nspm-20240930
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
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☒
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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For the quarterly period ended Sept. 30, 2024
or
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☐
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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For the transition period from to
Commission File Number: 001-31387
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Northern States Power Company
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(Exact Name of Registrant as Specified in its Charter)
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Minnesota
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41-1967505
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(State or Other Jurisdiction of Incorporation or Organization)
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(I.R.S. Employer Identification No.)
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414 Nicollet Mall
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Minneapolis
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Minnesota
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55401
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(Address of Principal Executive Offices)
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(Zip Code)
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(612)
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330-5500
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(Registrant's Telephone Number, Including Area Code)
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N/A
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(Former name, former address and former fiscal year, if changed since last report)
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Securities registered pursuant to Section 12(b) of the Act:
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Title of each class
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Trading Symbol(s)
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Name of each exchange on which registered
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N/A
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N/A
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N/A
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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.
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Large accelerated filer
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☐
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Accelerated filer
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☐
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Non-accelerated filer
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☒
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Smaller reporting company
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☐
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Emerging growth company
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☐
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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.
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Class
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Outstanding at October 31, 2024
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Common Stock, $0.01 par value
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1,000,000 shares
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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
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PART I
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FINANCIAL INFORMATION
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Item 1 -
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Financial Statements (Unaudited)
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4
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Consolidated Statements of Income
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4
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Consolidated Statements of Comprehensive Income
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5
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Consolidated Statements of Cash Flows
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6
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Consolidated Balance Sheets
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7
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Consolidated Statements of Common Stockholder's Equity
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8
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Notes to Consolidated Financial Statements
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8
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Item 2 -
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Management's Discussion and Analysis of Financial Condition and Results of Operations
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20
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Item 4 -
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Controls and Procedures
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23
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PART II
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OTHER INFORMATION
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Item 1 -
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Legal Proceedings
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23
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Item 1A -
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Risk Factors
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23
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Item 5 -
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Other Information
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23
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Item 6 -
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Exhibits
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24
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SIGNATURES
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25
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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
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Xcel Energy Inc.'s Subsidiaries and Affiliates (current and former)
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NSP-Minnesota
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Northern States Power Company, a Minnesota corporation
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NSP System
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The electric production and transmission system of NSP-Minnesota and NSP-Wisconsin operated on an integrated basis and managed by NSP-Minnesota
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NSP-Wisconsin
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Northern States Power Company, a Wisconsin corporation
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PSCo
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Public Service Company of Colorado
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SPS
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Southwestern Public Service Company
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Utility subsidiaries
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NSP-Minnesota, NSP-Wisconsin, PSCo and SPS
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Xcel Energy
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Xcel Energy Inc. and its subsidiaries
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Federal and State Regulatory Agencies
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DOC
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Minnesota Department of Commerce
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EPA
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United States Environmental Protection Agency
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FASB
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Financial Accounting Standards Board
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FERC
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Federal Energy Regulatory Commission
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MPUC
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Minnesota Public Utilities Commission
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NDPSC
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North Dakota Public Service Commission
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PSCW
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Public Service Commission of Wisconsin
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SEC
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Securities and Exchange Commission
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Other
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ALJ
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Administrative Law Judge
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ASU
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Accounting standards update
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C&I
|
Commercial and Industrial
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CCR
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Coal combustion residuals
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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
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CEO
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Chief executive officer
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CERCLA
|
Comprehensive Environmental Response, Compensation, and Liability Act
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CFO
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Chief financial officer
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CO2
|
Carbon dioxide
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CSPV
|
Crystalline Silicon Photovoltaic
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ETR
|
Effective tax rate
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FCA
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Fuel clause adjustment
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FTR
|
Financial transmission right
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GAAP
|
United States generally accepted accounting principles
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GE
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General Electric Company
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IPP
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Independent power producing entity
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MGP
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Manufactured gas plant
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MISO
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Midcontinent Independent System Operator, Inc.
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NAV
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Net asset value
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NOx
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Nitrogen Oxides
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O&M
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Operating and maintenance
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PFAS
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Per- and Polyfluoroalkyl Substances
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PPA
|
Power purchase agreement
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PTC
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Production tax credit
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RFP
|
Request for proposal
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ROE
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Return on equity
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RTO
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Regional Transmission Organization
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SMMPA
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Southern Minnesota Municipal Power Agency
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VIE
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Variable interest entity
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Measurements
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MW
|
Megawatts
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|
Forward-Looking Statements
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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 legal proceeding 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-Kfor 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
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ITEM 1 - FINANCIAL STATEMENTS
|
NSP-MINNESOTA AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)
(amounts in millions)
|
Three Months Ended Sept. 30
|
Nine Months Ended Sept. 30
|
2024
|
2023
|
2024
|
2023
|
Operating revenues
|
Electric, non-affiliates
|
$
|
1,444
|
$
|
1,383
|
$
|
3,694
|
$
|
3,590
|
Electric, affiliates
|
128
|
130
|
370
|
368
|
Natural gas
|
59
|
65
|
422
|
563
|
Other
|
2
|
13
|
13
|
35
|
Total operating revenues
|
1,633
|
1,591
|
4,499
|
4,556
|
|
Operating expenses
|
Electric fuel and purchased power
|
591
|
570
|
1,514
|
1,593
|
Cost of natural gas sold and transported
|
13
|
22
|
175
|
364
|
Cost of sales - other
|
-
|
8
|
4
|
22
|
Operating and maintenance expenses
|
338
|
306
|
961
|
957
|
Conservation program expenses
|
48
|
27
|
138
|
83
|
Depreciation and amortization
|
277
|
249
|
817
|
713
|
Taxes (other than income taxes)
|
53
|
62
|
173
|
172
|
Total operating expenses
|
1,320
|
1,244
|
3,782
|
3,904
|
|
Operating income
|
313
|
347
|
717
|
652
|
|
Other income (expense), net
|
4
|
(7)
|
12
|
(5)
|
Allowance for funds used during construction - equity
|
15
|
9
|
39
|
26
|
|
Interest charges and financing costs
|
Interest charges and other financing costs
|
92
|
81
|
271
|
241
|
Allowance for funds used during construction - debt
|
(8)
|
(5)
|
(19)
|
(15)
|
Total interest charges and financing costs
|
84
|
76
|
252
|
226
|
|
Income before income taxes
|
248
|
273
|
516
|
447
|
Income tax (benefit) expense
|
(4)
|
13
|
(78)
|
(79)
|
Net income
|
$
|
252
|
$
|
260
|
$
|
594
|
$
|
526
|
See Notes to Consolidated Financial Statements
4
Table of Contents
NSP-MINNESOTA AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)
(amounts in millions)
|
Three Months Ended Sept. 30
|
Nine Months Ended Sept. 30
|
2024
|
2023
|
2024
|
2023
|
Net income
|
$
|
252
|
$
|
260
|
$
|
594
|
$
|
526
|
Other comprehensive income
|
Derivative instruments:
|
Net fair value increase, net of tax
|
-
|
-
|
12
|
3
|
Reclassification of losses to net income, net of tax
|
-
|
1
|
-
|
1
|
|
Total other comprehensive income
|
-
|
1
|
12
|
4
|
Total comprehensive income
|
$
|
252
|
$
|
261
|
$
|
606
|
$
|
530
|
See Notes to Consolidated Financial Statements
5
Table of Contents
NSP-MINNESOTA AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)
(amounts in millions)
|
Nine Months Ended Sept. 30
|
2024
|
2023
|
Operating activities
|
Net income
|
$
|
594
|
$
|
526
|
Adjustments to reconcile net income to cash provided by operating activities:
|
Depreciation and amortization
|
821
|
717
|
Nuclear fuel amortization
|
85
|
84
|
Deferred income taxes
|
249
|
16
|
Allowance for equity funds used during construction
|
(39)
|
(26)
|
Provision for bad debts
|
15
|
20
|
Changes in operating assets and liabilities:
|
Accounts receivable
|
(34)
|
(19)
|
Accrued unbilled revenues
|
4
|
117
|
Inventories
|
(3)
|
37
|
Other current assets
|
(4)
|
(11)
|
Accounts payable
|
11
|
(97)
|
Net regulatory assets and liabilities
|
22
|
307
|
Other current liabilities
|
(189)
|
98
|
Pension and other employee benefit obligations
|
(42)
|
(17)
|
Other, net
|
2
|
14
|
Net cash provided by operating activities
|
1,492
|
1,766
|
|
Investing activities
|
Capital/construction expenditures
|
(2,043)
|
(1,668)
|
Purchase of investment securities
|
(693)
|
(704)
|
Proceeds from the sale of investment securities
|
666
|
678
|
Investments in utility money pool arrangement
|
(357)
|
(200)
|
Repayments from utility money pool arrangement
|
414
|
200
|
Other, net
|
(3)
|
(2)
|
Net cash used in investing activities
|
(2,016)
|
(1,696)
|
|
Financing activities
|
Repayments of short-term borrowings, net
|
(165)
|
(207)
|
Borrowings under utility money pool arrangement
|
100
|
189
|
Repayments under utility money pool arrangement
|
(100)
|
(189)
|
Proceeds from issuance of long-term debt
|
687
|
783
|
Repayment of long-term debt
|
-
|
(400)
|
Capital contributions from parent
|
603
|
251
|
Dividends paid to parent
|
(325)
|
(413)
|
Net cash provided by financing activities
|
800
|
14
|
|
Net change in cash, cash equivalents and restricted cash
|
276
|
84
|
Cash, cash equivalents and restricted cash at beginning of period
|
34
|
65
|
Cash, cash equivalents and restricted cash at end of period
|
$
|
310
|
$
|
149
|
|
Supplemental disclosure of cash flow information:
|
Cash paid for interest (net of amounts capitalized)
|
$
|
(234)
|
$
|
(205)
|
Cash received from income taxes, net; includes proceeds from tax credit transfers
|
315
|
60
|
|
Supplemental disclosure of non-cash investing and financing transactions:
|
Accrued property, plant and equipment additions
|
$
|
253
|
$
|
163
|
Inventory transfers to property, plant and equipment
|
31
|
11
|
Operating lease right-of-use assets
|
39
|
52
|
Allowance for equity funds used during construction
|
39
|
26
|
See Notes to Consolidated Financial Statements
6
Table of Contents
NSP-MINNESOTA AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS (UNAUDITED)
(amounts in millions, except share and per share data)
|
Sept. 30, 2024
|
Dec. 31, 2023
|
Assets
|
Current assets
|
Cash and cash equivalents
|
$
|
310
|
$
|
34
|
Accounts receivable, net
|
488
|
490
|
Accounts receivable from affiliates
|
25
|
15
|
Investments in money pool arrangements
|
-
|
57
|
Accrued unbilled revenues
|
287
|
290
|
Inventories
|
328
|
356
|
Regulatory assets
|
348
|
250
|
Derivative instruments
|
52
|
50
|
Prepayments and other
|
94
|
87
|
Total current assets
|
1,932
|
1,629
|
|
Property, plant and equipment, net
|
20,083
|
18,757
|
|
Other assets
|
Nuclear decommissioning fund and other investments
|
3,596
|
3,262
|
Regulatory assets
|
828
|
837
|
Derivative instruments
|
56
|
61
|
Operating lease right-of-use assets
|
414
|
439
|
Other
|
20
|
16
|
Total other assets
|
4,914
|
4,615
|
Total assets
|
$
|
26,929
|
$
|
25,001
|
|
Liabilities and Equity
|
Current liabilities
|
Current portion of long-term debt
|
$
|
250
|
$
|
-
|
Short-term debt
|
-
|
165
|
Accounts payable
|
612
|
579
|
Accounts payable to affiliates
|
56
|
89
|
Regulatory liabilities
|
429
|
300
|
Taxes accrued
|
233
|
223
|
Accrued interest
|
88
|
79
|
Dividends payable to parent
|
99
|
121
|
Derivative instruments
|
29
|
44
|
Operating lease liabilities
|
96
|
91
|
Other
|
167
|
351
|
Total current liabilities
|
2,059
|
2,042
|
|
Deferred credits and other liabilities
|
Deferred income taxes
|
2,353
|
1,992
|
Deferred investment tax credits
|
13
|
14
|
Regulatory liabilities
|
2,263
|
2,097
|
Asset retirement obligations
|
2,802
|
2,658
|
Derivative instruments
|
68
|
86
|
Pension and employee benefit obligations
|
132
|
168
|
Operating lease liabilities
|
340
|
372
|
Other
|
28
|
35
|
Total deferred credits and other liabilities
|
7,999
|
7,422
|
|
Commitments and contingencies
|
Capitalization
|
Long-term debt
|
7,771
|
7,330
|
Common stock - 5,000,000 shares authorized of $0.01 par value; 1,000,000 shares
outstanding at Sept. 30, 2024 and Dec. 31, 2023, respectively
|
-
|
-
|
Additional paid in capital
|
6,276
|
5,686
|
Retained earnings
|
2,832
|
2,541
|
Accumulated other comprehensive loss
|
(8)
|
(20)
|
Total common stockholder's equity
|
9,100
|
8,207
|
Total liabilities and equity
|
$
|
26,929
|
$
|
25,001
|
|
See Notes to Consolidated Financial Statements
7
Table of Contents
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 Paid
In Capital
|
Three Months Ended Sept. 30, 2024 and 2023
|
Balance at June 30, 2023
|
1,000,000
|
$
|
-
|
$
|
5,585
|
$
|
2,502
|
$
|
(15)
|
$
|
8,072
|
Net income
|
260
|
260
|
Other comprehensive loss
|
1
|
1
|
Dividends declared to parent
|
(181)
|
(181)
|
Balance at Sept. 30, 2023
|
1,000,000
|
$
|
-
|
$
|
5,585
|
$
|
2,581
|
$
|
(14)
|
$
|
8,152
|
|
Balance at June 30, 2024
|
1,000,000
|
$
|
-
|
$
|
6,184
|
$
|
2,679
|
$
|
(8)
|
$
|
8,855
|
Net income
|
252
|
252
|
Dividends declared to parent
|
(99)
|
(99)
|
Contribution of capital by parent
|
92
|
92
|
Balance at Sept. 30, 2024
|
1,000,000
|
$
|
-
|
$
|
6,276
|
$
|
2,832
|
$
|
(8)
|
$
|
9,100
|
|
Common Stock Issued
|
Retained Earnings
|
Accumulated Other Comprehensive Loss
|
Total Common Stockholder's Equity
|
Shares
|
Par Value
|
Additional Paid
In Capital
|
Nine Months Ended Sept. 30, 2024 and 2023
|
Balance at Dec. 31, 2022
|
1,000,000
|
$
|
-
|
$
|
5,374
|
$
|
2,480
|
$
|
(18)
|
$
|
7,836
|
Net income
|
526
|
526
|
Other comprehensive income
|
4
|
4
|
Dividends declared to parent
|
(425)
|
(425)
|
Contribution of capital by parent
|
211
|
211
|
Balance at Sept. 30, 2023
|
1,000,000
|
$
|
-
|
$
|
5,585
|
$
|
2,581
|
$
|
(14)
|
$
|
8,152
|
|
Balance at Dec. 31, 2023
|
1,000,000
|
$
|
-
|
$
|
5,686
|
$
|
2,541
|
$
|
(20)
|
$
|
8,207
|
Net income
|
594
|
594
|
Other comprehensive income
|
12
|
12
|
Dividends declared to parent
|
(303)
|
(303)
|
Contribution of capital by parent
|
590
|
590
|
Balance at Sept. 30, 2024
|
1,000,000
|
$
|
-
|
$
|
6,276
|
$
|
2,832
|
$
|
(8)
|
$
|
9,100
|
|
|
See Notes to Consolidated Financial Statements
|
8
Table of Contents
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 Sept. 30, 2024 and Dec. 31, 2023; the results of NSP-Minnesota's operations, including the components of net income, comprehensive income and changes in stockholder's equity for the three and nine months ended Sept. 30, 2024 and 2023; and NSP-Minnesota's cash flows for the nine months ended Sept. 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 Sept. 30, 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-Kfor 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-Kfor 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-Kfor 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 NSP-Minnesota 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 ETR reconciliation and disclosures regarding state and local tax payments. The ASU is effective for annual periods beginning after Dec. 15, 2024, and NSP-Minnesota 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. 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)
|
Sept. 30, 2024
|
Dec. 31, 2023
|
Accounts receivable, net
|
Accounts receivable
|
$
|
528
|
$
|
538
|
Less allowance for bad debts
|
(40)
|
(48)
|
Accounts receivable, net
|
$
|
488
|
$
|
490
|
|
(Millions of Dollars)
|
Sept. 30, 2024
|
Dec. 31, 2023
|
Inventories
|
Materials and supplies
|
$
|
230
|
$
|
219
|
Fuel
|
74
|
105
|
Natural gas
|
24
|
32
|
Total inventories
|
$
|
328
|
$
|
356
|
|
(Millions of Dollars)
|
Sept. 30, 2024
|
Dec. 31, 2023
|
Property, plant and equipment, net
|
Electric plant
|
$
|
22,116
|
$
|
21,206
|
Natural gas plant
|
2,392
|
2,256
|
Common and other property
|
1,383
|
1,301
|
Plant to be retired (a)
|
561
|
604
|
Construction work in progress
|
1,855
|
1,085
|
Total property, plant and equipment
|
28,307
|
26,452
|
Less accumulated depreciation
|
(8,603)
|
(8,044)
|
Nuclear fuel
|
3,452
|
3,337
|
Less accumulated amortization
|
(3,073)
|
(2,988)
|
Property, plant and equipment, net
|
$
|
20,083
|
$
|
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.
9
Table of Contents
Money pool borrowings:
|
(Amounts in Millions, Except Interest Rates)
|
Three Months Ended Sept. 30, 2024
|
Year Ended Dec. 31, 2023
|
Borrowing limit
|
$
|
250
|
$
|
250
|
Amount outstanding at period end
|
-
|
-
|
Average amount outstanding
|
-
|
17
|
Maximum amount outstanding
|
N/A
|
135
|
Weighted average interest rate, computed on a daily basis
|
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 Sept. 30, 2024
|
Year Ended Dec. 31, 2023
|
Borrowing limit
|
$
|
700
|
$
|
700
|
Amount outstanding at period end
|
-
|
165
|
Average amount outstanding
|
-
|
92
|
Maximum amount outstanding
|
N/A
|
441
|
Weighted average interest rate, computed on a daily basis
|
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 Sept. 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 Sept. 30, 2024, NSP-Minnesota had the following committed revolving credit facility available (in millions of dollars):
|
Credit Facility (a)
|
Drawn (b)
|
Available
|
$
|
700
|
$
|
12
|
$
|
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 Sept. 30, 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 Sept. 30, 2024, NSP-Minnesota had $70 million of outstanding letters of credit under the $75 million bilateral credit agreement.
Long-Term Borrowings
During the nine months ended Sept. 30, 2024, NSP-Minnesota issued $700 million of 5.40% first mortgage bonds due March 15, 2054.
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 Sept. 30, 2024
|
(Millions of Dollars)
|
Electric
|
Natural Gas
|
All Other
|
Total
|
Major revenue types
|
Revenue from contracts with customers:
|
Residential
|
$
|
490
|
$
|
29
|
$
|
-
|
$
|
519
|
C&I
|
675
|
19
|
-
|
694
|
Other
|
10
|
-
|
2
|
12
|
Total retail
|
1,175
|
48
|
2
|
1,225
|
Wholesale
|
115
|
-
|
-
|
115
|
Transmission
|
79
|
-
|
-
|
79
|
Interchange and other
|
111
|
3
|
-
|
114
|
Total revenue from contracts with customers
|
1,480
|
51
|
2
|
1,533
|
Alternative revenue and other
|
92
|
8
|
-
|
100
|
Total revenues
|
$
|
1,572
|
$
|
59
|
$
|
2
|
$
|
1,633
|
|
Three Months Ended Sept. 30, 2023
|
(Millions of Dollars)
|
Electric
|
Natural Gas
|
All Other
|
Total
|
Major revenue types
|
Revenue from contracts with customers:
|
Residential
|
$
|
445
|
$
|
28
|
$
|
11
|
$
|
484
|
C&I
|
664
|
26
|
-
|
690
|
Other
|
9
|
-
|
2
|
11
|
Total retail
|
1,118
|
54
|
13
|
1,185
|
Wholesale
|
103
|
-
|
-
|
103
|
Transmission
|
72
|
-
|
-
|
72
|
Interchange and other
|
130
|
4
|
-
|
134
|
Total revenue from contracts with customers
|
1,423
|
58
|
13
|
1,494
|
Alternative revenue and other
|
90
|
7
|
-
|
97
|
Total revenues
|
$
|
1,513
|
$
|
65
|
$
|
13
|
$
|
1,591
|
|
Nine Months Ended Sept. 30, 2024
|
(Millions of Dollars)
|
Electric
|
Natural Gas
|
All Other
|
Total
|
Major revenue types
|
Revenue from contracts with customers:
|
Residential
|
$
|
1,208
|
$
|
204
|
$
|
7
|
$
|
1,419
|
C&I
|
1,768
|
134
|
-
|
1,902
|
Other
|
29
|
|
6
|
35
|
Total retail
|
3,005
|
338
|
13
|
3,356
|
Wholesale
|
247
|
-
|
-
|
247
|
Transmission
|
198
|
-
|
-
|
198
|
Interchange and other
|
351
|
31
|
-
|
382
|
Total revenue from contracts with customers
|
3,801
|
369
|
13
|
4,183
|
Alternative revenue and other
|
263
|
53
|
-
|
316
|
Total revenues
|
$
|
4,064
|
$
|
422
|
$
|
13
|
$
|
4,499
|
10
Table of Contents
|
Nine Months Ended Sept. 30, 2023
|
(Millions of Dollars)
|
Electric
|
Natural Gas
|
All Other
|
Total
|
Major revenue types
|
Revenue from contracts with customers:
|
Residential
|
$
|
1,120
|
$
|
277
|
$
|
30
|
$
|
1,427
|
C&I
|
1,724
|
239
|
-
|
1,963
|
Other
|
26
|
-
|
5
|
31
|
Total retail
|
2,870
|
516
|
35
|
3,421
|
Wholesale
|
287
|
-
|
-
|
287
|
Transmission
|
202
|
-
|
-
|
202
|
Interchange and other
|
364
|
9
|
-
|
373
|
Total revenue from contracts with customers
|
3,723
|
525
|
35
|
4,283
|
Alternative revenue and other
|
235
|
38
|
-
|
273
|
Total revenues
|
$
|
3,958
|
$
|
563
|
$
|
35
|
$
|
4,556
|
Reconciliation between the statutory rate and ETR:
|
Nine Months Ended Sept. 30
|
2024
|
2023
|
Federal statutory rate
|
21.0
|
%
|
21.0
|
%
|
State tax (net of federal tax effect)
|
7.1
|
7.0
|
(Decreases) increases:
|
Wind PTCs (a)
|
(36.8)
|
(39.5)
|
Plant regulatory differences (b)
|
(5.7)
|
(5.9)
|
Other tax credits, net operating loss & tax credit allowances
|
(1.2)
|
(1.3)
|
Other, net
|
0.5
|
1.0
|
Effective income tax rate
|
(15.1)
|
%
|
(17.7)
|
%
|
(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. Income tax benefits associated with the credit are offset by corresponding revenue reductions.
|
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.
11
Table of Contents
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 $1.4 billion and $1.2 billion as of Sept. 30, 2024 and Dec. 31, 2023, and unrealized losses were $23 million and $29 million as of Sept. 30, 2024 and Dec. 31, 2023, respectively.
Non-derivative instruments with recurring fair value measurements in the nuclear decommissioning fund:
|
Sept. 30, 2024
|
Fair Value
|
(Millions of Dollars)
|
Cost
|
Level 1
|
Level 2
|
Level 3
|
NAV
|
Total
|
Nuclear decommissioning fund (a)
|
Cash equivalents
|
$
|
42
|
$
|
42
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
42
|
Commingled funds
|
711
|
-
|
-
|
-
|
1,046
|
1,046
|
Debt securities
|
850
|
-
|
848
|
17
|
-
|
865
|
Equity securities
|
521
|
1,586
|
2
|
-
|
-
|
1,588
|
Total
|
$
|
2,124
|
$
|
1,628
|
$
|
850
|
$
|
17
|
$
|
1,046
|
$
|
3,541
|
(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.
For the three and nine months ended Sept. 30, 2024 and 2023, there were no transfers of Level 3 investments between levels.
Contractual maturity dates of debt securities in the nuclear decommissioning fund as of Sept. 30, 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
|
$
|
9
|
$
|
303
|
$
|
277
|
$
|
276
|
$
|
865
|
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 Sept. 30, 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 Sept. 30, 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 Sept. 30, 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 Sept. 30, 2024, NSP-Minnesota had no commodity contracts designated as cash flow hedges.
12
Table of Contents
Gross notional amounts of commodity forwards, options and FTRs:
|
(Amounts in Millions)(a)(b)
|
Sept. 30, 2024
|
Dec. 31, 2023
|
Megawatt hours of electricity
|
44
|
38
|
Million British thermal units of natural gas
|
60
|
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 Sept. 30, 2024, five of NSP-Minnesota's ten most significant counterparties for these activities, comprising $20 million, or 26%, 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 $21 million, or 26%, 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.
Two of these significant counterparties, comprising $36 million or 46% of this credit exposure, had credit quality less than investment grade, based on internal analysis.
Six 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 Sept. 30, 2024 and Dec. 31, 2023, there were $10 million and $12 million of derivative liabilities with such underlying contract provisions, respectively .
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 Sept. 30, 2024 and Dec. 31, 2023, there were approximately $57 million and $80 million of derivative liabilities with such underlying contract provisions, respectively.
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 Sept. 30, 2024 and Dec. 31, 2023.
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 Sept. 30, 2024
|
Other derivative instruments:
|
Electric commodity
|
$
|
-
|
$
|
(15)
|
Natural gas commodity
|
-
|
(1)
|
Total
|
$
|
-
|
$
|
(16)
|
|
Nine Months Ended Sept. 30, 2024
|
Derivatives designated as cash flow hedges:
|
Interest rate
|
$
|
16
|
$
|
-
|
Total
|
$
|
16
|
$
|
-
|
Other derivative instruments:
|
Electric commodity
|
$
|
-
|
$
|
(14)
|
Natural gas commodity
|
-
|
2
|
Total
|
$
|
-
|
$
|
(12)
|
|
Three Months Ended Sept. 30, 2023
|
Other derivative instruments
|
Electric commodity
|
$
|
-
|
$
|
(19)
|
Natural gas commodity
|
-
|
(3)
|
Total
|
$
|
-
|
$
|
(22)
|
|
Nine Months Ended Sept. 30, 2023
|
Derivatives designated as cash flow hedges:
|
Interest rate
|
$
|
5
|
$
|
-
|
Total
|
$
|
5
|
$
|
-
|
Other derivative instruments
|
Electric commodity
|
$
|
-
|
$
|
(47)
|
Natural gas commodity
|
$
|
-
|
$
|
(1)
|
Total
|
$
|
-
|
$
|
(48)
|
13
Table of Contents
.
|
Pre-Tax Losses Reclassified into Income During the Period from:
|
Pre-Tax Gains (Losses) Recognized During the Period in Income
|
(Millions of Dollars)
|
Accumulated Other Comprehensive Loss
|
Regulatory Assets and Liabilities
|
Three Months Ended Sept. 30, 2024
|
Derivatives designated as cash flow hedges:
|
Interest rate
|
$
|
1
|
(a)
|
$
|
-
|
$
|
-
|
Total
|
$
|
1
|
$
|
-
|
$
|
-
|
Other derivative instruments:
|
Commodity trading
|
$
|
-
|
$
|
-
|
$
|
4
|
(b)
|
Electric commodity
|
-
|
4
|
(c)
|
-
|
Total
|
$
|
-
|
$
|
4
|
$
|
4
|
|
Nine Months Ended Sept. 30, 2024
|
Derivatives designated as cash flow hedges:
|
Interest rate
|
$
|
1
|
(a)
|
$
|
-
|
$
|
-
|
Total
|
$
|
1
|
$
|
-
|
$
|
-
|
Other derivative instruments:
|
Commodity trading
|
$
|
-
|
$
|
-
|
$
|
(9)
|
(b)
|
Electric commodity
|
-
|
10
|
(c)
|
-
|
Natural gas commodity
|
-
|
-
|
(5)
|
(d)(e)
|
Total
|
$
|
-
|
$
|
10
|
$
|
(14)
|
|
Three Months Ended Sept. 30, 2023
|
Derivatives designated as cash flow hedges:
|
Interest rate
|
$
|
1
|
(a)
|
$
|
-
|
$
|
-
|
Total
|
$
|
1
|
$
|
-
|
$
|
-
|
Other derivative instruments:
|
Commodity trading
|
$
|
-
|
$
|
-
|
$
|
(2)
|
(b)
|
Electric Commodity
|
-
|
10
|
(c)
|
-
|
Total
|
$
|
-
|
$
|
10
|
$
|
(2)
|
|
Nine Months Ended Sept. 30, 2023
|
Derivatives designated as cash flow hedges:
|
Interest rate
|
$
|
1
|
(a)
|
$
|
-
|
$
|
-
|
Total
|
$
|
1
|
$
|
-
|
$
|
-
|
Other derivative instruments:
|
Commodity trading
|
$
|
-
|
$
|
-
|
$
|
(3)
|
(b)
|
Electric commodity
|
-
|
31
|
(c)
|
-
|
Natural gas commodity
|
-
|
-
|
(5)
|
(d)(e)
|
Total
|
$
|
-
|
$
|
31
|
$
|
(8)
|
(a)Recorded to interest charges.
(b)Recorded to electric revenues. Presented amounts do not reflect non-derivative transactions or margin sharing with customers.
(c)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.
(d)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.
(e)Relates primarily to option premium amortization.
NSP-Minnesota had no derivative instruments designated as fair value hedges during the nine months ended Sept. 30, 2024 and 2023.
14
Table of Contents
Derivative assets and liabilities measured at fair value on a recurring basis were as follows:
|
Sept. 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
|
$
|
4
|
$
|
20
|
$
|
10
|
$
|
34
|
$
|
(24)
|
$
|
10
|
$
|
7
|
$
|
32
|
$
|
32
|
$
|
71
|
$
|
(42)
|
$
|
29
|
Electric commodity
|
-
|
-
|
38
|
38
|
(2)
|
36
|
-
|
-
|
23
|
23
|
(7)
|
16
|
Natural gas commodity
|
-
|
6
|
-
|
6
|
-
|
6
|
-
|
5
|
-
|
5
|
-
|
5
|
Total current derivative assets
|
$
|
4
|
$
|
26
|
$
|
48
|
$
|
78
|
$
|
(26)
|
$
|
52
|
$
|
7
|
$
|
37
|
$
|
55
|
$
|
99
|
$
|
(49)
|
$
|
50
|
Noncurrent derivative assets
|
Other derivative instruments:
|
Commodity trading
|
$
|
4
|
$
|
27
|
$
|
43
|
$
|
74
|
$
|
(18)
|
$
|
56
|
$
|
7
|
$
|
43
|
$
|
45
|
$
|
95
|
$
|
(34)
|
$
|
61
|
Total noncurrent derivative assets
|
$
|
4
|
$
|
27
|
$
|
43
|
$
|
74
|
$
|
(18)
|
$
|
56
|
$
|
7
|
$
|
43
|
$
|
45
|
$
|
95
|
$
|
(34)
|
$
|
61
|
|
Sept. 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
|
$
|
6
|
$
|
34
|
$
|
6
|
$
|
46
|
$
|
(24)
|
$
|
22
|
$
|
6
|
$
|
60
|
$
|
5
|
$
|
71
|
$
|
(43)
|
$
|
28
|
Electric commodity
|
-
|
-
|
2
|
2
|
(2)
|
-
|
-
|
-
|
7
|
7
|
(7)
|
-
|
Natural gas commodity
|
-
|
1
|
-
|
1
|
-
|
1
|
-
|
3
|
-
|
3
|
-
|
3
|
Total current derivative liabilities
|
$
|
6
|
$
|
35
|
$
|
8
|
$
|
49
|
$
|
(26)
|
23
|
$
|
6
|
$
|
70
|
$
|
12
|
$
|
88
|
$
|
(50)
|
38
|
PPAs (b)
|
6
|
6
|
Current derivative instruments
|
$
|
29
|
$
|
44
|
Noncurrent derivative liabilities
|
Other derivative instruments:
|
Commodity trading
|
$
|
9
|
$
|
28
|
$
|
33
|
$
|
70
|
$
|
(20)
|
$
|
50
|
$
|
14
|
$
|
49
|
$
|
37
|
$
|
100
|
$
|
(36)
|
$
|
64
|
Total noncurrent derivative liabilities
|
$
|
9
|
$
|
28
|
$
|
33
|
$
|
70
|
$
|
(20)
|
50
|
$
|
14
|
$
|
49
|
$
|
37
|
$
|
100
|
$
|
(36)
|
64
|
PPAs (b)
|
18
|
22
|
Noncurrent derivative instruments
|
$
|
68
|
$
|
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 Sept. 30, 2024 and Dec. 31, 2023, derivative assets and liabilities include no obligations to return cash collateral. At both Sept. 30, 2024 and Dec. 31, 2023 derivative assets and liabilities include rights to reclaim cash collateral of $2 million and $3 million, respectively. 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.
15
Table of Contents
Changes in Level 3 commodity derivatives:
|
Three Months Ended Sept 30
|
(Millions of Dollars)
|
2024
|
2023
|
Balance at July 1
|
$
|
93
|
$
|
117
|
Settlements (a)
|
(13)
|
(32)
|
Net transactions recorded during the period:
|
(Losses) gains recognized in earnings (b)
|
(8)
|
17
|
Net losses recognized as regulatory assets and liabilities (a)
|
(22)
|
(33)
|
Balance at Sept. 30
|
$
|
50
|
$
|
69
|
|
Nine Months Ended Sept 30
|
(Millions of Dollars)
|
2024
|
2023
|
Balance at Jan. 1
|
$
|
51
|
$
|
107
|
Purchases (a)
|
72
|
98
|
Settlements (a)
|
(55)
|
(60)
|
Net transactions recorded during the period:
|
(Losses) gains recognized in earnings (b)
|
(5)
|
15
|
Net losses recognized as regulatory assets and liabilities (a)
|
(13)
|
(91)
|
Balance at Sept. 30
|
$
|
50
|
$
|
69
|
(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 Sept. 30, 2024, other financial instruments for which the carrying amount did not equal fair value:
|
Sept. 30, 2024
|
Dec. 31, 2023
|
(Millions of Dollars)
|
Carrying Amount
|
Fair Value
|
Carrying Amount
|
Fair Value
|
Long-term debt, including current portion
|
$
|
8,021
|
$
|
7,348
|
$
|
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 Sept. 30, 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 Sept. 30
|
2024
|
2023
|
2024
|
2023
|
(Millions of Dollars)
|
Pension Benefits
|
Postretirement Health
Care Benefits
|
Service cost
|
$
|
5
|
$
|
5
|
$
|
-
|
$
|
-
|
Interest cost (a)
|
8
|
9
|
1
|
1
|
Expected return on plan assets (a)
|
(11)
|
(11)
|
-
|
-
|
Amortization of net loss (a)
|
3
|
3
|
-
|
-
|
Settlement charge (b)
|
4
|
-
|
-
|
-
|
Net periodic benefit cost
|
9
|
6
|
1
|
1
|
Effects of regulation
|
(1)
|
8
|
-
|
-
|
Net benefit cost recognized for financial reporting
|
$
|
8
|
$
|
14
|
$
|
1
|
$
|
1
|
|
Nine Months Ended Sept. 30
|
2024
|
2023
|
2024
|
2023
|
(Millions of Dollars)
|
Pension Benefits
|
Postretirement Health
Care Benefits
|
Service cost
|
$
|
16
|
$
|
15
|
$
|
-
|
$
|
-
|
Interest cost (a)
|
25
|
27
|
2
|
2
|
Expected return on plan assets (a)
|
(34)
|
(34)
|
-
|
-
|
Amortization of net loss (a)
|
9
|
9
|
-
|
-
|
Settlement charge (b)
|
35
|
-
|
-
|
-
|
Net periodic benefit cost
|
51
|
17
|
2
|
2
|
Effects of regulation
|
(30)
|
13
|
-
|
-
|
Net benefit cost recognized for financial reporting
|
$
|
21
|
$
|
30
|
$
|
2
|
$
|
2
|
(a)The components of net periodic cost other than the service cost component are included in the line item "Other income (expense), 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. As a result of lump-sum distributions during the 2024 plan year, NSP-Minnesota recorded a pension settlement charge of $4 million and $35 million, respectively, which was not recognized in earnings due to the effects of rate making, for the three and nine months ended Sept. 30, 2024.
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.
16
Table of Contents
|
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.
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 Minnesota Office of Attorney General 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 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. In October 2024, the MPUC ordered customer refunds of $46 million, which is presented as a charge to electric revenues in the nine months ended Sept. 30, 2024.
Minnesota 2023 Fuel Clause Adjustment- In March 2024, NSP-Minnesota filed its annual fuel clause adjustment true-up petition to the MPUC.
In 2024, the DOC recommended customer refunds for 2023 replacement power costs incurred during an outage at the Prairie Island generating station (October 2023 through February 2024). NSP-Minnesota estimates that customer refunds would be approximately $22 million if the DOC recommendations are applied to both 2023 and 2024.
In September 2024, the MPUC ruled NSP-Minnesota was imprudent in the operation of the Prairie Island nuclear plant based on an incident that resulted in the extended outage. The MPUC declined to quantify the refund and referred the determination of the refund amount to the Office of Administrative Hearings. A procedural schedule will be determined in the fourth quarter of 2024. NSP-Minnesota has recorded an estimated liability for a customer refund.
Environmental
New and changing federal and state environmental mandates can create financial 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 for resolution of these issues; however, the 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.
Water and Waste
Coal Ash Regulation- NSP-Minnesota is subject to the CCR Rule, which imposes requirements for handling, storage, treatment and disposal of coal ash and other solid waste.
In May 2024, final amendments to the CCR Rule were published, widening its scope to include legacy CCR surface impoundments at inactive facilities and previously exempt areas where CCR was placed directly on land at CCR-regulated facilities, including areas of beneficial use.
As a 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.
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.
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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.
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.
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. In June 2024, the U.S. Supreme Court issued an order granting a stay of the final rule. In response, the EPA intends to issue an administrative stay of the rule nationwide. Depending on the outcomes of the underlying legal challenges, the regulation may become applicable in the future.
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 Sept. 30
|
(Millions of Dollars)
|
2024
|
2023
|
Operating leases
|
PPA capacity payments
|
$
|
24
|
$
|
25
|
Other operating leases (a)
|
4
|
3
|
Total operating lease expense (b)
|
$
|
28
|
$
|
28
|
(a)Includes immaterial short-term lease expense for both 2024and 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.
|
|
Nine Months Ended Sept. 30
|
(Millions of Dollars)
|
2024
|
2023
|
Operating leases
|
PPA capacity payments
|
$
|
72
|
$
|
74
|
Other operating leases (a)
|
12
|
12
|
Total operating lease expense (b)
|
$
|
84
|
$
|
86
|
(a)Includes short-term lease expense of $2 million and $3 million for 2024and 2023, respectively
(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 Sept. 30, 2024:
|
(Millions of Dollars)
|
PPA Operating
Leases
|
Other Operating
Leases
|
Total
Operating
Leases
|
Total minimum obligation
|
$
|
328
|
$
|
260
|
$
|
588
|
Interest component of obligation
|
(25)
|
(127)
|
(152)
|
Present value of minimum obligation
|
$
|
303
|
$
|
133
|
436
|
Less current portion
|
(96)
|
Noncurrent operating lease liabilities
|
$
|
340
|
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.
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 Sept. 30, 2024 and Dec. 31, 2023, with entities that have been determined to be VIEs. These agreements have expiration dates through 2039.
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|
10. Other Comprehensive Loss
|
Changes in accumulated other comprehensive loss, net of tax:
|
Three Months Ended Sept. 30, 2024
|
Three Months Ended Sept. 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 July 1
|
$
|
(6)
|
$
|
(2)
|
$
|
(8)
|
$
|
(13)
|
$
|
(2)
|
$
|
(15)
|
Losses reclassified from net accumulated other comprehensive loss:
|
Interest rate derivatives (a)
|
-
|
-
|
-
|
-
|
1
|
1
|
Net current period other comprehensive income
|
-
|
-
|
-
|
-
|
1
|
1
|
Accumulated other comprehensive loss at Sept 30
|
$
|
(6)
|
$
|
(2)
|
$
|
(8)
|
$
|
(13)
|
$
|
(1)
|
$
|
(14)
|
|
Nine Months Ended Sept. 30, 2024
|
Nine Months Ended Sept. 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
|
Losses reclassified from net accumulated other comprehensive loss:
|
Interest rate derivatives (a)
|
-
|
-
|
-
|
-
|
1
|
1
|
Net current period other comprehensive income
|
12
|
-
|
12
|
3
|
1
|
4
|
Accumulated other comprehensive loss at Sept 30
|
$
|
(6)
|
$
|
(2)
|
$
|
(8)
|
$
|
(13)
|
$
|
(1)
|
$
|
(14)
|
(a)Included in interest charges.
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.
NSP-Minnesota's segment information:
|
Three Months Ended Sept. 30
|
(Millions of Dollars)
|
2024
|
2023
|
Regulated Electric
|
Total revenues (a)
|
$
|
1,572
|
$
|
1,513
|
Net income
|
257
|
263
|
Regulated Natural Gas
|
Total revenues(b)
|
$
|
59
|
$
|
65
|
Intersegment revenue
|
-
|
1
|
Total revenues
|
$
|
59
|
$
|
66
|
Net loss
|
(8)
|
(8)
|
All Other
|
Total revenues
|
$
|
2
|
$
|
13
|
Net income
|
3
|
5
|
Consolidated Total
|
Total revenues (a)(b)
|
$
|
1,633
|
$
|
1,592
|
Reconciling eliminations
|
-
|
(1)
|
Total operating revenues
|
$
|
1,633
|
$
|
1,591
|
Net income
|
252
|
260
|
(a)Total revenues include $128 million and $130 million of affiliate electric revenue for the three months ended Sept. 30, 2024 and 2023.
(b)Total revenues include an immaterial amount of affiliate gas revenue for the three months ended Sept. 30, 2024 and 2023.
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|
Nine Months Ended Sept. 30
|
(Millions of Dollars)
|
2024
|
2023
|
Regulated Electric
|
Total revenues(a)
|
$
|
4,064
|
$
|
3,958
|
Net income
|
524
|
508
|
Regulated Natural Gas
|
Operating revenues(b)
|
$
|
422
|
$
|
563
|
Intersegment revenue
|
1
|
2
|
Total revenues
|
$
|
423
|
$
|
565
|
Net income
|
47
|
13
|
All Other
|
Total revenues
|
$
|
13
|
$
|
35
|
Net income
|
23
|
5
|
Consolidated Total
|
Total revenues (a)(b)
|
$
|
4,500
|
$
|
4,558
|
Reconciling eliminations
|
(1)
|
(2)
|
Total operating revenues
|
$
|
4,499
|
$
|
4,556
|
Net income
|
594
|
526
|
(a)Total revenues include $370 million and $368 million of affiliate electric revenue for the nine months ended Sept. 30, 2024 and 2023.
(b)Total revenues include an immaterial amount of affiliate gas revenue for the nine months ended Sept. 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.
Earnings Adjusted for Certain Items (Ongoing Earnings)
Ongoing earnings reflect adjustments to GAAP earnings (net income) for certain items.
We use this non-GAAP financial measure to evaluate and provide details of Xcel Energy's core earnings and underlying performance. For instance, to present ongoing earnings, we may adjust the related GAAP amounts for certain items that are non-recurring in nature. We believe this measurement is useful to investors to evaluate the actual and projected financial performance and contribution of our subsidiaries. This non-GAAP financial measure should not be considered as an alternative to measures calculated and reported in accordance with GAAP.
The following table provides a reconciliation of GAAP earnings (net income) to ongoing earnings:
|
Three Months Ended Sept. 30
|
Nine Months Ended Sept. 30
|
(Millions of Dollars)
|
2024
|
2023
|
2024
|
2023
|
GAAP net income
|
$
|
252
|
$
|
260
|
$
|
594
|
$
|
526
|
Sherco Unit 3 2011 outage refunds
|
35
|
-
|
46
|
-
|
Less: tax effect of adjustment
|
(10)
|
-
|
(13)
|
-
|
Ongoing earnings
|
$
|
277
|
$
|
260
|
$
|
627
|
$
|
526
|
Sherco Unit 3 2011 Outage Refunds -NSP-Minnesota's Sherco Unit 3 experienced an extended outage following a 2011 incident which damaged its turbine. In October 2024 following contested case procedures, the MPUC ordered a customer refund of $46 million for replacement power incurred during the outage.
NSP-Minnesota's GAAP net income was $594 million for the nine months ended Sept. 30, 2024 compared with $526 million for the prior year. Ongoing net income was $627 million for the nine months ended Sept. 30, 2024, compared to $526 million for the prior year. The higher ongoing earnings primarily reflect increased recovery of infrastructure investments (electric and natural gas), partially offset by higher depreciation and interest charges.
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.
|
(Millions of Dollars)
|
Nine Months Ended Sept. 30, 2024 vs. 2023
|
Regulatory rate outcomes
|
$
|
191
|
Conservation and demand side management (offset in expense)
|
57
|
Non-fuel riders
|
50
|
Recovery of lower electric fuel and purchased power expenses
|
(75)
|
2011 Sherco 3 outage refunds
|
(46)
|
PTCs flowed back to customers (offset by lower ETR)
|
(24)
|
Sales and demand (a)
|
(11)
|
Estimated impact of weather (net of sales true-up)
|
(7)
|
Other, net
|
(29)
|
Total increase
|
$
|
106
|
(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.
|
(Millions of Dollars)
|
Nine Months Ended Sept. 30, 2024 vs. 2023
|
Recovery of lower natural gas costs (sold and transported)
|
$
|
(189)
|
Regulatory rate outcomes
|
38
|
Infrastructure and integrity riders
|
6
|
Retail sales growth (net of decoupling)
|
6
|
Other, net
|
(2)
|
Total decrease
|
$
|
(141)
|
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. These incurred expenses are generally recovered through various regulatory recovery mechanisms. As a result, changes in these expenses are largely offset in operating revenues and have minimal earnings impact.
Electric fuel and purchased power expenses decreased $79 million year-to-date. The decrease is primarily due to decreased volumes and timing of fuel recovery mechanisms, partially offset by changes in 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 largely offset in operating revenues and have minimal earnings impact.
Natural gas sold and transported decreased $189 million year-to-date. The decrease is primarily due to timing of fuel recovery, lower volumes and commodity prices.
Non-Fuel Operating Expenses and Other Items
Depreciation and Amortization -Depreciation and amortization expense increased $104 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.
Interest Charges - Interest charges increased $30 million year-to-date, largely due to increased debt levels and higher interest rates.
|
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-Kfor 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 a natural gas rate increase of approximately $59 million, or 9.6%. The request was 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).
In June 2024, NSP-Minnesota and various partiesfiled an uncontested settlement, which includes the following terms:
•Natural gas rate increase of $46 million, or 7.5%.
•ROE of 9.6%.
•Equity ratio of 52.5%.
•Rate base of $1.25 billion.
•No change to Commission approved decoupling.
In October 2024, an ALJ recommended the MPUC approve the rate case settlement. A MPUC decision and order is expected in the first quarter of 2025.
2024 North Dakota Natural 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.
In August 2024, NSP-Minnesota filed a settlement agreement with NDPSC Staff and AARP. Key terms of the settlement included an increase in natural gas rates of $7.3 million (8.1%), based on a ROE of 9.9% and an equity ratio of 52.5%.
A NDPSC decision and order is expected by the end of 2024.
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 to the Minnesota Court of Appeals regarding MPUC decisions relating to executive compensation, insurance expense and treatment of prepaid pension assets.
The appeal is pending a court decision expected in the first quarter of 2025.
2024 Minnesota Electric Rate Case - In early November 2024, NSP-Minnesota plans to file an electric rate case in Minnesota, seeking a total revenue increase of $491 million (13.2%) over two years, based on an ROE of 10.3%, a 52.5% equity ratio and rate base of $13.2 billion in 2025 and $14 billion in 2026. NSP-Minnesota will also request interim rates of $224 million to go into effect in January 2025. A decision is expected in 2026.
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Table of Contents
NSP System
2022 Upper Midwest IRP Resource Acquisition - NSP-Minnesota and NSP-Wisconsin are actively engaged in multiple processes and proceedings to acquire resources to meet their identified generation resource needs.
•In the second quarter of 2023, NSP-Minnesota initiated the process with the MPUC for acquisition of firm dispatchable resources. In October 2024, a settlement was reached with various parties, pending MPUC approval. See below for more details.
•In October 2023, NSP-Minnesota issued an RFP seeking 1,200 MW of wind assets to replace capacity and reutilize interconnection rights associated with the retiring Sherco coal facilities. The RFP closed in December 2023. NSP-Minnesota expects to file for approval of recommended projects by the fourth quarter of 2024.
•In 2024, 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, including reutilization of the interconnection rights associated with the retiring Sherco coal units, and 650 MW of solar and storage resources to specifically reutilize the interconnection rights associated with the retiring King coal unit. Bids are currently under evaluation; NSP-Minnesota and NSP-Wisconsin expect to announce short listed projects in December 2024 and plan to file for the requisite approvals of the selected resources with the MPUC and PSCW, respectively, in the second quarter of 2025.
2024 Upper Midwest Resource Plan - In February 2024, NSP filed its Upper Midwest Resource Plan with the MPUC. In October 2024, NSP-Minnesota filed a settlement with several parties reaching agreement on the targeted resource additions for the 5-year Action Plan and the process under which those resources will be secured, as well as the proposed projects to be approved in the pending 800 MW firm dispatchable resource acquisition.
NSP-Minnesota anticipates a MPUC decision in 2025 and will file a RFP for remaining resource needs upon approval. The settlement included the following key items:
•The selection of the company-owned 420 MW Lyon County combustion turbine.
•The selection of the company-owned 300 MW 4-hour Sherco battery energy storage system.
•Multiple PPAs to proceed to the negotiation stage.
•3,200 MW of wind, 400 MW of solar and 600 MW of stand-alone storage to be added through 2030 based on an RFP process (a portion of which is expected to be fulfilled with the resources acquired as part of the June and July 2024 RFPs). Of these amounts, approximately 2,800 MW of wind are projected to utilize the Minnesota Energy Connection transmission line.
•Planned life extensions of the Prairie Island and Monticello nuclear plants through the early 2050s.
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-Kfor 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-Kfor 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.
Large 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 May 2024, the U.S. Department of Commerce announced the initiation of anti-dumping and countervailing duty investigations of CSPV cells from Cambodia, Malaysia, Thailand and Vietnam, whether or not assembled into modules.
In October 2024, the U.S. Department of Commerce announced its preliminary determination in the countervailing duty circumvention investigation, which is not expected to impact NSP-Minnesota projects. A preliminary decision related to the anti-dumping portion of the matter is anticipated in November 2024.
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.
Clean Air Act
Power Plant Greenhouse Gas Regulations -In April 2024, the EPA published final rules addressing control of CO2emissions 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 CO2control requirements vary by subcategory. Based on current estimates and assumptions, NSP-Minnesota has determined that due to scheduled plant retirements, there is minimal financial or operational impact associated with these requirements and believes that the cost of these initiatives or replacement generation would be recoverable through rates based on prior state commission practices.
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Table of Contents
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 June 2024, the EPA finalized a rule that designated certain PFAS as hazardous substances under CERCLA. In July 2024, the EPA finalized another rule that set enforceable drinking water standards for certain PFAS.
Potential costs for these rules and any additional proposed regulations related to PFAS are uncertain and will be determined on a site specific basis where applicable. If costs are incurred, NSP-Minnesota believes the costs will be recoverable through rates based on prior state commission practices.
Effluent Limitation Guidelines
In April 2024, the EPA published final rules under the Clean Water Act, setting 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. Based on current estimates and assumptions, NSP-Minnesota has determined that there is minimal financial or operational impact associated with these requirements and that any costs would be recoverable through rates based on prior state commission practices.
In May 2024, the Prohibiting Russian Uranium Imports Actwas signed into law. As such, NSP-Minnesota will no longer be permitted to accept deliveries of enriched nuclear material from Russia beginning in August 2024, unless specific waivers are requested and received. NSP-Minnesota has secured its enriched nuclear material requirements through 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.
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ITEM 4 - CONTROLS AND PROCEDURES
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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 Sept. 30, 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
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ITEM 1 - LEGAL PROCEEDINGS
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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 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.
NSP-Minnesota's risk factors are documented in Item 1A of Part I of its Annual Report on Form 10-Kfor 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
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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 Sept. 30, 2024.
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* Indicates incorporation by reference
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Exhibit Number
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Description
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Report or Registration Statement
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Exhibit Reference
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NSP-Minnesota Form 10-12G dated Oct. 5, 2000
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3.01
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NSP-Minnesota Form 10-K for the year ended Dec. 31, 2018
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3.02
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31.01
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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
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31.02
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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
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32.01
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Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
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101.INS
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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
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101.SCH
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Inline XBRL Schema
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101.CAL
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Inline XBRL Calculation
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101.DEF
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Inline XBRL Definition
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101.LAB
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Inline XBRL Label
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101.PRE
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Inline XBRL Presentation
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104
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Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
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Table of Contents
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.
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Northern States Power Company (a Minnesota corporation)
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10/31/2024
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By:
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/s/ MELISSA L. OSTROM
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Melissa L. Ostrom
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Senior Vice President, Controller
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(Principal Accounting Officer)
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By:
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/s/ BRIAN J. VAN ABEL
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Brian J. Van Abel
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Executive Vice President, Chief Financial Officer
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(Principal Financial Officer)
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