Xcel Energy (XEL) 10-Q 27 Oct 22 2022 Q3 Quarterly report Financial data

Cover Page

Cover Page - shares	9 Months Ended
	Sep. 30, 2022	Oct. 25, 2022
Cover [Abstract]
Entity Registrant Name	XCEL ENERGY INC
Entity Central Index Key	0000072903
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3
Amendment Flag	false
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
Document Transition Report	false
Entity File Number	001-3034
Entity Incorporation, State or Country Code	MN
Entity Tax Identification Number	41-0448030
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
Title of 12(b) Security	Common Stock, $2.50 par value
Trading Symbol	XEL
Security Exchange Name	NASDAQ
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		547,248,496

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) - USD ($) shares in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Operating revenues
Electric		$ 3,699	$ 3,176	$ 9,255	$ 8,643
Natural gas		357	268	1,923	1,364
Other		26	23	79	69
Total operating revenues		4,082	3,467	11,257	10,076
Operating expenses
Electric fuel and purchased power		1,497	1,210	3,772	3,643
Cost of natural gas sold and transported		173	86	1,134	603
Cost of sales — other		11	11	32	28
O&M expenses		611	568	1,827	1,752
Conservation and demand side management expenses		86	78	259	222
Depreciation and amortization		607	537	1,807	1,586
Taxes, Other		173	152	523	472
Total operating expenses		3,158	2,642	9,354	8,306
Operating income		924	825	1,903	1,770
Other (expense) income, net		(15)	(3)	(20)	5
Earnings from equity method investments		1	13	27	47
Allowance for funds used during construction — equity		20	21	53	53
Interest charges and financing costs
Interest charges — includes other financing costs of $8, $7, $24 and $22, respectively		244	211	705	628
Allowance for funds used during construction — debt		(7)	(7)	(19)	(18)
Total interest charges and financing costs		237	204	686	610
Income before income taxes		693	652	1,277	1,265
Income tax expense (benefit)		44	43	(80)	(17)
Net income		$ 649	$ 609	$ 1,357	$ 1,282
Weighted average common shares outstanding:
Basic (in shares)		548	539	546	539
Diluted (in shares)	[1]	548	539	546	539
Earnings per average common share:
Basic (in dollars per share)		$ 1.19	$ 1.13	$ 2.48	$ 2.38
Diluted (in dollars per share)		$ 1.18	$ 1.13	$ 2.48	$ 2.38
[1] Diluted common shares outstanding included common stock equivalents of 0.3 million for the three months ended September 30, 2022 and 2021, respectively. Diluted common shares outstanding included common stock equivalents of

CONSOLIDATED STATEMENTS OF IN_2

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Income Statement [Abstract]
Other financing costs	$ 8	$ 7	$ 24	$ 22

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Comprehensive income:
Net income	$ 649	$ 609	$ 1,357	$ 1,282
Pension and retiree medical benefits:
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, after Tax	10	0	11	0
Reclassifications of loss to net income, net of tax of $—, $1, $1 and $2, respectively	1	4	2	5
Derivative instruments:
Net fair value increase, net of tax of $—, $1, $6 and $1, respectively	0	3	15	4
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	(1)	(2)	(4)	(6)
Total other comprehensive income	12	9	32	15
Total comprehensive income	$ 661	$ 618	$ 1,389	$ 1,297

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Statement of Comprehensive Income [Abstract]
Pension reclassifications, tax	$ 0	$ 1	$ 1	$ 2
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, Tax	0	1	6	1
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, Tax	0	0	1	1
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax	$ 4	$ 0	$ 4	$ 0

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Operating activities
Net income	$ 1,357	$ 1,282
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	1,821	1,597
Nuclear fuel amortization	91	86
Deferred income taxes	(85)	(9)
Allowance for equity funds used during construction	(53)	(53)
Earnings from equity method investments	(27)	(47)
Dividends from equity method investments	30	31
Provision for bad debts	41	53
Share-based compensation expense	19	20
Changes in operating assets and liabilities:
Accounts receivable	(221)	(152)
Accrued unbilled revenues	69	58
Inventories	(272)	(82)
Other current assets	13	8
Accounts payable	152	61
Net regulatory assets and liabilities	239	(997)
Other current liabilities	51	(22)
Pension and other employee benefit obligations	(59)	(131)
Other, net	1	(124)
Net cash provided by operating activities	3,167	1,579
Investing activities
Capital/construction expenditures	(3,325)	(3,032)
Purchase of investment securities	(1,055)	(540)
Proceeds from the sale of investment securities	1,029	531
Other, net	30	(24)
Net cash used in investing activities	(3,321)	(3,065)
Financing activities
(Repayments of) proceeds from short-term borrowings, net	(847)	1,163
Proceeds from issuances of long-term debt	2,164	1,920
Repayments of long-term debt, including reacquisition premiums	(600)	(399)
Proceeds from issuance of common stock	156	13
Dividends paid	(754)	(698)
Other, net	(14)	(11)
Net cash provided by financing activities	105	1,988
Net change in cash, cash equivalents and restricted cash	(49)	502
Cash, cash equivalents and restricted cash at beginning of period	166	129
Cash, cash equivalents and restricted cash at end of period	117	631
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	(628)	(592)
Cash paid for income taxes, net	(16)	(6)
Supplemental disclosure of non-cash investing and financing transactions:
Accrued property, plant and equipment additions	393	476
Inventory transfers to property, plant and equipment	34	87
Operating lease right-of-use assets	17	4
Allowance for equity funds used during construction	53	53
Issuance of common stock for reinvested dividends and/or equity awards	$ 40	$ 26

CONSOLIDATED BALANCE SHEETS (UN

CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Current assets
Cash and cash equivalents	$ 117	$ 166
Accounts receivable, net	1,196	1,018
Accrued unbilled revenues	793	862
Inventories	870	631
Regulatory assets	1,275	1,106
Derivative instruments	456	123
Prepaid taxes	54	44
Prepayments and other	329	289
Total current assets	5,090	4,239
Property, plant and equipment, net	47,287	45,457
Other assets
Nuclear decommissioning fund and other investments	3,083	3,628
Regulatory assets	2,850	2,738
Derivative instruments	90	67
Operating lease right-of-use assets	1,155	1,291
Other	420	431
Total other assets	7,598	8,155
Total assets	59,975	57,851
Current liabilities
Current portion of long-term debt	651	601
Short-term debt	158	1,005
Accounts payable	1,586	1,409
Regulatory liabilities	596	271
Taxes accrued	545	569
Accrued interest	244	209
Dividends payable	267	249
Derivative instruments	100	69
Operating lease liabilities	211	205
Other	545	459
Total current liabilities	4,903	5,046
Deferred credits and other liabilities
Deferred income taxes	4,762	4,894
Deferred investment tax credits	50	53
Regulatory liabilities	5,567	5,405
Asset retirement obligations	3,296	3,151
Derivative instruments	114	105
Customer advances	187	196
Pension and employee benefit obligations	255	306
Operating lease liabilities	997	1,146
Other	151	158
Total deferred credits and other liabilities	15,379	15,414
Commitments and contingencies
Capitalization
Long-term debt	23,309	21,779
Common stock — 1,000,000,000 shares authorized of $2.50 par value; 547,006,076 and 544,025,269 shares outstanding at Sept. 30, 2022 and Dec. 31, 2021, respectively	$ 1,368	$ 1,360
Common Stock, Shares Authorized	1,000,000,000	1,000,000,000
Common Stock, Par or Stated Value Per Share	$ 2.50	$ 2.50
Common Stock, Shares, Outstanding	547,006,076	544,025,269
Additional paid in capital	$ 7,979	$ 7,803
Retained earnings	7,128	6,572
Accumulated other comprehensive loss	(91)	(123)
Total common stockholders’ equity	16,384	15,612
Total liabilities and equity	$ 59,975	$ 57,851

CONSOLIDATED STATEMENTS OF COMM

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		537,438,394
Beginning balance at Dec. 31, 2020	$ 14,575	$ 1,344	$ 7,404	$ 5,968	$ (141)
Increase (Decrease) in Stockholders' Equity
Net income	1,282			1,282
Other comprehensive income	15				15
Dividends declared on common stock (USD per share)		$ 1.373
Dividends declared on common stock	(739)			(739)
Issuances of common stock (in shares)		1,020,558
Issuances of common stock	40	$ 2	38
Share-based compensation	(2)		1	(3)
Balance (in shares) at Sep. 30, 2021		538,458,952
Ending balance at Sep. 30, 2021	15,171	$ 1,346	7,443	6,508	(126)
Balance (in shares) at Jun. 30, 2021		538,305,927
Beginning balance at Jun. 30, 2021	14,792	$ 1,346	7,435	6,146	(135)
Increase (Decrease) in Stockholders' Equity
Net income	609			609
Other comprehensive income	9				9
Dividends declared on common stock (USD per share)		$ 0.4575
Dividends declared on common stock	(247)			(247)
Issuances of common stock (in shares)		153,025
Issuances of common stock	10	$ 0	10
Share-based compensation	(2)		(2)
Balance (in shares) at Sep. 30, 2021		538,458,952
Ending balance at Sep. 30, 2021	$ 15,171	$ 1,346	7,443	6,508	(126)
Balance (in shares) at Dec. 31, 2021	544,025,269	544,025,269
Beginning balance at Dec. 31, 2021	$ 15,612	$ 1,360	7,803	6,572	(123)
Increase (Decrease) in Stockholders' Equity
Net income	1,357			1,357
Other comprehensive income	32				32
Dividends declared on common stock (USD per share)		$ 1.463
Dividends declared on common stock	(798)			(798)
Issuances of common stock (in shares)		2,980,807
Issuances of common stock	185	$ 8	177
Share-based compensation	$ (4)		(1)	(3)
Balance (in shares) at Sep. 30, 2022	547,006,076	547,006,076
Ending balance at Sep. 30, 2022	$ 16,384	$ 1,368	7,979	7,128	(91)
Balance (in shares) at Jun. 30, 2022		546,807,793
Beginning balance at Jun. 30, 2022	15,971	$ 1,367	7,960	6,747	(103)
Increase (Decrease) in Stockholders' Equity
Net income	649			649
Other comprehensive income	12				12
Dividends declared on common stock (USD per share)		$ 0.4875
Dividends declared on common stock	(267)			(267)
Issuances of common stock (in shares)		198,283
Issuances of common stock	14	$ 1	13
Share-based compensation	$ 5		6	(1)
Balance (in shares) at Sep. 30, 2022	547,006,076	547,006,076
Ending balance at Sep. 30, 2022	$ 16,384	$ 1,368	$ 7,979	$ 7,128	$ (91)

Management's Opinion

Management's Opinion	9 Months Ended
	Sep. 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 Xcel Energy as of Sept. 30, 2022 and Dec. 31, 2021; the results of Xcel Energy’s operations, including the components of net income, comprehensive income, and changes in stockholders’ equity for the three and nine months ended Sept. 30, 2022 and 2021; and Xcel Energy’s cash flows for the nine months ended Sept. 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 Sept. 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 Xcel Energy Inc. 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 Xcel Energy Inc. 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 Xcel Energy’s electric and natural gas sales, interim results are not necessarily an appropriate base from which to project annual results.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 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 Xcel Energy Inc. 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.

Accounting Pronouncements

Accounting Pronouncements	9 Months Ended
	Sep. 30, 2022
Accounting Standards Update and Change in Accounting Principle [Abstract]
Accounting Pronouncements	As of Sept. 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 Xcel Energy’s consolidated financial statements.

Selected Balance Sheet Data

Selected Balance Sheet Data	9 Months Ended
	Sep. 30, 2022
Balance Sheet Related Disclosures [Abstract]
Selected Balance Sheet Data	(Millions of Dollars) Sept. 30, 2022 Dec. 31, 2021 Accounts receivable, net Accounts receivable $ 1,308 $ 1,124 Less allowance for bad debts (112) (106) Accounts receivable, net $ 1,196 $ 1,018 (Millions of Dollars) Sept. 30, 2022 Dec. 31, 2021 Inventories Materials and supplies $ 321 $ 289 Fuel 234 182 Natural gas 315 160 Total inventories $ 870 $ 631 (Millions of Dollars) Sept. 30, 2022 Dec. 31, 2021 Property, plant and equipment, net Electric plant $ 48,959 $ 48,680 Natural gas plant 8,199 7,758 Common and other property 2,824 2,602 Plant to be retired (a) 2,258 1,200 Construction work in progress 2,445 1,969 Total property, plant and equipment 64,685 62,209 Less accumulated depreciation (17,639) (17,060) Nuclear fuel 3,105 3,081 Less accumulated amortization (2,864) (2,773) Property, plant and equipment, net $ 47,287 $ 45,457

Borrowings and Other Financing

Borrowings and Other Financing Instruments	9 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Borrowings and Other Financing Instruments	Short-Term Borrowings Short-Term Debt — Xcel Energy Inc. and its utility subsidiaries meet their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings under their credit facilities and term loan agreements. Commercial paper and term loan borrowings outstanding for Xcel Energy: (Amounts in Millions, Except Interest Rates) Three Months Ended Sept. 30, 2022 Year Ended Dec. 31, 2021 Borrowing limit $ 3,550 $ 3,100 Amount outstanding at period end 158 1,005 Average amount outstanding 187 1,399 Maximum amount outstanding 329 2,054 Weighted average interest rate, computed on a daily basis 2.51 % 0.57 % Weighted average interest rate at period end 3.40 0.31 Letters of Credit — Xcel Energy Inc. and its utility subsidiaries use letters of credit, generally with terms of one year, to provide financial guarantees for certain obligations. There we re $39 million and $19 million of letters of credit outstanding under the cr edit facilities at Sept. 30, 2022 and Dec. 31, 2021, respectively. Amounts approximate their fair value and are subject to fees. Revolving Credit Facilities — In order to issue commercial paper, Xcel Energy Inc. and its utility subsidiaries must have revolving credit facilities at least equal to the amount of commercial paper borrowing limits and cannot issue commercial paper exceeding available credit facility capacity. The lines of credit provide short-term financing in the form of notes payable to banks, letters of credit and back-up support for commercial paper borrowings. Amended Credit Agreements — In September 2022, Xcel Energy Inc., NSP-Minnesota, NSP-Wisconsin, PSCo and SPS each entered into an amended five-year credit agreement with a syndicate of banks. The aggregate borrowing limit was increased to $3.55 billion. The amended credit agreements have substantially the same terms and conditions as the prior agreements, with the following changes: • Maturities were extended from June 2024 to September 2027. • Borrowing limit for Xcel Energy Inc. was increased from $1.25 billion to $1.5 billion. • Borrowing limit for NSP-Minnesota was increased from $500 million to $700 million. As of Sept. 30, 2022, Xcel Energy Inc. and its utility subsidiaries had the following committed revolving credit facilities available: (Millions of Dollars) Credit Facility (a) Drawn (b) Available Xcel Energy Inc. $ 1,500 $ 158 $ 1,342 PSCo 700 26 674 NSP-Minnesota 700 11 689 SPS 500 2 498 NSP-Wisconsin 150 — 150 Total $ 3,550 $ 197 $ 3,353 (a) Expires in September 2027. (b) Includes outstanding commercial paper and letters of credit. Xcel Energy Inc., NSP-Minnesota, PSCo, and SPS each have the right to request an extension of the credit facility termination date for two additional one-year periods. NSP-Wisconsin has the right to request an extension of the credit facility termination date for an additional one-year period. All extension requests are subject to majority bank group approval. All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity of the credit facility. Xcel Energy Inc. and its utility subsidiaries had no direct advances on the credit facilities outstanding as of Sept. 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 Sept. 30, 2022, NSP-Minnesota had $50 million of outstanding letters of credit under the $75 million bilateral credit agreement. Long-Term Borrowings and Other Financing Instruments During the nine months ended September 30, 2022, Xcel Energy Inc. and its utility subsidiaries issued the following: • Xcel Energy issued $700 million of 4.60% unsecured senior notes due June 1, 2032. • NSP-Minnesota issued $500 million of 4.50% first mortgage bonds due June 1, 2052. • PSCo issued $300 million of 4.10% first mortgage bonds due June 1, 2032 and $400 million of 4.50% first mortgage bonds due June 1, 2052. • SPS issued $200 million of 5.15% first mortgage bonds due June 1, 2052. • NSP-Wisconsin issued $100 million of 4.86% first mortgage bonds due September 15, 2052. ATM Equity Offering — In November 2021, Xcel Energy Inc. filed a prospectus supplement under which it may sell up to $800 million of its common stock through an ATM program. In 2021, 5.33 million shares were issued (approximately $350 million). In the second quarter of 2022, 2.13 million shares of common stock were issued (approximately $150 million). As of Sept. 30, 2022, approximately $300 million remained available for sale under the ATM program. Other Equity —

Revenues

Revenues	9 Months Ended
	Sep. 30, 2022
Revenue from Contract with Customer [Abstract]
Revenues	Revenue is classified by the type of goods/services rendered and market/customer type. Xcel Energy’s operating revenues consisted of the following: Three Months Ended Sept. 30, 2022 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 1,109 $ 181 $ 15 $ 1,305 C&I 1,734 116 6 1,856 Other 42 — 2 44 Total retail 2,885 297 23 3,205 Wholesale 450 — — 450 Transmission 210 — — 210 Other 20 43 — 63 Total revenue from contracts with customers 3,565 340 23 3,928 Alternative revenue and other 134 17 3 154 Total revenues $ 3,699 $ 357 $ 26 $ 4,082 Three Months Ended Sept. 30, 2021 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 999 $ 133 $ 12 $ 1,144 C&I 1,515 76 7 1,598 Other 35 — 1 36 Total retail 2,549 209 20 2,778 Wholesale 288 — — 288 Transmission 167 — — 167 Other 17 45 — 62 Total revenue from contracts with customers 3,021 254 20 3,295 Alternative revenue and other 155 14 3 172 Total revenues $ 3,176 $ 268 $ 23 $ 3,467 Nine Months Ended Sept. 30, 2022 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 2,723 $ 1,100 $ 30 $ 3,853 C&I 4,385 636 15 5,036 Other 111 — 25 136 Total retail 7,219 1,736 70 9,025 Wholesale 1,027 — — 1,027 Transmission 518 — — 518 Other 55 125 — 180 Total revenue from contracts with customers 8,819 1,861 70 10,750 Alternative revenue and other 436 62 9 507 Total revenues $ 9,255 $ 1,923 $ 79 $ 11,257 Nine Months Ended Sept. 30, 2021 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 2,488 $ 774 $ 33 $ 3,295 C&I 3,830 389 22 4,241 Other 96 — 5 101 Total retail 6,414 1,163 60 7,637 Wholesale 1,265 — — 1,265 Transmission 461 — — 461 Other 51 106 — 157 Total revenue from contracts with customers 8,191 1,269 60 9,520 Alternative revenue and other 452 95 9 556 Total revenues $ 8,643 $ 1,364 $ 69 $ 10,076

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Income Taxes	Reconciliation between the statutory rate and ETR: Three Months Ended Sept. 30 Nine Months Ended Sept. 30 2022 2021 2022 2021 Federal statutory rate 21.0 % 21.0 % 21.0 % 21.0 % State tax (net of federal tax effect) 4.9 5.0 4.9 5.0 Decreases: Wind PTCs (a) (12.3) (12.1) (25.2) (20.0) Plant regulatory differences (b) (5.8) (5.8) (5.5) (6.0) Other tax credits, net operating loss & tax credits allowances (1.2) (1.2) (1.4) (1.1) Other (net) (0.3) (0.3) (0.1) (0.2) Effective income tax rate 6.3 % 6.6 % (6.3) % (1.3) % (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.

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2022
Earnings Per Share [Abstract]
Earnings Per Share	Basic EPS was computed by dividing the earnings available to common shareholders by the average weighted number of common shares outstanding. Diluted EPS was computed by dividing the earnings available to common shareholders by the diluted weighted average number of common shares outstanding. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock (i.e., common stock equivalents) were settled. The weighted average number of potentially dilutive shares outstanding used to calculate diluted EPS is calculated using the treasury stock method. Common Stock Equivalents — Xcel Energy Inc. has common stock equivalents related to time-based equity compensation awards. Stock equivalent units granted to Xcel Energy Inc.’s Board of Directors are included in common shares outstanding upon grant date as there is no further service, performance or market condition associated with these awards. Restricted stock issued to employees is included in common shares outstanding when granted. Share-based compensation arrangements for which there is currently no dilutive impact to EPS include the following: • Equity awards subject to a performance condition; included in common shares outstanding when all necessary conditions have been satisfied by the end of the reporting period. • Liability awards subject to a performance condition; any portions settled in shares are included in common shares outstanding upon settlement. Common shares outstanding used in the basic and diluted EPS computation: Three Months Ended Sept. 30 Nine Months Ended Sept. 30 (Shares in Millions) 2022 2021 2022 2021 Basic 548 539 546 539 Diluted (a) 548 539 546 539 (a) Diluted common shares outstanding included common stock equivalents of 0.3 million for the three months ended September 30, 2022 and 2021, respectively. Diluted common shares outstanding included common stock equivalents of

Fair Value of Financial Assets

Fair Value of Financial Assets and Liabilities	9 Months Ended
	Sep. 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 fund 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 — 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 and SPS include transmission congestion instruments, generally referred to as FTRs. FTRs purchased from an RTO are financial instruments that entitle or obligate the holder to monthly revenues or charges based on transmission congestion across a given transmission path. Non-Derivative Fair Value Measurements The NRC 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 $900 million and $1.3 billion as of Sept. 30, 2022 and Dec. 31, 2021, respectively, and unrealized losses were $133 million and $7 million as of Sept. 30, 2022 and Dec. 31, 2021, respectively. Non-derivative instruments with recurring fair value measurements in the nuclear decommissioning fund: Sept. 30, 2022 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 NAV Total Nuclear decommissioning fund (a) Cash equivalents $ 37 $ 37 $ — $ — $ — $ 37 Commingled funds 832 — — — 1,167 1,167 Debt securities 696 — 611 9 — 620 Equity securities 409 918 1 — — 919 Total $ 1,974 $ 955 $ 612 $ 9 $ 1,167 $ 2,743 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $214 million of equity method investments and $126 million of rabbi trust assets and miscellaneous investments. 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 $208 million of equity method investments and $164 million of rabbi trust assets and other miscellaneous investments. For the three and nine months ended Sept. 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 Sept. 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 $ 5 $ 190 $ 227 $ 198 $ 620 Rabbi Trusts Xcel Energy has established rabbi trusts to provide partial funding for future distributions of its supplemental executive retirement plan and deferred compensation plan. Cost and fair value of assets held in rabbi trusts: Sept. 30, 2022 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 Total Rabbi Trusts (a) Cash equivalents $ 1 $ 1 $ — $ — $ 1 Mutual funds 75 73 — — 73 Total $ 76 $ 74 $ — $ — $ 74 Dec. 31, 2021 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 Total Rabbi Trusts (a) Cash equivalents $ 20 $ 20 $ — $ — $ 20 Mutual funds 75 89 — — 89 Total $ 95 $ 109 $ — $ — $ 109 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets. Derivative Instruments Fair Value Measurements Xcel Energy 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 — Xcel Energy 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. As of Sept. 30, 2022, accumulated other comprehensive loss related to interest rate derivatives included $2 million of net losses expected to be reclassified into earnings during the next 12 months as the hedged transactions impact earnings. As of Sept. 30, 2022, Xcel Energy had no unsettled interest rate derivatives. Wholesale and Commodity Trading Risk — Xcel Energy Inc.’s utility subsidiaries conduct 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. Xcel Energy 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 — Xcel Energy 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. Xcel Energy 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. As of Sept. 30, 2022, Xcel Energy had no commodity contracts designated as cash flow hedges. Xcel Energy 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) Sept. 30, 2022 Dec. 31, 2021 Megawatt hours of electricity 82 80 Million British thermal units of natural gas 151 156 (a) Not reflective of net positions in the underlying commodities. (b) Notional amounts for options included on a gross basis but weighted for the probability of exercise. Consideration of Credit Risk and Concentrations — Xcel Energy 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 in the consolidated balance sheets. Xcel Energy’s utility subsidiaries’ most significant concentrations of credit risk with particular entities or industries are contracts with counterparties to their wholesale, trading and non-trading commodity activities. As of Sept. 30, 2022, five of Xcel Energy’s ten most significant counterparties for these activities, comprising $86 million, or 30%, of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings. Three of the ten most significant counterparties, comprising $61 million, or 22%, of this credit exposure, were not rated by these external ratings agencies, but based on Xcel Energy’s internal analysis, had credit quality consistent with investment grade. Two of these significant counterparties, comprising $68 million, or 24%, of this credit exposure, had credit quality less than investment grade, based on internal analysis. Six of these significant counterparties are municipal or cooperative electric entities, RTOs or other utilities. Impact of Derivative Activity — Pre-Tax Fair Value Gains (Losses) Recognized During the Period in: (Millions of Dollars) Accumulated Other Comprehensive Loss Regulatory (Assets) and Liabilities Three Months Ended Sept. 30, 2022 Other derivative instruments: Electric commodity $ — $ 6 Natural gas commodity — (6) Total $ — $ — Nine Months Ended Sept. 30, 2022 Derivatives designated as cash flow hedges: Interest rate $ 21 $ — Total $ 21 $ — Other derivative instruments: Electric commodity $ — $ 106 Natural gas commodity — (3) Total $ — $ 103 Three Months Ended Sept. 30, 2021 Derivatives designated as cash flow hedges: Interest rate $ 4 $ — Total $ 4 $ — Other derivative instruments: Electric commodity $ — $ 5 Natural gas commodity — 57 Total $ — $ 62 Nine Months Ended Sept. 30, 2021 Derivatives designated as cash flow hedges: Interest rate $ 5 $ — Total $ 5 $ — Other derivative instruments: Electric commodity $ — $ 18 Natural gas commodity — 57 Total $ — $ 75 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 Sept. 30, 2022 Derivatives designated as cash flow hedges: Interest rate $ 1 (a) $ — $ — Total $ 1 $ — $ — Other derivative instruments: Commodity trading $ — $ — $ 13 (b) Electric commodity — 6 (c) — Total $ — $ 6 $ 13 Nine Months Ended Sept. 30, 2022 Derivatives designated as cash flow hedges: Interest rate $ 5 (a) $ — $ — Total $ 5 $ — $ — Other derivative instruments: Commodity trading $ — $ — $ 21 (b) Electric commodity — (31) (c) — Natural gas commodity — 4 (d) (17) (d)(e) Total $ — $ (27) $ 4 Three Months Ended Sept. 30, 2021 Derivatives designated as cash flow hedges: Interest rate $ 2 (a) $ — $ — Total $ 2 $ — $ — Other derivative instruments: Commodity trading $ — $ — $ 1 (b) Electric commodity — 3 (c) — Total $ — $ 3 $ 1 Nine Months Ended Sept. 30, 2021 Derivatives designated as cash flow hedges: Interest rate $ 7 (a) $ — $ — Total $ 7 $ — $ — Other derivative instruments: Commodity trading $ — $ — $ 49 (b) Electric commodity — (26) (c) — Natural gas commodity — 8 (d) (10) (d)(e) Total $ — $ (18) $ 39 (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. Xcel Energy had no derivative instruments designated as fair value hedges during the nine months ended Sept. 30, 2022 and 2021. Credit Related Contingent Features — Contract provisions for derivative instruments that the utility subsidiaries enter, 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 the applicable utility subsidiary’s credit ratings are downgraded below its investment grade credit rating by any of the major credit rating agencies. At Sept. 30, 2022 and Dec. 31, 2021, there were $5 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 other financing arrangements related to payment terms or other covenants. As of Sept. 30, 2022 and Dec. 31, 2021, there were approximately $90 million and $64 million, respectively, of derivative liabilities with such underlying contract provisions. Certain derivative instruments are also subject to contract provisions that contain adequate assurance clauses. These provisions allow counterparties to seek performance assurance, including cash collateral, in the event that a given utility subsidiary’s ability to fulfill its contractual obligations is reasonably expected to be impaired. Xcel Energy had no collateral posted related to adequate assurance clauses in derivative contracts as of Sept. 30, 2022 and Dec. 31, 2021 . Recurring Fair Value Measurements — Derivative assets and liabilities measured at fair value on a recurring basis were as follows: Sept. 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 $ 53 $ 184 $ 47 $ 284 $ (211) $ 73 $ 22 $ 137 $ 21 $ 180 $ (134) $ 46 Electric commodity (b) — — 358 358 (4) 354 — — 57 57 (1) 56 Natural gas commodity — 26 — 26 — 26 — 18 — 18 — 18 Total current derivative assets $ 53 $ 210 $ 405 $ 668 $ (215) 453 $ 22 $ 155 $ 78 $ 255 $ (135) 120 PPAs (c) 3 3 Current derivative instruments $ 456 $ 123 Noncurrent derivative assets Other derivative instruments: Commodity trading $ 50 $ 64 $ 92 $ 206 $ (120) $ 86 $ 16 $ 63 $ 89 $ 168 $ (107) $ 61 Total noncurrent derivative assets $ 50 $ 64 $ 92 $ 206 $ (120) 86 $ 16 $ 63 $ 89 $ 168 $ (107) 61 PPAs (c) 4 6 Noncurrent derivative instruments $ 90 $ 67 Sept. 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 $ 44 $ 223 $ 23 $ 290 $ (219) $ 71 $ 19 $ 148 $ 20 $ 187 $ (143) $ 44 Electric commodity (b) — — 4 4 (4) — — — 1 1 (1) — Natural gas commodity — 12 — 12 — 12 — 8 — 8 — 8 Total current derivative liabilities $ 44 $ 235 $ 27 $ 306 $ (223) 83 $ 19 $ 156 $ 21 $ 196 $ (144) 52 PPAs (c) 17 17 Current derivative instruments $ 100 $ 69 Noncurrent derivative liabilities Other derivative instruments: Commodity trading $ 59 $ 86 $ 68 $ 213 $ (132) $ 81 $ 18 $ 48 $ 127 $ 193 $ (128) $ 65 Total noncurrent derivative liabilities $ 59 $ 86 $ 68 $ 213 $ (132) 81 $ 18 $ 48 $ 127 $ 193 $ (128) 65 PPAs (c) 33 40 Noncurrent derivative instruments $ 114 $ 105 (a) Xcel Energy nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At Sept. 30, 2022 and Dec. 31, 2021, derivatives include $2 million and no obligations to return cash collateral, respectively. At Sept. 30, 2022 and Dec. 31, 2021, derivative assets and liabilities include rights to reclaim cash collateral of $22 million and $30 million, respectively. Counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. (b) Amounts relate to FTR instruments administered by MISO and SPP (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, fair values for FTRs are offset/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, contracts are no longer adjusted to fair value and the previous carrying value of these contracts is being amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities. Changes in Level 3 commodity derivatives: Three Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Balance at July 1 $ 485 $ 71 Purchases / Issuances (a) 4 2 Settlements (a) (106) (53) Net transactions recorded during the period: Gains recognized in earnings (b) 16 12 Net gains recognized as regulatory assets and liabilities (a) 3 27 Balance at Sept. 30 $ 402 $ 59 Nine Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Balance at Jan. 1 $ 19 $ (49) Purchases / Issuances (a) 398 65 Settlements (a) (286) (101) Net transactions recorded during the period: Gains recognized in earnings (b) 136 59 Net gains recognized as regulatory assets and liabilities (a) 135 85 Balance at Sept. 30 $ 402 $ 59 (a) Relates primarily to FTR instruments administered by MISO and SPP (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. Xcel Energy recognizes transfers between levels as of the beginning of each period. There were no transfers of amounts between levels for derivative instruments for the nine months ended Sept. 30, 2022 and 2021. Fair Value of Long-Term Debt Other financial instruments for which the carrying amount did not equal fair value: Sept. 30, 2022 Dec. 31, 2021 (Millions of Dollars) Carrying Amount Fair Value Carrying Amount Fair Value Long-term debt, including current portion $ 23,960 $ 20,560 $ 22,380 $ 25,232 Fair value of Xcel Energy’s long-term debt is estimated based on recent trades and observable spreads from benchmark interest rates for similar securities. Fair value estimates are based on information available to management as of Sept. 30, 2022 and Dec. 31, 2021 and given the observability of the inputs, fair values presented for long-term debt were assigned as Level 2.

Benefit Plans and Other Postret

Benefit Plans and Other Postretirement Benefits	9 Months Ended
	Sep. 30, 2022
Retirement Benefits [Abstract]
Benefit Plans and Other Postretirement Benefits	Components of Net Periodic Benefit Cost (Credit) Three Months Ended Sept. 30 2022 2021 2022 2021 (Millions of Dollars) Pension Benefits Postretirement Health Service cost $ 24 $ 26 $ — $ — Interest cost (a) 28 26 3 4 Expected return on plan assets (a) (52) (52) (4) (4) Amortization of prior service credit (a) — — (2) (2) Amortization of net loss (a) 19 27 1 1 Settlement charge (b) 55 39 — — Net periodic benefit cost (credit) 74 66 (2) (1) Effects of regulation (37) (31) 1 1 Net benefit cost (credit) recognized for financial reporting $ 37 $ 35 $ (1) $ — Nine Months Ended Sept. 30 2022 2021 2022 2021 (Millions of Dollars) Pension Benefits Postretirement Health Service cost $ 73 $ 78 $ 1 $ 1 Interest cost (a) 83 78 11 11 Expected return on plan assets (a) (156) (155) (13) (13) Amortization of prior service credit (a) (1) (1) (5) (6) Amortization of net loss (a) 56 81 2 4 Settlement charge (b) 54 39 — — Net periodic benefit cost (credit) 109 120 (4) (3) Effects of regulation (30) (32) 2 2 Net benefit cost (credit) recognized for financial reporting $ 79 $ 88 $ (2) $ (1) (a) The components of net periodic cost other than the service cost component are included in the line item “Other income, net” in the consolidated statements of income or capitalized on the consolidated balance sheets as a regulatory asset. (b) A settlement charge is required when the amount of all lump-sum distributions during the year is greater than the sum of the service and interest cost components of the annual net periodic pension cost. In the third quarter of 2022 and 2021, as a result of lump-sum distributions during the 2022 and 2021 plan years, Xcel Energy recorded pension settlement charges of $55 million and $39 million, respectively, the majority of which were not recognized in earnings due to the effects of regulation. A total of $7 million and $4 million of those amounts were recorded in other expense in the third quarter of 2022 and 2021, respectively.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Legal Xcel Energy 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 Xcel Energy’s consolidated financial statements. Legal fees are generally expensed as incurred. Gas Trading Litigation — e prime is a wholly owned subsidiary of Xcel Energy. e prime was in the business of natural gas trading and marketing but has not engaged in natural gas trading or marketing activities since 2003. Multiple lawsuits involving multiple plaintiffs seeking monetary damages were commenced against e prime and its affiliates, including Xcel Energy, between 2003 and 2009 alleging fraud and anticompetitive activities in conspiring to restrain the trade of natural gas and manipulate natural gas prices. Cases were all consolidated in the U.S. District Court in Nevada. One case remains active which includes a multi-district litigation matter consisting of a Wisconsin purported class (Arandell Corp.). The Court issued a ruling on June 30, 2022 granting plaintiffs’ class certification. Defendants will work together to prepare and file a petition appealing the class certification ruling to the Seventh Circuit. Xcel Energy has concluded that a loss is remote for the remaining lawsuit. Comanche Unit 3 Litigation — In September 2021, CORE filed a lawsuit in Denver County District Court. CORE alleges PSCo breached ownership agreement terms by failing to operate Comanche Unit 3 in accordance with prudent utility practices. In January 2022, the Court granted PSCo’s motion and dismissed CORE’s claims for unjust enrichment, declaratory judgment and damages for replacement power costs. In February 2022, CORE disclosed that it is claiming in excess of $125 million in total damages. In April 2022, CORE filed a supplement to include the January 2022 outage. It claims additional undisclosed damages arising from this event. PSCo continues to believe CORE's claims are without merit. Rate Matters and Other Xcel Energy’s operating subsidiaries are involved in various regulatory proceedings arising in the ordinary course of business. Until resolution, typically in the form of a rate order, uncertainties may exist regarding the ultimate rate treatment for certain activities and transactions. Amounts have been recognized for probable and reasonably estimable losses that may result. Unless otherwise disclosed, any reasonably possible range of loss in excess of any recognized amount is not expected to have a material effect on the consolidated financial statements. Sherco — In 2018, NSP-Minnesota and SMMPA (Co-owner of Sherco Unit 3) reached a settlement with GE related to a 2011 incident, which damaged the turbine at Sherco Unit 3 and resulted in an extended outage for repair. NSP-Minnesota notified the MPUC of its proposal to refund settlement proceeds to customers through the fuel clause adjustment. In March 2019, the MPUC approved NSP-Minnesota’s settlement refund proposal. Additionally, the MPUC decided to withhold any decision as to NSP-Minnesota’s prudence in connection with the incident at Sherco Unit 3 until after conclusion of an appeal pending between GE and NSP-Minnesota’s insurers. In February 2020, the Minnesota Court of Appeals affirmed the district court’s judgment in favor of GE. In 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. 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 subsequently issued various related orders (including Opinion Nos. 569, 569A and 569B) related to ROE methodology/calculations and timing. NSP-Minnesota has processed refunds to customers for applicable complaint periods based on the ROE in the most recent applicable opinions. 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. In August 2022, the D.C. Circuit ruled that FERC had not adequately supported its conclusions, vacated FERC’s related orders, and remanded the issue back to FERC for further proceedings, which remain pending. SPP OATT Upgrade Costs — Costs of transmission upgrades may be recovered from other SPP customers whose transmission service depends on capacity enabled by the upgrade under the SPP OATT. SPP had not been charging its customers for these upgrades, even though the SPP OATT had allowed SPP to do so since 2008. In 2016, the FERC granted SPP’s request to recover these previously unbilled charges and SPP subsequently billed SPS approximately $13 million. In July 2018, SPS’ appeal to the D.C. Circuit over the FERC rulings granting SPP the right to recover previously unbilled charges was remanded to the FERC. In February 2019, the FERC reversed its 2016 decision and ordered SPP to refund charges retroactively collected from its transmission customers, including SPS, related to periods before September 2015. In March 2020, SPP and Oklahoma Gas & Electric separately filed petitions for review of the FERC’s orders at the D.C. Circuit. In August 2021, the D.C. Circuit issued a decision denying these appeals and upholding the FERC’s orders. Refunds received by SPS are expected to be given back to SPS customers through future rates. In October 2017, SPS filed a separate related complaint asserting SPP assessed upgrade charges to SPS in violation of the SPP OATT. In March 2018, the FERC issued an order denying the SPS complaint. SPS filed a request for rehearing in April 2018. The FERC issued a tolling order granting a rehearing for further consideration in May 2018. If SPS’ complaint results in additional charges or refunds, SPS will seek to recover or refund the amount through future SPS customer rates. In October 2020, SPS filed a petition for review of the FERC’s March 2018 order and May 2018 tolling order at the D.C. Circuit. In February 2022, FERC issued an order rejecting SPS’ request for hearing. SPS has appealed that order. That appeal has been combined with SPS’ prior appeal. Contract Termination — SPS and LP&L have a 25-year, 170 MW partial requirements contract. In May 2021, SPS and LP&L finalized a settlement which would terminate the contract upon LP&L’s move from the SPP to the Electric Reliability Council of Texas (expected in 2023). The settlement agreement requires LP&L to pay SPS $78 million, to the benefit of SPS’ remaining customers. LP&L would remain obligated to pay for SPP transmission charges associated with LP&L’s load in SPP. The agreement is subject to approval by the PUCT and FERC. Approval steps are in process, but approval timing from the PUCT is uncertain. Environmental MGP, Landfill and Disposal Sites Xcel Energy is investigating, remediating or performing post-closure actions at 14 MGP, landfill or other disposal sites across its service territories, excluding sites that are being addressed under current coal ash regulations (see below). Xcel Energy 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 — Xcel Energy’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 applicable landfills and surface impoundments as well as perform corrective actions where offsite groundwater has been impacted. As of Sept. 30, 2022, Xcel Energy had eight regulated ash units in operation. PSCo is currently exploring an agreement with a third party that would excavate and process ash for beneficial use (at two sites) at a cost of approximately $43 million. An estimated liability has been recorded and amounts are expected to be fully recoverable through regulatory mechanisms. Investigation and feasibility studies for additional corrective action related to offsite groundwater are ongoing (at two sites). While the results are uncertain, additional costs are estimated to be up to $35 million. An estimated liability has been recorded for the portion of these actions that are estimable, and are expected to be fully recoverable through regulatory mechanisms. Federal Clean Water Act Section 316(b) — The Federal Clean Water Act requires the EPA to regulate cooling water intake structures to assure they reflect the best technology available for minimizing impingement and entrainment of aquatic species. Estimated capital expenditures of approximately $40 million may be required to comply with the requirements. Xcel Energy anticipates these costs will be recoverable through regulatory mechanisms. Environmental Requirements — Air Reasonable Progress Rule: In 2016, the EPA adopted a final rule establishing a federal implementation plan for reasonable further progress under the regional haze program for the state of Texas. The rule imposes sulfur dioxide emission limitations which would require the installation of dry scrubbers on Tolk Units 1 and 2; compliance would have been required by February 2021. SPS appealed the EPA’s decision and obtained a stay of the final rule. In 2017, the Fifth Circuit remanded the rule to the EPA for reconsideration (leaving the stay in effect). In a future rulemaking, the EPA may address whether further sulfur dioxide emission reductions are necessary. Leases Xcel Energy 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 Sept. 30 (Millions of Dollars) 2022 2021 Operating leases PPA capacity payments $ 59 $ 56 Other operating leases (a) 8 2 Total operating lease expense (b) $ 67 $ 58 Finance leases Amortization of ROU assets $ 1 $ 2 Interest expense on lease liability 4 4 Total finance lease expense $ 5 $ 6 (a) Includes short-term lease expense o f $1 million for 2022 and 2021. (b) PPA capacity payments are included in electric fuel and purchased power on the consolidated statements of income. Expense for other operating leases is included in O&M expense and electric fuel and purchased power. Nine Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Operating leases PPA capacity payments $ 182 $ 170 Other operating leases (a) 28 19 Total operating lease expense (b) $ 210 $ 189 Finance leases Amortization of ROU assets $ 3 $ 6 Interest expense on lease liability 12 12 Total finance lease expense $ 15 $ 18 (a) Includes short-term lease expense o f $4 million for 2022 and 2021. (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 and finance leases as of Sept. 30, 2022: (Millions of Dollars) PPA Operating Other Operating Total Operating Finance Leases (a) Total minimum obligation $ 1,246 $ 166 $ 1,412 $ 239 Interest component of obligation (174) (30) (204) (169) Present value of minimum obligation $ 1,072 136 1,208 70 Less current portion (211) (4) Noncurrent operating and finance lease liabilities $ 997 $ 66 (a) Excludes certain amounts related to Xcel Energy’s 50% ownership interest in WYCO. Variable Interest Entities Under certain PPAs, NSP-Minnesota, PSCo and SPS purchase power from IPPs for which the utility subsidiaries are required to reimburse fuel costs, or to participate in tolling arrangements under which the utility subsidiaries procure the natural gas required to produce the energy that they purchase. These specific PPAs create a variable interest in the IPP. The utility subsidiaries had approxi ma tely 3,961 MW an d 4,062 MW of capacity under long-term PPAs at Sept. 30, 2022 and Dec. 31, 2021, respectively, with entities that have been determined to be variable interest entities. Xcel Energy 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 2041. Other Guarantees and Bond Indemnifications — Xcel Energy provides guarantees and bond indemnities, which guarantee payment or performance. Xcel Energy Inc.’s exposure is based upon the net liability under the agreements. Most of the guarantees and bond indemnities issued by Xcel Energy have a stated maximum amount. As of Sept. 30, 2022 and Dec. 31, 2021, Xcel Energy had no assets held as collateral related to their guarantees, bond indemnities and indemnification agreements. Guarantees and bond indemnities issued and outstanding for Xcel Energy were approximately $62 million and $60 million at Sept. 30, 2022 and Dec. 31, 2021, respectively . Other Indemnification Agreements — Xcel Energy provides indemnifications through various contracts. These are primarily indemnifications against adverse litigation outcomes in connection with underwriting agreements, as well as breaches of representations and warranties, including corporate existence, transaction authorization and income tax matters with respect to assets sold. Xcel Energy’s obligations under these agreements may be limited in duration and amount. Maximum future payments under these indemnifications cannot be reasonably estimated.

Other Comprehensive Income (Los

Other Comprehensive Income (Loss)	9 Months Ended
	Sep. 30, 2022
Stockholders' Equity Note [Abstract]
Other Comprehensive Income (Loss)	Changes in accumulated other comprehensive loss, net of tax, for the three and nine months ended Sept. 30, 2022 and 2021: Three Months Ended Sept. 30, 2022 Three Months Ended Sept. 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 July 1 $ (57) $ (46) $ (103) $ (80) $ (55) $ (135) Other comprehensive gain before reclassifications — 10 10 3 — 3 Losses reclassified from net accumulated other comprehensive loss: Interest rate derivatives (a) 1 — 1 2 — 2 Amortization of net actuarial loss (b) — 1 1 — 4 4 Net current period other comprehensive income 1 11 12 5 4 9 Accumulated other comprehensive loss at Sept. 30 $ (56) $ (35) $ (91) $ (75) $ (51) $ (126) Nine Months Ended Sept. 30, 2022 Nine Months Ended Sept. 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 $ (75) $ (48) $ (123) $ (85) $ (56) $ (141) Other comprehensive gain before reclassifications 15 11 26 4 — 4 Losses reclassified from net accumulated other comprehensive loss: Interest rate derivatives (a) 4 — 4 6 — 6 Amortization of net actuarial loss (b) — 2 2 — 5 5 Net current period other comprehensive income 19 13 32 10 5 15 Accumulated other comprehensive loss at Sept. 30 $ (56) $ (35) $ (91) $ (75) $ (51) $ (126) (a) Included in interest charges.

Segment Information

Segment Information	9 Months Ended
	Sep. 30, 2022
Segment Reporting [Abstract]
Segment Information	Xcel Energy evaluates performance by each utility subsidiary based on profit or loss generated from the product or service provided including the regulated electric utility operating results of NSP-Minnesota, NSP-Wisconsin, PSCo and SPS, as well as the regulated natural gas utility operating results of NSP-Minnesota, NSP-Wisconsin and PSCo. These segments are managed separately because the revenue streams are dependent upon regulated rate recovery, which is separately determined for each segment. Xcel Energy has the following reportable segments: • Regulated Electric — The regulated electric utility segment generates, transmits and distributes electricity in Minnesota, Wisconsin, Michigan, North Dakota, South Dakota, Colorado, Texas and New Mexico. 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 wholesale commodity and trading operations. • Regulated Natural Gas — The regulated natural gas utility segment transports, stores and distributes natural gas primarily in portions of Minnesota, Wisconsin, North Dakota, Michigan and Colorado. Xcel Energy also presents All Other, which includes operating segments with revenues below the necessary quantitative thresholds. Those operating segments primarily include steam revenue, appliance repair services, non-utility real estate activities, revenues associated with processing solid waste into refuse-derived fuel and investments in rental housing projects that qualify for low-income housing tax credits. Xcel Energy had equity method investments of $214 million and $208 million as of Sept. 30, 2022 and Dec. 31, 2021, respectively, included in the natural gas utility and all other segments. Asset and capital expenditure information is not provided for Xcel Energy’s reportable segments. As an integrated electric and natural gas utility, Xcel Energy 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. Xcel Energy’s segment information: Three Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Regulated Electric Total revenues $ 3,699 $ 3,176 Net income 697 629 Regulated Natural Gas Operating revenues $ 357 $ 268 Intersegment revenue 1 1 Total revenues $ 358 $ 269 Net (loss) income (7) 10 All Other Total revenues $ 26 $ 23 Net loss (41) (30) Consolidated Total Total revenues $ 4,083 $ 3,468 Reconciling eliminations (1) (1) Total operating revenues $ 4,082 $ 3,467 Net income 649 609 Nine Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Regulated Electric Operating revenues $ 9,255 $ 8,643 Intersegment revenue 1 1 Total revenues $ 9,256 $ 8,644 Net income 1,312 1,202 Regulated Natural Gas Operating revenues $ 1,923 $ 1,364 Intersegment revenue 1 2 Total revenues $ 1,924 $ 1,366 Net income 148 161 All Other Total operating revenue $ 79 $ 69 Net loss (103) (81) Consolidated Total Total revenues $ 11,259 $ 10,079 Reconciling eliminations (2) (3) Total operating revenues $ 11,257 $ 10,076 Net income 1,357 1,282

Selected Balance Sheet Data (Ta

Selected Balance Sheet Data (Tables)	9 Months Ended
	Sep. 30, 2022
Balance Sheet Related Disclosures [Abstract]
Accounts receivable, net	(Millions of Dollars) Sept. 30, 2022 Dec. 31, 2021 Accounts receivable, net Accounts receivable $ 1,308 $ 1,124 Less allowance for bad debts (112) (106) Accounts receivable, net $ 1,196 $ 1,018
Inventories	(Millions of Dollars) Sept. 30, 2022 Dec. 31, 2021 Inventories Materials and supplies $ 321 $ 289 Fuel 234 182 Natural gas 315 160 Total inventories $ 870 $ 631
Property, plant and equipment, net	(Millions of Dollars) Sept. 30, 2022 Dec. 31, 2021 Property, plant and equipment, net Electric plant $ 48,959 $ 48,680 Natural gas plant 8,199 7,758 Common and other property 2,824 2,602 Plant to be retired (a) 2,258 1,200 Construction work in progress 2,445 1,969 Total property, plant and equipment 64,685 62,209 Less accumulated depreciation (17,639) (17,060) Nuclear fuel 3,105 3,081 Less accumulated amortization (2,864) (2,773) Property, plant and equipment, net $ 47,287 $ 45,457

Borrowings and Other Financin_2

Borrowings and Other Financing Instruments (Tables)	9 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Commercial paper and term loan borrowings	Commercial paper and term loan borrowings outstanding for Xcel Energy: (Amounts in Millions, Except Interest Rates) Three Months Ended Sept. 30, 2022 Year Ended Dec. 31, 2021 Borrowing limit $ 3,550 $ 3,100 Amount outstanding at period end 158 1,005 Average amount outstanding 187 1,399 Maximum amount outstanding 329 2,054 Weighted average interest rate, computed on a daily basis 2.51 % 0.57 % Weighted average interest rate at period end 3.40 0.31
Credit Facilities	As of Sept. 30, 2022, Xcel Energy Inc. and its utility subsidiaries had the following committed revolving credit facilities available: (Millions of Dollars) Credit Facility (a) Drawn (b) Available Xcel Energy Inc. $ 1,500 $ 158 $ 1,342 PSCo 700 26 674 NSP-Minnesota 700 11 689 SPS 500 2 498 NSP-Wisconsin 150 — 150 Total $ 3,550 $ 197 $ 3,353 (a) Expires in September 2027. (b) Includes outstanding commercial paper and letters of credit.

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 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. Xcel Energy’s operating revenues consisted of the following: Three Months Ended Sept. 30, 2022 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 1,109 $ 181 $ 15 $ 1,305 C&I 1,734 116 6 1,856 Other 42 — 2 44 Total retail 2,885 297 23 3,205 Wholesale 450 — — 450 Transmission 210 — — 210 Other 20 43 — 63 Total revenue from contracts with customers 3,565 340 23 3,928 Alternative revenue and other 134 17 3 154 Total revenues $ 3,699 $ 357 $ 26 $ 4,082 Three Months Ended Sept. 30, 2021 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 999 $ 133 $ 12 $ 1,144 C&I 1,515 76 7 1,598 Other 35 — 1 36 Total retail 2,549 209 20 2,778 Wholesale 288 — — 288 Transmission 167 — — 167 Other 17 45 — 62 Total revenue from contracts with customers 3,021 254 20 3,295 Alternative revenue and other 155 14 3 172 Total revenues $ 3,176 $ 268 $ 23 $ 3,467 Nine Months Ended Sept. 30, 2022 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 2,723 $ 1,100 $ 30 $ 3,853 C&I 4,385 636 15 5,036 Other 111 — 25 136 Total retail 7,219 1,736 70 9,025 Wholesale 1,027 — — 1,027 Transmission 518 — — 518 Other 55 125 — 180 Total revenue from contracts with customers 8,819 1,861 70 10,750 Alternative revenue and other 436 62 9 507 Total revenues $ 9,255 $ 1,923 $ 79 $ 11,257 Nine Months Ended Sept. 30, 2021 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 2,488 $ 774 $ 33 $ 3,295 C&I 3,830 389 22 4,241 Other 96 — 5 101 Total retail 6,414 1,163 60 7,637 Wholesale 1,265 — — 1,265 Transmission 461 — — 461 Other 51 106 — 157 Total revenue from contracts with customers 8,191 1,269 60 9,520 Alternative revenue and other 452 95 9 556 Total revenues $ 8,643 $ 1,364 $ 69 $ 10,076

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Reconciliation between the statutory rate and ETR: Three Months Ended Sept. 30 Nine Months Ended Sept. 30 2022 2021 2022 2021 Federal statutory rate 21.0 % 21.0 % 21.0 % 21.0 % State tax (net of federal tax effect) 4.9 5.0 4.9 5.0 Decreases: Wind PTCs (a) (12.3) (12.1) (25.2) (20.0) Plant regulatory differences (b) (5.8) (5.8) (5.5) (6.0) Other tax credits, net operating loss & tax credits allowances (1.2) (1.2) (1.4) (1.1) Other (net) (0.3) (0.3) (0.1) (0.2) Effective income tax rate 6.3 % 6.6 % (6.3) % (1.3) % (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.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	3 Months Ended
	Sep. 30, 2022
Earnings Per Share [Abstract]
Schedule of Weighted Average Number of Shares [Table Text Block]	Common shares outstanding used in the basic and diluted EPS computation: Three Months Ended Sept. 30 Nine Months Ended Sept. 30 (Shares in Millions) 2022 2021 2022 2021 Basic 548 539 546 539 Diluted (a) 548 539 546 539 (a) Diluted common shares outstanding included common stock equivalents of 0.3 million for the three months ended September 30, 2022 and 2021, respectively. Diluted common shares outstanding included common stock equivalents of

Fair Value of Financial Asset_2

Fair Value of Financial Assets and Liabilities (Tables)	9 Months Ended
	Sep. 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: Sept. 30, 2022 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 NAV Total Nuclear decommissioning fund (a) Cash equivalents $ 37 $ 37 $ — $ — $ — $ 37 Commingled funds 832 — — — 1,167 1,167 Debt securities 696 — 611 9 — 620 Equity securities 409 918 1 — — 919 Total $ 1,974 $ 955 $ 612 $ 9 $ 1,167 $ 2,743 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $214 million of equity method investments and $126 million of rabbi trust assets and miscellaneous investments. 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 $208 million of equity method investments and $164 million of rabbi trust assets and other miscellaneous investments.
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 Sept. 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 $ 5 $ 190 $ 227 $ 198 $ 620
Rabbi Trust Securities Amortized Cost and Fair Value Measured on Recurrring Basis [Table Text Block]	Cost and fair value of assets held in rabbi trusts: Sept. 30, 2022 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 Total Rabbi Trusts (a) Cash equivalents $ 1 $ 1 $ — $ — $ 1 Mutual funds 75 73 — — 73 Total $ 76 $ 74 $ — $ — $ 74 Dec. 31, 2021 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 Total Rabbi Trusts (a) Cash equivalents $ 20 $ 20 $ — $ — $ 20 Mutual funds 75 89 — — 89 Total $ 95 $ 109 $ — $ — $ 109 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets.
Gross Notional Amounts of Commodity Forwards, Options, and FTRs	Gross notional amounts of commodity forwards, options and FTRs: (Amounts in Millions) (a)(b) Sept. 30, 2022 Dec. 31, 2021 Megawatt hours of electricity 82 80 Million British thermal units of natural gas 151 156 (a) Not reflective of net positions in the underlying commodities. (b) Notional amounts for options included on a gross basis but weighted for the probability of exercise.
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) Accumulated Other Comprehensive Loss Regulatory (Assets) and Liabilities Three Months Ended Sept. 30, 2022 Other derivative instruments: Electric commodity $ — $ 6 Natural gas commodity — (6) Total $ — $ — Nine Months Ended Sept. 30, 2022 Derivatives designated as cash flow hedges: Interest rate $ 21 $ — Total $ 21 $ — Other derivative instruments: Electric commodity $ — $ 106 Natural gas commodity — (3) Total $ — $ 103 Three Months Ended Sept. 30, 2021 Derivatives designated as cash flow hedges: Interest rate $ 4 $ — Total $ 4 $ — Other derivative instruments: Electric commodity $ — $ 5 Natural gas commodity — 57 Total $ — $ 62 Nine Months Ended Sept. 30, 2021 Derivatives designated as cash flow hedges: Interest rate $ 5 $ — Total $ 5 $ — Other derivative instruments: Electric commodity $ — $ 18 Natural gas commodity — 57 Total $ — $ 75 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 Sept. 30, 2022 Derivatives designated as cash flow hedges: Interest rate $ 1 (a) $ — $ — Total $ 1 $ — $ — Other derivative instruments: Commodity trading $ — $ — $ 13 (b) Electric commodity — 6 (c) — Total $ — $ 6 $ 13 Nine Months Ended Sept. 30, 2022 Derivatives designated as cash flow hedges: Interest rate $ 5 (a) $ — $ — Total $ 5 $ — $ — Other derivative instruments: Commodity trading $ — $ — $ 21 (b) Electric commodity — (31) (c) — Natural gas commodity — 4 (d) (17) (d)(e) Total $ — $ (27) $ 4 Three Months Ended Sept. 30, 2021 Derivatives designated as cash flow hedges: Interest rate $ 2 (a) $ — $ — Total $ 2 $ — $ — Other derivative instruments: Commodity trading $ — $ — $ 1 (b) Electric commodity — 3 (c) — Total $ — $ 3 $ 1 Nine Months Ended Sept. 30, 2021 Derivatives designated as cash flow hedges: Interest rate $ 7 (a) $ — $ — Total $ 7 $ — $ — Other derivative instruments: Commodity trading $ — $ — $ 49 (b) Electric commodity — (26) (c) — Natural gas commodity — 8 (d) (10) (d)(e) Total $ — $ (18) $ 39 (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.
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	Recurring Fair Value Measurements — Derivative assets and liabilities measured at fair value on a recurring basis were as follows: Sept. 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 $ 53 $ 184 $ 47 $ 284 $ (211) $ 73 $ 22 $ 137 $ 21 $ 180 $ (134) $ 46 Electric commodity (b) — — 358 358 (4) 354 — — 57 57 (1) 56 Natural gas commodity — 26 — 26 — 26 — 18 — 18 — 18 Total current derivative assets $ 53 $ 210 $ 405 $ 668 $ (215) 453 $ 22 $ 155 $ 78 $ 255 $ (135) 120 PPAs (c) 3 3 Current derivative instruments $ 456 $ 123 Noncurrent derivative assets Other derivative instruments: Commodity trading $ 50 $ 64 $ 92 $ 206 $ (120) $ 86 $ 16 $ 63 $ 89 $ 168 $ (107) $ 61 Total noncurrent derivative assets $ 50 $ 64 $ 92 $ 206 $ (120) 86 $ 16 $ 63 $ 89 $ 168 $ (107) 61 PPAs (c) 4 6 Noncurrent derivative instruments $ 90 $ 67 Sept. 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 $ 44 $ 223 $ 23 $ 290 $ (219) $ 71 $ 19 $ 148 $ 20 $ 187 $ (143) $ 44 Electric commodity (b) — — 4 4 (4) — — — 1 1 (1) — Natural gas commodity — 12 — 12 — 12 — 8 — 8 — 8 Total current derivative liabilities $ 44 $ 235 $ 27 $ 306 $ (223) 83 $ 19 $ 156 $ 21 $ 196 $ (144) 52 PPAs (c) 17 17 Current derivative instruments $ 100 $ 69 Noncurrent derivative liabilities Other derivative instruments: Commodity trading $ 59 $ 86 $ 68 $ 213 $ (132) $ 81 $ 18 $ 48 $ 127 $ 193 $ (128) $ 65 Total noncurrent derivative liabilities $ 59 $ 86 $ 68 $ 213 $ (132) 81 $ 18 $ 48 $ 127 $ 193 $ (128) 65 PPAs (c) 33 40 Noncurrent derivative instruments $ 114 $ 105 (a) Xcel Energy nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At Sept. 30, 2022 and Dec. 31, 2021, derivatives include $2 million and no obligations to return cash collateral, respectively. At Sept. 30, 2022 and Dec. 31, 2021, derivative assets and liabilities include rights to reclaim cash collateral of $22 million and $30 million, respectively. Counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. (b) Amounts relate to FTR instruments administered by MISO and SPP (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, fair values for FTRs are offset/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, contracts are no longer adjusted to fair value and the previous carrying value of these contracts is being amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities.
Change in Level 3 Commodity Derivative	Changes in Level 3 commodity derivatives: Three Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Balance at July 1 $ 485 $ 71 Purchases / Issuances (a) 4 2 Settlements (a) (106) (53) Net transactions recorded during the period: Gains recognized in earnings (b) 16 12 Net gains recognized as regulatory assets and liabilities (a) 3 27 Balance at Sept. 30 $ 402 $ 59 Nine Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Balance at Jan. 1 $ 19 $ (49) Purchases / Issuances (a) 398 65 Settlements (a) (286) (101) Net transactions recorded during the period: Gains recognized in earnings (b) 136 59 Net gains recognized as regulatory assets and liabilities (a) 135 85 Balance at Sept. 30 $ 402 $ 59 (a) Relates primarily to FTR instruments administered by MISO and SPP (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: Sept. 30, 2022 Dec. 31, 2021 (Millions of Dollars) Carrying Amount Fair Value Carrying Amount Fair Value Long-term debt, including current portion $ 23,960 $ 20,560 $ 22,380 $ 25,232

Benefit Plans and Other Postr_2

Benefit Plans and Other Postretirement Benefits (Tables)	9 Months Ended
	Sep. 30, 2022
Retirement Benefits [Abstract]
Components of Net Periodic Benefit Cost (Credit)	Components of Net Periodic Benefit Cost (Credit) Three Months Ended Sept. 30 2022 2021 2022 2021 (Millions of Dollars) Pension Benefits Postretirement Health Service cost $ 24 $ 26 $ — $ — Interest cost (a) 28 26 3 4 Expected return on plan assets (a) (52) (52) (4) (4) Amortization of prior service credit (a) — — (2) (2) Amortization of net loss (a) 19 27 1 1 Settlement charge (b) 55 39 — — Net periodic benefit cost (credit) 74 66 (2) (1) Effects of regulation (37) (31) 1 1 Net benefit cost (credit) recognized for financial reporting $ 37 $ 35 $ (1) $ — Nine Months Ended Sept. 30 2022 2021 2022 2021 (Millions of Dollars) Pension Benefits Postretirement Health Service cost $ 73 $ 78 $ 1 $ 1 Interest cost (a) 83 78 11 11 Expected return on plan assets (a) (156) (155) (13) (13) Amortization of prior service credit (a) (1) (1) (5) (6) Amortization of net loss (a) 56 81 2 4 Settlement charge (b) 54 39 — — Net periodic benefit cost (credit) 109 120 (4) (3) Effects of regulation (30) (32) 2 2 Net benefit cost (credit) recognized for financial reporting $ 79 $ 88 $ (2) $ (1) (a) The components of net periodic cost other than the service cost component are included in the line item “Other income, net” in the consolidated statements of income or capitalized on the consolidated balance sheets as a regulatory asset.

Commitment and Contingencies (T

Commitment and Contingencies (Tables)	3 Months Ended	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Finance Lease, Liability, Fiscal Year Maturity		Commitments under operating and finance leases as of Sept. 30, 2022: (Millions of Dollars) PPA Operating Other Operating Total Operating Finance Leases (a) Total minimum obligation $ 1,246 $ 166 $ 1,412 $ 239 Interest component of obligation (174) (30) (204) (169) Present value of minimum obligation $ 1,072 136 1,208 70 Less current portion (211) (4) Noncurrent operating and finance lease liabilities $ 997 $ 66 (a) Excludes certain amounts related to Xcel Energy’s 50% ownership interest in WYCO.
Lease, Cost	Components of lease expense: Three Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Operating leases PPA capacity payments $ 59 $ 56 Other operating leases (a) 8 2 Total operating lease expense (b) $ 67 $ 58 Finance leases Amortization of ROU assets $ 1 $ 2 Interest expense on lease liability 4 4 Total finance lease expense $ 5 $ 6 (a) Includes short-term lease expense o f $1 million for 2022 and 2021. (b) PPA capacity payments are included in electric fuel and purchased power on the consolidated statements of income. Expense for other operating leases is included in O&M expense and electric fuel and purchased power. Nine Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Operating leases PPA capacity payments $ 182 $ 170 Other operating leases (a) 28 19 Total operating lease expense (b) $ 210 $ 189 Finance leases Amortization of ROU assets $ 3 $ 6 Interest expense on lease liability 12 12 Total finance lease expense $ 15 $ 18 (a) Includes short-term lease expense o f $4 million for 2022 and 2021.

Other Comprehensive Income (L_2

Other Comprehensive Income (Loss) (Tables)	9 Months Ended
	Sep. 30, 2022
Stockholders' Equity Note [Abstract]
Changes in Accumulated Other Comprehensive Income (Loss), Net of Tax	Changes in accumulated other comprehensive loss, net of tax, for the three and nine months ended Sept. 30, 2022 and 2021: Three Months Ended Sept. 30, 2022 Three Months Ended Sept. 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 July 1 $ (57) $ (46) $ (103) $ (80) $ (55) $ (135) Other comprehensive gain before reclassifications — 10 10 3 — 3 Losses reclassified from net accumulated other comprehensive loss: Interest rate derivatives (a) 1 — 1 2 — 2 Amortization of net actuarial loss (b) — 1 1 — 4 4 Net current period other comprehensive income 1 11 12 5 4 9 Accumulated other comprehensive loss at Sept. 30 $ (56) $ (35) $ (91) $ (75) $ (51) $ (126) Nine Months Ended Sept. 30, 2022 Nine Months Ended Sept. 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 $ (75) $ (48) $ (123) $ (85) $ (56) $ (141) Other comprehensive gain before reclassifications 15 11 26 4 — 4 Losses reclassified from net accumulated other comprehensive loss: Interest rate derivatives (a) 4 — 4 6 — 6 Amortization of net actuarial loss (b) — 2 2 — 5 5 Net current period other comprehensive income 19 13 32 10 5 15 Accumulated other comprehensive loss at Sept. 30 $ (56) $ (35) $ (91) $ (75) $ (51) $ (126) (a) Included in interest charges.

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2022
Segment Reporting [Abstract]
Results from Operations by Reportable Segment	Xcel Energy’s segment information: Three Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Regulated Electric Total revenues $ 3,699 $ 3,176 Net income 697 629 Regulated Natural Gas Operating revenues $ 357 $ 268 Intersegment revenue 1 1 Total revenues $ 358 $ 269 Net (loss) income (7) 10 All Other Total revenues $ 26 $ 23 Net loss (41) (30) Consolidated Total Total revenues $ 4,083 $ 3,468 Reconciling eliminations (1) (1) Total operating revenues $ 4,082 $ 3,467 Net income 649 609 Nine Months Ended Sept. 30 (Millions of Dollars) 2022 2021 Regulated Electric Operating revenues $ 9,255 $ 8,643 Intersegment revenue 1 1 Total revenues $ 9,256 $ 8,644 Net income 1,312 1,202 Regulated Natural Gas Operating revenues $ 1,923 $ 1,364 Intersegment revenue 1 2 Total revenues $ 1,924 $ 1,366 Net income 148 161 All Other Total operating revenue $ 79 $ 69 Net loss (103) (81) Consolidated Total Total revenues $ 11,259 $ 10,079 Reconciling eliminations (2) (3) Total operating revenues $ 11,257 $ 10,076 Net income 1,357 1,282

Selected Balance Sheet Data Sel

Selected Balance Sheet Data Selected Balance Sheet Data, Accounts Receivable (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Balance Sheet Related Disclosures [Abstract]
Accounts receivable	$ 1,308	$ 1,124
Less allowance for bad debts	(112)	(106)
Accounts receivable, net	$ 1,196	$ 1,018

Selected Balance Sheet Data S_2

Selected Balance Sheet Data Selected Balance Sheet Data, Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Public Utilities, Inventory [Line Items]
Total inventories	$ 870	$ 631
Materials and supplies
Public Utilities, Inventory [Line Items]
Inventories	321	289
Fuel
Public Utilities, Inventory [Line Items]
Inventories	234	182
Natural gas
Public Utilities, Inventory [Line Items]
Inventories	$ 315	$ 160

Selected Balance Sheet Data, Pr

Selected Balance Sheet Data, Property, Plant and Equipment, Net (Details) - USD ($) $ in Millions		Sep. 30, 2022	Dec. 31, 2021
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		$ 64,685	$ 62,209
Less accumulated depreciation and amortization		(17,639)	(17,060)
Property, plant and equipment, net		47,287	45,457
Electric plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		48,959	48,680
Natural gas plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		8,199	7,758
Common and other property
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		2,824	2,602
Plant to be retired
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	[1]	2,258	1,200
Construction work in progress
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		2,445	1,969
Nuclear fuel
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		3,105	3,081
Less accumulated depreciation and amortization		$ (2,864)	$ (2,773)
[1]Amounts as of Dec. 31, 2021 include Sherco Units 1, 2 and 3 and A.S. King for NSP-Minnesota; Comanche Unit 1 and 2 and Craig Units 1 and 2 for PSCo; and Tolk and coal generation assets at Harrington pending facility gas conversion for SPS. Following the June 2022 approval of PSCo’s revised resource plan settlement, amounts as of Sept. 30, 2022 include the addition of Comanche Unit 3, Hayden Units 1 and 2 and coal generation assets at Pawnee pending facility gas conversion. Amounts are presented net of accumulated depreciation.

Short-Term Debt (Details)

Short-Term Debt (Details) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Short-term Debt [Line Items]
Amount outstanding at period end	$ 158	$ 1,005
Commercial Paper
Short-term Debt [Line Items]
Borrowing limit	3,550	3,100
Amount outstanding at period end	158	1,005
Average amount outstanding	187	1,399
Maximum amount outstanding	$ 329	$ 2,054
Weighted average interest rate, computed on a daily basis	2.51%	0.57%
Weighted average interest rate at period end	3.40%	0.31%

Letters of Credit (Details)

Letters of Credit (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Line of Credit Facility [Line Items]
Amount outstanding at period end	$ 158	$ 1,005
Letter of Credit
Line of Credit Facility [Line Items]
Debt Instrument, Term	1 year
Amount outstanding at period end	$ 39	$ 19

Borrowings and Other Financin_3

Borrowings and Other Financing Instruments Revolving Credit Facilities (Details) - Revolving Credit Facility [Member] - USD ($) $ in Millions		Sep. 30, 2022	Dec. 31, 2021
Line of Credit Facility [Line Items]
Credit Facility	[1]	$ 3,550
Outstanding	[2]	197
Available		3,353
Direct advances on the credit facility outstanding		0	$ 0
PSCo
Line of Credit Facility [Line Items]
Credit Facility	[1]	700
Outstanding	[2]	26
Available		674
NSP-Minnesota
Line of Credit Facility [Line Items]
Credit Facility	[1]	700
Outstanding	[2]	11
Available		689
SPS
Line of Credit Facility [Line Items]
Credit Facility	[1]	500
Outstanding	[2]	2
Available		498
NSP-Wisconsin
Line of Credit Facility [Line Items]
Credit Facility	[1]	150
Outstanding	[2]	0
Available		150
Xcel Energy Inc.
Line of Credit Facility [Line Items]
Credit Facility	[1]	1,500
Outstanding	[2]	158
Available		$ 1,342
[1]Expires in September 2027.[2]Includes outstanding commercial paper and letters of credit.

Borrowings and Other Financin_4

Borrowings and Other Financing Instruments Term Loan (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Short-term Debt [Line Items]
Amount outstanding at period end	$ 158		$ 1,005
Proceeds from issuance of common stock	156	$ 13
Letter of Credit
Short-term Debt [Line Items]
Amount outstanding at period end	$ 39		$ 19

Borrowings and Other Financin_5

Borrowings and Other Financing Instruments Bilateral Credit Agreement (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Short-term Debt [Line Items]
Amount outstanding at period end	$ 158	$ 1,005
Letter of Credit
Short-term Debt [Line Items]
Debt Instrument, Term	1 year
Amount outstanding at period end	$ 39	$ 19
Bilateral Credit Agreement [Member] | NSP-Minnesota | Letter of Credit
Short-term Debt [Line Items]
Debt Instrument, Term	1 year
Amount outstanding at period end	$ 50
Credit Facility	$ 75

Borrowings and Other Financin_6

Borrowings and Other Financing Instruments Long-Term Borrowings (Details) - Bonds [Member]	Sep. 30, 2022 USD ($)
PSCo | Series Due June 1, 2032
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 300,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.10%
PSCo | Series Due June 1, 2052
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 400,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.50%
SPS | Series Due June 1, 2052
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 200,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.15%
NSP-Wisconsin | Series Due September 15, 2052
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 100,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.86%
NSP-Minnesota | Series Due June 1, 2052
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 500,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.50%
XCEL ENERGY INC [Member] | Series Due June 1, 2032
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 700,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.60%

Borrowings and Other Financin_7

Borrowings and Other Financing Instruments Forward Equity Agreement (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Forward Contract Indexed to Issuer's Equity [Line Items]
Proceeds from issuance of common stock			$ 156	$ 13
Issuances of common stock	$ 14	$ 10	185	40
Dividend Reinvestment Program
Forward Contract Indexed to Issuer's Equity [Line Items]
Proceeds from issuance of common stock			$ 34	$ 38

Revenues (Details)

Revenues (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 3,205	$ 2,778	$ 9,025	$ 7,637
Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	450	288	1,027	1,265
Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	210	167	518	461
Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	63	62	180	157
Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3,928	3,295	10,750	9,520
Alternative revenue and other
Disaggregation of Revenue [Line Items]
Alternative revenue and other	154	172	507	556
Residential | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,305	1,144	3,853	3,295
C&I | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,856	1,598	5,036	4,241
Other | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	44	36	136	101
Operating Segments
Disaggregation of Revenue [Line Items]
Revenues	4,082	3,467	11,257	10,076
Regulated Electric | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,885	2,549	7,219	6,414
Regulated Electric | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	450	288	1,027	1,265
Regulated Electric | Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	210	167	518	461
Regulated Electric | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	20	17	55	51
Regulated Electric | Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3,565	3,021	8,819	8,191
Regulated Electric | Alternative revenue and other
Disaggregation of Revenue [Line Items]
Alternative revenue and other	134	155	436	452
Regulated Electric | Residential | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,109	999	2,723	2,488
Regulated Electric | C&I | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,734	1,515	4,385	3,830
Regulated Electric | Other | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	42	35	111	96
Regulated Electric | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues	3,699	3,176	9,255	8,643
Regulated Natural Gas | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	297	209	1,736	1,163
Regulated Natural Gas | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Regulated Natural Gas | Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Regulated Natural Gas | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	43	45	125	106
Regulated Natural Gas | Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	340	254	1,861	1,269
Regulated Natural Gas | Alternative revenue and other
Disaggregation of Revenue [Line Items]
Alternative revenue and other	17	14	62	95
Regulated Natural Gas | Residential | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	181	133	1,100	774
Regulated Natural Gas | C&I | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	116	76	636	389
Regulated Natural Gas | Other | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
Regulated Natural Gas | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues	357	268	1,923	1,364
All Other | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	23	20	70	60
All Other | Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
All Other | Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
All Other | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0	0	0
All Other | Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	23	20	70	60
All Other | Alternative revenue and other
Disaggregation of Revenue [Line Items]
Alternative revenue and other	3	3	9	9
All Other | Residential | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	15	12	30	33
All Other | C&I | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	6	7	15	22
All Other | Other | Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2	1	25	5
All Other | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues	$ 26	$ 23	$ 79	$ 69

Income Taxes (Details)

Income Taxes (Details)		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Income Tax Disclosure [Abstract]
Federal statutory rate		21%	21%	21%	21%
State tax (net of federal tax effect)		4.90%	5%	4.90%	5%
Effective Income Tax Rate Reconciliation, Tax Credit, Percent	[1]	(12.30%)	(12.10%)	(25.20%)	(20.00%)
Plant regulatory differences (b)	[2]	(5.80%)	(5.80%)	(5.50%)	(6.00%)
Effective Income Tax Rate Reconciliation, Net Operating Loss Carryback, Percent		(1.20%)	(1.20%)	(1.40%)	(1.10%)
Other (net)		(0.30%)	(0.30%)	(0.10%)	(0.20%)
Effective income tax rate		6.30%	6.60%	(6.30%)	(1.30%)
[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.

Common Stock Equivalents (Detai

Common Stock Equivalents (Details) - shares shares in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Earnings Per Share [Abstract]
Weighted Average Number of Shares Outstanding, Basic		548,000	539,000	546,000	539,000
Diluted (in shares)	[1]	548,000	539,000	546,000	539,000
Dilutive Effect of Contingently Issuable Shares		300	300		300
[1] Diluted common shares outstanding included common stock equivalents of 0.3 million for the three months ended September 30, 2022 and 2021, respectively. Diluted common shares outstanding included common stock equivalents of

Non-Derivative Fair Value Measu

Non-Derivative Fair Value Measurements (Details) - USD ($) $ in Millions		9 Months Ended		12 Months Ended
		Sep. 30, 2022		Dec. 31, 2021
Nuclear decommissinoning fund [Abstract]
Equity investments in unconsolidated subsidiaries		$ 214		$ 208
Miscellaneous investments		126		164
Debt Securities, Available-for-sale, Unrealized Gain		900		1,300
Debt Securities, Available-for-sale, Unrealized Loss		133		7
Debt Securities, Available-for-sale, Fair Value, Fiscal Year Maturity [Abstract]
Due in one year or less		5
Due in 1 to 5 years		190
Due in 5 to 10 years		227
Due after 10 years		198
Total		620
Interest Rate Swap
Nuclear decommissinoning fund [Abstract]
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net		2
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost
Nuclear decommissinoning fund [Abstract]
Decommissioning Fund Investments		1,974	[1]	1,962	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Cash equivalents
Nuclear decommissinoning fund [Abstract]
Cash equivalents		37	[1]	64	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Commingled funds
Nuclear decommissinoning fund [Abstract]
Commingled funds	[2]			856
Investments, Fair Value Disclosure	[1]	832
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Debt securities
Nuclear decommissinoning fund [Abstract]
Debt securities		696	[1]	631	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Equity securities
Nuclear decommissinoning fund [Abstract]
Equity Securities, FV-NI		409	[1]	411	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value
Nuclear decommissinoning fund [Abstract]
Alternative investment		1,167	[1]	1,294	[2]
Decommissioning Fund Investments		2,743	[1]	3,256	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Cash equivalents
Nuclear decommissinoning fund [Abstract]
Cash equivalents		37	[1]	64	[2]
Alternative investment		0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Commingled funds
Nuclear decommissinoning fund [Abstract]
Commingled funds				1,294
Alternative investment		1,167	[1]	1,294	[2]
Investments, Fair Value Disclosure		1,167
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Debt securities
Nuclear decommissinoning fund [Abstract]
Debt securities		620	[1]	675	[2]
Alternative investment		0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Equity securities
Nuclear decommissinoning fund [Abstract]
Equity Securities, FV-NI		919	[1]	1,223	[2]
Alternative investment		0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1
Nuclear decommissinoning fund [Abstract]
Decommissioning Fund Investments		955	[1]	1,286	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Cash equivalents
Nuclear decommissinoning fund [Abstract]
Cash equivalents		37	[1]	64	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Commingled funds
Nuclear decommissinoning fund [Abstract]
Commingled funds	[2]			0
Investments, Fair Value Disclosure	[1]	0
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Debt securities
Nuclear decommissinoning fund [Abstract]
Debt securities		0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Equity securities
Nuclear decommissinoning fund [Abstract]
Equity Securities, FV-NI		918	[1]	1,222	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2
Nuclear decommissinoning fund [Abstract]
Decommissioning Fund Investments		612	[1]	667	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Cash equivalents
Nuclear decommissinoning fund [Abstract]
Cash equivalents		0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Commingled funds
Nuclear decommissinoning fund [Abstract]
Commingled funds	[2]			0
Investments, Fair Value Disclosure	[1]	0
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Debt securities
Nuclear decommissinoning fund [Abstract]
Debt securities		611	[1]	666	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Equity securities
Nuclear decommissinoning fund [Abstract]
Equity Securities, FV-NI		1	[1]	1	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3
Nuclear decommissinoning fund [Abstract]
Decommissioning Fund Investments		9	[1]	9	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Cash equivalents
Nuclear decommissinoning fund [Abstract]
Cash equivalents		0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Commingled funds
Nuclear decommissinoning fund [Abstract]
Commingled funds	[2]			0
Investments, Fair Value Disclosure	[1]	0
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Debt securities
Nuclear decommissinoning fund [Abstract]
Debt securities		9	[1]	9	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Equity securities
Nuclear decommissinoning fund [Abstract]
Equity Securities, FV-NI		$ 0	[1]	$ 0	[2]
[1]Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $214 million of equity method investments and $126 million of rabbi trust assets and miscellaneous investments.[2]Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets, which also includes $208 million of equity method investments and $164 million of rabbi trust assets and other miscellaneous investments.

Rabbi Trust (Details)

Rabbi Trust (Details) - Rabbi Trust [Member] - Fair Value, Measured on a Recurring Basis - USD ($) $ in Millions		Sep. 30, 2022	Dec. 31, 2021
Cost
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi Trusts Assets at Fair Value	[1]	$ 76	$ 95
Cost | Cash Equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	[1]	1	20
Cost | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Mutual funds	[1]	75	75
Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi Trusts Assets at Fair Value	[1]	74	109
Fair Value | Cash Equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	[1]	1	20
Fair Value | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Mutual funds	[1]	73	89
Fair Value | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi Trusts Assets at Fair Value	[1]	74	109
Fair Value | Level 1 | Cash Equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	[1]	1	20
Fair Value | Level 1 | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Mutual funds	[1]	73	89
Fair Value | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi Trusts Assets at Fair Value	[1]	0	0
Fair Value | Level 2 | Cash Equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	[1]	0	0
Fair Value | Level 2 | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Mutual funds	[1]	0	0
Fair Value | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi Trusts Assets at Fair Value	[1]	0	0
Fair Value | Level 3 | Cash Equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	[1]	0	0
Fair Value | Level 3 | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Mutual funds	[1]	$ 0	$ 0
[1]Reported in nuclear decommissioning fund and other investments on the consolidated balance sheets.

Interest Rate Derivatives (Deta

Interest Rate Derivatives (Details) - USD ($) $ in Millions		Sep. 30, 2022	Dec. 31, 2021
Other Current Assets
Derivative [Line Items]
Derivative Asset, Net		$ 456	$ 123
Other Current Assets | Fair Value, Measured on a Recurring Basis
Derivative [Line Items]
Derivative Asset, Gross		668	255
Netting	[1]	215	135
Derivative Asset, Net		453	120
Other Current Assets | Level 1 | Fair Value, Measured on a Recurring Basis
Derivative [Line Items]
Derivative Asset, Gross		53	22
Other Current Assets | Level 2 | Fair Value, Measured on a Recurring Basis
Derivative [Line Items]
Derivative Asset, Gross		210	155
Other Current Assets | Level 3 | Fair Value, Measured on a Recurring Basis
Derivative [Line Items]
Derivative Asset, Gross		405	78
Other Noncurrent Assets
Derivative [Line Items]
Derivative Asset, Net		90	67
Other Noncurrent Assets | Fair Value, Measured on a Recurring Basis
Derivative [Line Items]
Derivative Asset, Gross		206	168
Netting	[1]	120	107
Derivative Asset, Net		86	61
Other Noncurrent Assets | Level 1 | Fair Value, Measured on a Recurring Basis
Derivative [Line Items]
Derivative Asset, Gross		50	16
Other Noncurrent Assets | Level 2 | Fair Value, Measured on a Recurring Basis
Derivative [Line Items]
Derivative Asset, Gross		64	63
Other Noncurrent Assets | Level 3 | Fair Value, Measured on a Recurring Basis
Derivative [Line Items]
Derivative Asset, Gross		92	89
Interest rate derivatives
Derivative [Line Items]
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net		2
Derivative Liability, Notional Amount		0
Commodity Trading | Other Current Assets | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		284	180
Netting	[1]	211	134
Derivative Asset, Net		73	46
Commodity Trading | Other Current Assets | Level 1 | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		53	22
Commodity Trading | Other Current Assets | Level 2 | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		184	137
Commodity Trading | Other Current Assets | Level 3 | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		47	21
Commodity Trading | Other Noncurrent Assets | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		206	168
Netting	[1]	120	107
Derivative Asset, Net		86	61
Commodity Trading | Other Noncurrent Assets | Level 1 | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		50	16
Commodity Trading | Other Noncurrent Assets | Level 2 | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		64	63
Commodity Trading | Other Noncurrent Assets | Level 3 | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		92	89
Electric Commodity | Other Current Assets | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		358	57
Netting	[1]	4	1
Derivative Asset, Net		354	56
Electric Commodity | Other Current Assets | Level 1 | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		0	0
Electric Commodity | Other Current Assets | Level 2 | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		0	0
Electric Commodity | Other Current Assets | Level 3 | Fair Value, Measured on a Recurring Basis | Other Derivative Instruments
Derivative [Line Items]
Derivative Asset, Gross		$ 358	$ 57
[1]Xcel Energy nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At Sept. 30, 2022 and Dec. 31, 2021, derivatives include $2 million and no obligations to return cash collateral, respectively. At Sept. 30, 2022 and Dec. 31, 2021, derivative assets and liabilities include rights to reclaim cash collateral of $22 million and $30 million, respectively. Counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. (b) Amounts relate to FTR instruments administered by MISO and SPP (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, fair values for FTRs are offset/deferred as a regulatory asset or liability and do not have a material impact on net income.

Commodity Derivatives (Details)

Commodity Derivatives (Details) MWh in Millions, MMBTU in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022 USD ($) MMBTU MWh	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) MMBTU MWh	Sep. 30, 2021 USD ($)	Dec. 31, 2021 MWh MMBTU
Other Derivative Instruments
Gross Notional Amounts of Commodity Forwards, Options and FTRs [Abstract]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		$ 0	$ 62	$ 103	$ 75
Cash Flow Hedge Commodity [Member]
Derivative [Line Items]
Commodity contracts designated as cash flow hedges		$ 0		$ 0
Electric Commodity [Member]
Gross Notional Amounts of Commodity Forwards, Options and FTRs [Abstract]
Derivative, Nonmonetary Notional Amount | MWh	[1],[2]	82		82		80
Natural Gas Commodity
Gross Notional Amounts of Commodity Forwards, Options and FTRs [Abstract]
Derivative, Nonmonetary Notional Amount | MMBTU	[1],[2]	151		151		156
Natural Gas Commodity | Other Derivative Instruments
Gross Notional Amounts of Commodity Forwards, Options and FTRs [Abstract]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		$ (6)	$ 57	$ (3)	$ 57
[1]Not reflective of net positions in the underlying commodities.[2]Notional amounts for options included on a gross basis but weighted for the probability of exercise.

Consideration of Credit Risk an

Consideration of Credit Risk and Concentrations (Details)		3 Months Ended		9 Months Ended
		Sep. 30, 2022 USD ($) Counterparty	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) Counterparty	Sep. 30, 2021 USD ($)
Impact of Derivative Activity [Abstract]
Fair value hedges		$ 0	$ 0	$ 0	$ 0
Other Derivative Instruments
Impact of Derivative Activity [Abstract]
Pre-tax fair value gains (losses) recognized during the period in accumulated other comprehensive loss		0	0	0	0
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		0	62,000,000	103,000,000	75,000,000
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)		6,000,000	3,000,000	(27,000,000)	(18,000,000)
Pre-tax gains (losses) recognized during the period in income		13,000,000	1,000,000	4,000,000	39,000,000
Other Derivative Instruments | Electric Commodity
Impact of Derivative Activity [Abstract]
Pre-tax fair value gains (losses) recognized during the period in accumulated other comprehensive loss		0	0	0	0
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		6,000,000	5,000,000	106,000,000	18,000,000
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]	6,000,000	3,000,000	(31,000,000)	(26,000,000)
Pre-tax gains (losses) recognized during the period in income		0	0	0	0
Other Derivative Instruments | Natural Gas Commodity
Impact of Derivative Activity [Abstract]
Pre-tax fair value gains (losses) recognized during the period in accumulated other comprehensive loss		0	0	0	0
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		(6,000,000)	57,000,000	(3,000,000)	57,000,000
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]			4,000,000	8,000,000
Pre-tax gains (losses) recognized during the period in income	[2],[3]			(17,000,000)	(10,000,000)
Other Derivative Instruments | Commodity Trading
Impact of Derivative Activity [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	[4]	13,000,000	1,000,000	21,000,000	49,000,000
Designated as Hedging Instrument | Cash Flow Hedges
Impact of Derivative Activity [Abstract]
Pre-tax fair value gains (losses) recognized during the period in accumulated other comprehensive loss			4,000,000	21,000,000	5,000,000
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities			0	0	0
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		1,000,000	2,000,000	5,000,000	7,000,000
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		0	0	0	0
Designated as Hedging Instrument | Cash Flow Hedges | Interest Rate
Impact of Derivative Activity [Abstract]
Pre-tax fair value gains (losses) recognized during the period in accumulated other comprehensive loss			4,000,000	21,000,000	5,000,000
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities			0	0	0
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	[5]	1,000,000	2,000,000	5,000,000	7,000,000
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		$ 0	$ 0	$ 0	$ 0
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		6		6
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		5		5
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties		$ 86,000,000		$ 86,000,000
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)		30%		30%
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		3		3
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties		$ 61,000,000		$ 61,000,000
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)		22%		22%
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		2		2
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties		$ 68,000,000		$ 68,000,000
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)		24%		24%
[1]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.[2]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.[3]Relates primarily to option premium amortization.[4]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.[5]Recorded to interest charges.

Credit Related Contingent Featu

Credit Related Contingent Features (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Derivative, Gross Liability Position, Aggregate Fair Value	$ 5	$ 3
Derivative, Gross Liability with Cross Default Position, Aggregate Fair Value	90	64
Collateral Already Posted Adequate Assurance Clauses Aggregate Fair Value	$ 0	$ 0

Recurring Fair Value Measuremen

Recurring Fair Value Measurements (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Return Cash Collateral		$ 2		$ 2		$ 0
Reclaim Cash Collateral		22		22		30
Commodity Trading
Changes in Level 3 Commodity Derivatives [Roll Forward]
Balance at beginning of period		485	$ 71	19	$ (49)
Purchases	[1]	4	2	398	65
Settlements	[1]	(106)	(53)	(286)	(101)
Gains (losses) recognized in earnings	[2]	16	12	136	59
Net gains recognized as regulatory assets and liabilities (a)	[1]	3	27	135	85
Balance at end of period		402	59	402	59
Transfers Level 3, Net		0	$ 0	0	$ 0
Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Net		456		456		123
Other Noncurrent Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Net		90		90		67
Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Net		100		100		69
Other Noncurrent Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Net		114		114		105
Fair Value Measured on a Recurring Basis | Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		668		668		255
Netting	[3]	(215)		(215)		(135)
Derivative Asset, Net		453		453		120
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		53		53		22
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		210		210		155
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		405		405		78
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		284		284		180
Netting	[3]	(211)		(211)		(134)
Derivative Asset, Net		73		73		46
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		358		358		57
Netting	[3]	(4)		(4)		(1)
Derivative Asset, Net		354		354		56
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		26		26		18
Netting	[3]	0		0		0
Derivative Asset, Net		26		26		18
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		53		53		22
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		184		184		137
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		26		26		18
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		47		47		21
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		358		358		57
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		206		206		168
Netting	[3]	(120)		(120)		(107)
Derivative Asset, Net		86		86		61
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		50		50		16
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		64		64		63
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		92		92		89
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		206		206		168
Netting	[3]	(120)		(120)		(107)
Derivative Asset, Net		86		86		61
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		50		50		16
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		64		64		63
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		92		92		89
Fair Value Measured on a Recurring Basis | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		306		306		196
Netting	[3]	(223)		(223)		(144)
Derivative Liability, Net		83		83		52
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		44		44		19
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		235		235		156
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		27		27		21
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		290		290		187
Netting	[3]	(219)		(219)		(143)
Derivative Liability, Net		71		71		44
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		4		4		1
Netting	[3]	(4)		(4)		(1)
Derivative Liability, Net		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		12		12		8
Netting	[3]	0		0		0
Derivative Liability, Net		12		12		8
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		44		44		19
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		223		223		148
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		12		12		8
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		23		23		20
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		4		4		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		213		213		193
Netting	[3]	(132)		(132)		(128)
Derivative Liability, Net		81		81		65
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		59		59		18
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		86		86		48
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		68		68		127
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		213		213		193
Netting	[3]	(132)		(132)		(128)
Derivative Liability, Net		81		81		65
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		59		59		18
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		86		86		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		68		68		127
Fair Value, Measurements, Nonrecurring | Other Current Assets | PPAs
Derivatives, Fair Value [Line Items]
Derivative Asset, Net	[4]	3		3		3
Fair Value, Measurements, Nonrecurring | Other Noncurrent Assets | PPAs
Derivatives, Fair Value [Line Items]
Derivative Asset, Net	[4]	4		4		6
Fair Value, Measurements, Nonrecurring | Other Current Liabilities | PPAs
Derivatives, Fair Value [Line Items]
Derivative Liability, Net	[4]	17		17		17
Fair Value, Measurements, Nonrecurring | Other Noncurrent Liabilities | PPAs
Derivatives, Fair Value [Line Items]
Derivative Liability, Net	[4]	$ 33		$ 33		$ 40
[1]Relates primarily to FTR instruments administered by MISO and SPP (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]Xcel Energy nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At Sept. 30, 2022 and Dec. 31, 2021, derivatives include $2 million and no obligations to return cash collateral, respectively. At Sept. 30, 2022 and Dec. 31, 2021, derivative assets and liabilities include rights to reclaim cash collateral of $22 million and $30 million, respectively. Counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. (b) Amounts relate to FTR instruments administered by MISO and SPP (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, fair values for FTRs are offset/deferred as a regulatory asset or liability and do not have a material impact on net income.

Fair Value of Long-Term Debt (D

Fair Value of Long-Term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Carrying Amount	$ 23,960	$ 22,380
Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 20,560	$ 25,232

Benefit Plans and Other Postr_3

Benefit Plans and Other Postretirement Benefits (Details) $ in Millions		1 Months Ended	3 Months Ended		9 Months Ended
		Jan. 31, 2022 USD ($) Plan	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)
Pension Plan [Member]
Components of Net Periodic Benefit Cost [Abstract]
Service cost			$ 24	$ 26	$ 73	$ 78
Interest Cost	[1]		28	26	83	78
Expected Return on Plan Assets	[1]		(52)	(52)	(156)	(155)
Amortization of Prior Service Credit	[1]		0	0	(1)	(1)
Amortization of Net Loss	[1]		19	27	56	81
Net periodic benefit cost (credit)			74	66	109	120
Effects of regulation			(37)	(31)	(30)	(32)
Net benefit cost (credit) recognized for financial reporting			37	35	79	88
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	[2]		55	39	54	39
Pension Plan [Member] | Parent Company
Components of Net Periodic Benefit Cost [Abstract]
Contributions to Xcel Energy's pension plans		$ 50
Number of 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	1	1
Interest Cost	[1]		3	4	11	11
Expected Return on Plan Assets	[1]		(4)	(4)	(13)	(13)
Amortization of Prior Service Credit	[1]		(2)	(2)	(5)	(6)
Amortization of Net Loss	[1]		1	1	2	4
Net periodic benefit cost (credit)			(2)	(1)	(4)	(3)
Effects of regulation			1	1	2	2
Net benefit cost (credit) recognized for financial reporting			(1)	0	(2)	(1)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	[2]		$ 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]A settlement charge is required when the amount of all lump-sum distributions during the year is greater than the sum of the service and interest cost components of the annual net periodic pension cost. In the third quarter of 2022 and 2021, as a result of lump-sum distributions during the 2022 and 2021 plan years, Xcel Energy recorded pension settlement charges of $55 million and $39 million, respectively, the majority of which were not recognized in earnings due to the effects of regulation. A total of $7 million and $4 million of those amounts were recorded in other expense in the third quarter of 2022 and 2021, respectively.

Gas Trading Litigation (Details

Gas Trading Litigation (Details)	Sep. 30, 2022
Gas Trading Litigation
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number	1

Commitments and Contingencies N

Commitments and Contingencies NSP-Minnesota-Sherco (Details) $ in Millions	1 Months Ended
	Jan. 31, 2021 USD ($)
Rate Matters [Abstract]
Sherco Dissallowance	$ 22
NSP-Minnesota
Rate Matters [Abstract]
Customer refund of previously recovered purchased power costs	$ 17

Commitments and Contingencies M

Commitments and Contingencies MISO ROE Complaints (Details) - NSP Minnesota and NSP Wisconsin - FERC Proceeding, MISO ROE Complaint [Member] - Federal Energy Regulatory Commission (FERC) [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	1,238%	1,238%
Public Utilities, ROE Applicable To Transmission Formula Rates In The MISO Region, Recommended By Third Parties	867%	915%

SPP OATT Upgrade Costs (Details

SPP OATT Upgrade Costs (Details) $ in Millions	6 Months Ended
	Jun. 30, 2017 USD ($)
SPS | Southwest Power Pool (SPP) | SPP Open Access Transmission Tariff Upgrade Costs
Public Utilities, General Disclosures [Line Items]
Public Utilities, Billed Charges For Transmission Service Upgrades	$ 13

Contract Termination (Details)

Contract Termination (Details) - SPS $ in Millions	9 Months Ended
	Sep. 30, 2022 USD ($) MW
Loss Contingencies [Line Items]
Megawatts, Lubbock Power and Light contract | MW	170
Lubbock Power and Light Contract Length	25 years
Settlement Agreement Payment, Lubbock Power and Light Contract | $	$ 78

MGP, Landfill and Disposal Site

MGP, Landfill and Disposal Sites (Details)	Sep. 30, 2022
Other MGP, Landfill, or Disposal Sites [Domain]
Manufactured Gas Plant (MGP) Site [Abstract]
Number of identified MGP, landfill, or disposal sites under current investigation and/or remediation	14

Commitments and Contingencies E

Commitments and Contingencies Environmental Requirements - Water and Waste (Details) $ in Millions	Sep. 30, 2022 USD ($) Period
Federal Coal Ash Regulation
Site Contingency [Line Items]
Number of sites where regulated ash units will still be in operation at a specified date | Period	8
Federal Coal Ash Regulation | PSCo
Site Contingency [Line Items]
Estimated cost to remediate groundwater sampling results	$ 35
Federal Coal Ash Regulation | PSCo | Maximum [Member]
Site Contingency [Line Items]
Cost of Beneficial Use Coal Ash Project	43
Federal Clean Water Act Section 316 (b) | Capital Addition Purchase Commitments
Site Contingency [Line Items]
Liability for estimated cost to comply with regulation	$ 40

Leases (Details)

Leases (Details) - USD ($) $ in Millions		3 Months Ended				9 Months Ended
		Sep. 30, 2022		Sep. 30, 2021		Sep. 30, 2022		Sep. 30, 2021		Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Finance Lease, Right-of-Use Asset, Amortization		$ 1		$ 2		$ 3		$ 6
Finance Lease, Interest Expense		4		4		12		12
Finance Lease, Cost		5		6		15		18
Operating Lease, Cost		67	[1]	58	[1]	210	[2]	189	[2]
Lessee, Operating Lease, Liability, to be Paid		1,412				1,412
Finance Lease, Liability, Payment, Due	[3]	239				239
Lessee, Operating Lease, Liability, Undiscounted Excess Amount		(204)				(204)
Finance Lease, Liability, Undiscounted Excess Amount	[3]	(169)				(169)
Operating Lease, Liability		1,208				1,208
Finance Lease, Liability	[3]	70				70
Operating Lease, Liability, Current		(211)				(211)				$ (205)
Finance Lease, Liability, Current	[3]	(4)				(4)
Operating lease liabilities		997				997				$ 1,146
Finance Lease, Liability, Noncurrent	[3]	66				66
Short-term Lease, Cost		1		1		4		4
PPAs
Lessee, Lease, Description [Line Items]
Operating Lease, Cost		59		56		182		170
Lessee, Operating Lease, Liability, to be Paid		1,246				1,246
Lessee, Operating Lease, Liability, Undiscounted Excess Amount		(174)				(174)
Property, Plant and Equipment, Other Types
Lessee, Lease, Description [Line Items]
Operating Lease, Cost		8	[4]	$ 2	[4]	28	[5]	$ 19	[5]
Lessee, Operating Lease, Liability, to be Paid		166				166
Lessee, Operating Lease, Liability, Undiscounted Excess Amount		(30)				(30)
Operating Lease, Liability		$ 136				$ 136
[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]Excludes certain amounts related to Xcel Energy’s 50% ownership interest in WYCO.[4] Includes short-term lease expense o f $1 million for 2022 and 2021. Includes short-term lease expense o f $4 million for 2022 and 2021.

Variable Interest Entities (Det

Variable Interest Entities (Details) - MW	Sep. 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 (in MW)	3,961	4,062

Commitments and Contingencies G

Commitments and Contingencies Guarantees and Bond Indemnifications (Details) - USD ($)	Sep. 30, 2022	Dec. 31, 2021
Commitments and Contingencies, Guarantees and Indemnifications [Abstract]
Assets Held As Collateral For Guarantor Obligations	$ 0	$ 0
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 62,000,000	$ 60,000,000

Commitments and Contingencies -

Commitments and Contingencies - Comanche Unit 3 (Details) $ in Millions	Sep. 30, 2022 USD ($)
Loss Contingencies [Line Items]
Comanche Unit 3 Litigation	$ 125

Other Comprehensive Income (L_3

Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2020
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss)		$ 16,384		$ 16,384			$ 15,612
Interest Rate Derivatives, Tax		44	$ 43	(80)	$ (17)
Gains and Losses on Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss)		(56)	(75)	(56)	(75)	$ (57)	(75)	$ (80)	$ (85)
Losses reclassified from net accumulated other comprehensive loss	[1]	0	0	0	0
Net current period other comprehensive income (loss)		1	5	19	10
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		0	3	15	4
Gains and Losses on Cash Flow Hedges | Interest Rate Swap
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Losses reclassified from net accumulated other comprehensive loss	[2]	1	2	4	6
Defined Benefit Pension and Postretirement Items
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss)		(35)	(51)	(35)	(51)	(46)	(48)	(55)	(56)
Losses reclassified from net accumulated other comprehensive loss	[1]	1	4	2	5
Net current period other comprehensive income (loss)		11	4	13	5
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		10	0	11	0
Defined Benefit Pension and Postretirement Items | Interest Rate Swap
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Losses reclassified from net accumulated other comprehensive loss	[2]	0	0	0	0
Total
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss)		(91)	(126)	(91)	(126)	$ (103)	$ (123)	$ (135)	$ (141)
Losses reclassified from net accumulated other comprehensive loss	[1]	1	4	2	5
Net current period other comprehensive income (loss)		12	9	32	15
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax		10	3	26	4
Total | Interest Rate Swap
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Losses reclassified from net accumulated other comprehensive loss	[2]	$ 1	$ 2	$ 4	$ 6
[1]Included in the computation of net periodic pension and postretirement benefit costs.[2]Included in interest charges.

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Segment Reporting [Abstract]
Equity Method Investments	$ 214		$ 214		$ 208
Segment Reporting Information [Line Items]
Electric	3,699	$ 3,176	9,255	$ 8,643
Net income	649	609	1,357	1,282
Natural gas	357	268	1,923	1,364
Other	26	23	79	69
Regulated and Unregulated Operating Revenue	4,082	3,467	11,257	10,076
Equity Method Investments	214		214		208
Operating Segments
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue	4,083	3,468	11,259	10,079
Intersegment Eliminations
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue	(1)	(1)	(2)	(3)
Regulated Electric
Segment Reporting Information [Line Items]
Net income	697	629	1,312	1,202
Revenues Including Intersegment Revenues	3,699	3,176	9,256	8,644
Regulated Electric | Operating Segments
Segment Reporting Information [Line Items]
Electric			9,255	8,643
Regulated Electric | Intersegment Eliminations
Segment Reporting Information [Line Items]
Electric			1	1
Regulated Natural Gas
Segment Reporting [Abstract]
Equity Method Investments	214		214		208
Segment Reporting Information [Line Items]
Net income	(7)	10	148	161
Revenues Including Intersegment Revenues	358	269	1,924	1,366
Equity Method Investments	214		214		$ 208
Regulated Natural Gas | Operating Segments
Segment Reporting Information [Line Items]
Natural gas	357	268	1,923	1,364
Regulated Natural Gas | Intersegment Eliminations
Segment Reporting Information [Line Items]
Natural gas	1	1	1	2
All Other
Segment Reporting Information [Line Items]
Net income	(41)	(30)	(103)	(81)
All Other | Operating Segments
Segment Reporting Information [Line Items]
Other	$ 26	$ 23	$ 79	$ 69