net	(27)
Total decrease	$	(1)
Total increase	$	47

(a)Sales excludes weather impact, net of sales true-up mechanism in Minnesota.

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Natural Gas Revenues

Natural gas revenues vary with changing sales, the cost of natural gas and regulatory outcomes. ~~In the first quarter, natural gas revenues decreased $127 million for the first quarter.~~

(Millions of Dollars)	~~Three~~Six Months Ended ~~March~~June 30, 2024 vs. 2023
Recovery of lower natural gas costs (sold and transported)	$	(~~158~~180)
Regulatory rate outcomes	2032
Infrastructure and integrity riders	35
Estimated impact of weather (net of decoupling)	2
Other, net	8
Retail sales growth (net of decoupling)	2
Total decrease	$	(135)
Other (net)	4
Total	$	(127)

Electric Fuel and Purchased Power — Expenses incurred for electric fuel and purchased power are impacted by fluctuations in market prices of natural gas, coal and uranium, as well as seasonality. ~~However,~~These ~~these~~ incurred expenses are generally recovered through various regulatory recovery mechanisms. As a result, changes in these expenses are ~~generally~~largely offset in operating revenues and have minimal earnings impact.

Electric fuel and purchased power expenses decreased $46100 million ~~for the first quarter of 2024~~year-to-date. The decrease is primarily due to decreased volumes and timing of fuel recovery mechanisms, partially offset by ~~higher~~changes ~~commodity~~in ~~prices~~generation mix.

Cost of Natural Gas Sold and Transported — Expenses incurred for the cost of natural gas sold are impacted by market prices and seasonality. These costs are generally recovered through various regulatory recovery mechanisms. As a result, changes in these expenses are ~~generally~~largely offset in operating revenues and have minimal earnings impact.

Natural gas sold and transported decreased $~~158~~180 million ~~for the first quarter of 2024~~year-to-date. The decrease is primarily due to timing of fuel recovery, lower commodity prices and volumes.

Non-Fuel Operating Expenses and Other Items

O&M Expenses — O&M expenses decreased $3028 million ~~for the first quarter~~year-to-date. The decrease was primarily due to decreased labor and benefit costs, gain on ~~the~~a land sale ofin ~~land~~the first quarter and lower bad debt expenses.

18Depreciation and Amortization — Depreciation and amortization expense increased $76 million year-to-date as a result of system expansion partially offset by wind and nuclear life extensions implemented in 2023 in the Minnesota Electric Rate Case.

~~Table~~Interest ofCharges ~~Contents~~— Interest charges increased $19 million year-to-date, largely due to increased debt levels and higher interest rates.

Depreciation and Amortization — Depreciation and amortization expense increased $6 million for the first quarter as a result of system expansion offset by depreciation life extensions implemented in the Minnesota Electric Rate Case.

Interest Charges — Interest charges increased $11 million year-to-date, largely due to increased long-term debt levels and higher interest rates to fund capital investments.

Public Utility Regulation and Other

The FERC and various state and local regulatory commissions regulate NSP-Minnesota. NSP-Minnesota is subject to rate regulation by state utility regulatory agencies, which have jurisdiction with respect to the rates of electric and natural gas distribution companies in Minnesota, North Dakota and South Dakota.

Rates are designed to recover plant investment, operating costs and an allowed return on investment. NSP-Minnesota requests changes in utility rates through commission filings. Changes in operating costs can affect NSP-Minnesota’s financial results, depending on the timing of rate cases and implementation of final rates. Other factors affecting rate filings are new investments, sales, conservation and demand side management efforts, and the cost of capital.

In addition, the regulatory commissions authorize the ROE, capital structure and depreciation rates in rate proceedings. Decisions by these regulators can significantly impact NSP-Minnesota’s results of operations.

Except to the extent noted below, the circumstances set forth in Public Utility Regulation included in Item 7 of NSP-Minnesota’s Annual Report on Form 10-K for the year ended Dec. 31, 2023 appropriately represent, in all material respects, the current status of public utility regulation and are incorporated herein by reference.

Pending and Recently Concluded Regulatory Proceedings

2024 Minnesota Natural Gas Rate Case — In November 2023, NSP-Minnesota filed a request with the MPUC for ana ~~annual~~ natural gas rate increase of approximately $59 million, or 9.6%. The request is based on a ROE of 10.2%, a 52.5% equity ratio and a 2024 forward test year with rate base of approximately $1.27 billion. In December 2023, the MPUC approved NSP-Minnesota’s request for interim rates, subject to refund, of approximately $51 million (implemented on Jan. 1, 2024).

OnIn ~~April~~June ~~19,~~ 2024, ~~four~~NSP-Minnesota ~~parties filed direct testimony. The DOC, OAG,~~ and ~~CUB~~various ~~were the only~~ parties tofiled ~~quantify~~an ~~recommended~~uncontested ~~financial adjustments. The OAG and CUB provided limited comments~~settlement, ~~recommending~~which aincludes ~~reduction~~the offollowing ~~approximately~~terms: ~~$1 million of O&M expenses each. The CUB additionally recommended a reduction to ROE.~~

~~Proposed~~•Natural ~~DOC~~gas ~~modifications~~rate toincrease ~~NSP-Minnesota’s~~of ~~request~~$46 ~~were~~million, asor ~~follows:~~7.5%.

(Millions of Dollars)
NSP-Minnesota’s filed base revenue request	$	59
Recommended adjustments:
Rate of return	(7)
Operating & maintenance expenses	(4)
Plant investments	(3)
Other, net	(2)
Total adjustments	$	(16)
Total proposed revenue change	$	43

•ROE of 9.6%.

~~Positions~~•Equity onratio ~~NSP-Minnesota’s~~of ~~filed rate request were as follows:~~52.5%.

Recommended Position	DOC		CUB
ROE	9.40	%	9.00-9.40%
Equity ratio	52.50	%	N/A

•Rate base of $1.25 billion.

~~Procedural~~•No ~~schedule:~~change to Commission approved decoupling.

~~•Mediation:~~A ~~May~~MPUC ~~17,~~decision ~~2024~~and ~~(day~~order ~~subject~~is toexpected ~~availability)~~by the end of 2024.

~~•Rebuttal~~2024 ~~testimony:~~North ~~May~~Dakota 24Natural Gas Rate Case — In December 2023, NSP-Minnesota filed a request with the NDPSC seeking an increase in natural gas rates of $8.5 million (9.4%), based on a ROE of 10.20%, an equity ratio of 52.5%, 2024 test year and rate base of $168 million. In February 2024, the NDPSC approved interim rates of $8 million, effective March 1, 2024.

~~•Evidentiary~~In ~~hearings:~~June ~~July~~2024, ~~10-12~~the North Dakota staff filed testimony and recommended a $6.3 million increase (7%), ~~2024~~based on a ROE of 9.8% and a 50% equity ratio.

~~•ALJ~~The ~~report:~~procedural ~~October~~schedule ~~28,~~is ~~2024~~as follows:

•~~MPUC~~Surrebuttal ~~Order Due~~testimony: ~~March~~Aug. 1412-26, ~~2025~~2024

~~2024~~•Evidentiary ~~North~~hearings: ~~Dakota~~Sept. ~~Natural Gas Rate Case — In December 2023, NSP~~3-~~Minnesota filed a request with the NDPSC seeking an increase in natural gas rates of $8.~~5 ~~million (9.4%)~~, a 2024 ~~test year, ROE of 10.20%, an equity ratio of 52.5% and rate base of $168 million. In February 2024, the NDPSC approved interim rates of $8 million, effective March 1, 2024.~~

~~Minnesota~~A ~~2023~~NDPSC ~~Fuel~~decision ~~Clause~~is ~~Adjustment~~expected —by ~~In March 2024, NSP~~year-~~Minnesota submitted an annual fuel clause adjustment true-up petition to the MPUC, with a requested refund of $126 million for fuel over-recoveries in 2023~~end. In April 2024, the DOC recommended the MPUC approve the non-nuclear aspects of the petition. The DOC stated it intends to submit supplemental comments in the second quarter of 2024 with recommendations related to costs associated with operation of NSP-Minnesota’s nuclear units, which includes costs associated with an outage at the Prairie Island generating station.

2022 Minnesota Electric Rate Case — In October 2021, NSP-Minnesota filed a three-year electric rate case with the MPUC.

In July 2023, the MPUC approved a three-year rate increase of approximately $332 million for 2022-2024, based on a ROE of 9.25% and an equity ratio of 52.5%. The MPUC also approved a continuation of the sales true-up mechanism.

In November 2023, NSP-Minnesota filed an appeal of the decision to the Minnesota Court of Appeals.

In June 2024, a group of Minnesota utilities filed an amicus brief supporting NSP-Minnesota’s position related to prepaid pension assets. The appeal is pending a court decision.

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NSP System

2022 Upper Midwest IRP Resource Acquisition — ~~Following the MPUC’s approval of~~ NSP-Minnesota and NSP-Wisconsin’s ~~latest IRP in April 2022, NSP-Minnesota and NSP-Wisconsin~~ have been engaged in multiple resource acquisition processes and proceedings to meet the need identified in the approved Upper Midwest IRP.

•In the second quarter of 2023, NSP-Minnesota initiated the process with the MPUC for acquisition of 800 MW of firm dispatchable resources. In January 2024, NSP-Minnesota and other companies submitted proposed resources and filed for project approval with the MPUC. NSP-Minnesota expects a decision by the second quarter of 2025.

•In July 2023, NSP-Wisconsin issued an RFP seeking ~~approximately~~ 650 MW of solar and/or solar plus storage development assets ~~that will be developed in the 2027-2029 timeframe~~ to replace the capacity from the retiring King Generating Station. ~~The~~NSP-Wisconsin ~~RFP~~did ~~closed~~not inaccept ~~September~~any ~~2023~~bids from the RFP and ~~bids~~continues ~~are~~to ~~being~~pursue ~~evaluated~~projects to meet this capacity need, including through the July 2024 RFP.

•In October 2023, NSP-Minnesota issued an RFP seeking ~~approximately~~ 1,200 MW of wind ~~development~~ assets to replace capacity and reutilize interconnection rights associated with the retiring Sherco coal facilities. The RFP closed in December 2023. ~~and~~ NSP-Minnesota expects to file for approval of recommended projects by ~~mid-~~the fourth quarter of 2024.

19•In June and July 2024, respectively, NSP-Minnesota and NSP-Wisconsin each issued an RFP collectively seeking up to 1,600 MW of wind, solar, storage or hybrid resources to interconnect to the NSP System. Among other things, the RFP will seek to reutilize interconnection rights associated with the retiring Sherco and King coal units in NSP-Minnesota. Dependent on the proposals received, NSP-Minnesota or NSP-Wisconsin plan to file for the requisite approvals of the selected resources with the MPUC and PSCW, respectively, in the second quarter of 2025.

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2024 Upper Midwest Resource Plan — In February 2024, NSP filed its Upper Midwest Resource Plan with the MPUC which included the following key items:

•Reduced carbon emissions by more than 80%, potentially up to 88%, by 2030.

•Extends the operation of Prairie Island and Monticello through the early 2050s.

•Adds 3,600 MWs of new wind and solar resources by 2030.

•Adds 600 MWs of battery energy storage by 2030.

•Adds more than 2,200 MWs of dispatchable resources by 2030.

These proposed resources are in addition to projects already approved by the MPUC. NSP-Minnesota anticipates a MPUC decision in 2025 and will file related RFPs upon approval.

Nuclear Power Operations

NSP-Minnesota owns two nuclear generating plants: the Monticello plant and the Prairie Island plant. See Note 10 to the consolidated financial statements of NSP-Minnesota’s Annual Report on Form 10-K for the year ended Dec. 31, 2023 for further information. The circumstances set forth in Nuclear Power Operations included in Item 7 of NSP-Minnesota’s Annual Report on Form 10-K for the year ended Dec. 31, 2023, appropriately represent, in all material respects, the current status of nuclear power operations.

Other

Supply Chain

NSP-Minnesota’s ability to meet customer energy requirements, respond to storm-related disruptions and execute our capital expenditure program are dependent on maintaining an efficient supply chain. Manufacturing processes have experienced disruptions related to scarcity of certain raw materials and interruptions in production and shipping. These disruptions have been further exacerbated by inflationary pressures, labor shortages and the impact of international conflicts/issues. NSP-Minnesota continues to monitor the situation as it remains fluid and seeks to mitigate the impacts by securing alternative suppliers, modifying design standards, and adjusting the timing of work.

~~Solar~~Large ~~Resources~~global demand for energy-related infrastructure (renewables and gas generation, data centers, etc.) has stretched equipment supply chains, extended delivery dates and increased prices for items like combustion turbines, transformers and other large electrical equipment. The labor market for skilled engineering and construction resources to build renewables and gas generation has also been strained, impacting cost and availability.

Tariffs and Trade Complaints

In August 2023, the U.S. Department of Commerce completed its anti-circumvention investigation and concluded that CSPV solar panels and cells imported from Malaysia, Vietnam, Thailand, and Cambodia would be subject to incremental tariffs ranging from 50% to 250%. These countries account for more than 80% of CSPV panel imports.

An interim stay on tariffs ~~remains~~remained in effect until June 2024 and many significant solar projects have resumed with modified costs and projected in-service dates, including the Sherco Solar facility. Further policy action, a change in the interim stay of tariffs, or other restrictions on solar imports (e.g., as a result of implementation of the Uyghur Forced Labor Protection Act), disruptions in solar imports from key suppliers or any new trade complaint could impact project timelines and costs.

OnIn April ~~24,~~ 2024, the American Alliance for Solar Manufacturing Trade Committee filed a petition related to new anti-dumping and countervailing duty cases targeting solar products from Cambodia, Malaysia, Thailand and Vietnam with the United States Department of Commerce and the United States International Trade Commission. ~~NSP-Minnesota continues to assess the impacts (if any) of this trade complaint on its business.~~

~~Emerging~~In ~~Environmental~~May ~~Regulation~~2024, the U.S. Department of Commerce announced the initiation of anti-dumping and countervailing duty investigations of CSPV cells, whether or not assembled into modules. A preliminary decision related to this matter is anticipated in November 2024.

In June 2024, a previous tariff exclusion for bi-facial panels ended. Tariff rate is now 14.25% until February 2025 and 14% until February 2026 for imported panels.

In May 2024, the White House imposed a new 25% tariff on Lithium-Ion storage along with other trade measures. The tariff went into immediate effect for EV batteries but has a grace period until January 2026 for stationary energy storage applications.

NSP-Minnesota continues to assess the impacts of these tariffs and trade complaints on its business, including company-owned projects and PPAs. NSP-Minnesota may seek regulatory relief for tariffs, if required, in its jurisdictions.

Further policy actions or other restrictions on solar and storage imports, disruptions in imports from key suppliers, or any new trade complaint could impact project timelines and costs of various generation projects and PPAs.

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Environmental Regulation

Clean Air Act

Power Plant Greenhouse Gas Regulations — In April 2024, the EPA published final rules addressing control of CO2 emissions from the power sector. The rules regulate new natural gas generating units and emission guidelines for existing coal and certain natural gas generation. The rules create subcategories of coal units based on planned retirement date and subcategories of natural gas combustion turbines and combined cycle units based on utilization. The CO2 control requirements vary by subcategory. Based on current estimates and assumptions, NSP-Minnesota ~~continues~~has determined that due to ~~evaluate~~scheduled ~~the~~plant retirements, there is minimal financial or operational impact ofassociated with these ~~rules~~requirements and believes that the cost of these initiatives or replacement generation would be recoverable through rates based on prior state commission practices.

Coal Ash Regulation

In April 2024, the EPA published final rules to regulate additional areas under the CCR Rule for the first time, including legacy CCR surface impoundments at inactive facilities and previously exempt areas where CCR was placed directly on land at regulated CCR facilities. The rule subjects these areas to groundwater monitoring, corrective action and closure and post-closure care requirements, among other requirements, with several of the deadlines accelerated. NSP-Minnesota believes that the cost of these requirements would be recoverable through rates based on prior state commission practices.

Emerging Contaminants of Concern

PFAS are man-made chemicals that are widely used in consumer products and can persist and bio-accumulate in the environment. NSP-Minnesota does not manufacture PFAS, but because PFAS are so ubiquitous in products and the environment, it may impact our operations.

In September 2022, the EPA proposed to designate two types of PFAS as “hazardous substances” under the CERCLA. In July 2024, the EPA’s final rule went into effect.

In March 2023, the EPA published a proposed rule that would establish enforceable drinking water standards for certain PFAS chemicals. In June 2024, the EPA’s final rule went into effect.

In February 2024, the EPA proposed to change the Resource Conservation and Recovery Act by adding nine PFAS to its list of hazardous constituents.

~~Final~~Potential ~~rules~~costs ~~for~~are ~~all~~uncertain ~~three~~and ~~proposals~~will ~~are~~be ~~expected~~determined inon ~~2024~~a ~~which~~site ~~could~~specific ~~result~~basis inwhere ~~new obligations~~applicable. ~~Potential~~If costs are ~~uncertain~~incurred, ~~until~~NSP-Minnesota ~~final~~believes ~~rules~~the ~~are~~costs ~~published~~will ~~and/or~~be ~~agency~~recoverable ~~action~~through isrates ~~taken~~based on prior state commission practices.

Effluent Limitation Guidelines

In April 2024, the EPA published final rules under the Clean Water Act, setting ~~forth~~ Effluent Limitations Guidelines and Standards for steam generating coal plants. This rule establishes more stringent wastewater discharge standards for bottom ash transport water, flue-gas desulfurization wastewater, and combustion residuals leachate from steam electric power plants, particularly coal-fired power plants. ~~NSP-Minnesota~~Based ~~continues~~on tocurrent ~~evaluate~~estimates ~~the~~and ~~impact~~assumptions, ofNSP-Minnesota ~~these~~has ~~rules~~determined ~~and~~that ~~believes~~there ~~that~~is ~~any~~minimal ~~costs~~financial or operational impact associated with these requirements and that any costs would be recoverable through rates based on prior state commission practices.

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Nuclear Fuel Supply

~~NSP-Minnesota~~In isMay ~~scheduled~~2024, tothe ~~take~~Prohibiting ~~delivery~~Russian ofUranium ~~approximately~~Imports ~~29%~~Act ofwas ~~its~~signed ~~average~~into ~~enriched~~law. ~~nuclear~~As ~~material~~such, ~~requirements~~NSP-Minnesota ~~from~~will ~~Russia~~no ~~through~~longer ~~2030.~~be ~~Given~~permitted ~~the~~to ~~evolving~~accept ~~situation~~deliveries inof ~~Ukraine~~enriched ~~and~~nuclear ~~its~~material ~~global~~from ~~impacts,~~Russia webeginning ~~have~~in ~~entered~~August ~~into~~2024, ~~additional~~unless ~~contracts~~specific ~~that~~waivers ~~cover~~are ~~potential~~requested ~~supply~~and ~~interruptions of nuclear material from Russia~~received. ~~With these contracts,~~ NSP-Minnesota has secured its enriched nuclear material requirements through ~~2028~~2029 with non-Russian material, which are in various stages of processing in Canada, Europe and the United States. NSP-Minnesota continues to assess the impacts of this legislation on its existing contracts related to Russian-sourced nuclear material.


ITEM 4 — CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

NSP-Minnesota maintains a set of disclosure controls and procedures designed to ensure that information required to be disclosed in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in SEC rules and forms.

In addition, the disclosure controls and procedures ensure that information required to be disclosed is accumulated and communicated to management, including the CEO and CFO, allowing timely decisions regarding required disclosure.

As of ~~March~~June 3130, 2024, based on an evaluation carried out under the supervision and with the participation of NSP-Minnesota’s management, including the CEO and CFO, of the effectiveness of its disclosure controls and procedures, the CEO and CFO have concluded that NSP-Minnesota’s disclosure controls and procedures were effective.

Internal Control Over Financial Reporting

No changes in NSP-Minnesota’s internal control over financial reporting occurred during the most recent fiscal quarter that materially affected, or are reasonably likely to materially affect, NSP-Minnesota’s internal control over financial reporting.

PART II — OTHER INFORMATION


ITEM 1 — LEGAL PROCEEDINGS

Management is sometimes unable to estimate an amount or range of a reasonably possible loss in certain situations, including but not limited to when (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution of such matters, including a possible eventual loss.

For current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, would have a material effect on NSP-Minnesota’s consolidated financial statements. Legal fees are generally expensed as incurred.

See Note 9 to the consolidated financial statements and Part I Item 2 for further information.


ITEM 1A — RISK FACTORS

NSP-Minnesota’s risk factors are documented in Item 1A of Part I of its Annual Report on Form 10-K for the year ended Dec. 31, 2023, which is incorporated herein by reference. There have been no material changes from the risk factors previously disclosed in the Form 10-K.

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ITEM 5 — OTHER INFORMATION

None of the Company’s directors or officers adopted, modified, or terminated a Rule 10b5-1 trading arrangement or a non-Rule 10b5-1 trading arrangement during the Company’s fiscal quarter ended ~~March~~June 3130, 2024.


ITEM 6 — EXHIBITS

* Indicates incorporation by reference

Exhibit Number	Description	Report or Registration Statement	Exhibit Reference
3.01*	Articles of Incorporation and Amendments of Northern Power Corp. (renamed NSP-Minnesota on Aug. 21, 2000)	NSP-Minnesota Form 10-12G dated Oct. 5, 2000	3.01
3.02*	Amended and Restated Bylaws of NSP-Minnesota, dated Jan. 25, 2019	NSP-Minnesota Form 10-K for the year ended Dec. 31, 2018	3.02
4.01*	Supplemental Trust Indenture dated as of February 1, 2024 between Northern States Power Company and The Bank of New York Mellon Trust Company, N.A., as successor Trustee, creating $700,000,000 aggregate principal amount of 5.40% First Mortgage Bonds, Series due March 15, 2054.	NSP-Minnesota Form 8-K dated February 29, 2024	4.01
31.01	Principal Executive Officer’s certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.02	Principal Financial Officer’s certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.01	Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
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 Schema
101.CAL	Inline XBRL Calculation
101.DEF	Inline XBRL Definition
101.LAB	Inline XBRL Label
101.PRE	Inline XBRL Presentation
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

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SIGNATURES

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

		Northern States Power Company (a Minnesota corporation)
4/25/2024	By:	/s/ MELISSA L. OSTROM
8/1/2024	By:	/s/ MELISSA L. OSTROM
		Melissa L. Ostrom
		Vice President, Controller
		(Principal Accounting Officer)
	By:	/s/ BRIAN J. VAN ABEL
		Brian J. Van Abel
		Executive Vice President, Chief Financial Officer
		(Principal Financial Officer)

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