10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2022

or

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

For the transition period from to

Commission File Number: 001-31387

Northern States Power Company

(Exact Name of Registrant as Specified in its Charter)

Minnesota	41-1967505
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)

414 Nicollet Mall	Minneapolis	Minnesota	55401
(Address of Principal Executive Offices)			(Zip Code)

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

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

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
N/A	N/A	N/A

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☒ Yes ☐ No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). ☒ Yes ☐ No

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

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

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes ☒ No

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

Class	Outstanding at July 28, 2022
Common Stock, $0.01 par value	1,000,000 shares

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

TABLE OF CONTENTS

PART I	FINANCIAL INFORMATION
Item 1 —	Financial Statements (Unaudited)	4
	Consolidated Statements of Income	4
	Consolidated Statements of Comprehensive Income	5
	Consolidated Statements of Cash Flows	6
	Consolidated Balance Sheets	7
	Consolidated Statements of Common Stockholder’s Equity	8
	Notes to Consolidated Financial Statements	9
Item 2 —	Management’s Discussion and Analysis of Financial Condition and Results of Operations	19
Item 4 —	Controls and Procedures	22
PART II	OTHER INFORMATION
Item 1 —	Legal Proceedings	22
Item 1A —	Risk Factors	22
Item 6 —	Exhibits	23
SIGNATURES		24

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

Definitions of Abbreviations

Xcel Energy Inc.’s Subsidiaries and Affiliates (current and former)
NSP-Minnesota	Northern States Power Company, a Minnesota corporation
NSP System	The electric production and transmission system of NSP-Minnesota and NSP-Wisconsin operated on an integrated basis and managed by NSP-Minnesota
NSP-Wisconsin	Northern States Power Company, a Wisconsin corporation
PSCo	Public Service Company of Colorado
SPS	Southwestern Public Service Company
Utility subsidiaries	NSP-Minnesota, NSP-Wisconsin, PSCo and SPS
Xcel Energy	Xcel Energy Inc. and its subsidiaries
Federal and State Regulatory Agencies
D.C. Circuit	United States Court of Appeals for the District of Columbia Circuit
DOC	Minnesota Department of Commerce
EPA	United States Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
MPUC	Minnesota Public Utilities Commission
NDPSC	North Dakota Public Service Commission
OAG	Minnesota Office of Attorney General
SEC	Securities and Exchange Commission
Electric, Purchased Gas and Resource Adjustment Clauses
GUIC	Gas utility infrastructure cost rider
RES	Renewable energy standard
TCR	Transmission cost recovery adjustment
Other
ACE	Affordable Clean Energy
ALJ	Administrative Law Judge
C&I	Commercial and Industrial
CCR	Coal combustion residuals
CCR Rule	Final rule (40 CFR 257.50 - 257.107) published by the EPA regulating the management, storage and disposal of CCRs as nonhazardous waste.
CEO	Chief executive officer
CFO	Chief financial officer
CPP	Clean Power Plan
CSPV	Crystalline Silicon Photovoltaic
ETR	Effective tax rate
FTR	Financial transmission right
GAAP	United States generally accepted accounting principles
GE	General Electric Company
IPP	Independent power producing entity
MGP	Manufactured gas plant
MISO	Midcontinent Independent System Operator, Inc.
NAV	Net asset value
O&M	Operating and maintenance
PPA	Power purchase agreement
PTC	Production tax credit
ROE	Return on equity
RTO	Regional Transmission Organization
SMMPA	Southern Minnesota Municipal Power Agency
TOs	Transmission owners
Measurements
MW	Megawatts

Forward-Looking Statements

Except for the historical statements contained in this report, the matters discussed herein are forward-looking statements that are subject to certain risks, uncertainties and assumptions. Such forward-looking statements, including those relating to future sales, future expenses, future tax rates, future operating performance, estimated base capital expenditures and financing plans, projected capital additions and forecasted annual revenue requirements with respect to rider filings, expected rate increases to customers, expectations and intentions regarding regulatory proceedings, and expected impact on our results of operations, financial condition and cash flows of resettlement calculations and credit losses relating to certain energy transactions, as well as assumptions and other statements are intended to be identified in this document by the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “objective,” “outlook,” “plan,” “project,” “possible,” “potential,” “should,” “will,” “would” and similar expressions. Actual results may vary materially. Forward-looking statements speak only as of the date they are made, and we expressly disclaim any obligation to update any forward-looking information. The following factors, in addition to those discussed in NSP-Minnesota’s Annual Report on Form 10-K for the fiscal year ended Dec. 31, 2021, and subsequent filings with the SEC, could cause actual results to differ materially from management expectations as suggested by such forward-looking information: uncertainty around the impacts and duration of the COVID-19 pandemic, including potential workforce impacts resulting from vaccination requirements, quarantine policies or government restrictions, and sales volatility; 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 work force and third-party contractor factors; violations of our Codes of Conduct; ability to recover costs; changes in regulation; reductions in our credit ratings and the cost of maintaining certain contractual relationships; general economic conditions, including inflation rates, monetary fluctuations, supply chain constraints and their impact on capital expenditures and/or the ability of NSP-Minnesota and its subsidiaries 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; effects of geopolitical events, including war and acts of terrorism; cyber security threats and data security breaches; seasonal weather patterns; changes in environmental laws and regulations; climate change and other weather; natural disaster and resource depletion, including compliance with any accompanying legislative and regulatory changes; costs of potential regulatory penalties; and regulatory changes and/or limitations related to the use of natural gas as an energy source.

PART I — FINANCIAL INFORMATION

ITEM 1 — FINANCIAL STATEMENTS

NSP-MINNESOTA AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

(amounts in millions)

	Three Months Ended June 30				Six Months Ended June 30
	2022		2021		2022		2021
Operating revenues
Electric, non-affiliates	$	1,191	$	1,095	$	2,316	$	2,119
Electric, affiliates	133		131		262		246
Natural gas	167		80		601		284
Other	11		9		21		18
Total operating revenues	1,502		1,315		3,200		2,667
Operating expenses
Electric fuel and purchased power	578		487		1,107		920
Cost of natural gas sold and transported	109		32		445		157
Cost of sales — other	7		6		12		11
O&M expenses	304		313		610		611
Conservation program expenses	41		31		90		65
Depreciation and amortization	251		229		503		450
Taxes (other than income taxes)	68		66		141		135
Total operating expenses	1,358		1,164		2,908		2,349
Operating income	144		151		292		318
Other (expense) income, net	(5)		2		(5)		4
Allowance for funds used during construction — equity	6		7		12		14
Interest charges and financing costs
Interest charges — includes other financing costs of $2, $2, $4 and $4, respectively	72		70		141		133
Allowance for funds used during construction — debt	(3)		(3)		(5)		(6)
Total interest charges and financing costs	69		67		136		127
Income before income taxes	76		93		163		209
Income tax benefit	(42)		(19)		(82)		(32)
Net income	$	118	$	112	$	245	$	241

See Notes to Consolidated Financial Statements

4

NSP-MINNESOTA AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

(amounts in millions)

	Three Months Ended June 30				Six Months Ended June 30
	2022		2021		2022		2021
Net income	$	118	$	112	$	245	$	241
Other comprehensive income
Derivative instruments:
Reclassification of losses to net income, net of tax of $—, $—, $— and $—, respectively	—		—		—		1
Total other comprehensive income	—		—		—		1
Total comprehensive income	$	118	$	112	$	245	$	242

See Notes to Consolidated Financial Statements

5

NSP-MINNESOTA AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(amounts in millions)

	Six Months Ended June 30
	2022		2021
Operating activities
Net income	$	245	$	241
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	507		453
Nuclear fuel amortization	61		56
Deferred income taxes	(144)		(30)
Allowance for equity funds used during construction	(12)		(14)
Provision for bad debts	9		12
Changes in operating assets and liabilities:
Accounts receivable	(16)		(62)
Accrued unbilled revenues	13		(22)
Inventories	(28)		16
Other current assets	1		10
Accounts payable	50		5
Net regulatory assets and liabilities	258		(105)
Other current liabilities	12		(45)
Pension and other employee benefit obligations	(7)		(35)
Other, net	20		(24)
Net cash provided by operating activities	969		456
Investing activities
Capital/construction expenditures	(752)		(842)
Purchase of investment securities	(787)		(628)
Proceeds from the sale of investment securities	769		410
Investments in utility money pool arrangement	(856)		(189)
Repayments from utility money pool arrangement	855		93
Other, net	2		(3)
Net cash used in investing activities	(769)		(1,159)
Financing activities
Repayments of short-term borrowings, net	—		(179)
Borrowings under utility money pool arrangement	—		434
Repayments under utility money pool arrangement	—		(434)
Proceeds from issuance of long-term debt	489		836
Repayment of long-term debt	(300)		—
Capital contributions (to) from parent	(7)		624
Dividends paid to parent	(263)		(216)
Other, net	—		2
Net cash (used in) provided by financing activities	(81)		1,067
Net change in cash, cash equivalents and restricted cash	119		364
Cash, cash equivalents and restricted cash at beginning of period	73		46
Cash, cash equivalents and restricted cash at end of period	$	192	$	410
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	$	(129)	$	(116)
Cash (paid) received for income taxes, net	(25)		4
Supplemental disclosure of non-cash investing and financing transactions:
Accrued property, plant and equipment additions	$	148	$	305
Inventory transfers to property, plant and equipment	9		6
Allowance for equity funds used during construction	12		14

See Notes to Consolidated Financial Statements

6

NSP-MINNESOTA AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (UNAUDITED)

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

	June 30, 2022		Dec. 31, 2021
Assets
Current assets
Cash and cash equivalents	$	192	$	73
Accounts receivable, net	457		429
Accounts receivable from affiliates	27		29
Investments in money pool arrangements	92		91
Accrued unbilled revenues	306		319
Inventories	328		309
Regulatory assets	505		527
Derivative instruments	204		53
Prepayments and other	46		46
Total current assets	2,157		1,876
Property, plant and equipment, net	16,751		16,430
Other assets
Nuclear decommissioning fund and other investments	2,905		3,308
Regulatory assets	883		718
Derivative instruments	73		33
Operating lease right-of-use assets	366		408
Other	37		36
Total other assets	4,264		4,503
Total assets	$	23,172	$	22,809
Liabilities and Equity
Current liabilities
Current portion of long-term debt	$	400	$	300
Accounts payable	577		522
Accounts payable to affiliates	85		63
Regulatory liabilities	277		117
Taxes accrued	251		260
Accrued interest	80		78
Dividends payable to parent	114		96
Derivative instruments	99		35
Operating lease liabilities	96		90
Other	216		166
Total current liabilities	2,195		1,727
Deferred credits and other liabilities
Deferred income taxes	1,713		1,949
Deferred investment tax credits	16		17
Regulatory liabilities	1,955		1,927
Asset retirement obligations	2,668		2,585
Derivative instruments	103		71
Pension and employee benefit obligations	105		112
Operating lease liabilities	303		353
Other	26		48
Total deferred credits and other liabilities	6,889		7,062
Commitments and contingencies
Capitalization
Long-term debt	6,540		6,447
Common stock — 5,000,000 shares authorized of $0.01 par value; 1,000,000 shares outstanding at June 30, 2022 and Dec. 31, 2021, respectively	—		—
Additional paid in capital	5,213		5,202
Retained earnings	2,355		2,391
Accumulated other comprehensive loss	(20)		(20)
Total common stockholder's equity	7,548		7,573
Total liabilities and equity	$	23,172	$	22,809

See Notes to Consolidated Financial Statements

7

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 June 30, 2022 and 2021
Balance at March 31, 2021	1,000,000	$	—	$	4,985	$	2,226	$	(21)	$	7,190
Net income						112				112
Dividends declared to parent						(107)				(107)
Contribution of capital by parent				200						200
Balance at June 30, 2021	1,000,000	$	—	$	5,185	$	2,231	$	(21)	$	7,395
Balance March 31, 2022	1,000,000	$	—	$	5,202	$	2,351	$	(20)	$	7,533
Net income						118				118
Dividends declared to parent						(114)				(114)
Contribution of capital by parent				11						11
Balance at June 30, 2022	1,000,000	$	—	$	5,213	$	2,355	$	(20)	$	7,548
	Common Stock Issued					Retained Earnings		Accumulated Other Comprehensive Loss		Total Common Stockholder's Equity
	Shares	Par Value		Additional Paid In Capital
Six Months Ended June 30, 2022 and 2021
Balance at Dec. 31, 2020	1,000,000	$	—	$	4,585	$	2,206	$	(22)	$	6,769
Net income						241				241
Other comprehensive income								1		1
Dividends declared to parent						(216)				(216)
Contribution of capital by parent				600						600
Balance at June 30, 2021	1,000,000	$	—	$	5,185	$	2,231	$	(21)	$	7,395
Balance at Dec. 31, 2021	1,000,000	$	—	$	5,202	$	2,391	$	(20)	$	7,573
Net income						245				245
Dividends declared to parent						(281)				(281)
Contribution of capital by parent				11						11
Balance at June 30, 2022	1,000,000	$	—	$	5,213	$	2,355	$	(20)	$	7,548
See Notes to Consolidated Financial Statements

8

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 June 30, 2022 and Dec. 31, 2021; the results of NSP-Minnesota’s operations, including the components of net income and comprehensive income, and changes in stockholder’s equity for the six months ended June 30, 2022 and 2021; and NSP-Minnesota’s cash flows for the six months ended June 30, 2022 and 2021.

All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after June 30, 2022 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, 2021 balance sheet information has been derived from the audited 2021 consolidated financial statements included in the NSP-Minnesota Annual Report on Form 10-K for the year ended Dec. 31, 2021.

Notes to the consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with GAAP on an annual basis have been condensed or omitted pursuant to such rules and regulations. For further information, refer to the consolidated financial statements and notes thereto included in the NSP-Minnesota Annual Report on Form 10-K for the year ended Dec. 31, 2021, filed with the SEC on Feb. 23, 2022. Due to the seasonality of NSP-Minnesota’s electric and natural gas sales, interim results are not necessarily an appropriate base from which to project annual results.

1. Summary of Significant Accounting Policies

The significant accounting policies set forth in Note 1 to the consolidated financial statements in the NSP-Minnesota Annual Report on Form 10-K for the year ended Dec. 31, 2021 appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

2. Accounting Pronouncements

As of June 30, 2022, there was no material impact from the recent adoption of new accounting pronouncements, nor expected material impact from recently issued accounting pronouncements yet to be adopted, on NSP-Minnesota’s financial statements.

3. Selected Balance Sheet Data

(Millions of Dollars)	June 30, 2022		Dec. 31, 2021
Accounts receivable, net
Accounts receivable	$	502	$	474
Less allowance for bad debts	(45)		(45)
Accounts receivable, net	$	457	$	429

(Millions of Dollars)	June 30, 2022		Dec. 31, 2021
Inventories
Materials and supplies	$	190	$	181
Fuel	106		81
Natural gas	32		47
Total inventories	$	328	$	309

(Millions of Dollars)	June 30, 2022		Dec. 31, 2021
Property, plant and equipment, net
Electric plant	$	19,826	$	19,154
Natural gas plant	1,940		1,864
Common and other property	1,083		1,007
Plant to be retired (a)	682		719
Construction work in progress	896		984
Total property, plant and equipment	24,427		23,728
Less accumulated depreciation	(7,938)		(7,606)
Nuclear fuel	3,096		3,081
Less accumulated amortization	(2,834)		(2,773)
Property, plant and equipment, net	$	16,751	$	16,430

(a)Amounts include regulator-approved retirements of Sherco Units 1, 2 and 3 and A.S. King and are reported 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.

Money pool borrowings for NSP-Minnesota:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2022		Year Ended Dec. 31, 2021
Borrowing limit	$	250	$	250
Amount outstanding at period end	—		—
Average amount outstanding	—		6
Maximum amount outstanding	—		236
Weighted average interest rate, computed on a daily basis	N/A		0.07		%
Weighted average interest rate at period end	N/A		N/A

Commercial Paper — Commercial paper outstanding for NSP-Minnesota:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2022		Year Ended Dec. 31, 2021
Borrowing limit	$	500	$	500
Amount outstanding at period end	—		—
Average amount outstanding	—		26
Maximum amount outstanding	—		317
Weighted average interest rate, computed on a daily basis	N/A		0.18		%
Weighted average interest rate at period end	N/A		N/A

Letters of Credit — NSP-Minnesota uses letters of credit, generally with terms of one year, to provide financial guarantees for certain obligations. There were $11 million and $9 million of letters of credit outstanding under the credit facility at June 30, 2022 and Dec. 31, 2021, respectively. Amounts approximate their fair value and are subject to fees.

9

Revolving Credit Facility — In order to issue its commercial paper, NSP-Minnesota must have a revolving credit facility in place at least equal to the amount of its 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 June 30, 2022, NSP-Minnesota had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)		Drawn (b)		Available
$	500	$	11	$	489

(a)Expires in June 2024.

(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 June 30, 2022 and Dec. 31, 2021.

Bilateral Credit Agreement — In April 2022, 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 June 30, 2022, NSP-Minnesota had $43 million of outstanding letters of credit under the $75 million bilateral credit agreement.

Long-Term Borrowings

During the three months ended June 30, 2022, NSP-Minnesota issued $500 million of 4.50% first mortgage bonds due June 1, 2052.

5. Revenues

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

	Three Months Ended June 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	338	$	76	$	3	$	417
C&I	588		76		—		664
Other	10		—		8		18
Total retail	936		152		11		1,099
Wholesale	138		—		—		138
Transmission	63		—		—		63
Interchange	133		—		—		133
Other	(5)		3		—		(2)
Total revenue from contracts with customers	1,265		155		11		1,431
Alternative revenue and other	59		12		—		71
Total revenues	$	1,324	$	167	$	11	$	1,502

	Three Months Ended June 30, 2021
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	334	$	38	$	7	$	379
C&I	547		29		—		576
Other	8		—		2		10
Total retail	889		67		9		965
Wholesale	69		—		—		69
Transmission	58		—		—		58
Interchange	131		—		—		131
Other	3		4		—		7
Total revenue from contracts with customers	1,150		71		9		1,230
Alternative revenue and other	76		9		—		85
Total revenues	$	1,226	$	80	$	9	$	1,315

	Six Months Ended June 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	675	$	311	$	9	$	995
C&I	1,102		256		—		1,358
Other	19		—		12		31
Total retail	1,796		567		21		2,384
Wholesale	263		—		—		263
Transmission	124		—		—		124
Interchange	262		—		—		262
Other	1		5		—		6
Total revenue from contracts with customers	2,446		572		21		3,039
Alternative revenue and other	132		29		—		161
Total revenues	$	2,578	$	601	$	21	$	3,200

	Six Months Ended June 30, 2021
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	660	$	152	$	14	$	826
C&I	964		108		—		1,072
Other	15		—		4		19
Total retail	1,639		260		18		1,917
Wholesale	167		—		—		167
Transmission	114		—		—		114
Interchange	246		—		—		246
Other	5		3		—		8
Total revenue from contracts with customers	2,171		263		18		2,452
Alternative revenue and other	194		21		—		215
Total revenues	$	2,365	$	284	$	18	$	2,667

10

6. Income Taxes

Reconciliation between the statutory rate and ETR:

	Six Months Ended June 30
	2022		2021
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	7.0		7.0
Increases (decreases) in tax from:
Wind PTCs (a)	(71.7)		(34.8)
Plant regulatory differences (b)	(6.2)		(8.0)
Other tax credits, net operating loss & tax credit allowances	(1.5)		(1.3)
Other (net)	1.1		0.8
Effective income tax rate	(50.3)	%	(15.3)	%

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

(b)Regulatory differences for income tax primarily relate to the credit of excess deferred taxes to customers through the average rate assumption method. Income tax benefits associated with the credit of excess deferred taxes 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 single definition of fair value and requires disclosures about assets and liabilities measured at fair value. A hierarchical framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value is established by this guidance.

•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 highly liquid and actively traded instruments with quoted prices.

•Level 2 — Pricing inputs are other than quoted 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 are those valued with models requiring significant management judgment or estimation.

Specific valuation methods include:

Cash equivalents — The fair values of cash equivalents are generally based on cost plus accrued interest; money market funds are measured using quoted NAV.

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 fund investments 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’ investments 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 — The 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 contractual settlements relate to inactive delivery locations or extend to periods beyond those readily observable on active exchanges or quoted by brokers, 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 a 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 estimated 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.

If costs of electric transmission congestion increase or decrease for a given path, the value of that particular instrument will likewise increase or decrease. 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.

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 regulatory asset.

Unrealized gains for the nuclear decommissioning fund were $1.0 billion and $1.3 billion as of June 30, 2022 and Dec. 31, 2021, respectively, and unrealized losses were $76 million and $7 million as of June 30, 2022 and Dec. 31, 2021, respectively.

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

	June 30, 2022
			Fair Value
(Millions of Dollars)	Cost		Level 1		Level 2		Level 3		NAV		Total
Nuclear decommissioning fund (a)
Cash equivalents	$	53	$	53	$	—	$	—	$	—	$	53
Commingled funds	835		—		—		—		1,209		1,209
Debt securities	668		—		615		6		—		621
Equity securities	407		971		1		—		—		972
Total	$	1,963	$	1,024	$	616	$	6	$	1,209	$	2,855

(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $50 million of other investments, including the rabbi trust.

	Dec. 31, 2021
			Fair Value
(Millions of Dollars)	Cost		Level 1		Level 2		Level 3		NAV		Total
Nuclear decommissioning fund (a)
Cash equivalents	$	64	$	64	$	—	$	—	$	—	$	64
Commingled funds	856		—		—		—		1,294		1,294
Debt securities	631		—		666		9		—		675
Equity securities	411		1,222		1		—		—		1,223
Total	$	1,962	$	1,286	$	667	$	9	$	1,294	$	3,256

(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $52 million of other investments, including the rabbi trust.

For the three and six months ended June 30, 2022 and 2021, there were immaterial Level 3 nuclear decommissioning fund investments or transfer of amounts between levels.

Contractual maturity dates of debt securities in the nuclear decommissioning fund as of June 30, 2022:

	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	$	3	$	190	$	232	$	196	$	621

Derivative Instruments 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, utility commodity prices and vehicle fuel prices.

Interest Rate Derivatives — NSP-Minnesota enters into various instruments that effectively fix the yield or price on a specified benchmark interest rate for an anticipated debt issuance for a specific period. These derivative instruments are generally designated as cash flow hedges for accounting purposes, with changes in fair value prior to settlement recorded as other comprehensive income.

At June 30, 2022, accumulated other comprehensive loss related to interest rate derivatives included $1 million of net losses expected to be reclassified into earnings during the next 12 months as the hedged interest rate transactions impact earnings. As of June 30, 2022, NSP-Minnesota had no unsettled interest rate derivatives.

Wholesale and Commodity Trading Risk — 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. Sharing of any 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, as well as for trading purposes. This could include the purchase or sale of energy or energy-related products, natural gas to generate electric energy, natural gas for resale, FTRs, vehicle fuel, and weather derivatives.

At June 30, 2022, NSP-Minnesota had no commodity contracts designated as cash flow hedges. NSP-Minnesota may enter into derivative instruments that mitigate commodity price risk on behalf of electric and natural gas customers, but may not be designated as qualifying hedging transactions. The classification of gains or losses for these instruments as a regulatory asset or liability, if applicable, is based on approved regulatory recovery mechanisms.

NSP-Minnesota also enters into commodity derivative instruments for trading purposes not directly related to commodity price risks associated with serving its electric and natural gas customers. Changes in the fair value of these commodity derivatives are recorded in electric operating revenues, net of amounts credited to customers under margin-sharing mechanisms.

Gross notional amounts of commodity forwards, options and FTRs:

(Amounts in Millions) (a)(b)	June 30, 2022	Dec. 31, 2021
Megawatt hours of electricity	76	57
Million British thermal units of natural gas	106	85

(a)Amounts are not reflective of net positions in the underlying commodities.

(b)Notional amounts for options are included on a gross basis, but are 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.

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As of June 30, 2022, eight of NSP-Minnesota’s ten most significant counterparties for these activities, comprising $33 million, or 31%, of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings. One of the ten most significant counterparties, comprising $24 million, or 23%, 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. One of these significant counterparties, comprising $47 million or 45% of this credit exposure, had credit quality less than investment grade, based on internal analysis. Four of these significant counterparties are municipal or cooperative electric entities, RTOs or other utilities.

Impact of Derivative Activity —

	Pre-Tax Fair Value Gains (Losses) Recognized During the Period in:
(Millions of Dollars)	Regulatory (Assets) and Liabilities
Three Months Ended June 30, 2022
Other derivative instruments
Electric commodity	$	7
Natural gas commodity	$	(1)
Total	$	6
Six Months Ended June 30, 2022
Other derivative instruments
Electric commodity	$	6
Natural gas commodity	2
Total	$	8

Three Months Ended June 30, 2021
Other derivative instruments
Electric commodity	$	3
Natural gas commodity	$	1
Total	$	4
Six Months Ended June 30, 2021
Other derivative instruments
Electric commodity	$	3
Natural gas commodity	2
Total	$	5

	Pre-Tax (Gains) 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 June 30, 2022
Other derivative instruments
Commodity trading	$	—	$	—		$	5	(b)
Electric commodity	—		(1)		(c)	—
Total	$	—	$	(1)		$	5
Six Months Ended June 30, 2022
Other derivative instruments
Commodity trading	$	—	$	—		$	6	(b)
Electric commodity	—		(3)		(c)	—
Natural gas commodity	—		2		(d)	(5)		(d)(e)
Total	$	—	$	(1)		$	1

	Pre-Tax (Gains) 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 June 30, 2021
Other derivative instruments
Commodity trading	$	—		$	—		$	2	(b)
Electric commodity	—			(1)		(c)	—
Total	$	—		$	(1)		$	2
Six Months Ended June 30, 2021
Derivatives designated as cash flow hedges
Interest rate	$	1	(a)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	33	(b)
Electric commodity	—			(12)		(c)	—
Natural gas commodity	—			1		(d)	(3)		(d)(e)
Total	$	—		$	(11)		$	30

(a)Recorded to interest charges.

(b)Recorded to electric operating revenues. Portions of these gains and losses are subject to sharing with electric customers through margin-sharing mechanisms and deducted from gross revenue, as appropriate.

(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. All 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 three and six months ended June 30, 2022 and 2021.

Credit Related Contingent Features — Contract provisions for derivative instruments that NSP-Minnesota enters into, including those accounted for as normal purchase-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 NSP-Minnesota’s credit ratings are downgraded below its investment grade credit rating by any of the major credit rating agencies.

As of June 30, 2022 and Dec. 31, 2021, there were $11 million and $3 million, respectively, of derivative liabilities with such underlying contract provisions. 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 the other financing arrangements related to payment terms or other covenants. As of June 30, 2022 and Dec. 31, 2021, there were approximately $110 million and $48 million, respectively, of derivative liabilities with such underlying contract provisions.

Certain derivative instruments are also subject to contract provisions that contain adequate assurance clauses. These provisions allow counterparties to seek performance assurance, including cash collateral, in the event that NSP-Minnesota’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 June 30, 2022 and Dec. 31, 2021.

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Recurring Fair Value Measurements — NSP-Minnesota’s derivative assets and liabilities measured at fair value on a recurring basis were as follows:

	June 30, 2022												Dec. 31, 2021
	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	$	32	$	128	$	61	$	221	$	(160)	$	61	$	9	$	40	$	22	$	71	$	(53)	$	18
Electric commodity (b)	—		—		144		144		(3)		141		—		—		30		30		(1)		29
Natural gas commodity	—		—		—		—		—		—		—		6		—		6		—		6
Total current derivative assets	$	32	$	128	$	205	$	365	$	(163)	202		$	9	$	46	$	52	$	107	$	(54)	53
PPAs (c)											2												—
Current derivative instruments											$	204											$	53
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	26	$	49	$	79	$	154	$	(81)	$	73	$	6	$	34	$	35	$	75	$	(42)	$	33
Total noncurrent derivative assets	$	26	$	49	$	79	$	154	$	(81)	$	73	$	6	$	34	$	35	$	75	$	(42)	$	33

	June 30, 2022												Dec. 31, 2021
	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
Other derivative instruments:
Commodity trading	$	35	$	172	$	11	$	218	$	(134)	$	84	$	13	$	58	$	4	$	75	$	(58)	$	17
Electric commodity	—		—		3		3		(3)		—		—		—		1		1		(1)		—
Natural gas commodity	—		1		—		1		—		1		—		4		—		4		—		4
Total current derivative liabilities	$	35	$	173	$	14	$	222	$	(137)	85		$	13	$	62	$	5	$	80	$	(59)	21
PPAs (c)											14												14
Current derivative instruments											$	99											$	35
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	47	$	77	$	40	$	164	$	(93)	$	71	$	15	$	48	$	26	$	89	$	(53)	$	36
Total noncurrent derivative liabilities	$	47	$	77	$	40	$	164	$	(93)	71		$	15	$	48	$	26	$	89	$	(53)	36
PPAs (c)											32												35
Noncurrent derivative instruments											$	103											$	71

(a)NSP-Minnesota nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at June 30, 2022 and Dec. 31, 2021. At both June 30, 2022 and Dec. 31, 2021, derivative assets and liabilities include no obligations to return cash collateral. At June 30, 2022 and Dec. 31, 2021 derivative assets and liabilities include rights to reclaim cash collateral of $12 million and $16 million, respectively. The counterparty netting excludes settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.

(b)Amounts relate to FTR instruments administered by MISO (annual auctions occurring in the second quarter). These instruments are utilized/intended to offset the impacts of transmission system congestion. Higher congestion costs have led to an increase in the fair value of FTRs. Due to regulatory recovery, changes in fair value are deferred as a regulatory asset or liability and do not have a material impact on net income.

(c)During 2006, Xcel Energy qualified these contracts under the normal purchase exception. Based on this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities.

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Changes in Level 3 commodity derivatives for the three and six months ended June 30, 2022 and 2021:

	Three Months Ended June 30
(Millions of Dollars)	2022		2021
Balance at April 1	$	76	$	12
Purchases/Issuances (a)	158		54
Settlements (a)	(73)		(19)
Net transactions recorded during the period:
Gains recognized in earnings (b)	41		33
Net gains recognized as regulatory assets and liabilities (a)	28		12
Balance at June 30	$	230	$	92
	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Balance at Jan. 1	$	56	$	(11)
Purchases/Issuances (a)	157		54
Settlements (a)	(92)		(26)
Net transactions recorded during the period:
Gains recognized in earnings (b)	91		63
Net gains recognized as regulatory assets and liabilities (a)	18		12
Balance at June 30	$	230	$	92

(a)Relates primarily to FTR instruments administered by MISO (annual auctions occurring in the second quarter). These instruments are utilized/intended to offset the impacts of transmission system congestion. Higher congestion costs have led to an increase in the fair value of FTRs. Due to regulatory recovery, changes in fair value are deferred as a regulatory asset or liability and do not have a material impact on net income.

(b)Relates to commodity trading and is subject to offsetting losses of derivative instruments categorized as levels 1 and 2 in the consolidated income statement.

NSP-Minnesota recognizes transfers between levels as of the beginning of each period. There were no transfers of amounts between levels for derivative instruments for the six months ended June 30, 2022 and 2021.

Fair Value of Long-Term Debt

Other financial instruments for which the carrying amount did not equal fair value:

	June 30, 2022				Dec. 31, 2021
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	6,940	$	6,984	$	6,747	$	7,761

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 June 30, 2022 and Dec. 31, 2021 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 June 30
	2022		2021		2022		2021
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	7	$	8	$	—	$	—
Interest cost (a)	6		6		—		—
Expected return on plan assets (a)	(12)		(13)		—		—
Amortization of prior service credit (a)	—		—		—		(1)
Amortization of net loss (a)	6		8		—		1
Net periodic benefit cost	7		9		—		—
Effects of regulation	—		(1)		—		—
Net benefit cost recognized for financial reporting	$	7	$	8	$	—	$	—
	Six Months Ended June 30
	2022		2021		2022		2021
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	14	$	15	$	—	$	—
Interest cost (a)	12		12		1		1
Expected return on plan assets (a)	(24)		(26)		—		—
Amortization of prior service credit (a)	—		—		(1)		(2)
Amortization of net loss (a)	12		17		—		1
Settlement charge (b)	(1)		—		—		—
Net periodic benefit cost	13		18		—		—
Effects of regulation	1		(2)		—		—
Net benefit cost recognized for financial reporting	$	14	$	16	$	—	$	—

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

(b)     In the first quarter of 2022, NSP-Minnesota recognized $1 million in settlement charge true-ups related to fourth quarter 2021.

In January 2022, contributions of $50 million were made across four of Xcel Energy’s pension plans, of which $5 million was attributable to NSP-Minnesota. Xcel Energy does not expect additional pension contributions during 2022.

9. Commitments and Contingencies

The following includes commitments, contingencies and unresolved contingencies that are material to NSP-Minnesota’s financial position.

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.

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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.

Minnesota Winter Storm Uri Costs — NSP-Minnesota is participating in a contested case regarding the prudency of incremental natural gas costs incurred during Winter Storm Uri. Other parties to the case have recommended significant cost disallowances, and while ultimate resolution of the matter is uncertain, it is reasonably possible that the MPUC could disallow certain deferred costs, resulting in earnings losses.

NSP-Minnesota filed rebuttal testimony in January 2022 detailing its position that the disallowances recommended by other parties lack any merit in the prudency review given the pertinent facts regarding NSP-Minnesota’s actions before, during and after the storm event.

In March 2022, following February 2022 ALJ hearings, the OAG recommended a disallowance of up to $148 million, the largest recommendation among the intervenor positions. In May 2022, the ALJs found that the natural gas costs for Winter Storm Uri were prudently incurred and recommended no disallowances. A MPUC decision is expected in August 2022.

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

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

In April 2020, the Minnesota Supreme Court denied the insurers’ petition for further review, ending the litigation.

In January 2021, the OAG and DOC recommended that NSP-Minnesota refund approximately $17 million of replacement power costs previously recovered through the fuel clause adjustment. NSP-Minnesota subsequently filed its response, asserting 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. A final decision by the MPUC is expected in mid-2023. A loss related to this matter is deemed remote.

Westmoreland Arbitration — In November 2014, insurers of the Westmoreland Coal Company filed an arbitration demand against NSP-Minnesota, SMMPA and Western Fuels Association, seeking recovery of alleged business losses due to a turbine failure at Sherco Unit 3, which currently include $19 million in damages, plus prejudgment interest. The Westmoreland insurers claim NSP-Minnesota’s invocation of the force majeure clause to stop the supply of coal was improper because the incident was allegedly caused by NSP-Minnesota’s failure to conform to industry maintenance standards.

NSP-Minnesota denies the claims asserted by the Westmoreland insurers and believes it properly stopped the supply of coal based upon the force majeure provision. In the second quarter of 2022, this matter settled for $2 million.

MISO ROE Complaints — In November 2013 and February 2015, customer groups filed two ROE complaints against MISO TOs, which includes NSP-Minnesota and NSP-Wisconsin. The first complaint requested a reduction in base ROE transmission formula rates from 12.38% to 9.15% for the time period of Nov. 12, 2013 to Feb. 11, 2015, and removal of ROE adders (including those for RTO membership). The second complaint requested, for a subsequent time period, a base ROE reduction from 12.38% to 8.67%.

The FERC has subsequently issued various related orders (including Opinion Nos. 569, 569A and 569B) related to ROE methodology/calculations and timing. NSP-Minnesota has recognized a liability for its best estimate of final refunds to customers for applicable complaint periods.

The MISO TOs and various other parties have filed petitions for review of the FERC’s most recent applicable opinions at the D.C. Circuit. A decision is expected by the end of the third quarter of 2022.

Environmental

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 its best estimate of costs/liabilities from final resolution of these issues, however, the outcome and timing are unknown. In addition, there may be insurance recovery and/or recovery from other potentially responsible parties, offsetting a portion of costs incurred.

Environmental Requirements — Water and Waste

Coal Ash Regulation — NSP-Minnesota’s operations are subject to federal and state regulations that impose requirements for handling, storage, treatment and disposal of solid waste. Under the CCR Rule, utilities are required to complete groundwater sampling around their CCR landfills and surface impoundments. Currently, NSP-Minnesota has three regulated ash units in operation.

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

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In August 2020, the EPA published its final rule to implement closure by April 2021 for CCR impoundments. This final rule required Xcel Energy to expedite closure plans for one impoundment.

In October 2020, NSP-Minnesota completed construction and placed in service a new impoundment to replace the clay lined impoundment. With the new ash pond in service, NSP-Minnesota has initiated closure activities for the existing ash pond at an estimated cost of $4 million. NSP-Minnesota has five years to complete closure activities.

Closure costs for existing impoundments are included in the calculation of the asset retirement obligation.

Federal Clean Water Act Section 316(b) — The federal Clean Water Act requires the EPA to regulate cooling water intake structures to assure that these structures reflect the best technology available for minimizing impingement and entrainment of aquatic species. NSP-Minnesota estimates capital expenditures of approximately $36 million to comply with impingement and entrainment requirements. NSP-Minnesota believes six plants could be required to make improvements to reduce impingement and entrainment. NSP-Minnesota anticipates these costs will be recoverable through regulatory mechanisms.

Leases

NSP-Minnesota evaluates contracts that may contain leases, including PPAs and arrangements for the use of office space 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 June 30
(Millions of Dollars)	2022		2021
Operating leases
PPA capacity payments	$	24	$	17
Other operating leases (a)	2		3
Total operating lease expense (b)	$	26	$	20

(a)Includes short-term lease expense of $1 million for 2022 and 2021, 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.

	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Operating leases
PPA capacity payments	$	49	$	36
Other operating leases (a)	4		5
Total operating lease expense (b)	$	53	$	41

(a)Includes short-term lease expense of $1 million for 2022 and 2021, 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 June 30, 2022:

(Millions of Dollars)	PPA Operating Leases		Other Operating Leases		Total Operating Leases
Total minimum obligation	$	366	$	69	$	435
Interest component of obligation	(25)		(11)		(36)
Present value of minimum obligation	$	341	$	58	399
Less current portion					(96)
Noncurrent operating lease liabilities					$	303

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 they purchase. These specific PPAs create a variable interest in the IPP.

NSP-Minnesota had approximately 1,322 MW and 1,347 MW of capacity under long-term PPAs at June 30, 2022 and Dec. 31, 2021, respectively, with entities that have been determined to be variable interest entities. NSP-Minnesota concluded that these entities are not required to be consolidated in its financial statements because it does not have the power to direct the activities that most significantly impact the entities’ economic performance. The PPAs have expiration dates through 2039.

10. Other Comprehensive Income (Loss)

Changes in accumulated other comprehensive income (loss), net of tax, for the three and six months ended June 30, 2022 and 2021:

	Three Months Ended June 30, 2022						Three Months Ended June 30, 2021
(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 April 1	$	(17)	$	(3)	$	(20)	$	(18)	$	(3)	$	(21)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (a)	—		—		—		—		—		—
Accumulated other comprehensive loss at June 30	$	(17)	$	(3)	$	(20)	$	(18)	$	(3)	$	(21)

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	Six Months Ended June 30, 2022						Six Months Ended June 30, 2021
(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	$	(17)	$	(3)	$	(20)	$	(19)	$	(3)	$	(22)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (a)	—		—		—		1		—		1
Accumulated other comprehensive loss at June 30	$	(17)	$	(3)	$	(20)	$	(18)	$	(3)	$	(21)

(a)Included in interest charges.

11. Segment Information

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

NSP-Minnesota has the following reportable segments:

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

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

NSP-Minnesota also presents All Other, which includes operating segments with revenues below the necessary quantitative thresholds. Those operating segments primarily include appliance repair services, 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 June 30
(Millions of Dollars)	2022		2021
Regulated Electric
Operating revenues (a)	$	1,324	$	1,226
Intersegment revenue	—		1
Total revenues	$	1,324	$	1,227
Net income	113		112
Regulated Natural Gas
Operating revenues (b)	$	167	$	80
Intersegment revenue	1		—
Total revenues	$	168	$	80
Net income (loss)	4		(1)
All Other
Total revenues	$	11	$	9
Net income	1		1
Consolidated Total
Operating revenues (a)(b)	$	1,503	$	1,316
Reconciling eliminations	(1)		(1)
Total revenues	$	1,502	$	1,315
Net income	118		112

(a)    Operating revenues include $133 million and $131 million of affiliate electric revenue for the three months ended June 30, 2022 and 2021.

(b)    Operating revenues include an immaterial amount of affiliate gas revenue for the three months ended June 30, 2022 and 2021.

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	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Regulated Electric
Operating revenues (a)	$	2,578	$	2,365
Intersegment revenue	—		1
Total revenues	$	2,578	$	2,366
Net income	211		219
Regulated Natural Gas
Operating revenues (b)	$	601	$	284
Intersegment revenue	1		1
Total revenues	$	602	$	285
Net income	33		19
All Other
Total operating revenues	$	21	$	18
Net income	1		3
Consolidated Total
Operating revenues (a)(b)	$	3,201	$	2,669
Reconciling eliminations	(1)		(2)
Total operating revenues	$	3,200	$	2,667
Net income	245		241

(a)    Operating revenues include $262 million and $246 million of affiliate electric revenue for the six months ended June 30, 2022 and 2021.

(b)    Operating revenues include an immaterial amount of affiliate gas revenue for the six months ended June 30, 2022 and 2021.

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 excludes (or includes) amounts that are adjusted from 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 NSP-Minnesota’s core earnings and underlying performance. We believe this measurement is useful to investors to evaluate the actual and projected financial performance and contribution of NSP-Minnesota. For the three and six months ended June 30, 2022 and 2021, there were no such adjustments to GAAP earnings and therefore GAAP earnings equal ongoing earnings.

Results of Operations

NSP-Minnesota’s net income was approximately $245 million for the six months ended June 30, 2022 compared with approximately $241 million for the prior year. The increase reflects regulatory recovery of capital investment, offset by increased depreciation and interest expense.

Electric Margin

Electric margin is presented as electric revenues less electric fuel and purchased power expenses. Expenses incurred for electric fuel and purchased power are generally recovered through various regulatory recovery mechanisms. As a result, changes in these expenses are generally offset in operating revenues.

Electric revenues and fuel and purchased power expenses are impacted by fluctuations in the price of natural gas, coal and uranium. However, these price fluctuations generally have minimal impact on earnings due to fuel recovery mechanisms. In addition, electric customers receive a credit for PTCs generated, which reduce electric revenue and income taxes.

Electric revenues, fuel and purchased power and electric margin and explanation of the changes are listed as follows:

	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Electric revenues	$	2,578	$	2,365
Electric fuel and purchased power	(1,107)		(920)
Electric margin	$	1,471	$	1,445

(Millions of Dollars)	Six Months Ended June 30, 2022 vs. 2021
Regulatory rate outcome (Minnesota)	$	63
Non-fuel riders	25
Conservation and demand side revenues (offset in expense)	17
PTCs flowed back to customers (offset by lower ETR)	(69)
Proprietary commodity trading, net of sharing (a)	(15)
Other (net)	5
Total increase	$	26

(a)Includes $12 million of trading margin recognized in the first quarter of 2021, driven by market changes associated with Winter Storm Uri.

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Natural Gas Margin

Natural gas margin is presented as natural gas revenues less the cost of natural gas sold and transported. Expenses incurred for the cost of natural gas sold are generally recovered through various regulatory recovery mechanisms. As a result, changes in these expenses are generally offset in operating revenues.

Natural gas revenues, cost of natural gas sold and transported and natural gas margin and explanation of the changes are listed as follows:

	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Natural gas revenues	$	601	$	284
Cost of natural gas sold and transported	(445)		(157)
Natural gas margin	$	156	$	127

(Millions of Dollars)	Six Months Ended June 30, 2022 vs. 2021
Regulatory rate outcomes (Minnesota, North Dakota)	$	17
Estimated impact of weather	9
Other (net)	3
Total increase	$	29

Non-Fuel Operating Expenses and Other Items

Depreciation and Amortization — Depreciation and amortization expense increased $53 million year-to-date. The increase was primarily driven by several wind farms going into service and normal system expansion.

Other (Expense) Income — Other (expense) income decreased $9 million year-to-date, largely related to rabbi trust performance, which is primarily offset in O&M expenses (employee benefit costs).

Interest Charges — Interest charges increased $8 million year-to-date, largely due to increased long-term debt levels to fund capital investments and deferred balances related to Winter Storm Uri.

Income Taxes — Income tax benefit increased $50 million for the first six months of 2022. The increase was primarily driven by increased wind PTCs due to several new wind farms going into service and greater production at existing wind farms and lower pretax earnings in 2022. Wind PTCs are credited to customers (recorded as a reduction to revenue) and do not have a material impact on net income. These were partially offset by lower plant regulatory differences.

In April 2022, the Internal Revenue Service published inflation factors used to determine the PTC rate. As a result, the 2022 PTC rate on the sale of electricity produced from wind is 2.6 cents per kilowatt hour, compared to 2.5 cents for 2021.

See Note 6 to the consolidated financial statements for further information.

Public Utility Regulation and Other

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

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

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

Except to the extent noted below, the circumstances set forth in Public Utility Regulation included in Item 7 of NSP-Minnesota’s Annual Report on Form 10-K for the year ended Dec. 31, 2021 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

2022 Minnesota Electric Rate Case — In October 2021, NSP-Minnesota filed a three-year electric rate case with the MPUC. The rate case is based on a requested ROE of 10.2%, a 52.50% equity ratio and forward test years.

The request is detailed as follows:

(Amounts in Millions, Except Percentages)	2022			2023			2024			Total
Rate request	$	396		$	150		$	131		$	677
Increase percentage	12.2		%	4.8		%	4.2		%	21.2		%
Rate base	$	10,931		$	11,446		$	11,918		N/A

In December 2021, the MPUC approved interim rates, subject to refund, of $247 million, effective Jan. 1, 2022. A current liability that represents NSP-Minnesota’s best estimate of a refund obligation associated with interim rates was recorded as of June 30, 2022.

Next steps in the procedural schedule are expected to be as follows:

•Intervenor testimony: Oct. 3, 2022.

•Rebuttal testimony: Nov. 8, 2022.

•Hearing: Dec. 13-16, 2022.

•ALJ Report: March 31, 2023.

•MPUC Order: June 30, 2023.

2022 Minnesota Natural Gas Rate Case — In November 2021, NSP-Minnesota filed a request with the MPUC for an annual natural gas rate increase of $36 million, or 6.6%. The filing is based on a 2022 forecast test year and includes a requested ROE of 10.5%, an equity ratio of 52.5% and a rate base of $934 million.

In December 2021, the MPUC approved interim rates of $25 million, subject to refund, effective Jan. 1, 2022.

Next steps in the procedural schedule are expected to be as follows:

•Intervenor testimony: Aug. 30, 2022.

•Rebuttal testimony: Oct. 4, 2022.

•Hearing: Nov. 1-4, 2022.

•ALJ Report: Feb. 6, 2023.

•MPUC Order: April 26, 2023.

2021 North Dakota Natural Gas Rate Case — In September 2021, NSP-Minnesota filed a request with the NDPSC for a natural gas rate increase of $7 million, or 10.5%. The filing is based on a requested ROE of 10.5%, an equity ratio of 52.54%, a 2022 forecast test year and a rate base of $124 million. Interim rates of $7 million, subject to refund, were implemented on Nov. 1, 2021.

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In May 2022, NSP-Minnesota and NDPSC Staff reached a natural gas settlement, which reflects a rate increase of $5 million, based on a 9.8% ROE and 52.54% equity ratio. A NDPSC decision is expected in the third quarter of 2022.

2022 South Dakota Electric Rate Case — On June 30, 2022, NSP-Minnesota filed a South Dakota electric rate case (first since 2014) seeking a revenue increase of approximately $44 million. The filing is based on a 2021 historic test year adjusted for certain known and measurable changes for 2022 and 2023, a requested ROE of 10.75%, rate base of approximately $947 million and an equity ratio of 53%. Final rates are expected to be effective in the first quarter of 2023.

Wind Repowering — In January 2021, the MPUC approved NSP-Minnesota’s request for the repowering of 651 MW of owned wind projects. Two of the four repowering projects, where construction has not yet begun (in-service dates in 2025), now expect costs in excess of the original approval. Evaluation of options to mitigate the impact of these cost increases is on-going. An update to the MPUC is expected in the third or fourth quarter 2022.

Sherco Solar Proposal — In April 2021, NSP-Minnesota proposed to add 460 MW of solar facilities at the Sherco site with an initial estimated investment of approximately $575 million. NSP-Minnesota requested a delay in the procedural schedule due to recent solar supply chain disruptions and potential impact on pricing. An updated request was filed with the MPUC in July 2022 and a decision is now anticipated in the fourth quarter of 2022 or the first quarter of 2023. The proposed facilities are still expected to be in-service by the end of 2025.

Wind PPA Buyout — In July 2022, NSP-Minnesota requested approval from the MPUC for updated agreements with ALLETE Clean Energy to purchase the repowered 100 MW Northern Wind Facility and 22 MW Rock Aetna Facility. The MPUC previously approved NSP-Minnesota’s acquisition of the projects, but the agreements required further approval due to updated terms of the acquisition, including an increase in the purchase price. The price increase is offset by higher expected PTC benefits, resulting in minimal change to the net cost to customers.

2022 RES Electric Rider — In November 2021, NSP-Minnesota filed the RES Rider. The requested amount of $264 million includes a true-up (2020 and 2021 riders) of $154 million and the 2022 requested amount of $110 million. A MPUC decision is pending.

2022 GUIC Natural Gas Rider — In October 2021, NSP-Minnesota filed the GUIC Rider for an amount of $27 million. A MPUC decision is pending.

2021 GUIC Natural Gas Rider — In October 2020, NSP-Minnesota filed the GUIC Rider for an amount of $27 million. A MPUC decision is pending.

2022 TCR Electric Rider — In November 2021, NSP-Minnesota filed the TCR Rider for an amount of $105 million. A MPUC decision is pending.

Nuclear Power Operations

NSP-Minnesota owns two nuclear generating plants: the Monticello plant and the Prairie Island plant. See Note 10 to the consolidated financial statements of NSP-Minnesota’s Annual Report on Form 10-K for the year ended Dec. 31, 2021 for further information. The circumstances set forth in Nuclear Power Operations included in Item 7 of NSP-Minnesota’s Annual Report on Form 10-K for the year ended Dec. 31, 2021, appropriately represent, in all material respects, the current status of nuclear power operations, and are incorporated by reference.

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 availability of materials and has sought to mitigate impacts by seeking alternative suppliers as necessary.

Advanced Metering Infrastructure Implementation

Supply chain issues associated with semi-conductors have delayed the availability of advanced metering infrastructure electric meters. Impacts are currently being evaluated and the 2022 and 2023 deployment schedule could be impacted.

Solar Resources

In April 2022, the U.S. Department of Commerce initiated an anti-circumvention investigation that would subject CSPV solar panels and cells imported from Malaysia, Vietnam, Thailand, and Cambodia with potential incremental tariffs ranging from 50% to 250%. These countries account for more than 80% of CSPV panel imports.

Uncertainty of the investigation and the adverse impact on potential tariffs has resulted in the cancellation or delay of certain domestic solar projects.

In April 2021, NSP-Minnesota proposed to add 460 MW of solar facilities at the Sherco site with an initial estimated investment of approximately $575 million. NSP-Minnesota requested a delay in the procedural schedule due to recent solar supply chain disruptions and potential impact on pricing. An updated request was filed with the MPUC in July 2022 and a decision is now anticipated in the fourth quarter of 2022 or the first quarter of 2023. The proposed facilities are still expected to be in-service by the end of 2025.

MISO Capacity Credits

The NSP System offered 1,500 MW of excess capacity into the MISO planning resource auction for June 2022 through May 2023. Due to a projected overall capacity shortfall in the MISO region, the 1,500 MWs offered cleared the auction at maximum pricing and is expected to generate revenues to the NSP System of approximately $89 million in 2022 and approximately $64 million in 2023. During the second quarter of 2022, the NSP System received approximately $13 million of capacity credits.

NSP-Minnesota’s approximate share is $75 million of 2022 capacity revenues. These revenues will primarily be used to mitigate customer rate increases or returned through earnings sharing or other mechanisms.

Winter Storm Uri

In February 2021, the United States experienced Winter Storm Uri. Extreme cold temperatures impacted certain operational assets as well as the availability of renewable generation. The cold weather also affected the country’s supply and demand for natural gas. These factors contributed to extremely high market prices for natural gas and electricity. As a result of the extremely high market prices, NSP-Minnesota incurred net natural gas, fuel and purchased energy costs of approximately $230 million (largely deferred as regulatory assets).

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NSP-Minnesota has natural gas, fuel and purchased energy mechanisms in each jurisdiction for recovering incurred costs. However, February cost increases were deferred for future recovery with recovery proposed over a period of up to 63 months to mitigate the impact to customer bills. Additionally, NSP-Minnesota did not request recovery of financing costs in order to further limit the impact to our customers. NSP-Minnesota currently has approval for recovery of Winter Storm Uri costs in North Dakota. There were no material costs for South Dakota.

Minnesota Regulatory Overview — In 2021, the MPUC allowed recovery of $179 million of costs (with no financing charge) starting in September 2021, with a potential true-up pending a prudency review. The C&I class ($82 million) will be recovered over 27 months and the residential class ($97 million) will be recovered over a 63-month recovery period.

The Department of Commerce recommended a disallowance of $122 million, the Office of the Attorney General recommended disallowances of $110 million to $148 million and the Citizens Utility Board recommended a $69 million disallowance.

In May 2022, the ALJs found the Winter Storm Uri fuel costs were prudently incurred and recommended no disallowances. A MPUC decision is expected in August 2022.

Environmental

Affordable Clean Energy

In July 2019, the EPA adopted the ACE rule, which requires states to develop plans by 2022 for greenhouse gas reductions from coal-fired power plants. In January 2021, the U.S. Court of Appeals for the D.C. Circuit issued a decision vacating and remanding the ACE rule. That decision essentially held that EPA’s previous economy-wide regulatory approach taken in the 2015 CPP was consistent with the Clean Air Act. If upheld, that decision would have allowed the EPA to proceed with alternate regulation of coal-fired power plants consistent with the CPP approach. However, the Court of Appeals decision was appealed to the U.S Supreme Court. In a June 30, 2022, ruling, the Supreme Court held that a CPP economy-wide approach is not consistent with the Clean Air Act. Thus, if EPA is to proceed with new rules, they must be consistent with this ruling and be more similar to the ACE rule “inside the fenceline” approach. If any new rules require additional investment, NSP-Minnesota believes that the cost of these initiatives or replacement generation would be recoverable through rates based on prior state commission practices.

Nuclear Fuel Supply

NSP-Minnesota has contracted for and has its 2022 and 2023 enriched nuclear material requirements in various stages of processing in Canada, Europe and the United States. We will continue to monitor the evolving situation in Ukraine and its global impacts and will take necessary actions to ensure a secure supply of enriched nuclear material. NSP-Minnesota is scheduled to take delivery of approximately 30% of its average enriched nuclear material requirements from Russia through 2030.

ITEM 4 — CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

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

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

As of June 30, 2022, based on an evaluation carried out under the supervision and with the participation of NSP-Minnesota’s management, including the CEO and CFO, of the effectiveness of its disclosure controls and procedures, the CEO and CFO have concluded that NSP-Minnesota’s disclosure controls and procedures were effective.

Internal Control Over Financial Reporting

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

PART II — OTHER INFORMATION

ITEM 1 — LEGAL PROCEEDINGS

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.

ITEM 1A — RISK FACTORS

NSP-Minnesota’s risk factors are documented in Item 1A of Part I of its Annual Report on Form 10-K for the year ended Dec. 31, 2021, 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 6 — EXHIBITS

* Indicates incorporation by reference

Exhibit Number	Description	Report or Registration Statement	Exhibit Reference
3.01*	Articles of Incorporation and Amendments of Northern Power Corp. (renamed NSP-Minnesota on Aug. 21, 2000)	NSP-Minnesota Form 10-12G dated Oct. 5, 2000	3.01
3.02*	Amended and Restated Bylaws of NSP-Minnesota, dated Jan. 25, 2019	NSP-Minnesota Form 10-K for the year ended Dec. 31, 2018	3.02
4.01*	Supplemental Trust Indenture dated as of May 1, 2022 between NSP-Minnesota and the Bank of New York Mellon Trust Company, N.A., as successor trustee, creating $500,000,000 aggregate principal amount of 4.50% First Mortgage Bonds, Series due June 1, 2052	NSP-Minnesota Form 8-K dated May 9, 2022	4.01
31.01	Principal Executive Officer’s certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.02	Principal Financial Officer’s certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.01	Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH	Inline XBRL Schema
101.CAL	Inline XBRL Calculation
101.DEF	Inline XBRL Definition
101.LAB	Inline XBRL Label
101.PRE	Inline XBRL Presentation
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

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SIGNATURES

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

		Northern States Power Company (a Minnesota corporation)
7/28/2022	By:	/s/ BRIAN J. VAN ABEL
		Brian J. Van Abel
		Executive Vice President, Chief Financial Officer
		(Duly Authorized Officer and Principal Financial Officer)

24

EX-31.01

Exhibit 31.01

CERTIFICATION

I, Robert C. Frenzel, certify that:

1.I have reviewed this report on Form 10-Q of Northern States Power Company (a Minnesota corporation);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: 7/28/2022

/s/ ROBERT C. FRENZEL

Robert C. Frenzel

Chairman, Chief Executive Officer and Director

(Principal Executive Officer)

1

EX-31.02

Exhibit 31.02

CERTIFICATION

I, Brian J. Van Abel, certify that:

1.I have reviewed this report on Form 10-Q of Northern States Power Company (a Minnesota corporation);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: 7/28/2022

/s/ BRIAN J. VAN ABEL

Brian J. Van Abel

Executive Vice President, Chief Financial Officer and Director

(Duly Authorized Officer and Principal Financial Officer)

2

EX-32.01

Exhibit 32.01

OFFICER CERTIFICATION

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Northern States Power Company, a Minnesota corporation (NSP-Minnesota) on Form 10-Q for the quarter ended June 30, 2022, as filed with the SEC on the date hereof (Form 10-Q), each of the undersigned officers of NSP-Minnesota certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to such officer’s knowledge:

(1)The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of NSP-Minnesota as of the dates and for the periods expressed in the Form 10-Q.

Date: 7/28/2022

/s/ ROBERT C. FRENZEL

Robert C. Frenzel

Chairman, Chief Executive Officer and Director

(Principal Executive Officer)

/s/ BRIAN J. VAN ABEL

Brian J. Van Abel

Executive Vice President, Chief Financial Officer and Director

(Duly Authorized Officer and Principal Financial Officer)

The foregoing certification is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of the Report or as a separate disclosure document.

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to NSP-Minnesota and will be retained by NSP-Minnesota and furnished to the SEC or its staff upon request.

1

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Cover Page - shares	6 Months Ended
	Jun. 30, 2022	Jul. 28, 2022
Cover [Abstract]
Entity Registrant Name	NORTHERN STATES POWER CO
Entity Central Index Key	0001123852
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q2
Amendment Flag	false
Document Period End Date	Jun. 30, 2022
Document Type	10-Q
Document Quarterly Report	true
Document Transition Report	false
Entity File Number	001-31387
Entity Incorporation, State or Country Code	MN
Entity Tax Identification Number	41-1967505
Entity Address, Address Line One	414 Nicollet Mall
Entity Address, City or Town	Minneapolis
Entity Address, State or Province	MN
Entity Address, Postal Zip Code	55401
City Area Code	(612)
Local Phone Number	330-5500
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		1,000,000

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CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating revenues
Electric, non-affiliates	$ 1,191	$ 1,095	$ 2,316	$ 2,119
Electric, affiliates	133	131	262	246
Natural gas	167	80	601	284
Other	11	9	21	18
Total operating revenues	1,502	1,315	3,200	2,667
Operating expenses
Electric fuel and purchased power	578	487	1,107	920
Cost of natural gas sold and transported	109	32	445	157
Cost of sales — other	7	6	12	11
O&M expenses	304	313	610	611
Conservation program expenses	41	31	90	65
Depreciation and amortization	251	229	503	450
Taxes (other than income taxes)	68	66	141	135
Total operating expenses	1,358	1,164	2,908	2,349
Operating income	144	151	292	318
Other (expense) income, net	(5)	2	(5)	4
Allowance for funds used during construction — equity	6	7	12	14
Interest charges and financing costs
Interest charges — includes other financing costs of $2, $2, $4 and $4, respectively	72	70	141	133
Allowance for funds used during construction — debt	(3)	(3)	(5)	(6)
Total interest charges and financing costs	69	67	136	127
Income before income taxes	76	93	163	209
Income tax benefit	(42)	(19)	(82)	(32)
Net income	$ 118	$ 112	$ 245	$ 241

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CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Income Statement [Abstract]
Other financing costs	$ 2	$ 2	$ 4	$ 4

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Comprehensive income:
Net income	$ 118	$ 112	$ 245	$ 241
Derivative instruments:
Reclassification of losses to net income, net of tax of $—, $—, $— and $—, respectively	0	0	0	(1)
Total other comprehensive income	0	0	0	1
Total comprehensive income	$ 118	$ 112	$ 245	$ 242

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Statement of Comprehensive Income [Abstract]
Reclassification of losses on derivatives to net income, tax	$ 0	$ 0	$ 0	$ 0

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CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Operating activities
Net income	$ 245	$ 241
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	507	453
Nuclear fuel amortization	61	56
Deferred income taxes	(144)	(30)
Allowance for equity funds used during construction	(12)	(14)
Provision for bad debts	9	12
Changes in operating assets and liabilities:
Accounts receivable	(16)	(62)
Accrued unbilled revenues	13	(22)
Inventories	(28)	16
Other current assets	1	10
Accounts payable	50	5
Net regulatory assets and liabilities	258	(105)
Other current liabilities	12	(45)
Pension and other employee benefit obligations	(7)	(35)
Other, net	20	(24)
Net cash provided by operating activities	969	456
Investing activities
Capital/construction expenditures	(752)	(842)
Purchase of investment securities	(787)	(628)
Proceeds from the sale of investment securities	769	410
Investments in utility money pool arrangement	(856)	(189)
Repayments from utility money pool arrangement	855	93
Other, net	2	(3)
Net cash used in investing activities	(769)	(1,159)
Financing activities
Repayments of short-term borrowings, net	0	(179)
Borrowings under utility money pool arrangement	0	434
Repayments under utility money pool arrangement	0	(434)
Proceeds from issuance of long-term debt	489	836
Repayment of long-term debt	(300)	0
Capital contributions (to) from parent	(7)	624
Dividends paid to parent	(263)	(216)
Other, net	0	2
Net cash (used in) provided by financing activities	(81)	1,067
Net change in cash, cash equivalents and restricted cash	119	364
Cash, cash equivalents and restricted cash at beginning of period	73	46
Cash, cash equivalents and restricted cash at end of period	192	410
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	(129)	(116)
Cash (paid) received for income taxes, net	(25)	4
Other Noncash Investing and Financing Items [Abstract]
Accrued property, plant and equipment additions	148	305
Inventory transfers to property, plant and equipment	9	6
Allowance for equity funds used during construction	$ 12	$ 14

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CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current assets
Cash, cash equivalents and restricted cash at beginning of period	$ 192	$ 73
Accounts receivable, net	457	429
Accounts receivable from affiliates	27	29
Investments in money pool arrangements	92	91
Accrued unbilled revenues	306	319
Inventories	328	309
Regulatory assets	505	527
Derivative instruments	204	53
Prepayments and other	46	46
Total current assets	2,157	1,876
Property, plant and equipment, net	16,751	16,430
Other assets
Nuclear decommissioning fund and other investments	2,905	3,308
Regulatory assets	883	718
Derivative instruments	73	33
Operating lease right-of-use assets	366	408
Other	37	36
Total other assets	4,264	4,503
Total assets	23,172	22,809
Current liabilities
Current portion of long-term debt	400	300
Accounts payable	577	522
Accounts payable to affiliates	85	63
Regulatory liabilities	277	117
Taxes accrued	251	260
Accrued interest	80	78
Dividends payable to parent	114	96
Derivative instruments	99	35
Operating lease liabilities	96	90
Other	216	166
Total current liabilities	2,195	1,727
Deferred credits and other liabilities
Deferred income taxes	1,713	1,949
Deferred investment tax credits	16	17
Regulatory liabilities	1,955	1,927
Asset retirement obligations	2,668	2,585
Derivative instruments	103	71
Pension and employee benefit obligations	105	112
Operating lease liabilities	303	353
Other	26	48
Total deferred credits and other liabilities	6,889	7,062
Capitalization
Long-term debt	6,540	6,447
Common stock — 5,000,000 shares authorized of $0.01 par value; 1,000,000 shares outstanding at June 30, 2022 and Dec. 31, 2021, respectively	$ 0	$ 0
Common Stock, Shares Authorized	5,000,000	5,000,000
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Common Stock, Shares, Outstanding	1,000,000	1,000,000
Additional paid in capital	$ 5,213	$ 5,202
Retained earnings	2,355	2,391
Accumulated other comprehensive loss	(20)	(20)
Total common stockholder's equity	7,548	7,573
Total liabilities and equity	$ 23,172	$ 22,809

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CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDERS' EQUITY (UNAUDITED) - USD ($) $ in Millions	Total	Common Stock	Additional Paid In Capital	Retained Earnings	Accumulated Other Comprehensive Loss
Balance (in shares) at Dec. 31, 2020		1,000,000
Beginning balance at Dec. 31, 2020	$ 6,769	$ 0	$ 4,585	$ 2,206	$ (22)
Increase (Decrease) in Stockholders' Equity
Net income	241			241
Other comprehensive income	1				1
Dividends declared on common stock	(216)			(216)
Contribution of capital by parent	600		600
Balance (in shares) at Jun. 30, 2021		1,000,000
Ending balance at Jun. 30, 2021	7,395	$ 0	5,185	2,231	(21)
Balance (in shares) at Mar. 31, 2021		1,000,000
Beginning balance at Mar. 31, 2021	7,190	$ 0	4,985	2,226	(21)
Increase (Decrease) in Stockholders' Equity
Net income	112			112
Other comprehensive income	0
Dividends declared on common stock	(107)			(107)
Contribution of capital by parent	200		200
Balance (in shares) at Jun. 30, 2021		1,000,000
Ending balance at Jun. 30, 2021	$ 7,395	$ 0	5,185	2,231	(21)
Balance (in shares) at Dec. 31, 2021	1,000,000	1,000,000
Beginning balance at Dec. 31, 2021	$ 7,573	$ 0	5,202	2,391	(20)
Increase (Decrease) in Stockholders' Equity
Net income	245			245
Other comprehensive income	0
Dividends declared on common stock	(281)			(281)
Contribution of capital by parent	$ 11		11
Balance (in shares) at Jun. 30, 2022	1,000,000	1,000,000
Ending balance at Jun. 30, 2022	$ 7,548	$ 0	5,213	2,355	(20)
Balance (in shares) at Mar. 31, 2022		1,000,000
Beginning balance at Mar. 31, 2022	7,533	$ 0	5,202	2,351	(20)
Increase (Decrease) in Stockholders' Equity
Net income	118			118
Other comprehensive income	0
Dividends declared on common stock	(114)			(114)
Contribution of capital by parent	$ 11		11
Balance (in shares) at Jun. 30, 2022	1,000,000	1,000,000
Ending balance at Jun. 30, 2022	$ 7,548	$ 0	$ 5,213	$ 2,355	$ (20)

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Management's Opinion

6 Months Ended

Jun. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Management's Opinion

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 June 30, 2022 and Dec. 31, 2021; the results of NSP-Minnesota’s operations, including the components of net income and comprehensive income, and changes in stockholder’s equity for the six months ended June 30, 2022 and 2021; and NSP-Minnesota’s cash flows for the six months ended June 30, 2022 and 2021.

All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after June 30, 2022 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, 2021 balance sheet information has been derived from the audited 2021 consolidated financial statements included in the NSP-Minnesota Annual Report on Form 10-K for the year ended Dec. 31, 2021.

Notes to the consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with GAAP on an annual basis have been condensed or omitted pursuant to such rules and regulations. For further information, refer to the consolidated financial statements and notes thereto included in the NSP-Minnesota Annual Report on Form 10-K for the year ended Dec. 31, 2021, filed with the SEC on Feb. 23, 2022. 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.

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Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2022
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	The significant accounting policies set forth in Note 1 to the consolidated financial statements in the NSP-Minnesota Annual Report on Form 10-K for the year ended Dec. 31, 2021 appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

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Accounting Pronouncements	6 Months Ended
	Jun. 30, 2022
Accounting Standards Update and Change in Accounting Principle [Abstract]
Accounting Pronouncements	As of June 30, 2022, there was no material impact from the recent adoption of new accounting pronouncements, nor expected material impact from recently issued accounting pronouncements yet to be adopted, on NSP-Minnesota’s financial statements.

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Selected Balance Sheet Data

6 Months Ended

Jun. 30, 2022

Balance Sheet Related Disclosures [Abstract]

Selected Balance Sheet Data

(Millions of Dollars)	June 30, 2022		Dec. 31, 2021
Accounts receivable, net
Accounts receivable	$	502	$	474
Less allowance for bad debts	(45)		(45)
Accounts receivable, net	$	457	$	429

(Millions of Dollars)	June 30, 2022		Dec. 31, 2021
Inventories
Materials and supplies	$	190	$	181
Fuel	106		81
Natural gas	32		47
Total inventories	$	328	$	309

(Millions of Dollars)	June 30, 2022		Dec. 31, 2021
Property, plant and equipment, net
Electric plant	$	19,826	$	19,154
Natural gas plant	1,940		1,864
Common and other property	1,083		1,007
Plant to be retired (a)	682		719
Construction work in progress	896		984
Total property, plant and equipment	24,427		23,728
Less accumulated depreciation	(7,938)		(7,606)
Nuclear fuel	3,096		3,081
Less accumulated amortization	(2,834)		(2,773)
Property, plant and equipment, net	$	16,751	$	16,430

(a)Amounts include regulator-approved retirements of Sherco Units 1, 2 and 3 and A.S. King and are reported net of accumulated depreciation.

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Borrowings and Other Financing Instruments

6 Months Ended

Jun. 30, 2022

Debt Disclosure [Abstract]

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.

Money pool borrowings for NSP-Minnesota:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2022		Year Ended Dec. 31, 2021
Borrowing limit	$	250	$	250
Amount outstanding at period end	—		—
Average amount outstanding	—		6
Maximum amount outstanding	—		236
Weighted average interest rate, computed on a daily basis	N/A		0.07		%
Weighted average interest rate at period end	N/A		N/A

Commercial Paper — Commercial paper outstanding for NSP-Minnesota:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2022		Year Ended Dec. 31, 2021
Borrowing limit	$	500	$	500
Amount outstanding at period end	—		—
Average amount outstanding	—		26
Maximum amount outstanding	—		317
Weighted average interest rate, computed on a daily basis	N/A		0.18		%
Weighted average interest rate at period end	N/A		N/A

Letters of Credit — NSP-Minnesota uses letters of credit, generally with terms of one year, to provide financial guarantees for certain obligations. There were $11 million and $9 million of letters of credit outstanding under the credit facility at June 30, 2022 and Dec. 31, 2021, 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 in place at least equal to the amount of its 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 June 30, 2022, NSP-Minnesota had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)		Drawn (b)		Available
$	500	$	11	$	489

(a)Expires in June 2024.

(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 June 30, 2022 and Dec. 31, 2021.

Bilateral Credit Agreement — In April 2022, 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 June 30, 2022, NSP-Minnesota had $43 million of outstanding letters of credit under the $75 million bilateral credit agreement.

Long-Term Borrowings

During the three months ended June 30, 2022, NSP-Minnesota issued $500 million of 4.50% first mortgage bonds due June 1, 2052.

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Revenues

6 Months Ended

Jun. 30, 2022

Revenue from Contract with Customer [Abstract]

Revenues

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

	Three Months Ended June 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	338	$	76	$	3	$	417
C&I	588		76		—		664
Other	10		—		8		18
Total retail	936		152		11		1,099
Wholesale	138		—		—		138
Transmission	63		—		—		63
Interchange	133		—		—		133
Other	(5)		3		—		(2)
Total revenue from contracts with customers	1,265		155		11		1,431
Alternative revenue and other	59		12		—		71
Total revenues	$	1,324	$	167	$	11	$	1,502

	Three Months Ended June 30, 2021
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	334	$	38	$	7	$	379
C&I	547		29		—		576
Other	8		—		2		10
Total retail	889		67		9		965
Wholesale	69		—		—		69
Transmission	58		—		—		58
Interchange	131		—		—		131
Other	3		4		—		7
Total revenue from contracts with customers	1,150		71		9		1,230
Alternative revenue and other	76		9		—		85
Total revenues	$	1,226	$	80	$	9	$	1,315

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Income Taxes

6 Months Ended

Jun. 30, 2022

Income Tax Disclosure [Abstract]

Income Taxes

6. Income Taxes

Reconciliation between the statutory rate and ETR:

	Six Months Ended June 30
	2022		2021
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	7.0		7.0
Increases (decreases) in tax from:
Wind PTCs (a)	(71.7)		(34.8)
Plant regulatory differences (b)	(6.2)		(8.0)
Other tax credits, net operating loss & tax credit allowances	(1.5)		(1.3)
Other (net)	1.1		0.8
Effective income tax rate	(50.3)	%	(15.3)	%

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

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

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Fair Value of Financial Assets and Liabilities

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

Fair Value of Financial Assets and Liabilities

Fair Value Measurements

Accounting guidance for fair value measurements and disclosures provides a single definition of fair value and requires disclosures about assets and liabilities measured at fair value. A hierarchical framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value is established by this guidance.

•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 highly liquid and actively traded instruments with quoted prices.

•Level 2 — Pricing inputs are other than quoted 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 are those valued with models requiring significant management judgment or estimation.

Specific valuation methods include:

Cash equivalents — The fair values of cash equivalents are generally based on cost plus accrued interest; money market funds are measured using quoted NAV.

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 fund investments 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’ investments 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 — The 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 contractual settlements relate to inactive delivery locations or extend to periods beyond those readily observable on active exchanges or quoted by brokers, 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 a 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 estimated 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.

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.

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 regulatory asset.

Unrealized gains for the nuclear decommissioning fund were $1.0 billion and $1.3 billion as of June 30, 2022 and Dec. 31, 2021, respectively, and unrealized losses were $76 million and $7 million as of June 30, 2022 and Dec. 31, 2021, respectively.

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

	June 30, 2022
			Fair Value
(Millions of Dollars)	Cost		Level 1		Level 2		Level 3		NAV		Total
Nuclear decommissioning fund (a)
Cash equivalents	$	53	$	53	$	—	$	—	$	—	$	53
Commingled funds	835		—		—		—		1,209		1,209
Debt securities	668		—		615		6		—		621
Equity securities	407		971		1		—		—		972
Total	$	1,963	$	1,024	$	616	$	6	$	1,209	$	2,855

(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $50 million of other investments, including the rabbi trust.

	Dec. 31, 2021
			Fair Value
(Millions of Dollars)	Cost		Level 1		Level 2		Level 3		NAV		Total
Nuclear decommissioning fund (a)
Cash equivalents	$	64	$	64	$	—	$	—	$	—	$	64
Commingled funds	856		—		—		—		1,294		1,294
Debt securities	631		—		666		9		—		675
Equity securities	411		1,222		1		—		—		1,223
Total	$	1,962	$	1,286	$	667	$	9	$	1,294	$	3,256

(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $52 million of other investments, including the rabbi trust.

For the three and six months ended June 30, 2022 and 2021, there were immaterial Level 3 nuclear decommissioning fund investments or transfer of amounts between levels.

Contractual maturity dates of debt securities in the nuclear decommissioning fund as of June 30, 2022:

	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	$	3	$	190	$	232	$	196	$	621

Derivative Instruments 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, utility commodity prices and vehicle fuel prices.

Interest Rate Derivatives — NSP-Minnesota enters into various instruments that effectively fix the yield or price on a specified benchmark interest rate for an anticipated debt issuance for a specific period. These derivative instruments are generally designated as cash flow hedges for accounting purposes, with changes in fair value prior to settlement recorded as other comprehensive income.

At June 30, 2022, accumulated other comprehensive loss related to interest rate derivatives included $1 million of net losses expected to be reclassified into earnings during the next 12 months as the hedged interest rate transactions impact earnings. As of June 30, 2022, NSP-Minnesota had no unsettled interest rate derivatives.

Wholesale and Commodity Trading Risk — 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. Sharing of any 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, as well as for trading purposes. This could include the purchase or sale of energy or energy-related products, natural gas to generate electric energy, natural gas for resale, FTRs, vehicle fuel, and weather derivatives.

At June 30, 2022, NSP-Minnesota had no commodity contracts designated as cash flow hedges. NSP-Minnesota may enter into derivative instruments that mitigate commodity price risk on behalf of electric and natural gas customers, but may not be designated as qualifying hedging transactions. The classification of gains or losses for these instruments as a regulatory asset or liability, if applicable, is based on approved regulatory recovery mechanisms.

NSP-Minnesota also enters into commodity derivative instruments for trading purposes not directly related to commodity price risks associated with serving its electric and natural gas customers. Changes in the fair value of these commodity derivatives are recorded in electric operating revenues, net of amounts credited to customers under margin-sharing mechanisms.

Gross notional amounts of commodity forwards, options and FTRs:

(Amounts in Millions) (a)(b)	June 30, 2022	Dec. 31, 2021
Megawatt hours of electricity	76	57
Million British thermal units of natural gas	106	85

(a)Amounts are not reflective of net positions in the underlying commodities.

(b)Notional amounts for options are included on a gross basis, but are 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 June 30, 2022, eight of NSP-Minnesota’s ten most significant counterparties for these activities, comprising $33 million, or 31%, of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings. One of the ten most significant counterparties, comprising $24 million, or 23%, 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. One of these significant counterparties, comprising $47 million or 45% of this credit exposure, had credit quality less than investment grade, based on internal analysis. Four of these significant counterparties are municipal or cooperative electric entities, RTOs or other utilities.

Impact of Derivative Activity —

	Pre-Tax Fair Value Gains (Losses) Recognized During the Period in:
(Millions of Dollars)	Regulatory (Assets) and Liabilities
Three Months Ended June 30, 2022
Other derivative instruments
Electric commodity	$	7
Natural gas commodity	$	(1)
Total	$	6
Six Months Ended June 30, 2022
Other derivative instruments
Electric commodity	$	6
Natural gas commodity	2
Total	$	8

Three Months Ended June 30, 2021
Other derivative instruments
Electric commodity	$	3
Natural gas commodity	$	1
Total	$	4
Six Months Ended June 30, 2021
Other derivative instruments
Electric commodity	$	3
Natural gas commodity	2
Total	$	5

	Pre-Tax (Gains) 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 June 30, 2022
Other derivative instruments
Commodity trading	$	—	$	—		$	5	(b)
Electric commodity	—		(1)		(c)	—
Total	$	—	$	(1)		$	5
Six Months Ended June 30, 2022
Other derivative instruments
Commodity trading	$	—	$	—		$	6	(b)
Electric commodity	—		(3)		(c)	—
Natural gas commodity	—		2		(d)	(5)		(d)(e)
Total	$	—	$	(1)		$	1

	Pre-Tax (Gains) 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 June 30, 2021
Other derivative instruments
Commodity trading	$	—		$	—		$	2	(b)
Electric commodity	—			(1)		(c)	—
Total	$	—		$	(1)		$	2
Six Months Ended June 30, 2021
Derivatives designated as cash flow hedges
Interest rate	$	1	(a)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	33	(b)
Electric commodity	—			(12)		(c)	—
Natural gas commodity	—			1		(d)	(3)		(d)(e)
Total	$	—		$	(11)		$	30

(a)Recorded to interest charges.

(b)Recorded to electric operating revenues. Portions of these gains and losses are subject to sharing with electric customers through margin-sharing mechanisms and deducted from gross revenue, as appropriate.

(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. All 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 three and six months ended June 30, 2022 and 2021.

Credit Related Contingent Features — Contract provisions for derivative instruments that NSP-Minnesota enters into, including those accounted for as normal purchase-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 NSP-Minnesota’s credit ratings are downgraded below its investment grade credit rating by any of the major credit rating agencies.

As of June 30, 2022 and Dec. 31, 2021, there were $11 million and $3 million, respectively, of derivative liabilities with such underlying contract provisions. 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 the other financing arrangements related to payment terms or other covenants. As of June 30, 2022 and Dec. 31, 2021, there were approximately $110 million and $48 million, respectively, of derivative liabilities with such underlying contract provisions.

Certain derivative instruments are also subject to contract provisions that contain adequate assurance clauses. These provisions allow counterparties to seek performance assurance, including cash collateral, in the event that NSP-Minnesota’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 June 30, 2022 and Dec. 31, 2021.

Recurring Fair Value Measurements — NSP-Minnesota’s derivative assets and liabilities measured at fair value on a recurring basis were as follows:

	June 30, 2022												Dec. 31, 2021
	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	$	32	$	128	$	61	$	221	$	(160)	$	61	$	9	$	40	$	22	$	71	$	(53)	$	18
Electric commodity (b)	—		—		144		144		(3)		141		—		—		30		30		(1)		29
Natural gas commodity	—		—		—		—		—		—		—		6		—		6		—		6
Total current derivative assets	$	32	$	128	$	205	$	365	$	(163)	202		$	9	$	46	$	52	$	107	$	(54)	53
PPAs (c)											2												—
Current derivative instruments											$	204											$	53
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	26	$	49	$	79	$	154	$	(81)	$	73	$	6	$	34	$	35	$	75	$	(42)	$	33
Total noncurrent derivative assets	$	26	$	49	$	79	$	154	$	(81)	$	73	$	6	$	34	$	35	$	75	$	(42)	$	33

	June 30, 2022												Dec. 31, 2021
	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
Other derivative instruments:
Commodity trading	$	35	$	172	$	11	$	218	$	(134)	$	84	$	13	$	58	$	4	$	75	$	(58)	$	17
Electric commodity	—		—		3		3		(3)		—		—		—		1		1		(1)		—
Natural gas commodity	—		1		—		1		—		1		—		4		—		4		—		4
Total current derivative liabilities	$	35	$	173	$	14	$	222	$	(137)	85		$	13	$	62	$	5	$	80	$	(59)	21
PPAs (c)											14												14
Current derivative instruments											$	99											$	35
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	47	$	77	$	40	$	164	$	(93)	$	71	$	15	$	48	$	26	$	89	$	(53)	$	36
Total noncurrent derivative liabilities	$	47	$	77	$	40	$	164	$	(93)	71		$	15	$	48	$	26	$	89	$	(53)	36
PPAs (c)											32												35
Noncurrent derivative instruments											$	103											$	71

(a)NSP-Minnesota nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at June 30, 2022 and Dec. 31, 2021. At both June 30, 2022 and Dec. 31, 2021, derivative assets and liabilities include no obligations to return cash collateral. At June 30, 2022 and Dec. 31, 2021 derivative assets and liabilities include rights to reclaim cash collateral of $12 million and $16 million, respectively. The counterparty netting excludes settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.

(b)Amounts relate to FTR instruments administered by MISO (annual auctions occurring in the second quarter). These instruments are utilized/intended to offset the impacts of transmission system congestion. Higher congestion costs have led to an increase in the fair value of FTRs. Due to regulatory recovery, changes in fair value are deferred as a regulatory asset or liability and do not have a material impact on net income.

(c)During 2006, Xcel Energy qualified these contracts under the normal purchase exception. Based on this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities.

Changes in Level 3 commodity derivatives for the three and six months ended June 30, 2022 and 2021:

	Three Months Ended June 30
(Millions of Dollars)	2022		2021
Balance at April 1	$	76	$	12
Purchases/Issuances (a)	158		54
Settlements (a)	(73)		(19)
Net transactions recorded during the period:
Gains recognized in earnings (b)	41		33
Net gains recognized as regulatory assets and liabilities (a)	28		12
Balance at June 30	$	230	$	92
	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Balance at Jan. 1	$	56	$	(11)
Purchases/Issuances (a)	157		54
Settlements (a)	(92)		(26)
Net transactions recorded during the period:
Gains recognized in earnings (b)	91		63
Net gains recognized as regulatory assets and liabilities (a)	18		12
Balance at June 30	$	230	$	92

(a)Relates primarily to FTR instruments administered by MISO (annual auctions occurring in the second quarter). These instruments are utilized/intended to offset the impacts of transmission system congestion. Higher congestion costs have led to an increase in the fair value of FTRs. Due to regulatory recovery, changes in fair value are deferred as a regulatory asset or liability and do not have a material impact on net income.

(b)Relates to commodity trading and is subject to offsetting losses of derivative instruments categorized as levels 1 and 2 in the consolidated income statement.

NSP-Minnesota recognizes transfers between levels as of the beginning of each period. There were no transfers of amounts between levels for derivative instruments for the six months ended June 30, 2022 and 2021.

Fair Value of Long-Term Debt

Other financial instruments for which the carrying amount did not equal fair value:

	June 30, 2022				Dec. 31, 2021
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	6,940	$	6,984	$	6,747	$	7,761

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 June 30, 2022 and Dec. 31, 2021 and given the observability of the inputs, fair values presented for long-term debt were assigned as Level 2.

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Benefit Plans and Other Postretirement Benefits

6 Months Ended

Jun. 30, 2022

Retirement Benefits [Abstract]

Benefit Plans and Other Postretirement Benefits

Components of Net Periodic Benefit Cost

	Three Months Ended June 30
	2022		2021		2022		2021
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	7	$	8	$	—	$	—
Interest cost (a)	6		6		—		—
Expected return on plan assets (a)	(12)		(13)		—		—
Amortization of prior service credit (a)	—		—		—		(1)
Amortization of net loss (a)	6		8		—		1
Net periodic benefit cost	7		9		—		—
Effects of regulation	—		(1)		—		—
Net benefit cost recognized for financial reporting	$	7	$	8	$	—	$	—
	Six Months Ended June 30
	2022		2021		2022		2021
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	14	$	15	$	—	$	—
Interest cost (a)	12		12		1		1
Expected return on plan assets (a)	(24)		(26)		—		—
Amortization of prior service credit (a)	—		—		(1)		(2)
Amortization of net loss (a)	12		17		—		1
Settlement charge (b)	(1)		—		—		—
Net periodic benefit cost	13		18		—		—
Effects of regulation	1		(2)		—		—
Net benefit cost recognized for financial reporting	$	14	$	16	$	—	$	—

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

(b)     In the first quarter of 2022, NSP-Minnesota recognized $1 million in settlement charge true-ups related to fourth quarter 2021.

In January 2022, contributions of $50 million were made across four of Xcel Energy’s pension plans, of which $5 million was attributable to NSP-Minnesota. Xcel Energy does not expect additional pension contributions during 2022.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2022

Commitments and Contingencies Disclosure [Abstract]

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.

Minnesota Winter Storm Uri Costs — NSP-Minnesota is participating in a contested case regarding the prudency of incremental natural gas costs incurred during Winter Storm Uri. Other parties to the case have recommended significant cost disallowances, and while ultimate resolution of the matter is uncertain, it is reasonably possible that the MPUC could disallow certain deferred costs, resulting in earnings losses.

NSP-Minnesota filed rebuttal testimony in January 2022 detailing its position that the disallowances recommended by other parties lack any merit in the prudency review given the pertinent facts regarding NSP-Minnesota’s actions before, during and after the storm event.

In March 2022, following February 2022 ALJ hearings, the OAG recommended a disallowance of up to $148 million, the largest recommendation among the intervenor positions. In May 2022, the ALJs found that the natural gas costs for Winter Storm Uri were prudently incurred and recommended no disallowances. A MPUC decision is expected in August 2022.

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

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

In April 2020, the Minnesota Supreme Court denied the insurers’ petition for further review, ending the litigation.

In January 2021, the OAG and DOC recommended that NSP-Minnesota refund approximately $17 million of replacement power costs previously recovered through the fuel clause adjustment. NSP-Minnesota subsequently filed its response, asserting 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. A final decision by the MPUC is expected in mid-2023. A loss related to this matter is deemed remote.

Westmoreland Arbitration — In November 2014, insurers of the Westmoreland Coal Company filed an arbitration demand against NSP-Minnesota, SMMPA and Western Fuels Association, seeking recovery of alleged business losses due to a turbine failure at Sherco Unit 3, which currently include $19 million in damages, plus prejudgment interest. The Westmoreland insurers claim NSP-Minnesota’s invocation of the force majeure clause to stop the supply of coal was improper because the incident was allegedly caused by NSP-Minnesota’s failure to conform to industry maintenance standards.

NSP-Minnesota denies the claims asserted by the Westmoreland insurers and believes it properly stopped the supply of coal based upon the force majeure provision. In the second quarter of 2022, this matter settled for $2 million.

MISO ROE Complaints — In November 2013 and February 2015, customer groups filed two ROE complaints against MISO TOs, which includes NSP-Minnesota and NSP-Wisconsin. The first complaint requested a reduction in base ROE transmission formula rates from 12.38% to 9.15% for the time period of Nov. 12, 2013 to Feb. 11, 2015, and removal of ROE adders (including those for RTO membership). The second complaint requested, for a subsequent time period, a base ROE reduction from 12.38% to 8.67%.

The FERC has subsequently issued various related orders (including Opinion Nos. 569, 569A and 569B) related to ROE methodology/calculations and timing. NSP-Minnesota has recognized a liability for its best estimate of final refunds to customers for applicable complaint periods.

The MISO TOs and various other parties have filed petitions for review of the FERC’s most recent applicable opinions at the D.C. Circuit. A decision is expected by the end of the third quarter of 2022.

Environmental

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 its best estimate of costs/liabilities from final resolution of these issues, however, the outcome and timing are unknown. In addition, there may be insurance recovery and/or recovery from other potentially responsible parties, offsetting a portion of costs incurred.

Environmental Requirements — Water and Waste

Coal Ash Regulation — NSP-Minnesota’s operations are subject to federal and state regulations that impose requirements for handling, storage, treatment and disposal of solid waste. Under the CCR Rule, utilities are required to complete groundwater sampling around their CCR landfills and surface impoundments. Currently, NSP-Minnesota has three regulated ash units in operation.

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

In August 2020, the EPA published its final rule to implement closure by April 2021 for CCR impoundments. This final rule required Xcel Energy to expedite closure plans for one impoundment.

In October 2020, NSP-Minnesota completed construction and placed in service a new impoundment to replace the clay lined impoundment. With the new ash pond in service, NSP-Minnesota has initiated closure activities for the existing ash pond at an estimated cost of $4 million. NSP-Minnesota has five years to complete closure activities.

Closure costs for existing impoundments are included in the calculation of the asset retirement obligation.

Federal Clean Water Act Section 316(b) — The federal Clean Water Act requires the EPA to regulate cooling water intake structures to assure that these structures reflect the best technology available for minimizing impingement and entrainment of aquatic species. NSP-Minnesota estimates capital expenditures of approximately $36 million to comply with impingement and entrainment requirements. NSP-Minnesota believes six plants could be required to make improvements to reduce impingement and entrainment. NSP-Minnesota anticipates these costs will be recoverable through regulatory mechanisms.

Leases

NSP-Minnesota evaluates contracts that may contain leases, including PPAs and arrangements for the use of office space 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 June 30
(Millions of Dollars)	2022		2021
Operating leases
PPA capacity payments	$	24	$	17
Other operating leases (a)	2		3
Total operating lease expense (b)	$	26	$	20

(a)Includes short-term lease expense of $1 million for 2022 and 2021, 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.

	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Operating leases
PPA capacity payments	$	49	$	36
Other operating leases (a)	4		5
Total operating lease expense (b)	$	53	$	41

(a)Includes short-term lease expense of $1 million for 2022 and 2021, 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 June 30, 2022:

(Millions of Dollars)	PPA Operating Leases		Other Operating Leases		Total Operating Leases
Total minimum obligation	$	366	$	69	$	435
Interest component of obligation	(25)		(11)		(36)
Present value of minimum obligation	$	341	$	58	399
Less current portion					(96)
Noncurrent operating lease liabilities					$	303

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 they purchase. These specific PPAs create a variable interest in the IPP.

NSP-Minnesota had approximately 1,322 MW and 1,347 MW of capacity under long-term PPAs at June 30, 2022 and Dec. 31, 2021, respectively, with entities that have been determined to be variable interest entities. NSP-Minnesota concluded that these entities are not required to be consolidated in its financial statements because it does not have the power to direct the activities that most significantly impact the entities’ economic performance. The PPAs have expiration dates through 2039.

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Other Comprehensive Income (Loss)

6 Months Ended

Jun. 30, 2022

Stockholders' Equity Note [Abstract]

Other Comprehensive Income (Loss)

Changes in accumulated other comprehensive income (loss), net of tax, for the three and six months ended June 30, 2022 and 2021:

	Three Months Ended June 30, 2022						Three Months Ended June 30, 2021
(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 April 1	$	(17)	$	(3)	$	(20)	$	(18)	$	(3)	$	(21)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (a)	—		—		—		—		—		—
Accumulated other comprehensive loss at June 30	$	(17)	$	(3)	$	(20)	$	(18)	$	(3)	$	(21)

	Six Months Ended June 30, 2022						Six Months Ended June 30, 2021
(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	$	(17)	$	(3)	$	(20)	$	(19)	$	(3)	$	(22)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (a)	—		—		—		1		—		1
Accumulated other comprehensive loss at June 30	$	(17)	$	(3)	$	(20)	$	(18)	$	(3)	$	(21)

(a)Included in interest charges.

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Segment Information

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

Segment Information

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

NSP-Minnesota has the following reportable segments:

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

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

NSP-Minnesota also presents All Other, which includes operating segments with revenues below the necessary quantitative thresholds. Those operating segments primarily include appliance repair services, 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 June 30
(Millions of Dollars)	2022		2021
Regulated Electric
Operating revenues (a)	$	1,324	$	1,226
Intersegment revenue	—		1
Total revenues	$	1,324	$	1,227
Net income	113		112
Regulated Natural Gas
Operating revenues (b)	$	167	$	80
Intersegment revenue	1		—
Total revenues	$	168	$	80
Net income (loss)	4		(1)
All Other
Total revenues	$	11	$	9
Net income	1		1
Consolidated Total
Operating revenues (a)(b)	$	1,503	$	1,316
Reconciling eliminations	(1)		(1)
Total revenues	$	1,502	$	1,315
Net income	118		112

(a)    Operating revenues include $133 million and $131 million of affiliate electric revenue for the three months ended June 30, 2022 and 2021.

(b)    Operating revenues include an immaterial amount of affiliate gas revenue for the three months ended June 30, 2022 and 2021.

	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Regulated Electric
Operating revenues (a)	$	2,578	$	2,365
Intersegment revenue	—		1
Total revenues	$	2,578	$	2,366
Net income	211		219
Regulated Natural Gas
Operating revenues (b)	$	601	$	284
Intersegment revenue	1		1
Total revenues	$	602	$	285
Net income	33		19
All Other
Total operating revenues	$	21	$	18
Net income	1		3
Consolidated Total
Operating revenues (a)(b)	$	3,201	$	2,669
Reconciling eliminations	(1)		(2)
Total operating revenues	$	3,200	$	2,667
Net income	245		241

(a)    Operating revenues include $262 million and $246 million of affiliate electric revenue for the six months ended June 30, 2022 and 2021.

(b)    Operating revenues include an immaterial amount of affiliate gas revenue for the six months ended June 30, 2022 and 2021.

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Selected Balance Sheet Data (Tables)

6 Months Ended

Jun. 30, 2022

Balance Sheet Related Disclosures [Abstract]

Accounts Receivable, Net

(Millions of Dollars)	June 30, 2022		Dec. 31, 2021
Accounts receivable, net
Accounts receivable	$	502	$	474
Less allowance for bad debts	(45)		(45)
Accounts receivable, net	$	457	$	429

Inventories

(Millions of Dollars)	June 30, 2022		Dec. 31, 2021
Inventories
Materials and supplies	$	190	$	181
Fuel	106		81
Natural gas	32		47
Total inventories	$	328	$	309

Property, plant and equipment, net

(Millions of Dollars)	June 30, 2022		Dec. 31, 2021
Property, plant and equipment, net
Electric plant	$	19,826	$	19,154
Natural gas plant	1,940		1,864
Common and other property	1,083		1,007
Plant to be retired (a)	682		719
Construction work in progress	896		984
Total property, plant and equipment	24,427		23,728
Less accumulated depreciation	(7,938)		(7,606)
Nuclear fuel	3,096		3,081
Less accumulated amortization	(2,834)		(2,773)
Property, plant and equipment, net	$	16,751	$	16,430

(a)Amounts include regulator-approved retirements of Sherco Units 1, 2 and 3 and A.S. King and are reported net of accumulated depreciation.

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Borrowings and Other Financing Instruments (Tables)

6 Months Ended

Jun. 30, 2022

Borrowings and Other Financing Instruments [Abstract]

Credit Facilities

At June 30, 2022, NSP-Minnesota had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)		Drawn (b)		Available
$	500	$	11	$	489

(a)Expires in June 2024.

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

Money Pool

Borrowings and Other Financing Instruments [Abstract]

Short-Term Borrowings

Money pool borrowings for NSP-Minnesota:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2022		Year Ended Dec. 31, 2021
Borrowing limit	$	250	$	250
Amount outstanding at period end	—		—
Average amount outstanding	—		6
Maximum amount outstanding	—		236
Weighted average interest rate, computed on a daily basis	N/A		0.07		%
Weighted average interest rate at period end	N/A		N/A

Commercial Paper

Borrowings and Other Financing Instruments [Abstract]

Short-Term Borrowings

Commercial paper outstanding for NSP-Minnesota:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2022		Year Ended Dec. 31, 2021
Borrowing limit	$	500	$	500
Amount outstanding at period end	—		—
Average amount outstanding	—		26
Maximum amount outstanding	—		317
Weighted average interest rate, computed on a daily basis	N/A		0.18		%
Weighted average interest rate at period end	N/A		N/A

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Revenues (Tables)

6 Months Ended

Jun. 30, 2022

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

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 June 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	338	$	76	$	3	$	417
C&I	588		76		—		664
Other	10		—		8		18
Total retail	936		152		11		1,099
Wholesale	138		—		—		138
Transmission	63		—		—		63
Interchange	133		—		—		133
Other	(5)		3		—		(2)
Total revenue from contracts with customers	1,265		155		11		1,431
Alternative revenue and other	59		12		—		71
Total revenues	$	1,324	$	167	$	11	$	1,502

	Three Months Ended June 30, 2021
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	334	$	38	$	7	$	379
C&I	547		29		—		576
Other	8		—		2		10
Total retail	889		67		9		965
Wholesale	69		—		—		69
Transmission	58		—		—		58
Interchange	131		—		—		131
Other	3		4		—		7
Total revenue from contracts with customers	1,150		71		9		1,230
Alternative revenue and other	76		9		—		85
Total revenues	$	1,226	$	80	$	9	$	1,315

	Six Months Ended June 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	675	$	311	$	9	$	995
C&I	1,102		256		—		1,358
Other	19		—		12		31
Total retail	1,796		567		21		2,384
Wholesale	263		—		—		263
Transmission	124		—		—		124
Interchange	262		—		—		262
Other	1		5		—		6
Total revenue from contracts with customers	2,446		572		21		3,039
Alternative revenue and other	132		29		—		161
Total revenues	$	2,578	$	601	$	21	$	3,200

	Six Months Ended June 30, 2021
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	660	$	152	$	14	$	826
C&I	964		108		—		1,072
Other	15		—		4		19
Total retail	1,639		260		18		1,917
Wholesale	167		—		—		167
Transmission	114		—		—		114
Interchange	246		—		—		246
Other	5		3		—		8
Total revenue from contracts with customers	2,171		263		18		2,452
Alternative revenue and other	194		21		—		215
Total revenues	$	2,365	$	284	$	18	$	2,667

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2022

Income Tax Disclosure [Abstract]

Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]

Reconciliation between the statutory rate and ETR:

	Six Months Ended June 30
	2022		2021
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	7.0		7.0
Increases (decreases) in tax from:
Wind PTCs (a)	(71.7)		(34.8)
Plant regulatory differences (b)	(6.2)		(8.0)
Other tax credits, net operating loss & tax credit allowances	(1.5)		(1.3)
Other (net)	1.1		0.8
Effective income tax rate	(50.3)	%	(15.3)	%

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

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

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Fair Value of Financial Assets and Liabilities (Tables)

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

Cost and Fair Value of Nuclear Decommissioning Fund Investments

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

	June 30, 2022
			Fair Value
(Millions of Dollars)	Cost		Level 1		Level 2		Level 3		NAV		Total
Nuclear decommissioning fund (a)
Cash equivalents	$	53	$	53	$	—	$	—	$	—	$	53
Commingled funds	835		—		—		—		1,209		1,209
Debt securities	668		—		615		6		—		621
Equity securities	407		971		1		—		—		972
Total	$	1,963	$	1,024	$	616	$	6	$	1,209	$	2,855

(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $50 million of other investments, including the rabbi trust.

	Dec. 31, 2021
			Fair Value
(Millions of Dollars)	Cost		Level 1		Level 2		Level 3		NAV		Total
Nuclear decommissioning fund (a)
Cash equivalents	$	64	$	64	$	—	$	—	$	—	$	64
Commingled funds	856		—		—		—		1,294		1,294
Debt securities	631		—		666		9		—		675
Equity securities	411		1,222		1		—		—		1,223
Total	$	1,962	$	1,286	$	667	$	9	$	1,294	$	3,256

(a)Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $52 million of other investments, including the rabbi trust.

Final Contractual Maturity Dates of Debt Securities in the Nuclear Decommissioning Fund by Asset Class

Contractual maturity dates of debt securities in the nuclear decommissioning fund as of June 30, 2022:

	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	$	3	$	190	$	232	$	196	$	621

Gross Notional Amounts of Commodity Forwards, Options, and FTRs

Gross notional amounts of commodity forwards, options and FTRs:

(Amounts in Millions) (a)(b)	June 30, 2022	Dec. 31, 2021
Megawatt hours of electricity	76	57
Million British thermal units of natural gas	106	85

(a)Amounts are not reflective of net positions in the underlying commodities.

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

Impact of Derivative Activity on Accumulated Other Comprehensive Loss, Regulatory Assets and Liabilities, and Income

Impact of Derivative Activity —

	Pre-Tax Fair Value Gains (Losses) Recognized During the Period in:
(Millions of Dollars)	Regulatory (Assets) and Liabilities
Three Months Ended June 30, 2022
Other derivative instruments
Electric commodity	$	7
Natural gas commodity	$	(1)
Total	$	6
Six Months Ended June 30, 2022
Other derivative instruments
Electric commodity	$	6
Natural gas commodity	2
Total	$	8

Three Months Ended June 30, 2021
Other derivative instruments
Electric commodity	$	3
Natural gas commodity	$	1
Total	$	4
Six Months Ended June 30, 2021
Other derivative instruments
Electric commodity	$	3
Natural gas commodity	2
Total	$	5

	Pre-Tax (Gains) 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 June 30, 2022
Other derivative instruments
Commodity trading	$	—	$	—		$	5	(b)
Electric commodity	—		(1)		(c)	—
Total	$	—	$	(1)		$	5
Six Months Ended June 30, 2022
Other derivative instruments
Commodity trading	$	—	$	—		$	6	(b)
Electric commodity	—		(3)		(c)	—
Natural gas commodity	—		2		(d)	(5)		(d)(e)
Total	$	—	$	(1)		$	1

	Pre-Tax (Gains) 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 June 30, 2021
Other derivative instruments
Commodity trading	$	—		$	—		$	2	(b)
Electric commodity	—			(1)		(c)	—
Total	$	—		$	(1)		$	2
Six Months Ended June 30, 2021
Derivatives designated as cash flow hedges
Interest rate	$	1	(a)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	33	(b)
Electric commodity	—			(12)		(c)	—
Natural gas commodity	—			1		(d)	(3)		(d)(e)
Total	$	—		$	(11)		$	30

(a)Recorded to interest charges.

(b)Recorded to electric operating revenues. Portions of these gains and losses are subject to sharing with electric customers through margin-sharing mechanisms and deducted from gross revenue, as appropriate.

(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. All 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.

Derivative Assets and Liabilities Measured at Fair Value on a Recurring Basis by Hierarchy Level

Recurring Fair Value Measurements — NSP-Minnesota’s derivative assets and liabilities measured at fair value on a recurring basis were as follows:

	June 30, 2022												Dec. 31, 2021
	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	$	32	$	128	$	61	$	221	$	(160)	$	61	$	9	$	40	$	22	$	71	$	(53)	$	18
Electric commodity (b)	—		—		144		144		(3)		141		—		—		30		30		(1)		29
Natural gas commodity	—		—		—		—		—		—		—		6		—		6		—		6
Total current derivative assets	$	32	$	128	$	205	$	365	$	(163)	202		$	9	$	46	$	52	$	107	$	(54)	53
PPAs (c)											2												—
Current derivative instruments											$	204											$	53
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	26	$	49	$	79	$	154	$	(81)	$	73	$	6	$	34	$	35	$	75	$	(42)	$	33
Total noncurrent derivative assets	$	26	$	49	$	79	$	154	$	(81)	$	73	$	6	$	34	$	35	$	75	$	(42)	$	33

	June 30, 2022												Dec. 31, 2021
	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
Other derivative instruments:
Commodity trading	$	35	$	172	$	11	$	218	$	(134)	$	84	$	13	$	58	$	4	$	75	$	(58)	$	17
Electric commodity	—		—		3		3		(3)		—		—		—		1		1		(1)		—
Natural gas commodity	—		1		—		1		—		1		—		4		—		4		—		4
Total current derivative liabilities	$	35	$	173	$	14	$	222	$	(137)	85		$	13	$	62	$	5	$	80	$	(59)	21
PPAs (c)											14												14
Current derivative instruments											$	99											$	35
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	47	$	77	$	40	$	164	$	(93)	$	71	$	15	$	48	$	26	$	89	$	(53)	$	36
Total noncurrent derivative liabilities	$	47	$	77	$	40	$	164	$	(93)	71		$	15	$	48	$	26	$	89	$	(53)	36
PPAs (c)											32												35
Noncurrent derivative instruments											$	103											$	71

(a)NSP-Minnesota nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at June 30, 2022 and Dec. 31, 2021. At both June 30, 2022 and Dec. 31, 2021, derivative assets and liabilities include no obligations to return cash collateral. At June 30, 2022 and Dec. 31, 2021 derivative assets and liabilities include rights to reclaim cash collateral of $12 million and $16 million, respectively. The counterparty netting excludes settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.

(b)Amounts relate to FTR instruments administered by MISO (annual auctions occurring in the second quarter). These instruments are utilized/intended to offset the impacts of transmission system congestion. Higher congestion costs have led to an increase in the fair value of FTRs. Due to regulatory recovery, changes in fair value are deferred as a regulatory asset or liability and do not have a material impact on net income.

(c)During 2006, Xcel Energy qualified these contracts under the normal purchase exception. Based on this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities.

Changes in Level 3 Commodity Derivatives

Changes in Level 3 commodity derivatives for the three and six months ended June 30, 2022 and 2021:

	Three Months Ended June 30
(Millions of Dollars)	2022		2021
Balance at April 1	$	76	$	12
Purchases/Issuances (a)	158		54
Settlements (a)	(73)		(19)
Net transactions recorded during the period:
Gains recognized in earnings (b)	41		33
Net gains recognized as regulatory assets and liabilities (a)	28		12
Balance at June 30	$	230	$	92
	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Balance at Jan. 1	$	56	$	(11)
Purchases/Issuances (a)	157		54
Settlements (a)	(92)		(26)
Net transactions recorded during the period:
Gains recognized in earnings (b)	91		63
Net gains recognized as regulatory assets and liabilities (a)	18		12
Balance at June 30	$	230	$	92

(a)Relates primarily to FTR instruments administered by MISO (annual auctions occurring in the second quarter). These instruments are utilized/intended to offset the impacts of transmission system congestion. Higher congestion costs have led to an increase in the fair value of FTRs. Due to regulatory recovery, changes in fair value are deferred as a regulatory asset or liability and do not have a material impact on net income.

(b)Relates to commodity trading and is subject to offsetting losses of derivative instruments categorized as levels 1 and 2 in the consolidated income statement.

Carrying Amount and Fair Value of Long-term Debt

Other financial instruments for which the carrying amount did not equal fair value:

	June 30, 2022				Dec. 31, 2021
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	6,940	$	6,984	$	6,747	$	7,761

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Benefit Plans and Other Postretirement Benefits (Tables)

6 Months Ended

Jun. 30, 2022

Retirement Benefits [Abstract]

Components of Net Periodic Benefit Cost (Credit)

Components of Net Periodic Benefit Cost

	Three Months Ended June 30
	2022		2021		2022		2021
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	7	$	8	$	—	$	—
Interest cost (a)	6		6		—		—
Expected return on plan assets (a)	(12)		(13)		—		—
Amortization of prior service credit (a)	—		—		—		(1)
Amortization of net loss (a)	6		8		—		1
Net periodic benefit cost	7		9		—		—
Effects of regulation	—		(1)		—		—
Net benefit cost recognized for financial reporting	$	7	$	8	$	—	$	—
	Six Months Ended June 30
	2022		2021		2022		2021
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	14	$	15	$	—	$	—
Interest cost (a)	12		12		1		1
Expected return on plan assets (a)	(24)		(26)		—		—
Amortization of prior service credit (a)	—		—		(1)		(2)
Amortization of net loss (a)	12		17		—		1
Settlement charge (b)	(1)		—		—		—
Net periodic benefit cost	13		18		—		—
Effects of regulation	1		(2)		—		—
Net benefit cost recognized for financial reporting	$	14	$	16	$	—	$	—

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

(b)     In the first quarter of 2022, NSP-Minnesota recognized $1 million in settlement charge true-ups related to fourth quarter 2021.

^[1]

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

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Commitment and Contingencies (Tables)

3 Months Ended

6 Months Ended

Jun. 30, 2022

Jun. 30, 2022

Commitments and Contingencies Disclosure [Abstract]

Lease, Cost

Components of lease expense:

	Three Months Ended June 30
(Millions of Dollars)	2022		2021
Operating leases
PPA capacity payments	$	24	$	17
Other operating leases (a)	2		3
Total operating lease expense (b)	$	26	$	20

(a)Includes short-term lease expense of $1 million for 2022 and 2021, 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.

	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Operating leases
PPA capacity payments	$	49	$	36
Other operating leases (a)	4		5
Total operating lease expense (b)	$	53	$	41

(a)Includes short-term lease expense of $1 million for 2022 and 2021, 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.

Lessee, Operating Lease, Liability, Maturity

Commitments under operating leases as of June 30, 2022:

(Millions of Dollars)	PPA Operating Leases		Other Operating Leases		Total Operating Leases
Total minimum obligation	$	366	$	69	$	435
Interest component of obligation	(25)		(11)		(36)
Present value of minimum obligation	$	341	$	58	399
Less current portion					(96)
Noncurrent operating lease liabilities					$	303

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Other Comprehensive Income (Loss) (Tables)

6 Months Ended

Jun. 30, 2022

Stockholders' Equity Note [Abstract]

Changes in Accumulated Other Comprehensive Income (Loss), Net of Tax

Changes in accumulated other comprehensive income (loss), net of tax, for the three and six months ended June 30, 2022 and 2021:

	Three Months Ended June 30, 2022						Three Months Ended June 30, 2021
(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 April 1	$	(17)	$	(3)	$	(20)	$	(18)	$	(3)	$	(21)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (a)	—		—		—		—		—		—
Accumulated other comprehensive loss at June 30	$	(17)	$	(3)	$	(20)	$	(18)	$	(3)	$	(21)

	Six Months Ended June 30, 2022						Six Months Ended June 30, 2021
(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	$	(17)	$	(3)	$	(20)	$	(19)	$	(3)	$	(22)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (a)	—		—		—		1		—		1
Accumulated other comprehensive loss at June 30	$	(17)	$	(3)	$	(20)	$	(18)	$	(3)	$	(21)

(a)Included in interest charges.

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Segment Information (Tables)

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

Results from Operations by Reportable Segment

NSP-Minnesota’s segment information:

	Three Months Ended June 30
(Millions of Dollars)	2022		2021
Regulated Electric
Operating revenues (a)	$	1,324	$	1,226
Intersegment revenue	—		1
Total revenues	$	1,324	$	1,227
Net income	113		112
Regulated Natural Gas
Operating revenues (b)	$	167	$	80
Intersegment revenue	1		—
Total revenues	$	168	$	80
Net income (loss)	4		(1)
All Other
Total revenues	$	11	$	9
Net income	1		1
Consolidated Total
Operating revenues (a)(b)	$	1,503	$	1,316
Reconciling eliminations	(1)		(1)
Total revenues	$	1,502	$	1,315
Net income	118		112

(a)    Operating revenues include $133 million and $131 million of affiliate electric revenue for the three months ended June 30, 2022 and 2021.

(b)    Operating revenues include an immaterial amount of affiliate gas revenue for the three months ended June 30, 2022 and 2021.

	Six Months Ended June 30
(Millions of Dollars)	2022		2021
Regulated Electric
Operating revenues (a)	$	2,578	$	2,365
Intersegment revenue	—		1
Total revenues	$	2,578	$	2,366
Net income	211		219
Regulated Natural Gas
Operating revenues (b)	$	601	$	284
Intersegment revenue	1		1
Total revenues	$	602	$	285
Net income	33		19
All Other
Total operating revenues	$	21	$	18
Net income	1		3
Consolidated Total
Operating revenues (a)(b)	$	3,201	$	2,669
Reconciling eliminations	(1)		(2)
Total operating revenues	$	3,200	$	2,667
Net income	245		241

(a)    Operating revenues include $262 million and $246 million of affiliate electric revenue for the six months ended June 30, 2022 and 2021.

(b)    Operating revenues include an immaterial amount of affiliate gas revenue for the six months ended June 30, 2022 and 2021.

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Accounts Receivable (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Balance Sheet Related Disclosures [Abstract]
Accounts Receivable	$ 502	$ 474
Less allowance for bad debts	(45)	(45)
Accounts receivable, net	$ 457	$ 429

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Inventories (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Public Utilities, Inventory [Line Items]
Inventories	$ 328	$ 309
Materials and supplies
Public Utilities, Inventory [Line Items]
Inventories	190	181
Fuel
Public Utilities, Inventory [Line Items]
Inventories	106	81
Natural Gas
Public Utilities, Inventory [Line Items]
Inventories	$ 32	$ 47

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Property, Plant and Equipment (Details) - USD ($) $ in Millions		Jun. 30, 2022	Dec. 31, 2021
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		$ 24,427	$ 23,728
Accumulated depreciation and amortization		(7,938)	(7,606)
Property, plant and equipment, net		16,751	16,430
Electric plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		19,826	19,154
Natural gas plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		1,940	1,864
Common and other property
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		1,083	1,007
Plant to be Retired (a)
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[1]	682	719
Construction work in progress
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		896	984
Nuclear fuel
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		3,096	3,081
Accumulated depreciation and amortization		$ (2,834)	$ (2,773)

[1] Amounts include regulator-approved retirements of Sherco Units 1, 2 and 3 and A.S. King and are reported net of accumulated depreciation.

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Money Pool (Details) - Money Pool - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Short-term Debt [Line Items]
Borrowing limit	$ 250	$ 250
Amount outstanding at period end	0	0
Average amount outstanding	0	6
Maximum amount outstanding	$ 0	$ 236
Weighted average interest rate, computed on a daily basis		0.07%

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Borrowings and Other Financing Instruments Commercial Paper (Details) - Commercial Paper - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Short-term Debt [Line Items]
Borrowing limit	$ 500	$ 500
Amount outstanding at period end	0	0
Average amount outstanding	0	26
Maximum amount outstanding	$ 0	$ 317
Weighted average interest rate, computed on a daily basis		0.18%

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Letters of Credit (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Letter of Credit
Line of Credit Facility [Line Items]
Direct advances on the credit facility outstanding	$ 11	$ 9

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Credit Facility (Details) - Credit Facility $ in Millions		6 Months Ended
		Jun. 30, 2022 USD ($)	Dec. 31, 2021 USD ($)
Line of Credit Facility [Line Items]
Borrowing limit	[1]	$ 500
Amount outstanding at period end	[2]	$ 11
Number of extension you can request		2
Available		$ 489
Direct advances on the credit facility outstanding		$ 0	$ 0

[1] Expires in June 2024.

[2] Includes outstanding commercial paper and letters of credit.

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Bilateral Credit Agreement (Details)	6 Months Ended
	Jun. 30, 2022 USD ($)
Series Due June 1, 2052 | NSP Minnesota [Member] | Bonds [Member]
Short-term Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.50%
Debt Instrument, Face Amount	$ 500,000,000
Letter of Credit | Bilateral Credit Agreement
Short-term Debt [Line Items]
Borrowing Limit	75,000,000
Amount outstanding at period end	$ 43,000,000
Letter of Credit | Bilateral Credit Agreement | NSP Minnesota [Member]
Short-term Debt [Line Items]
Debt Instrument, Term	1 year

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Revenues (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Total revenues
Disaggregation of Revenue [Line Items]
Total revenues	$ 1,502	$ 1,315	$ 3,200	$ 2,667
Regulated Electric | Total revenues
Disaggregation of Revenue [Line Items]
Total revenues	1,324	1,226	2,578	2,365
Regulated Natural Gas | Total revenues
Disaggregation of Revenue [Line Items]
Total revenues	167	80	601	284
All Other | Total revenues
Disaggregation of Revenue [Line Items]
Total revenues	11	9	21	18
Retail
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	1,099	965	2,384	1,917
Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	417	379	995	826
Retail | C&I
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	664	576	1,358	1,072
Retail | Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	18	10	31	19
Retail | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	936	889	1,796	1,639
Retail | Regulated Electric | Residential
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	338	334	675	660
Retail | Regulated Electric | C&I
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	588	547	1,102	964
Retail | Regulated Electric | Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	10	8	19	15
Retail | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	152	67	567	260
Retail | Regulated Natural Gas | Residential
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	76	38	311	152
Retail | Regulated Natural Gas | C&I
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	76	29	256	108
Retail | Regulated Natural Gas | Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0	0
Retail | All Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	11	9	21	18
Retail | All Other | Residential
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	3	7	9	14
Retail | All Other | C&I
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0	0
Retail | All Other | Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	8	2	12	4
Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	138	69	263	167
Wholesale | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	138	69	263	167
Wholesale | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0	0
Wholesale | All Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0	0
Transmission
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	63	58	124	114
Transmission | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	63	58	124	114
Transmission | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0	0
Transmission | All Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0	0
Interchange
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	133	131	262	246
Interchange | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	133	131	262	246
Interchange | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0	0
Interchange | All Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0	0
Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(2)	7	6	8
Other | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	(5)	3	1	5
Other | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	3	4	5	3
Other | All Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	0	0	0	0
Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	1,431	1,230	3,039	2,452
Total revenue from contracts with customers | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	1,265	1,150	2,446	2,171
Total revenue from contracts with customers | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	155	71	572	263
Total revenue from contracts with customers | All Other
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	11	9	21	18
Alternative revenue and other
Disaggregation of Revenue [Line Items]
Alternative revenue and other	71	85	161	215
Alternative revenue and other | Regulated Electric
Disaggregation of Revenue [Line Items]
Alternative revenue and other	59	76	132	194
Alternative revenue and other | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Alternative revenue and other	12	9	29	21
Alternative revenue and other | All Other
Disaggregation of Revenue [Line Items]
Alternative revenue and other	$ 0	$ 0	$ 0	$ 0

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Income Taxes (Details)		6 Months Ended
		Jun. 30, 2022	Jun. 30, 2021
Income Tax Disclosure [Abstract]
Federal statutory rate		21.00%	21.00%
State tax (net of federal tax effect)		7.00%	7.00%
Wind PTCs	[1]	(71.70%)	(34.80%)
Plant regulatory differences	[2]	(6.20%)	(8.00%)
Other tax credits, net operating loss & tax credit allowances		(1.50%)	(1.30%)
Other (net)		1.10%	0.80%
Effective income tax rate		(50.30%)	(15.30%)

[1] Wind PTCs are credited to customers (reduction to revenue) and do not materially impact net income

[2] Regulatory differences for income tax primarily relate to the credit of excess deferred taxes to customers through the average rate assumption method. Income tax benefits associated with the credit of excess deferred taxes are offset by corresponding revenue reductions.

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Non-Derivative Fair Value Measurements (Details) - USD ($) $ in Millions	6 Months Ended		12 Months Ended
	Jun. 30, 2022		Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Miscellaneous investments	$ 50		$ 52
Debt Securities, Available-for-sale, Unrealized Gain	1,000		1,300
Debt Securities, Available-for-sale, Unrealized Loss	76		7
Final Contractual Maturity [Abstract]
Due in 1 Year or Less	3
Due in 1 to 5 Years	190
Due in 5 to 10 Years	232
Due after 10 Years	196
Total	621
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	1,963	[1]	1,962	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	53	[1]	64	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Commingled funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commingled funds	835	[1]	856	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt securities	668	[1]	631	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	407	[1]	411	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	2,855	[1]	3,256	[2]
NAV	1,209	[1]	1,294	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	53	[1]	64	[2]
NAV	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Commingled funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commingled funds	1,209	[1]	1,294	[2]
NAV	1,209	[1]	1,294	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt securities	621	[1]	675	[2]
NAV	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	972	[1]	1,223	[2]
NAV	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	1,024	[1]	1,286	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	53	[1]	64	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Commingled funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commingled funds	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt securities	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	971	[1]	1,222	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	616	[1]	667	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Commingled funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commingled funds	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt securities	615	[1]	666	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	1	[1]	1	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	6	[1]	9	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Commingled funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commingled funds	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt securities	6	[1]	9	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity securities	$ 0	[1]	$ 0	[2]

[1] Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $50 million of other investments, including the rabbi trust.

[2] Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $52 million of other investments, including the rabbi trust.

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Interest Rate Derivative (Details) - USD ($) $ in Millions		3 Months Ended				6 Months Ended
		Jun. 30, 2022		Jun. 30, 2021		Jun. 30, 2022		Jun. 30, 2021
Other Derivative Instruments
Interest Rate Derivatives [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		$ 0		$ 0		$ 0		$ 0
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)		(1)		1		(1)		11
Pre-tax gains (losses) recognized during the period in income		5		2		1		30
Designated as Hedging Instrument [Member] | Cash Flow Hedges
Interest Rate Derivatives [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net								1
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)								0
Pre-tax gains (losses) recognized during the period in income								0
Interest Rate Derivatives
Interest Rate Derivatives [Abstract]
Amount or interest rate derivatives expected to be reclassified		1				1
Derivative Liability, Notional Amount		0				0
Commodity Trading Contract | Other Derivative Instruments
Interest Rate Derivatives [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		0		0		0		0
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)		0		0		0		0
Pre-tax gains (losses) recognized during the period in income		5	[1]	2	[2]	6	[2]	33	[1]
Electric Commodity | Other Derivative Instruments
Interest Rate Derivatives [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		0		0		0		0
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)		1	[2]	1	[3]	(3)	[3]	12	[2]
Pre-tax gains (losses) recognized during the period in income		$ 0		$ 0		0		0
Natural Gas Commodity | Other Derivative Instruments
Interest Rate Derivatives [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net						0		0
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)						(2)	[4]	(1)	[3]
Pre-tax gains (losses) recognized during the period in income	[3],[4]					$ (5)		(3)
Interest Rate Contract [Member] | Designated as Hedging Instrument [Member] | Cash Flow Hedges
Interest Rate Derivatives [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	[5]							1
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)								0
Pre-tax gains (losses) recognized during the period in income								$ 0

[1] Recorded to electric operating revenues. Portions of these gains and losses are subject to sharing with electric customers through margin-sharing mechanisms and deducted from gross revenue, as appropriate.

[2] 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. All 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.

[3] 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.

[4] Relates primarily to option premium amortization.

[5] Recorded to interest charges.

XML

Commodity Derivatives (Details) MWh in Millions, MMBTU in Millions, $ in Millions		Jun. 30, 2022 USD ($) MMBTU MWh	Dec. 31, 2021 USD ($) MWh MMBTU
Gross Notional Amounts of Commodity Forwards, Options and FTRs [Abstract]
Miscellaneous investments		$ 50	$ 52
Cash flow hedge commodity
Derivative [Line Items]
Commodity contracts designated as cash flow hedges		$ 0
Electric commodity
Gross Notional Amounts of Commodity Forwards, Options and FTRs [Abstract]
Derivative, Nonmonetary Notional amount | MWh	[1],[2]	76	57
Natural Gas Commodity
Gross Notional Amounts of Commodity Forwards, Options and FTRs [Abstract]
Derivative, Nonmonetary Notional amount | MMBTU	[1],[2]	106	85

[1] Amounts are not reflective of net positions in the underlying commodities.

[2] Notional amounts for options are included on a gross basis, but are weighted for the probability of exercise.

XML

Consideration of Credit Risk and Concentrations (Details) $ in Millions		3 Months Ended				6 Months Ended
		Jun. 30, 2022 USD ($) Counterparty		Jun. 30, 2021 USD ($)		Jun. 30, 2022 USD ($) Counterparty		Jun. 30, 2021 USD ($)
Impact of Derivative Activity on Accumulated Other Comprehensive Loss, Regulatory Assets and Liabilities, and Income [Abstract]
Fair Value Hedges, Net		$ 0		$ 0		$ 0		$ 0
Other Derivative Instruments
Impact of Derivative Activity on Accumulated Other Comprehensive Loss, Regulatory Assets and Liabilities, and Income [Abstract]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		6		4		8		5
Pre-tax (gains) losses reclassified into income during the period from accumulated other comprehensive loss		0		0		0		0
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		1		(1)		1		(11)
Pre-tax gains (losses) recognized during the period in income		5		2		1		30
Commodity Trading Contract | Other Derivative Instruments
Impact of Derivative Activity on Accumulated Other Comprehensive Loss, Regulatory Assets and Liabilities, and Income [Abstract]
Pre-tax (gains) losses reclassified into income during the period from accumulated other comprehensive loss		0		0		0		0
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		0		0		0		0
Pre-tax gains (losses) recognized during the period in income		5	[1]	2	[2]	6	[2]	33	[1]
Electric Commodity | Other Derivative Instruments
Impact of Derivative Activity on Accumulated Other Comprehensive Loss, Regulatory Assets and Liabilities, and Income [Abstract]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities						6		3
Pre-tax (gains) losses reclassified into income during the period from accumulated other comprehensive loss		0		0		0		0
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		(1)	[2]	(1)	[3]	3	[3]	(12)	[2]
Pre-tax gains (losses) recognized during the period in income		0		0		0		0
Natural Gas Commodity | Other Derivative Instruments
Impact of Derivative Activity on Accumulated Other Comprehensive Loss, Regulatory Assets and Liabilities, and Income [Abstract]
Pre-tax (gains) losses reclassified into income during the period from accumulated other comprehensive loss						0		0
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)						2	[4]	1	[3]
Pre-tax gains (losses) recognized during the period in income	[3],[4]					(5)		(3)
Natural gas commodity | Other Derivative Instruments
Impact of Derivative Activity on Accumulated Other Comprehensive Loss, Regulatory Assets and Liabilities, and Income [Abstract]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		(1)		1		$ 2		$ 2
Electric commodity | Other Derivative Instruments
Impact of Derivative Activity on Accumulated Other Comprehensive Loss, Regulatory Assets and Liabilities, and Income [Abstract]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		$ 7		$ 3
Credit Concentration Risk
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		10				10
Credit Concentration Risk | Municipal or Cooperative Entities or Other Utilities [Member]
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		4				4
Credit Concentration Risk | External Credit Rating, Investment Grade [Member]
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		8				8
Wholesale, trading and non trading commodity credit exposure for the most significant counterparties		$ 33				$ 33
Percentage of wholesale, trading and non trading commodity credit exposure for the most significant counterparties		31.00%				31.00%
Credit Concentration Risk | Internal Investment Grade [Member]
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		1				1
Wholesale, trading and non trading commodity credit exposure for the most significant counterparties		$ 24				$ 24
Percentage of wholesale, trading and non trading commodity credit exposure for the most significant counterparties		23.00%				23.00%
Credit Concentration Risk | External Credit Rating, Non Investment Grade [Member]
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		1				1
Wholesale, trading and non trading commodity credit exposure for the most significant counterparties		$ 47				$ 47
Percentage of wholesale, trading and non trading commodity credit exposure for the most significant counterparties		45.00%				45.00%

[1] Recorded to electric operating revenues. Portions of these gains and losses are subject to sharing with electric customers through margin-sharing mechanisms and deducted from gross revenue, as appropriate.

[2] 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. All 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.

[3] 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.

[4] Relates primarily to option premium amortization.

XML

Credit Related Contingent Features (Details) $ in Millions		3 Months Ended				6 Months Ended
		Jun. 30, 2022 USD ($) Counterparty		Jun. 30, 2021 USD ($)		Jun. 30, 2022 USD ($) Counterparty		Jun. 30, 2021 USD ($)		Dec. 31, 2021 USD ($)
Fair Value Disclosures [Abstract]
Derivative instruments in a gross liability position		$ 11				$ 11				$ 3
Derivative, Gross Liability with Cross Default Position, Aggregate Fair Value		110				110				48
Collateral posted related to adequate assurance clauses in derivative contracts		0				0				0
Derivative [Line Items]
Fair Value Hedges, Net		0		$ 0		0		$ 0
Derivative instruments in a gross liability position		11				11				3
Derivative, Gross Liability with Cross Default Position, Aggregate Fair Value		$ 110				$ 110				$ 48
Credit Concentration Risk
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		10				10
Credit Concentration Risk | Municipal or Cooperative Entities or Other Utilities [Member]
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		4				4
External Credit Rating, Investment Grade [Member] | Credit Concentration Risk
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		8				8
Wholesale, trading and non trading commodity credit exposure for the most significant counterparties		$ 33				$ 33
Percentage of wholesale, trading and non trading commodity credit exposure for the most significant counterparties		31.00%				31.00%
Internal Investment Grade [Member] | Credit Concentration Risk
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		1				1
Wholesale, trading and non trading commodity credit exposure for the most significant counterparties		$ 24				$ 24
Percentage of wholesale, trading and non trading commodity credit exposure for the most significant counterparties		23.00%				23.00%
External Credit Rating, Non Investment Grade [Member] | Credit Concentration Risk
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		1				1
Wholesale, trading and non trading commodity credit exposure for the most significant counterparties		$ 47				$ 47
Percentage of wholesale, trading and non trading commodity credit exposure for the most significant counterparties		45.00%				45.00%
Other Derivative Instruments
Derivative [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		$ 0		0		$ 0		0
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)		(1)		1		(1)		11
Pre-tax gains (losses) recognized during the period in income		5		2		1		30
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		6		4		8		5
Commodity Trading Contract | Other Derivative Instruments
Derivative [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		0		0		0		0
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)		0		0		0		0
Pre-tax gains (losses) recognized during the period in income		5	[1]	2	[2]	6	[2]	33	[1]
Electric Commodity | Other Derivative Instruments
Derivative [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		0		0		0		0
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)		1	[2]	1	[3]	(3)	[3]	12	[2]
Pre-tax gains (losses) recognized during the period in income		0		0		0		0
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities						6		3
Natural Gas Commodity | Other Derivative Instruments
Derivative [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net						0		0
Pre-tax gains (losses) reclassified into income during the period from regulatory assets and (liabilities)						(2)	[4]	(1)	[3]
Pre-tax gains (losses) recognized during the period in income	[3],[4]					(5)		(3)
Natural gas commodity | Other Derivative Instruments
Derivative [Line Items]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		(1)		1		$ 2		$ 2
Electric commodity | Other Derivative Instruments
Derivative [Line Items]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		$ 7		$ 3

[1] Recorded to electric operating revenues. Portions of these gains and losses are subject to sharing with electric customers through margin-sharing mechanisms and deducted from gross revenue, as appropriate.

[2] 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. All 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.

[3] 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.

[4] Relates primarily to option premium amortization.

XML

Recurring Fair Value Measurements (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Obligation to return cash		$ 0		$ 0		$ 0
Right to reclaim cash		12		12		16
Commodity Trading
Changes in Level 3 Commodity Derivatives [Roll Forward]
Balance at beginning of period		76	$ 12	56	$ (11)
Settlements	[1]	(73)	(19)	(92)	(26)
Gains recognized in earnings (b)	[2]	41	33	91	63
Net gains recognized as regulatory assets and liabilities (a)	[1]	28	12	18	12
Balance at end of period		230	92	230	92
Purchases/Issuances (a)	[1]	158	54	157	$ 54
Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative asset		204		204		53
Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative liability		99		99		35
Other Noncurrent Liabilities
Derivatives, Fair Value [Line Items]
Derivative liability		103		103		71
Fair Value Measured on a Recurring Basis | Level 3
Changes in Level 3 Commodity Derivatives [Roll Forward]
Transfers level 3, net			$ 0	0
Fair Value Measured on a Recurring Basis | Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross		365		365		107
Netting, asset	[3]	(163)		(163)		(54)
Derivative asset		202		202		53
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative asset, gross		32		32		9
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative asset, gross		128		128		46
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative asset, gross		205		205		52
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative asset, gross		221		221		71
Netting, asset	[3]	(160)		(160)		(53)
Derivative asset		61		61		18
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative asset, gross		144		144		30
Netting, asset	[3]	(3)		(3)		(1)
Derivative asset		141		141		29
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative asset, gross		0		0		6
Netting, asset	[3]	0		0		0
Derivative asset		0		0		6
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 1 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative asset, gross		32		32		9
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 1 | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative asset, gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 1 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative asset, gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 2 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative asset, gross		128		128		40
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 2 | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative asset, gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 2 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative asset, gross		0		0		6
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 3 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative asset, gross		61		61		22
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 3 | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative asset, gross		144		144		30
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 3 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative asset, gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross		154		154		75
Netting, asset	[3]	(81)		(81)		(42)
Derivative asset		73		73		33
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative asset, gross		26		26		6
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative asset, gross		49		49		34
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative asset, gross		79		79		35
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative asset, gross		154		154		75
Netting, asset	[3]	(81)		(81)		(42)
Derivative asset		73		73		33
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Level 1 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative asset, gross		26		26		6
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Level 2 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative asset, gross		49		49		34
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Level 3 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative asset, gross		79		79		35
Fair Value Measured on a Recurring Basis | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross		222		222		80
Netting, liability	[3]	(137)		(137)		(59)
Derivative liability		85		85		21
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative liability, gross		35		35		13
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative liability, gross		173		173		62
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative liability, gross		14		14		5
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative liability, gross		218		218		75
Netting, liability	[3]	(134)		(134)		(58)
Derivative liability		84		84		17
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative liability, gross		3		3		1
Netting, liability	[3]	(3)		(3)		(1)
Derivative liability		0		0		0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative liability, gross		1		1		4
Netting, liability	[3]	0		0		0
Derivative liability		1		1		4
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 1 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative liability, gross		35		35		13
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 1 | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative liability, gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 1 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative liability, gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 2 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative liability, gross		172		172		58
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 2 | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative liability, gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 2 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative liability, gross		1		1		4
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 3 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative liability, gross		11		11		4
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 3 | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative liability, gross		3		3		1
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 3 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative liability, gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross		164		164		89
Netting, liability	[3]	(93)		(93)		(53)
Derivative liability		71		71		36
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative liability, gross		47		47		15
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative liability, gross		77		77		48
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative liability, gross		40		40		26
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative liability, gross		164		164		89
Netting, liability	[3]	(93)		(93)		(53)
Derivative liability		71		71		36
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Other Derivative Instruments | Level 1 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative liability, gross		47		47		15
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Other Derivative Instruments | Level 2 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative liability, gross		77		77		48
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Other Derivative Instruments | Level 3 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative liability, gross		40		40		26
Fair Value, Measurements, Nonrecurring | Other Current Assets | PPAs
Derivatives, Fair Value [Line Items]
Derivative asset	[4]	2		2		0
Fair Value, Measurements, Nonrecurring | Other Current Liabilities | PPAs
Derivatives, Fair Value [Line Items]
Derivative liability	[4]	14		14		14
Fair Value, Measurements, Nonrecurring | Other Noncurrent Liabilities | PPAs
Derivatives, Fair Value [Line Items]
Derivative liability	[4]	$ 32		$ 32		$ 35

[1] Relates primarily to FTR instruments administered by MISO (annual auctions occurring in the second quarter). These instruments are utilized/intended to offset the impacts of transmission system congestion. Higher congestion costs have led to an increase in the fair value of FTRs. Due to regulatory recovery, changes in fair value are deferred as a regulatory asset or liability and do not have a material impact on net income.

[2] Relates to commodity trading and is subject to offsetting losses of derivative instruments categorized as levels 1 and 2 in the consolidated income statement.

[3] NSP-Minnesota nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at June 30, 2022 and Dec. 31, 2021. At both June 30, 2022 and Dec. 31, 2021, derivative assets and liabilities include no obligations to return cash collateral. At June 30, 2022 and Dec. 31, 2021 derivative assets and liabilities include rights to reclaim cash collateral of $12 million and $16 million, respectively. The counterparty netting excludes settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.(b)Amounts relate to FTR instruments administered by MISO (annual auctions occurring in the second quarter). These instruments are utilized/intended to offset the impacts of transmission system congestion. Higher congestion costs have led to an increase in the fair value of FTRs. Due to regulatory recovery, changes in fair value are deferred as a regulatory asset or liability and do not have a material impact on net income.

[4] During 2006, Xcel Energy qualified these contracts under the normal purchase exception. Based on this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities.

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Fair Value of Long-Term Debt (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, carrying amount	$ 6,940	$ 6,747
Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 6,984	$ 7,761

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Benefit Plans and Other Postretirement Benefits (Details) $ in Millions		1 Months Ended	3 Months Ended		6 Months Ended
		Jan. 31, 2022 USD ($) Plan	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)
Pension Plan [Member]
Components of Net Periodic Benefit Cost [Abstract]
Service Cost			$ 7	$ 8	$ 14	$ 15
Interest cost (a)	[1]		6	6	12	12
Expected return on plan assets (a)	[1]		(12)	(13)	(24)	(26)
Amortization of prior service credit (a)	[1]		0	0	0	0
Amortization of net loss (a)	[1]		6	8	12	17
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	[2]				(1)	0
Net periodic benefit cost			7	9	13	18
Effects of regulation			0	(1)	1	(2)
Net benefit cost recognized for financial reporting			7	8	14	16
Total contributions to the pension plans during the period		$ 5
Pension Plan [Member] | Xcel Energy Inc.
Components of Net Periodic Benefit Cost [Abstract]
Total contributions to the pension plans during the period		$ 50
Number of Xcel Energy's pension plans to which contributions were made | Plan		4
Other Postretirement Benefits Plan [Member]
Components of Net Periodic Benefit Cost [Abstract]
Service Cost			0	0	0	0
Interest cost (a)	[1]		0	0	1	1
Expected return on plan assets (a)	[1]		0	0	0	0
Amortization of prior service credit (a)	[1]		0	(1)	(1)	(2)
Amortization of net loss (a)	[1]		0	1	0	1
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	[2]				0	0
Net periodic benefit cost			0	0	0	0
Effects of regulation			0	0	0	0
Net benefit cost recognized for financial reporting			$ 0	$ 0	$ 0	$ 0

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

[2] In the first quarter of 2022, NSP-Minnesota recognized $1 million in settlement charge true-ups related to fourth quarter 2021.

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Commitments and Contingencies - Winter Storm Uri (Details) $ in Millions	Jun. 30, 2022 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Winter Storm Uri Costs	$ 148

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Commitments and Contingencies - Sherco (Details) $ in Millions	1 Months Ended
	Jan. 31, 2021 USD ($)
Rate Matters [Abstract]
Customer refund of previously recovered purchased power costs	$ 17
Amount MPUC previously disallowed related to Sherco outage	$ 22

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Commitments and Contingencies - Westmoreland Arbitration (Details) $ in Millions	Jun. 30, 2022 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Westmoreland Recovery	$ 19
Westmoreland Settlement	$ 2

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Commitments and Contingencies - MISO ROE Complaints (Details) - Federal Energy Regulatory Commission (FERC) - FERC Proceeding, MISO ROE Complaint - NSP Minnesota and NSP Wisconsin [Member] [Member]	1 Months Ended
	Feb. 28, 2015	Nov. 30, 2013
Public Utilities, General Disclosures [Line Items]
Public Utilities, Base Return On Equity Charged To Customers Through Transmission Formula Rates	12.38%	12.38%
Public Utilities, ROE Applicable To Transmission Formula Rates In The MISO Region, Recommended By Third Parties	8.67%	9.15%

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Commitments and Contingencies - Environmental, MGP, Landfill or Disposal Sites (Details)	Jun. 30, 2022
Other MGP, Landfill, or Disposal Sites
Site Contingency [Line Items]
Number of identified MGP, landfill, or disposal sites under current investigation and/or remediation	7

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Commitments and Contingencies - Environmental Requirements - Water and Waste (Details) $ in Millions	3 Months Ended
	Jun. 30, 2022 USD ($) Plant
Federal Coal Ash Regulation
Site Contingency [Line Items]
Number of sites where regulated ash units will still be in operation at a specified date	3
Number of impoundments where closure plans will be expedited	1
Estimated cost of closure of an impoundment	$ 4
Time period of existing ash pond closure completion in accordance with the CCR rule	5 years
Federal Clean Water Act Section 316 (b) | NSP Minnesota [Member]
Site Contingency [Line Items]
Minimum number of plants which could be required to make improvements to reduce entrainment | Plant	6
Federal Clean Water Act Section 316 (b) | Capital Addition Purchase Commitments
Site Contingency [Line Items]
Liability for estimated cost to comply with regulation	$ 36

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Commitments and Contingencies - Leases (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2022		Jun. 30, 2021		Jun. 30, 2022		Jun. 30, 2021		Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Operating Lease, Cost	$ 26	[1]	$ 20	[1]	$ 53	[2]	$ 41	[2]
Lessee, Operating Lease, Liability, to be Paid	435				435
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	(36)				(36)
Operating Lease, Liability	399				399
Operating Lease, Liability, Current	(96)				(96)				$ (90)
Operating lease liabilities	303				303				$ 353
Purchased Power Agreements
Lessee, Lease, Description [Line Items]
Operating Lease, Cost	24		17		49		36
Lessee, Operating Lease, Liability, to be Paid	366				366
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	(25)				(25)
Operating Lease, Liability	341				341
Property, Plant and Equipment, Other Types
Lessee, Lease, Description [Line Items]
Operating Lease, Cost	2	[3]	$ 3	[3]	4	[4]	$ 5	[4]
Lessee, Operating Lease, Liability, to be Paid	69				69
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	(11)				(11)
Operating Lease, Liability	$ 58				$ 58

[1] 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.

[2] 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.

[3] Includes short-term lease expense of $1 million for 2022 and 2021, respectively.

[4] Includes short-term lease expense of $1 million for 2022 and 2021, respectively.

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Commitments and Contingencies - Variable Interest Entities (Details) - MW	Jun. 30, 2022	Dec. 31, 2021
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member]
Variable Interest Entity [Line Items]
Generating capacity under long term purchased power agreements	1,322	1,347

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Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive (loss) income at beginning of period				$ 7,573
Accumulated other comprehensive (loss) income at end of period		$ 7,548		7,548
Income Tax Expense (Benefit)		(42)	$ (19)	(82)	$ (32)
Gains and Losses on Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive (loss) income at beginning of period		(17)	(18)	(17)	(19)
Accumulated other comprehensive (loss) income at end of period		(17)	(18)	(17)	(18)
Gains and Losses on Cash Flow Hedges | Interest Rate Swap [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	[1]	0	0	0	1
Defined Benefit Pension and Postretirement Items
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive (loss) income at beginning of period		(3)	(3)	(3)	(3)
Accumulated other comprehensive (loss) income at end of period		(3)	(3)	(3)	(3)
Defined Benefit Pension and Postretirement Items | Interest Rate Swap [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	[1]	0	0	0	0
Total
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive (loss) income at beginning of period		(20)	(21)	(20)	(22)
Accumulated other comprehensive (loss) income at end of period		(20)	(21)	(20)	(21)
Total | Interest Rate Swap [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	[1]	$ 0	$ 0	$ 0	$ 1

[1] Included in interest charges

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Segment Information (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2022		Jun. 30, 2021		Jun. 30, 2022		Jun. 30, 2021
Segment Reporting Information [Line Items]
Net income	$ 118		$ 112		$ 245		$ 241
Natural gas	167		80		601		284
Other	11		9		21		18
Regulated and Unregulated Operating Revenue	1,502		1,315		3,200		2,667
Affiliate Revenue	133		131		262		246
Total revenues
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue	1,503	[1],[2]	1,316	[1],[2]	3,201	[3],[4]	2,669	[3],[4]
Intersegment Eliminations
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue	(1)		(1)		(1)		(2)
Regulated Electric
Segment Reporting Information [Line Items]
Net income	113		112		211		219
Revenues Including Intersegment Revenues	1,324		1,227		2,578		2,366
Regulated Electric | Total revenues
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Electric	1,324	[1]	1,226	[1]	2,578	[3]	2,365	[3]
Regulated Electric | Intersegment Eliminations
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Electric	0		1		0		1
Regulated Natural Gas
Segment Reporting Information [Line Items]
Net income	4		(1)		33		19
Revenues Including Intersegment Revenues	168		80		602		285
Regulated Natural Gas | Total revenues
Segment Reporting Information [Line Items]
Natural gas	167	[2]	80	[2]	601	[4]	284	[4]
Regulated Natural Gas | Intersegment Eliminations
Segment Reporting Information [Line Items]
Natural gas	1		0		1		1
All Other
Segment Reporting Information [Line Items]
Net income	1		1		1		3
All Other | Total revenues
Segment Reporting Information [Line Items]
Other	$ 11		$ 9		$ 21		$ 18

[1] Operating revenues include $133 million and $131 million of affiliate electric revenue for the three months ended June 30, 2022 and 2021.

[2] Operating revenues include an immaterial amount of affiliate gas revenue for the three months ended June 30, 2022 and 2021.

[3] Operating revenues include $262 million and $246 million of affiliate electric revenue for the six months ended June 30, 2022 and 2021.

[4] Operating revenues include an immaterial amount of affiliate gas revenue for the six months ended June 30, 2022 and 2021.