Xcel Energy (XEL) 10-Q 7 May 20 2020 Q1 Quarterly report Financial data

Cover Page

Cover Page - shares	3 Months Ended
	Mar. 31, 2020	Apr. 30, 2020
Cover [Abstract]
Entity Registrant Name	XCEL ENERGY INC
Entity Central Index Key	0000072903
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
Amendment Flag	false
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2020
Document Transition Report	false
Entity Incorporation, State or Country Code	MN
Entity File Number	001-3034
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		525,170,820

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Operating revenues
Electric	$ 2,203	$ 2,325
Natural gas	583	794
Other	25	22
Total operating revenues	2,811	3,141
Operating expenses
Electric fuel and purchased power	797	914
Cost of natural gas sold and transported	285	479
Cost of sales — other	9	10
Operating and maintenance expenses	579	597
Conservation and demand side management expenses	74	72
Depreciation and amortization	463	433
Taxes (other than income taxes)	149	150
Total operating expenses	2,356	2,655
Operating income	455	486
Other (expense) income, net	(11)	4
Equity earnings of unconsolidated subsidiaries	11	9
Allowance for funds used during construction — equity	23	20
Interest charges and financing costs
Interest charges — includes other financing costs of $7 and $6, respectively	199	189
Allowance for funds used during construction — debt	(10)	(10)
Total interest charges and financing costs	189	179
Income before income taxes	289	340
Income tax (benefit) expense	(6)	25
Net income	$ 295	$ 315
Weighted average common shares outstanding:
Basic (in shares)	526	515
Diluted (in shares)	527	516
Earnings per average common share:
Basic (in dollars per share)	$ 0.56	$ 0.61
Diluted (in dollars per share)	$ 0.56	$ 0.61

CONSOLIDATED STATEMENTS OF IN_2

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Interest charges and financing costs
Other financing costs	$ 7	$ 6

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Comprehensive income:
Net income	$ 295	$ 315
Pension and retiree medical benefits:
Net pension and retiree medical gains arising during the period, net of tax of $0 and $1, respectively	0	2
Reclassifications of loss to net income, net of tax of $0	1	1
Derivative instruments:
Net fair value decrease, net of tax of $(3) and $(2), respectively	(10)	(7)
Reclassification of losses to net income, net of tax of $0	2	1
Total other comprehensive loss	(7)	(3)
Total comprehensive income	$ 288	$ 312

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Pension and retiree medical benefits:
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss) Arising During Period, Tax	$ 0	$ 1
Amortization of losses included in net periodic benefit cost, tax	0	0
Derivative instruments:
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	(3)	(2)
Reclassification of losses to net income, tax	$ (1)	$ 0

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Operating activities
Net income	$ 295	$ 315
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	466	438
Nuclear fuel amortization	33	31
Deferred income taxes	34	26
Allowance for equity funds used during construction	(23)	(20)
Equity earnings of unconsolidated subsidiaries	(11)	(9)
Dividends from unconsolidated subsidiaries	11	10
Share-based compensation expense	26	19
Changes in operating assets and liabilities:
Accounts receivable	7	(114)
Accrued unbilled revenues	149	92
Inventories	33	84
Other current assets	(31)	(33)
Accounts payable	(201)	4
Net regulatory assets and liabilities	101	153
Other current liabilities	(77)	(36)
Pension and other employee benefit obligations	(157)	(145)
Other, net	14	(22)
Net cash provided by operating activities	669	793
Investing activities
Capital/construction expenditures	(1,607)	(844)
Purchases of investment securities	(835)	(305)
Proceeds from the sale of investment securities	830	300
Other, net	6	(3)
Net cash used in investing activities	(1,606)	(852)
Financing activities
Proceeds from short-term borrowings, net	1,170	214
Proceeds from issuances of long-term debt	0	392
Repayments of long-term debt, including reacquisition premiums	0	(400)
Dividends paid	(204)	(187)
Other, net	(33)	(13)
Net cash provided by financing activities	933	6
Net change in cash, cash equivalents and restricted cash	(4)	(53)
Cash, cash equivalents and restricted cash at beginning of period	248	147
Cash, cash equivalents and restricted cash at end of period	244	94
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	(207)	(190)
Cash received (paid) for income taxes, net	0	0
Supplemental disclosure of non-cash investing and financing transactions:
Accrued property, plant and equipment additions	284	238
Inventory transfers to property, plant and equipment	33	18
Operating lease right-of-use assets	0	1,659
Allowance for equity funds used during construction	23	20
Issuance of common stock for equity awards	$ 18	$ 17

CONSOLIDATED BALANCE SHEETS (UN

CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Current assets
Cash and cash equivalents	$ 244	$ 248
Accounts receivable, net	839	837
Accrued unbilled revenues	561	713
Inventories	488	544
Regulatory assets	508	488
Derivative instruments	45	55
Prepaid taxes	68	43
Prepayments and other	230	185
Total current assets	2,983	3,113
Property, plant and equipment, net	40,776	39,483
Other assets
Nuclear decommissioning fund and other investments	2,429	2,731
Regulatory assets	3,130	2,935
Derivative instruments	39	22
Operating lease right-of-use assets	1,260	1,672
Other	516	492
Total other assets	7,374	7,852
Total assets	51,133	50,448
Current liabilities
Current portion of long-term debt	1,102	702
Short-term debt	1,765	595
Accounts payable	996	1,294
Regulatory liabilities	456	407
Taxes accrued	553	466
Accrued interest	167	192
Dividends payable	226	212
Derivative instruments	52	38
Operating lease liabilities	143	194
Other	379	468
Total current liabilities	5,839	4,568
Deferred credits and other liabilities
Deferred income taxes	4,492	4,509
Deferred investment tax credits	48	49
Regulatory liabilities	5,342	5,077
Asset retirement obligations	2,734	2,701
Derivative instruments	183	175
Customer advances	202	203
Pension and employee benefit obligations	622	785
Operating lease liabilities	1,163	1,549
Other	196	186
Total deferred credits and other liabilities	14,982	15,234
Commitments and contingencies
Capitalization
Long-term debt	17,010	17,407
Common stock — 1,000,000,000 shares authorized of $2.50 par value; 525,033,594 and 524,539,000 shares outstanding at March 31, 2020 and Dec. 31, 2019, respectively	1,313	1,311
Additional paid in capital	6,659	6,656
Retained earnings	5,478	5,413
Accumulated other comprehensive loss	(148)	(141)
Total common stockholders’ equity	13,302	13,239
Total liabilities and equity	$ 51,133	$ 50,448

CONSOLIDATED BALANCE SHEETS (_2

CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - $ / shares	Mar. 31, 2020	Dec. 31, 2019
Capitalization, Long-term Debt and Equity
Common stock, shares authorized (in shares)	1,000,000,000	1,000,000,000
Common stock, par value (in dollars per share)	$ 2.50	$ 2.50
Common stock, shares outstanding (in shares)	525,033,594	524,539,000

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, 2018		514,037,000
Beginning balance at Dec. 31, 2018	$ 12,222	$ 1,285	$ 6,168	$ 4,893	$ (124)
Increase (Decrease) in Stockholders' Equity
Net income	315			315
Other comprehensive income	(3)				(3)
Dividends declared on common stock	(210)			(210)
Issuances of common stock (in shares)		637,000
Issuances of common stock	12	$ 2	10
Stock Repurchased During Period, Shares		(6,000)
Stock Repurchased During Period, Value	0	$ 0	0
Share-based compensation	(7)		(5)	(2)
Balance (in shares) at Mar. 31, 2019		514,668,000
Ending balance at Mar. 31, 2019	$ 12,329	$ 1,287	6,173	4,996	(127)
Balance (in shares) at Dec. 31, 2019	524,539,000	524,539,000
Beginning balance at Dec. 31, 2019	$ 13,239	$ 1,311	6,656	5,413	(141)
Increase (Decrease) in Stockholders' Equity
Net income	295			295
Other comprehensive income	(7)				(7)
Dividends declared on common stock	(227)			(227)
Issuances of common stock (in shares)		495,000
Issuances of common stock	12	$ 2	10
Share-based compensation	(8)		(7)	(1)
Adoption of ASC Topic 326	$ (2)			(2)
Balance (in shares) at Mar. 31, 2020	525,033,594	525,034,000
Ending balance at Mar. 31, 2020	$ 13,302	$ 1,313	$ 6,659	$ 5,478	$ (148)

CONSOLIDATED STATEMENTS OF CO_3

CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDERS' EQUITY (UNAUDITED) (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Common Stock
Dividends declared on common stock (USD per share)	$ 0.43	$ 0.41

Management's Opinion

Management's Opinion	3 Months Ended
	Mar. 31, 2020
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 U.S. GAAP, the financial position of Xcel Energy Inc. and its subsidiaries as of March 31, 2020 and Dec. 31, 2019 ; the results of its operations, including the components of net income and comprehensive income, and changes in stockholders’ equity for the three months ended March 31, 2020 and 2019 ; and its cash flows for the three months ended March 31, 2020 and 2019 . All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after March 31, 2020 , 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, 2019 , balance sheet information has been derived from the audited 2019 consolidated financial statements included in the Xcel Energy Inc. Annual Report on Form 10-K for the year ended Dec. 31, 2019 . 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, 2019 , filed with the SEC on Feb. 21, 2020. 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	3 Months Ended
	Mar. 31, 2020
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, 2019 , appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

Accounting Pronouncements

Accounting Pronouncements	3 Months Ended
	Mar. 31, 2020
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Accounting Pronouncements	Recently Adopted Credit Losses — In 2016, the FASB issued Financial Instruments - Credit Losses, Topic 326 (ASC Topic 326), which changes how entities account for losses on receivables and certain other assets. The guidance requires use of a current expected credit loss model, which may result in earlier recognition of credit losses than under previous accounting standards. Xcel Energy implemented the guidance using a modified-retrospective approach, recognizing a cumulative effect charge of $2 million

Selected Balance Sheet Data

Selected Balance Sheet Data	3 Months Ended
	Mar. 31, 2020
Balance Sheet Related Disclosures [Abstract]
Selected Balance Sheet Data	(Millions of Dollars) March 31, 2020 Dec. 31, 2019 Accounts receivable, net Accounts receivable $ 897 $ 892 Less allowance for bad debts (58 ) (55 ) Accounts receivable, net $ 839 $ 837 (Millions of Dollars) March 31, 2020 Dec. 31, 2019 Inventories Materials and supplies $ 283 $ 270 Fuel 170 191 Natural gas 35 83 Total inventories $ 488 $ 544 (Millions of Dollars) March 31, 2020 Dec. 31, 2019 Property, plant and equipment, net Electric plant $ 44,544 $ 44,355 Natural gas plant 6,653 6,560 Common and other property 2,991 2,341 Plant to be retired (a) 217 259 CWIP 2,756 2,329 Total property, plant and equipment 57,161 55,844 Less accumulated depreciation (16,730 ) (16,735 ) Nuclear fuel 2,913 2,909 Less accumulated amortization (2,568 ) (2,535 ) Property, plant and equipment, net $ 40,776 $ 39,483 (a) In 2018, the CPUC approved early retirement of PSCo’s Comanche Units 1 and 2 in approximately 2022 and 2025, respectively. PSCo also expects Craig Unit 1 to be retired early in 2025. Amounts are presented net of accumulated depreciation.

Borrowings and Other Financing

Borrowings and Other Financing Instruments	3 Months Ended
	Mar. 31, 2020
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 were as follows: (Amounts in Millions, Except Interest Rates) Three Months Ended March 31, 2020 Year Ended Borrowing limit $ 4,300 $ 3,600 Amount outstanding at period end 1,765 595 Average amount outstanding 1,404 1,115 Maximum amount outstanding 2,080 1,780 Weighted average interest rate, computed on a daily basis 2.05 % 2.72 % Weighted average interest rate at period end 1.96 2.34 Letters of Credit — Xcel Energy Inc. and its subsidiaries use letters of credit, generally with terms of one year , to provide financial guarantees for certain operating obligations. At both March 31, 2020 and Dec. 31, 2019 , there were $20 million of letters of credit outstanding under the credit facilities. The contract amounts of these letters of credit approximate their fair value and are subject to fees. Revolving Credit Facilities — In order to use commercial paper programs to fulfill short-term funding needs, Xcel Energy Inc. and its utility subsidiaries must have revolving credit facilities in place at least equal to the amount of their respective commercial paper borrowing limits and cannot issue commercial paper in an aggregate amount exceeding available capacity under these credit facilities. 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. As of March 31, 2020 , Xcel Energy Inc. and its utility subsidiaries had the following committed revolving credit facilities available: (Millions of Dollars) Credit Facility (a) Outstanding (b) Available Xcel Energy Inc. $ 1,250 $ 449 $ 801 PSCo 700 8 692 NSP-Minnesota 500 10 490 SPS 500 42 458 NSP-Wisconsin 150 76 74 Total $ 3,100 $ 585 $ 2,515 (a) Expires in June 2024 . (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 revolving credit facility termination date for two additional one year periods. NSP-Wisconsin has the right to request an extension of the revolving 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 under the respective credit facilities. Xcel Energy Inc. and its subsidiaries had no direct advances on the credit facilities outstanding as of March 31, 2020 and Dec. 31, 2019 . Term Loan Agreements — In March 2020, Xcel Energy Inc. entered into a $700 million , 364 -Day Term Loan Agreement. The loan is unsecured and matures March 22, 2021. Xcel Energy has an option to request an extension through March 21, 2022. The term loan includes one financial covenant, requiring Xcel Energy’s consolidated funded debt to total capitalization ratio to be less than or equal to 65 percent . Interest is at a rate equal to either the Eurodollar rate, plus 60.0 basis points, or an alternate base rate. As of March 31, 2020 , Xcel Energy Inc.’s term loan borrowings were as follows: (Millions of Dollars) Limit Amount Used Available Xcel Energy Inc. $ 1,200 $ 1,200 $ — Bilateral Credit Agreement In March 2019, NSP-Minnesota entered into a one year uncommitted bilateral credit agreement. The credit agreement is limited in use to support letters of credit. In March 2020, NSP-Minnesota renewed its bilateral credit agreement for an additional one-year term. As of March 31, 2020 , NSP-Minnesota’s outstanding letters of credit under the Bilateral Credit Agreement were as follows: (Millions of Dollars) Limit Amount Outstanding Available NSP-Minnesota $ 75 $ 26 $ 49 Long-Term Borrowings During the three months ended March 31, 2020 , Xcel Energy Inc. and its utility subsidiaries did not issue any long-term debt. On April 1, 2020, Xcel Energy Inc. issued $600 million of 3.40% senior unsecured notes due June 1, 2030. Forward Equity Agreements — In November 2019, Xcel Energy Inc. entered into forward sale agreements in connection with a completed $743 million public offering of 11.8 million shares of Xcel Energy common stock. The initial forward agreement was for 10.3 million shares with an additional agreement for 1.5 million shares that was exercised at the option of the banking counterparty. At March 31, 2020 , the forward agreements could have been settled with physical delivery of 11.8 million common shares to the banking counterparty in exchange for cash of $734 million . The forward instruments could also have been settled at March 31, 2020 , with delivery of approximately $19 million of cash or approximately 0.3 million shares of common stock to the counterparty, if Xcel Energy unilaterally elected net cash or net share settlement, respectively. The forward price used to determine amounts due at settlement is calculated based on the November 2019, public offering price for Xcel Energy’s common stock of $62.69 , increased for the overnight bank funding rate, less a spread of 0.75% and less expected dividends on Xcel Energy’s common stock during the period the instruments are outstanding. Xcel Energy may settle the agreements at any time up to the maturity date of Dec. 31, 2020. Depending on settlement timing, cash proceeds are expected to be approximately $720 million to $735 million . Forward equity instruments were recognized within stockholders’ equity at fair value at execution of the agreements and will not be subsequently adjusted until settlement. Other Equity — Xcel Energy Inc. issued $ 10 million of equity through the DRIP during both the three months ended March 31, 2020 and 2019 . The program allows shareholders to elect dividend reinvestment in Xcel Energy Inc. common stock through a non-cash transaction.

Revenues

Revenues	3 Months Ended
	Mar. 31, 2020
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 consists of the following: Three Months Ended March 31, 2020 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 676 $ 355 $ 11 $ 1,042 C&I 1,066 180 9 1,255 Other 29 — 1 30 Total retail 1,771 535 21 2,327 Wholesale 166 — — 166 Transmission 132 — — 132 Other 17 32 — 49 Total revenue from contracts with customers 2,086 567 21 2,674 Alternative revenue and other 117 16 4 137 Total revenues $ 2,203 $ 583 $ 25 $ 2,811 Three Months Ended March 31, 2019 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 727 $ 495 $ 9 $ 1,231 C&I 1,140 255 9 1,404 Other 32 — 1 33 Total retail 1,899 750 19 2,668 Wholesale 189 — — 189 Transmission 131 — — 131 Other 18 34 — 52 Total revenue from contracts with customers 2,237 784 19 3,040 Alternative revenue and other 88 10 3 101 Total revenues $ 2,325 $ 794 $ 22 $ 3,141

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Note 7 to the consolidated financial statements included in Xcel Energy’s Annual Report on Form 10-K for the year ended Dec. 31, 2019 , represents, in all material respects, the current status of other income tax matters except to the extent noted below, and are incorporated herein by reference. The following table reconciles the difference between the statutory rate and the ETR: Three Months Ended March 31 2020 2019 Federal statutory rate 21.0 % 21.0 % State tax (net of federal tax effect) 4.9 5.0 Decreases in tax from: Wind PTCs (17.2 ) (8.6 ) Plant regulatory differences (a) (8.4 ) (5.7 ) Other tax credits, net NOL & tax credit allowances (0.9 ) (2.7 ) Other (net) (1.5 ) (1.6 ) Effective income tax rate (2.1 )% 7.4 % (a) 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 credits are offset by corresponding revenue reductions. Federal Audits — Statute of limitations applicable to Xcel Energy’s consolidated federal income tax returns expire as follows: Tax Years Expiration 2009 - 2013 September 2020 2014 - 2016 June 2021 In 2015, the IRS commenced an examination of tax years 2012 and 2013. In 2017, the IRS concluded the audit of tax years 2012 and 2013 and proposed an adjustment that would impact Xcel Energy’s NOL and ETR. Xcel Energy filed a protest with the IRS. As of March 31, 2020, the case has been forwarded to the Office of Appeals and Xcel Energy has recognized its best estimate of income tax expense that will result from a final resolution of this issue; however, the outcome and timing of a resolution is unknown. In 2018, the IRS began an audit of tax years 2014 - 2016. As of March 31, 2020 , no adjustments have been proposed. State Audits — Xcel Energy files consolidated state tax returns based on income in its major operating jurisdictions and various other state income-based tax returns. As of March 31, 2020 , Xcel Energy’s earliest open tax years (subject to examination by state taxing authorities in its major operating jurisdictions) were as follows: State Year Colorado 2009 Minnesota 2009 Texas 2009 Wisconsin 2014 • In 2018, Wisconsin began an audit of tax years 2014 - 2016. As of March 31, 2020 , no material adjustments have been proposed. • No other state income tax audits were in progress as of March 31, 2020 . Unrecognized Benefits — Unrecognized tax benefit balance includes permanent tax positions, which if recognized would affect the annual ETR. In addition, the unrecognized tax benefit balance includes temporary tax positions for which ultimate deductibility is highly certain, but for which there is uncertainty about the timing of such deductibility. A change in the period of deductibility would not affect the ETR but would accelerate the payment to the taxing authority to an earlier period. Unrecognized tax benefits — permanent vs. temporary: (Millions of Dollars) March 31, 2020 Dec. 31, 2019 Unrecognized tax benefit — Permanent tax positions $ 36 $ 35 Unrecognized tax benefit — Temporary tax positions 10 9 Total unrecognized tax benefit $ 46 $ 44 Unrecognized tax benefits were reduced by tax benefits associated with NOL and tax credit carryforwards: (Millions of Dollars) March 31, 2020 Dec. 31, 2019 NOL and tax credit carryforwards $ (42 ) $ (40 ) Net deferred tax liability associated with the unrecognized tax benefit amounts and related NOLs and tax credits carryforwards were $30 million at March 31, 2020 and $29 million at Dec. 31, 2019 . As the IRS Appeals and federal and state audits progress, it is reasonably possible that the amount of unrecognized tax benefit could decrease up to approximately $28 million in the next 12 months. Payables for interest related to unrecognized tax benefits were not material and no amounts were accrued for penalties related to unrecognized tax benefits as of March 31, 2020 or Dec. 31, 2019 .

Earnings Per Share

Earnings Per Share	3 Months Ended
	Mar. 31, 2020
Earnings Per Share [Abstract]
Earnings Per Share	Basic EPS was computed by dividing the earnings available to common shareholders by the weighted average 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 forward equity agreements and 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 for settlement have been satisfied by the end of the reporting period; and • Liability awards subject to a performance condition; any portions settled in shares are included in common shares outstanding upon settlement. Diluted common shares outstanding included common stock equivalents of 0.8 million and 1.2 million for the three months ended March 31, 2020 and 2019 , respectively.

Fair Value of Financial Assets

Fair Value of Financial Assets and Liabilities	3 Months Ended
	Mar. 31, 2020
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; and • Level 3 — Significant inputs to pricing have little or no observability as of the reporting date. The types of assets and liabilities included in Level 3 are those valued with models requiring significant management judgment or estimation. Specific valuation methods include: Cash equivalents — The fair values of cash equivalents are generally based on cost plus accrued interest; money market funds are measured using quoted NAV. Investments in equity securities and other funds — Equity securities are valued using quoted prices in active markets. The fair values for commingled funds are measured using NAVs. The investments in commingled funds may be redeemed for NAV with proper notice. Private equity commingled fund investments require approval of the fund for any unscheduled redemption, and such redemptions may be approved or denied by the fund at its sole discretion. Unscheduled distributions from real estate commingled funds investments may be redeemed with proper notice, however, withdrawals may be delayed or discounted as a result of fund illiquidity. Investments in debt securities — Fair values for debt securities are determined by a third party pricing service using recent trades and observable spreads from benchmark interest rates for similar securities. Interest rate derivatives — 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 forecasts of forward prices and volatilities 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 a RTO are financial instruments that entitle or obligate the holder to monthly revenues or charges based on transmission congestion across a given transmission path. The value of an FTR is derived from, and designed to offset, the cost of transmission congestion. In addition to overall transmission load, congestion is also influenced by the operating schedules of power plants and the consumption of electricity pertinent to a given transmission path. Unplanned plant outages, scheduled plant maintenance, changes in the relative costs of fuels used in generation, weather and overall changes in demand for electricity can each impact the operating schedules of the power plants on the transmission grid and the value of an FTR. If forecasted costs of electric transmission congestion increase or decrease for a given FTR path, the value of that particular FTR instrument will likewise increase or decrease. Given the limited observability of certain inputs to the value of FTRs between auction processes, including expected plant operating schedules and retail and wholesale demand, fair value measurements for FTRs have been assigned a Level 3. Non-trading monthly FTR settlements are included in fuel and purchased energy cost recovery mechanisms as applicable in each jurisdiction and therefore changes in the fair value of the yet to be settled portions of most FTRs are deferred as a regulatory asset or liability. Given this regulatory treatment and the limited magnitude of FTRs relative to the electric utility operations of NSP-Minnesota and SPS, the numerous unobservable quantitative inputs pertinent to the value of FTRs are insignificant to the consolidated financial statements. 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 escrow and investment targets by asset class for both the escrow and 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 $454 million and $706 million as of March 31, 2020 and Dec. 31, 2019 , respectively, and unrealized losses were $88 million and $6 million as of March 31, 2020 and Dec. 31, 2019 , respectively. Non-derivative instruments with recurring fair value measurements in the nuclear decommissioning fund: March 31, 2020 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 NAV Total Nuclear decommissioning fund (a) Cash equivalents $ 71 $ 71 $ — $ — $ — $ 71 Commingled funds 756 — — — 843 843 Debt securities 514 — 488 13 — 501 Equity securities 435 726 1 — — 727 Total $ 1,776 $ 797 $ 489 $ 13 $ 843 $ 2,142 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheet, which also includes $158 million of equity investments in unconsolidated subsidiaries and $129 million of rabbi trust assets and miscellaneous investments. Dec. 31, 2019 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 NAV Total Nuclear decommissioning fund (a) Cash equivalents $ 33 $ 33 $ — $ — $ — $ 33 Commingled funds 733 — — — 935 935 Debt securities 489 — 495 13 — 508 Equity securities 485 962 2 — — 964 Total $ 1,740 $ 995 $ 497 $ 13 $ 935 $ 2,440 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheet, which also includes $155 million of equity investments in unconsolidated subsidiaries and $136 million of rabbi trust assets and miscellaneous investments. For the three months ended March 31, 2020 and 2019 , 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 March 31, 2020 : 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 $ 11 $ 81 $ 205 $ 204 $ 501 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: March 31, 2020 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 Total Rabbi Trusts (a) Cash equivalents $ 17 $ 17 $ — $ — $ 17 Mutual funds 57 56 — — 56 Total $ 74 $ 73 $ — $ — $ 73 Dec. 31, 2019 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 Total Rabbi Trusts (a) Cash equivalents $ 17 $ 17 $ — $ — $ 17 Mutual funds 57 65 — — 65 Total $ 74 $ 82 $ — $ — $ 82 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheet. 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 interest payments on certain floating rate debt obligations or 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. As of March 31, 2020 , Xcel Energy had $13 million of settlement payables related to interest rate swaps, which were paid in April 2020. These interest rate derivatives were designated as hedges and changes in fair value were recorded as other comprehensive income. As of March 31, 2020 , accumulated other comprehensive loss related to interest rate derivatives included $5 million of net losses expected to be reclassified into earnings during the next 12 months as the hedged transactions impact earnings. 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 activities governed by this policy. 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. Changes in the fair value of non-trading commodity derivative instruments are recorded as other comprehensive income or deferred as a regulatory asset or liability. The classification as a regulatory asset or liability is based on approved regulatory recovery mechanisms. As of March 31, 2020 , Xcel Energy had no commodity contracts designated as cash flow hedges. Xcel Energy 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) March 31, 2020 Dec. 31, 2019 MWh of electricity 79 95 MMBtu of natural gas 149 110 (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 March 31, 2020 , six of Xcel Energy’s 10 most significant counterparties for these activities, comprising $154 million , or 56% , of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings. Three of the 10 most significant counterparties, comprising $35 million , or 13% , of this credit exposure, were not rated by these external agencies, but based on Xcel Energy’s internal analysis, had credit quality consistent with investment grade. One of these significant counterparties, comprising $12 million or 4% of this credit exposure, had credit quality less than investment grade, based on internal analysis. Eight 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 Regulatory Three Months Ended March 31, 2020 Derivatives designated as cash flow hedges Interest rate $ (13 ) $ — Total (13 ) — Three Months Ended March 31, 2019 Derivatives designated as cash flow hedges Interest rate (9 ) — Total (9 ) — Other derivative instruments Electric commodity — 12 Natural gas commodity — 4 Total $ — $ 16 Pre-Tax (Gains) Losses Reclassified into Income During the Period from: Pre-Tax Gains (Losses) Recognized (Millions of Dollars) Accumulated Regulatory Three Months Ended March 31, 2020 Derivatives designated as cash flow hedges Interest rate $ 2 (a) $ — $ — Total 2 — — Other derivative instruments Commodity trading — — 1 (b) Electric commodity — (4 ) (c) — Natural gas commodity — 5 (d) (6 ) (d) Total — 1 (5 ) Three Months Ended March 31, 2019 Derivatives designated as cash flow hedges Interest rate 1 (a) — — Total 1 — — Other derivative instruments Commodity trading — — 1 (b) Electric commodity — 1 (c) — Natural gas commodity — (1 ) (d) (3 ) (d) Total $ — $ — $ (2 ) (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. (d) Amounts for both the three months ended March 31, 2020 and 2019 included no settlement gains or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining settlement losses for the three months ended March 31, 2020 and 2019 related to natural gas operations and were recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate. Xcel Energy had no derivative instruments designated as fair value hedges during the three months ended March 31, 2020 and 2019 . 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, or for cross default contractual provisions if there was a failure under other financing arrangements related to payment terms or other covenants. As of March 31, 2020 and Dec. 31, 2019 , there were $11 million and $7 million derivative instruments in a liability position with such underlying contract provisions, respectively. Certain derivative instruments are also subject to contract provisions that contain adequate assurance clauses. 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 March 31, 2020 and Dec. 31, 2019 . Recurring Fair Value Measurements — Derivative assets and liabilities measured at fair value on a recurring basis: March 31, 2020 Dec. 31, 2019 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 $ 8 $ 63 $ 16 $ 87 $ (63 ) $ 24 $ 3 $ 51 $ 24 $ 78 $ (52 ) $ 26 Electric commodity — — 18 18 — 18 — — 21 21 (1 ) 20 Natural gas commodity — — — — — — — 6 — 6 — 6 Total current derivative assets $ 8 $ 63 $ 34 $ 105 $ (63 ) 42 $ 3 $ 57 $ 45 $ 105 $ (53 ) 52 PPAs (b) 3 3 Current derivative instruments $ 45 $ 55 Noncurrent derivative assets Other derivative instruments: Commodity trading $ 10 $ 38 $ 22 $ 70 $ (45 ) $ 25 $ 9 $ 38 $ 7 $ 54 $ (45 ) $ 9 Electric commodity — — 2 2 — 2 — — — — — — Total noncurrent derivative assets $ 10 $ 38 $ 24 $ 72 $ (45 ) 27 $ 9 $ 38 $ 7 $ 54 $ (45 ) 9 PPAs (b) 12 13 Noncurrent derivative instruments $ 39 $ 22 March 31, 2020 Dec. 31, 2019 Fair Value Fair Value Total Netting (a) Total Fair Value Fair Value Total Netting (a) Total (Millions of Dollars) Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Current derivative liabilities Derivatives designated as cash flow hedges: Interest rate $ — $ 13 $ — $ 13 $ — $ 13 $ — $ — $ — $ — $ — $ — Other derivative instruments: Commodity trading $ 8 $ 62 $ 14 $ 84 $ (63 ) $ 21 $ 4 $ 59 $ 15 $ 78 $ (63 ) $ 15 Electric commodity — — — — — — — — 1 1 (1 ) — Natural gas commodity — — — — — — — 5 — 5 — 5 Total current derivative liabilities $ 8 $ 75 $ 14 $ 97 $ (63 ) 34 $ 4 $ 64 $ 16 $ 84 $ (64 ) 20 PPAs (b) 18 18 Current derivative instruments $ 52 $ 38 Noncurrent derivative liabilities Other derivative instruments: Commodity trading $ 3 $ 89 $ 39 $ 131 $ (19 ) $ 112 $ 2 $ 79 $ 32 $ 113 $ (13 ) $ 100 Total noncurrent derivative liabilities $ 3 $ 89 $ 39 $ 131 $ (19 ) 112 $ 2 $ 79 $ 32 $ 113 $ (13 ) 100 PPAs (b) 71 75 Noncurrent derivative instruments $ 183 $ 175 (a) Xcel Energy nets derivative instruments and related collateral in its consolidated balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at March 31, 2020 and Dec. 31, 2019 . At both March 31, 2020 and Dec. 31, 2019 , derivative assets and liabilities include $32 million of obligations to return cash collateral and rights to reclaim cash collateral of $6 million and $11 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) 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 March 31 (Millions of Dollars) 2020 2019 Balance at Jan. 1 $ 4 $ 29 Purchases 12 4 Settlements (18 ) (11 ) Net transactions recorded during the period: Gains (losses) recognized in earnings (a) 6 (18 ) Net gains (losses) recognized as regulatory assets and liabilities 1 (11 ) Balance at March 31 $ 5 $ (7 ) (a) Amounts relate to commodity derivatives held at the end of the period. 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 three months ended March 31, 2020 and 2019 Fair Value of Long-Term Debt Other financial instruments which the carrying amount did not equal fair value: March 31, 2020 Dec. 31, 2019 (Millions of Dollars) Carrying Amount Fair Value Carrying Amount Fair Value Long-term debt, including current portion $ 18,112 $ 19,864 $ 18,109 $ 20,227 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 March 31, 2020 and Dec. 31, 2019 , 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	3 Months Ended
	Mar. 31, 2020
Retirement Benefits [Abstract]
Benefit Plans and Other Postretirement Benefits	Components of Net Periodic Benefit Cost (Credit) Three Months Ended March 31 2020 2019 2020 2019 (Millions of Dollars) Pension Benefits Postretirement Health Service cost $ 24 $ 22 $ — $ — Interest cost (a) 31 36 5 6 Expected return on plan assets (a) (52 ) (51 ) (5 ) (5 ) Amortization of prior service credit (a) (1 ) (1 ) (2 ) (3 ) Amortization of net loss (a) 25 22 1 1 Net periodic benefit cost (credit) 27 28 (1 ) (1 ) Credits not recognized due to effects of regulation 2 1 1 — Net benefit cost (credit) recognized for financial reporting $ 29 $ 29 $ — $ (1 ) (a) Components of net periodic cost other than the service cost component are included in the line item “other (expense) income, net” in the consolidated statement of income or capitalized on the consolidated balance sheet as a regulatory asset. In January 2020, contributions of $150 million were made across four

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	The following include commitments, contingencies and unresolved contingencies that are material to Xcel Energy’s financial position. 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 of such matters, including a possible eventual loss. For current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, would have a material effect on Xcel Energy’s financial statements. Unless otherwise required by GAAP, legal fees are 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 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. Two cases remain active which include an MDL matter consisting of a Colorado purported class (Breckenridge) and a Wisconsin purported class (Arandell Corp.). Breckenridge/Colorado — In February 2019, the MDL panel remanded Breckenridge back to the U.S. District Court in Colorado. Arandell Corp. — In February 2019, the case was remanded back to the U.S. District Court in Wisconsin. Plaintiffs are seeking class certification. It is uncertain when the court will rule on this issue. Xcel Energy has concluded that a loss is remote for both remaining lawsuits. Rate Matters MEC Transactions — In November 2018, NSP-Minnesota reached an agreement with Southern Power Company (a subsidiary of Southern Company) to purchase MEC, a 760 MW natural gas combined cycle facility, for approximately $650 million . In September 2019, the MPUC denied NSP-Minnesota's request to purchase MEC as a rate base asset. In January 2020, the MPUC approved Xcel Energy’s plan to acquire MEC as a non-regulated investment and step into the existing PPAs with NSP-Minnesota. A newly formed non-regulated subsidiary of Xcel Energy completed the transaction to purchase MEC in January 2020. In April 2020, Xcel Energy reached agreement to sell MEC to Southwest Generation for $680 million , subject to working capital adjustments. Proceeds from the sale will primarily be used to reduce Xcel Energy’s overall financing needs. The transaction is not anticipated to have a material impact on long-term earnings per share and is expected to close in the third quarter of 2020. The sale will result in a gain, which Xcel Energy plans to use to fund its corporate giving efforts, including support related to COVID-19 recovery. NSP-Minnesota — Sherco — In NSP-Minnesota’s 2013 fuel reconciliation filing, the MPUC made recovery of replacement power costs associated with the 2011 incident at its Sherco Unit 3 plant provisional and subject to further review following conclusion of litigation commenced by NSP-Minnesota, SMMPA (Co-owner of Sherco Unit 3) and insurance companies against GE. In 2018, NSP-Minnesota and SMMPA reached a settlement with GE. NSP-Minnesota notified the MPUC of its proposal to refund the GE settlement proceeds back to customers through the FCA. The insurance providers continued their litigation against GE and the case went to trial. In 2018, GE prevailed in the lawsuit with the insurance companies, however, the jury found comparable fault, finding that GE was 52% and NSP-Minnesota was 48% at fault. At that point in the litigation, NSP-Minnesota was no longer involved in the case and was not present to make arguments about its role in the event. The specific issue leading to the fault apportionment was also not before the jury and not relevant to the outcome of the trial. In January 2019, the DOC recommended that NSP-Minnesota refund $20 million of previously recovered purchased power costs to its customers, based on the jury’s apportionment of fault. The OAG recommended the MPUC withhold any decision until the underlying litigation by the insurance providers (currently under appeal) is concluded. The DOC subsequently filed comments agreeing with the OAG’s recommendation to withhold a decision pending the outcome of any appeals. NSP-Minnesota filed reply comments arguing that the DOC recommendations are without merit and that it acted prudently in operating the plant and its settlement with GE was reasonable. In March 2019, MPUC approved NSP-Minnesota’s proposal to refund the GE settlement proceeds back to customers through the FCA. It also decided to withhold any decision as to NSP-Minnesota’s prudence in connection with the incident at Sherco Unit 3 until after conclusion of the pending litigation between GE and NSP-Minnesota’s insurers. The lower court’s decision was affirmed on appeal. In March 2020, NSP-Minnesota’s insurers filed a petition seeking additional review by the Minnesota Supreme Court, which remains pending. MISO ROE Complaints — In November 2013 and February 2015, customers filed complaints against MISO TOs including NSP-Minnesota and NSP-Wisconsin. The first complaint argued for a reduction in the base ROE in MISO transmission formula rates from 12.38% to 9.15% , and removal of ROE adders (including those for RTO membership). The second complaint sought to reduce base ROE from 12.38% to 8.67% . In September 2016, the FERC issued an order granting a 10.32% base ROE ( 10.82% with the RTO adder) effective for the first complaint period of Nov. 12, 2013 to Feb. 11, 2015 and subsequent to the date of the order. The D.C. Circuit subsequently vacated and remanded FERC Opinion No. 531, which had established the ROE methodology on which the September 2016 FERC order was based. On March 21, 2019, FERC announced a NOI seeking public comments on whether, and if so how, to revise ROE policies in light of the D.C. Circuit Court decision. FERC also initiated a NOI on whether to revise its policies on incentives for electric transmission investments, including the RTO membership incentive. In November 2019, the FERC issued an order adopting a new ROE methodology and settling the MISO base ROE at 9.88% ( 10.38% with the RTO adder), effective Sept. 28, 2016 and for the Nov. 12, 2013 to Feb. 11, 2015 refund period. The FERC also dismissed the second complaint. In December 2019, MISO TOs filed a request for rehearing. Customers also filed requests for rehearing claiming, among other points, that the FERC erred by dismissing the second complaint without refunds. FERC accepted the requests for rehearing in January 2020, however, it is uncertain when the FERC will act on the requests or any other pending matters related to the 2019 NOIs . NSP-Minnesota has recognized a liability for its best estimate of final refunds to customers. In March 2020, the FERC issued a Notice of Proposed Rulemaking regarding changes to its policies for transmission incentives, including a proposal to increase the RTO participation adder from 50 to 100 basis points and to make the adder available regardless of whether a utility’s ongoing participation in the RTO is voluntary or required by legislation or a regulator. It is uncertain if or when this change will be adopted and implemented as a final order. SPP OATT Upgrade Costs — Under the SPP OATT, costs of transmission upgrades may be recovered from other SPP customers whose transmission service depends on capacity enabled by the upgrade. 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 these previously unbilled charges was remanded to the FERC. In February 2019, the FERC reversed its 2016 decision and ordered SPP to refund the charges retroactively collected from its transmission customers, including SPS, related to periods before September 2015. In April 2019, several parties, including SPP, filed requests for a rehearing. In February 2020, FERC issued an order rejecting all rehearing requests and providing certain clarifications. In March 2020, SPP and Oklahoma Gas & Electric separately filed petitions for review of FERC’s orders at the D.C. Circuit. SPS has intervened in both appeals in support of FERC. The timing of an appeals decision is uncertain. Any refunds received by SPS are expected to be given back to SPS customers through future rates. In October 2017, SPS filed a separate complaint against SPP asserting that SPP has assessed upgrade charges to SPS in violation of the SPP OATT. The FERC granted a rehearing for further consideration in May 2018. The timing of FERC action on the SPS rehearing is uncertain. If SPS’ complaint results in additional charges or refunds, SPS will seek to recover or refund the amounts through future SPS customer rates. Environmental MGP, Landfill and Disposal Sites Ashland MGP Site — NSP-Wisconsin was named a responsible party for contamination at the Ashland/Northern States Power Lakefront Superfund Site (the Site) in Ashland, Wisconsin. Remediation was completed in 2019 and restoration activities are anticipated to be completed in 2020. Groundwater treatment activities will continue for many years. The current cost estimate for remediation and restoration of the entire site is approximately $199 million . At March 31, 2020 and Dec. 31, 2019, NSP‑Wisconsin had a total liability of $22 million and $23 million , respectively, for the entire site. NSP-Wisconsin has deferred the unrecovered portion of the estimated Site remediation and restoration costs as a regulatory asset. The PSCW has authorized NSP-Wisconsin rate recovery for all remediation and restoration costs incurred at the Site. In its final December 2019 order approving 2020 and 2021 natural gas base rates, the PSCW authorized continued amortization of costs and application of a 3% carrying charge to the regulatory asset. Rice Yards (Denver ) MGP Site — PSCo is cooperating with the City of Denver on an environmental investigation of the Rice Yards Site in Denver, Colorado, which had various historic industrial uses by multiple parties, including railroad, maintenance shop, scrap metal yard and MGP operations. The area is being redeveloped into residential and commercial mixed uses, and PSCo is in discussions with the current property owner regarding legal claims related to the Rice Yards Site. In addition to the Rice Yards and Ashland Sites, Xcel Energy is currently investigating, remediating or performing post-closure actions at 11 other MGP, landfill or other disposal sites across its service territories. Xcel Energy has recognized its best estimate of costs/liabilities that will result from final resolution of these issues, however, the outcome and timing is 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 CCR landfills and surface impoundments. Currently, Xcel Energy has nine regulated ash units in operation. Xcel Energy is conducting groundwater sampling and, where appropriate, implementing assessment of corrective measures at certain CCR landfills and surface impoundments. In 2019, groundwater monitoring consistent with the CCR Rule was conducted. In NSP-Minnesota, no results above the groundwater protection standards in the rule were identified. In PSCo, statistically significant increases above background concentrations were detected at four locations. Subsequently, assessment monitoring samples were collected, and PSCo is evaluating options for corrective action at two locations. Until PSCo completes its assessment, it is uncertain what impact, if any, there will be on the operations, financial condition or cash flows. In August 2018, the D.C. Circuit ruled that the EPA cannot allow utilities to continue to use unlined impoundments (including clay lined impoundments) for the storage or disposal of coal ash. In November 2019, the EPA proposed rules in response to this decision. If finalized in their current form, these rules would require NSP-Minnesota to expedite closure plans for one impoundment at an estimated cost of $4 million and the construction of a new impoundment at the cost of $8 million . In 2019, NSP-Minnesota initiated the construction of this new impoundment, an ash pond, expected to be in service in 2020. Upon placing the new ash pond in service, the existing ash pond will be taken out of service, and closure activities as prescribed by the CCR Rule and the facility’s National Pollutant Discharge Elimination System permit will be initiated. In addition, the rules proposed by the EPA under the D.C. Circuit ruling may require PSCo to expedite the closure of one coal ash impoundment that was not previously required to close. PSCo is pursuing options through comment on the proposed rules or some other means to allow continued operation of this impoundment until the generating units are retired in 2025, at which time the impoundment would be closed. Closure costs for existing impoundments are included in the calculation of the asset retirement obligation liability. Leases Operating lease liabilities at Dec. 31, 2019 include a present value of remaining lease payments of approximately $400 million for the MEC PPAs. At March 31, 2020, NSP-Minnesota operating lease liabilities and related ROU assets are eliminated from Xcel Energy’s consolidated balance sheet following the completed January 2020 purchase of MEC by Xcel Energy. VIEs 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 approximately 3,266 MW and 3,986 MW of capacity under long‑term PPAs at March 31, 2020 and Dec. 31, 2019, respectively, with entities that have been determined to be VIEs. Xcel Energy concluded that these entities are not required to be consolidated in its consolidated financial statements because it does not have the power to direct the activities that most significantly impact the entities’ economic performance. Agreements have expiration dates through 2041 . Other Guarantees and Bond Indemnifications — Xcel Energy Inc. and its subsidiaries provide guarantees and bond indemnities, which guarantee payment or performance. Xcel Energy Inc.’s exposure is based upon the net liability under the specified agreements or transactions. Most of the guarantees and bond indemnities issued by Xcel Energy Inc. and its subsidiaries have a stated maximum amount. As of March 31, 2020 and Dec. 31, 2019 , Xcel Energy Inc. and its subsidiaries 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 $60 million and $62 million at March 31, 2020 and Dec. 31, 2019 , respectively. Other Indemnification Agreements — Xcel Energy Inc. and its subsidiaries provide 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 Inc.’s and its subsidiaries’ obligations under these agreements may be limited in terms of duration and amount. Maximum future payments under these indemnifications cannot be reasonably estimated as the dollar amounts are often not explicitly stated.

Other Comprehensive Income

Other Comprehensive Income	3 Months Ended
	Mar. 31, 2020
Stockholders' Equity Note [Abstract]
Other Comprehensive Income	Changes in accumulated other comprehensive loss, net of tax, for the three months ended March 31, 2020 and 2019 : Three Months Ended March 31, 2020 (Millions of Dollars) Gains and Losses on Cash Flow Hedges Defined Benefit Pension and Postretirement Items Total Accumulated other comprehensive loss at Jan. 1 $ (80 ) $ (61 ) $ (141 ) Other comprehensive loss before reclassifications (net of taxes of $(3) and $0, respectively) (10 ) — (10 ) Losses reclassified from net accumulated other comprehensive loss: Interest rate derivatives (net of taxes of $0) (a) 2 — 2 Amortization of net actuarial loss (net of taxes of $0) (b) — 1 1 Net current period other comprehensive (loss) income (8 ) 1 (7 ) Accumulated other comprehensive loss at March 31 $ (88 ) $ (60 ) $ (148 ) (a) Included in interest charges. (b) Included in the computation of net periodic pension and postretirement benefit costs. Three Months Ended March 31, 2019 (Millions of Dollars) Gains and Losses on Cash Flow Hedges Defined Benefit Pension and Postretirement Items Total Accumulated other comprehensive loss at Jan. 1 $ (60 ) $ (64 ) $ (124 ) Other comprehensive (loss) gain before reclassifications (net of taxes of $(2) and $1, respectively) (7 ) 2 (5 ) Losses reclassified from net accumulated other comprehensive loss: Interest rate derivatives (net of taxes of $0) (a) 1 — 1 Amortization of net actuarial loss (net of taxes of $0) (b) — 1 1 Net current period other comprehensive (loss) income (6 ) 3 (3 ) Accumulated other comprehensive loss at March 31 $ (66 ) $ (61 ) $ (127 ) (a) Included in interest charges. (b) Included in the computation of net periodic pension and postretirement benefit costs.

Segment Information

Segment Information	3 Months Ended
	Mar. 31, 2020
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; and • 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 presents 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 investments in unconsolidated subsidiaries of $158 million and $155 million as of March 31, 2020 and Dec. 31, 2019 , 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 for the three months ended March 31 : (Millions of Dollars) 2020 2019 Regulated Electric Operating revenues from external customers $ 2,203 $ 2,325 Net income 227 234 Regulated Natural Gas Operating revenues from external customers $ 583 $ 794 Intersegment revenue — 1 Total revenues $ 583 $ 795 Net income 91 105 All Other Total operating revenue $ 25 $ 22 Net loss (23 ) (24 ) Consolidated Total Total revenue $ 2,811 $ 3,142 Reconciling eliminations — (1 ) Consolidated total revenue $ 2,811 $ 3,141 Net income 295 315

Selected Balance Sheet Data (Ta

Selected Balance Sheet Data (Tables)	3 Months Ended
	Mar. 31, 2020
Balance Sheet Related Disclosures [Abstract]
Accounts receivable, net	(Millions of Dollars) March 31, 2020 Dec. 31, 2019 Accounts receivable, net Accounts receivable $ 897 $ 892 Less allowance for bad debts (58 ) (55 ) Accounts receivable, net $ 839 $ 837
Inventories	(Millions of Dollars) March 31, 2020 Dec. 31, 2019 Inventories Materials and supplies $ 283 $ 270 Fuel 170 191 Natural gas 35 83 Total inventories $ 488 $ 544
Property, plant and equipment, net	(Millions of Dollars) March 31, 2020 Dec. 31, 2019 Property, plant and equipment, net Electric plant $ 44,544 $ 44,355 Natural gas plant 6,653 6,560 Common and other property 2,991 2,341 Plant to be retired (a) 217 259 CWIP 2,756 2,329 Total property, plant and equipment 57,161 55,844 Less accumulated depreciation (16,730 ) (16,735 ) Nuclear fuel 2,913 2,909 Less accumulated amortization (2,568 ) (2,535 ) Property, plant and equipment, net $ 40,776 $ 39,483 (a) In 2018, the CPUC approved early retirement of PSCo’s Comanche Units 1 and 2 in approximately 2022 and 2025, respectively. PSCo also expects Craig Unit 1 to be retired early in 2025. Amounts are presented net of accumulated depreciation.

Borrowings and Other Financin_2

Borrowings and Other Financing Instruments (Tables)	3 Months Ended
	Mar. 31, 2020
Debt Disclosure [Abstract]
Commercial paper and term loan borrowings	Commercial paper and term loan borrowings outstanding for Xcel Energy were as follows: (Amounts in Millions, Except Interest Rates) Three Months Ended March 31, 2020 Year Ended Borrowing limit $ 4,300 $ 3,600 Amount outstanding at period end 1,765 595 Average amount outstanding 1,404 1,115 Maximum amount outstanding 2,080 1,780 Weighted average interest rate, computed on a daily basis 2.05 % 2.72 % Weighted average interest rate at period end 1.96 2.34 In March 2020, Xcel Energy Inc. entered into a $700 million , 364 -Day Term Loan Agreement. The loan is unsecured and matures March 22, 2021. Xcel Energy has an option to request an extension through March 21, 2022. The term loan includes one financial covenant, requiring Xcel Energy’s consolidated funded debt to total capitalization ratio to be less than or equal to 65 percent . Interest is at a rate equal to either the Eurodollar rate, plus 60.0 basis points, or an alternate base rate. As of March 31, 2020 , Xcel Energy Inc.’s term loan borrowings were as follows: (Millions of Dollars) Limit Amount Used Available Xcel Energy Inc. $ 1,200 $ 1,200 $ —
Credit Facilities	As of March 31, 2020 , Xcel Energy Inc. and its utility subsidiaries had the following committed revolving credit facilities available: (Millions of Dollars) Credit Facility (a) Outstanding (b) Available Xcel Energy Inc. $ 1,250 $ 449 $ 801 PSCo 700 8 692 NSP-Minnesota 500 10 490 SPS 500 42 458 NSP-Wisconsin 150 76 74 Total $ 3,100 $ 585 $ 2,515 (a) Expires in June 2024 . (b) Includes outstanding commercial paper and letters of credit. As of March 31, 2020 , NSP-Minnesota’s outstanding letters of credit under the Bilateral Credit Agreement were as follows: (Millions of Dollars) Limit Amount Outstanding Available NSP-Minnesota $ 75 $ 26 $ 49

Revenues (Tables)

Revenues (Tables)	3 Months Ended
	Mar. 31, 2020
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	Three Months Ended March 31, 2019 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 727 $ 495 $ 9 $ 1,231 C&I 1,140 255 9 1,404 Other 32 — 1 33 Total retail 1,899 750 19 2,668 Wholesale 189 — — 189 Transmission 131 — — 131 Other 18 34 — 52 Total revenue from contracts with customers 2,237 784 19 3,040 Alternative revenue and other 88 10 3 101 Total revenues $ 2,325 $ 794 $ 22 $ 3,141 Revenue is classified by the type of goods/services rendered and market/customer type. Xcel Energy’s operating revenues consists of the following: Three Months Ended March 31, 2020 (Millions of Dollars) Electric Natural Gas All Other Total Major revenue types Revenue from contracts with customers: Residential $ 676 $ 355 $ 11 $ 1,042 C&I 1,066 180 9 1,255 Other 29 — 1 30 Total retail 1,771 535 21 2,327 Wholesale 166 — — 166 Transmission 132 — — 132 Other 17 32 — 49 Total revenue from contracts with customers 2,086 567 21 2,674 Alternative revenue and other 117 16 4 137 Total revenues $ 2,203 $ 583 $ 25 $ 2,811

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2020
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	The following table reconciles the difference between the statutory rate and the ETR: Three Months Ended March 31 2020 2019 Federal statutory rate 21.0 % 21.0 % State tax (net of federal tax effect) 4.9 5.0 Decreases in tax from: Wind PTCs (17.2 ) (8.6 ) Plant regulatory differences (a) (8.4 ) (5.7 ) Other tax credits, net NOL & tax credit allowances (0.9 ) (2.7 ) Other (net) (1.5 ) (1.6 ) Effective income tax rate (2.1 )% 7.4 % (a) 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 credits are offset by corresponding revenue reductions.
Summary of Statute of Limitations Applicable to Open Tax Years [Table Text Block]	Federal Audits — Statute of limitations applicable to Xcel Energy’s consolidated federal income tax returns expire as follows: Tax Years Expiration 2009 - 2013 September 2020 2014 - 2016 June 2021
Earliest Open Tax Years Subject to Examination by State Taxing Authorities in the Major Operating Jurisdictions	As of March 31, 2020 , Xcel Energy’s earliest open tax years (subject to examination by state taxing authorities in its major operating jurisdictions) were as follows: State Year Colorado 2009 Minnesota 2009 Texas 2009 Wisconsin 2014 • In 2018, Wisconsin began an audit of tax years 2014 - 2016. As of March 31, 2020 , no material adjustments have been proposed. • No other state income tax audits were in progress as of March 31, 2020 .
Reconciliation of Unrecognized Tax Benefits	Unrecognized tax benefits — permanent vs. temporary: (Millions of Dollars) March 31, 2020 Dec. 31, 2019 Unrecognized tax benefit — Permanent tax positions $ 36 $ 35 Unrecognized tax benefit — Temporary tax positions 10 9 Total unrecognized tax benefit $ 46 $ 44
Tax Benefits Associated with NOL and Tax Credit Carryforwards	Unrecognized tax benefits were reduced by tax benefits associated with NOL and tax credit carryforwards: (Millions of Dollars) March 31, 2020 Dec. 31, 2019 NOL and tax credit carryforwards $ (42 ) $ (40 )

Fair Value of Financial Asset_2

Fair Value of Financial Assets and Liabilities (Tables)	3 Months Ended
	Mar. 31, 2020
Fair Value Disclosures [Abstract]
Cost and Fair Value of Nuclear Decommissioning Fund Investments	Dec. 31, 2019 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 NAV Total Nuclear decommissioning fund (a) Cash equivalents $ 33 $ 33 $ — $ — $ — $ 33 Commingled funds 733 — — — 935 935 Debt securities 489 — 495 13 — 508 Equity securities 485 962 2 — — 964 Total $ 1,740 $ 995 $ 497 $ 13 $ 935 $ 2,440 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheet, which also includes $155 million of equity investments in unconsolidated subsidiaries and $136 million of rabbi trust assets and miscellaneous investments. Non-derivative instruments with recurring fair value measurements in the nuclear decommissioning fund: March 31, 2020 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 NAV Total Nuclear decommissioning fund (a) Cash equivalents $ 71 $ 71 $ — $ — $ — $ 71 Commingled funds 756 — — — 843 843 Debt securities 514 — 488 13 — 501 Equity securities 435 726 1 — — 727 Total $ 1,776 $ 797 $ 489 $ 13 $ 843 $ 2,142 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheet, which also includes $158 million of equity investments in unconsolidated subsidiaries and $129 million of rabbi trust assets and 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 March 31, 2020 : 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 $ 11 $ 81 $ 205 $ 204 $ 501
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: March 31, 2020 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 Total Rabbi Trusts (a) Cash equivalents $ 17 $ 17 $ — $ — $ 17 Mutual funds 57 56 — — 56 Total $ 74 $ 73 $ — $ — $ 73 Dec. 31, 2019 Fair Value (Millions of Dollars) Cost Level 1 Level 2 Level 3 Total Rabbi Trusts (a) Cash equivalents $ 17 $ 17 $ — $ — $ 17 Mutual funds 57 65 — — 65 Total $ 74 $ 82 $ — $ — $ 82 (a) Reported in nuclear decommissioning fund and other investments on the consolidated balance sheet.
Gross Notional Amounts of Commodity Forwards, Options, and FTRs	Gross notional amounts of commodity forwards, options and FTRs: (Amounts in Millions) (a)(b) March 31, 2020 Dec. 31, 2019 MWh of electricity 79 95 MMBtu of natural gas 149 110 (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 Regulatory Three Months Ended March 31, 2020 Derivatives designated as cash flow hedges Interest rate $ (13 ) $ — Total (13 ) — Three Months Ended March 31, 2019 Derivatives designated as cash flow hedges Interest rate (9 ) — Total (9 ) — Other derivative instruments Electric commodity — 12 Natural gas commodity — 4 Total $ — $ 16 Pre-Tax (Gains) Losses Reclassified into Income During the Period from: Pre-Tax Gains (Losses) Recognized (Millions of Dollars) Accumulated Regulatory Three Months Ended March 31, 2020 Derivatives designated as cash flow hedges Interest rate $ 2 (a) $ — $ — Total 2 — — Other derivative instruments Commodity trading — — 1 (b) Electric commodity — (4 ) (c) — Natural gas commodity — 5 (d) (6 ) (d) Total — 1 (5 ) Three Months Ended March 31, 2019 Derivatives designated as cash flow hedges Interest rate 1 (a) — — Total 1 — — Other derivative instruments Commodity trading — — 1 (b) Electric commodity — 1 (c) — Natural gas commodity — (1 ) (d) (3 ) (d) Total $ — $ — $ (2 ) (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. (d) Amounts for both the three months ended March 31, 2020 and 2019 included no settlement gains or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining settlement losses for the three months ended March 31, 2020 and 2019 related to natural gas operations and were recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.
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: March 31, 2020 Dec. 31, 2019 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 $ 8 $ 63 $ 16 $ 87 $ (63 ) $ 24 $ 3 $ 51 $ 24 $ 78 $ (52 ) $ 26 Electric commodity — — 18 18 — 18 — — 21 21 (1 ) 20 Natural gas commodity — — — — — — — 6 — 6 — 6 Total current derivative assets $ 8 $ 63 $ 34 $ 105 $ (63 ) 42 $ 3 $ 57 $ 45 $ 105 $ (53 ) 52 PPAs (b) 3 3 Current derivative instruments $ 45 $ 55 Noncurrent derivative assets Other derivative instruments: Commodity trading $ 10 $ 38 $ 22 $ 70 $ (45 ) $ 25 $ 9 $ 38 $ 7 $ 54 $ (45 ) $ 9 Electric commodity — — 2 2 — 2 — — — — — — Total noncurrent derivative assets $ 10 $ 38 $ 24 $ 72 $ (45 ) 27 $ 9 $ 38 $ 7 $ 54 $ (45 ) 9 PPAs (b) 12 13 Noncurrent derivative instruments $ 39 $ 22 March 31, 2020 Dec. 31, 2019 Fair Value Fair Value Total Netting (a) Total Fair Value Fair Value Total Netting (a) Total (Millions of Dollars) Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Current derivative liabilities Derivatives designated as cash flow hedges: Interest rate $ — $ 13 $ — $ 13 $ — $ 13 $ — $ — $ — $ — $ — $ — Other derivative instruments: Commodity trading $ 8 $ 62 $ 14 $ 84 $ (63 ) $ 21 $ 4 $ 59 $ 15 $ 78 $ (63 ) $ 15 Electric commodity — — — — — — — — 1 1 (1 ) — Natural gas commodity — — — — — — — 5 — 5 — 5 Total current derivative liabilities $ 8 $ 75 $ 14 $ 97 $ (63 ) 34 $ 4 $ 64 $ 16 $ 84 $ (64 ) 20 PPAs (b) 18 18 Current derivative instruments $ 52 $ 38 Noncurrent derivative liabilities Other derivative instruments: Commodity trading $ 3 $ 89 $ 39 $ 131 $ (19 ) $ 112 $ 2 $ 79 $ 32 $ 113 $ (13 ) $ 100 Total noncurrent derivative liabilities $ 3 $ 89 $ 39 $ 131 $ (19 ) 112 $ 2 $ 79 $ 32 $ 113 $ (13 ) 100 PPAs (b) 71 75 Noncurrent derivative instruments $ 183 $ 175 (a) Xcel Energy nets derivative instruments and related collateral in its consolidated balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at March 31, 2020 and Dec. 31, 2019 . At both March 31, 2020 and Dec. 31, 2019 , derivative assets and liabilities include $32 million of obligations to return cash collateral and rights to reclaim cash collateral of $6 million and $11 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) 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 March 31 (Millions of Dollars) 2020 2019 Balance at Jan. 1 $ 4 $ 29 Purchases 12 4 Settlements (18 ) (11 ) Net transactions recorded during the period: Gains (losses) recognized in earnings (a) 6 (18 ) Net gains (losses) recognized as regulatory assets and liabilities 1 (11 ) Balance at March 31 $ 5 $ (7 ) (a) Amounts relate to commodity derivatives held at the end of the period.
Carrying Amount and Fair Value of Long-term Debt	Other financial instruments which the carrying amount did not equal fair value: March 31, 2020 Dec. 31, 2019 (Millions of Dollars) Carrying Amount Fair Value Carrying Amount Fair Value Long-term debt, including current portion $ 18,112 $ 19,864 $ 18,109 $ 20,227

Benefit Plans and Other Postr_2

Benefit Plans and Other Postretirement Benefits (Tables)	3 Months Ended
	Mar. 31, 2020
Retirement Benefits [Abstract]
Components of Net Periodic Benefit Cost (Credit)	Components of Net Periodic Benefit Cost (Credit) Three Months Ended March 31 2020 2019 2020 2019 (Millions of Dollars) Pension Benefits Postretirement Health Service cost $ 24 $ 22 $ — $ — Interest cost (a) 31 36 5 6 Expected return on plan assets (a) (52 ) (51 ) (5 ) (5 ) Amortization of prior service credit (a) (1 ) (1 ) (2 ) (3 ) Amortization of net loss (a) 25 22 1 1 Net periodic benefit cost (credit) 27 28 (1 ) (1 ) Credits not recognized due to effects of regulation 2 1 1 — Net benefit cost (credit) recognized for financial reporting $ 29 $ 29 $ — $ (1 ) (a) Components of net periodic cost other than the service cost component are included in the line item “other (expense) income, net” in the consolidated statement of income or capitalized on the consolidated balance sheet as a regulatory asset.

Other Comprehensive Income (Tab

Other Comprehensive Income (Tables)	3 Months Ended
	Mar. 31, 2020
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 months ended March 31, 2020 and 2019 : Three Months Ended March 31, 2020 (Millions of Dollars) Gains and Losses on Cash Flow Hedges Defined Benefit Pension and Postretirement Items Total Accumulated other comprehensive loss at Jan. 1 $ (80 ) $ (61 ) $ (141 ) Other comprehensive loss before reclassifications (net of taxes of $(3) and $0, respectively) (10 ) — (10 ) Losses reclassified from net accumulated other comprehensive loss: Interest rate derivatives (net of taxes of $0) (a) 2 — 2 Amortization of net actuarial loss (net of taxes of $0) (b) — 1 1 Net current period other comprehensive (loss) income (8 ) 1 (7 ) Accumulated other comprehensive loss at March 31 $ (88 ) $ (60 ) $ (148 ) (a) Included in interest charges. (b) Included in the computation of net periodic pension and postretirement benefit costs. Three Months Ended March 31, 2019 (Millions of Dollars) Gains and Losses on Cash Flow Hedges Defined Benefit Pension and Postretirement Items Total Accumulated other comprehensive loss at Jan. 1 $ (60 ) $ (64 ) $ (124 ) Other comprehensive (loss) gain before reclassifications (net of taxes of $(2) and $1, respectively) (7 ) 2 (5 ) Losses reclassified from net accumulated other comprehensive loss: Interest rate derivatives (net of taxes of $0) (a) 1 — 1 Amortization of net actuarial loss (net of taxes of $0) (b) — 1 1 Net current period other comprehensive (loss) income (6 ) 3 (3 ) Accumulated other comprehensive loss at March 31 $ (66 ) $ (61 ) $ (127 ) (a) Included in interest charges. (b) Included in the computation of net periodic pension and postretirement benefit costs.

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2020
Segment Reporting [Abstract]
Results from Operations by Reportable Segment	Xcel Energy’s segment information for the three months ended March 31 : (Millions of Dollars) 2020 2019 Regulated Electric Operating revenues from external customers $ 2,203 $ 2,325 Net income 227 234 Regulated Natural Gas Operating revenues from external customers $ 583 $ 794 Intersegment revenue — 1 Total revenues $ 583 $ 795 Net income 91 105 All Other Total operating revenue $ 25 $ 22 Net loss (23 ) (24 ) Consolidated Total Total revenue $ 2,811 $ 3,142 Reconciling eliminations — (1 ) Consolidated total revenue $ 2,811 $ 3,141 Net income 295 315

Accounting Pronouncements Accou

Accounting Pronouncements Accounting Pronouncements (Details) - USD ($) $ in Millions	Jan. 01, 2020	Mar. 31, 2020
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Credit Losses, Topic 326 (ASC Topic 326)		$ 2
Retained Earnings
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Credit Losses, Topic 326 (ASC Topic 326)	$ 2	$ 2

Selected Balance Sheet Data Sel

Selected Balance Sheet Data Selected Balance Sheet Data, Accounts Receivable (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Balance Sheet Related Disclosures [Abstract]
Accounts receivable	$ 897	$ 892
Less allowance for bad debts	(58)	(55)
Accounts receivable, net	$ 839	$ 837

Selected Balance Sheet Data S_2

Selected Balance Sheet Data Selected Balance Sheet Data, Inventories (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Public Utilities, Inventory [Line Items]
Total inventories	$ 488	$ 544
Materials and supplies
Public Utilities, Inventory [Line Items]
Inventories	283	270
Fuel
Public Utilities, Inventory [Line Items]
Inventories	170	191
Natural gas
Public Utilities, Inventory [Line Items]
Inventories	$ 35	$ 83

Selected Balance Sheet Data, Pr

Selected Balance Sheet Data, Property, Plant and Equipment, Net (Details) - USD ($) $ in Millions		Mar. 31, 2020	Dec. 31, 2019
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		$ 57,161	$ 55,844
Less accumulated depreciation and amortization		(16,730)	(16,735)
Property, plant and equipment, net		40,776	39,483
Electric plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		44,544	44,355
Natural gas plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		6,653	6,560
Common and other property
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		2,991	2,341
Plant to be retired
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	[1]	217	259
CWIP
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		2,756	2,329
Nuclear fuel
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		2,913	2,909
Less accumulated depreciation and amortization		$ (2,568)	$ (2,535)
[1]	In 2018, the CPUC approved early retirement of PSCo’s Comanche Units 1 and 2 in approximately 2022 and 2025, respectively. PSCo also expects Craig Unit 1 to be retired early in 2025. Amounts are presented net of accumulated depreciation.

Revenues (Details)

Revenues (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Operating Segments
Disaggregation of Revenue [Line Items]
Total revenues	$ 2,811	$ 3,141
Regulated Electric | Operating Segments
Disaggregation of Revenue [Line Items]
Total revenues	2,203	2,325
Regulated Natural Gas | Operating Segments
Disaggregation of Revenue [Line Items]
Total revenues	583	794
All Other | Operating Segments
Disaggregation of Revenue [Line Items]
Total revenues	25	22
Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,674	3,040
Total revenue from contracts with customers | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,086	2,237
Total revenue from contracts with customers | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	567	784
Total revenue from contracts with customers | All Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	21	19
Retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,327	2,668
Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,042	1,231
Retail | C&I
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,255	1,404
Retail | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	30	33
Retail | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,771	1,899
Retail | Regulated Electric | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	676	727
Retail | Regulated Electric | C&I
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,066	1,140
Retail | Regulated Electric | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	29	32
Retail | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	535	750
Retail | Regulated Natural Gas | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	355	495
Retail | Regulated Natural Gas | C&I
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	180	255
Retail | Regulated Natural Gas | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Retail | All Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	21	19
Retail | All Other | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	11	9
Retail | All Other | C&I
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	9	9
Retail | All Other | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1	1
Wholesale
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	166	189
Wholesale | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	166	189
Wholesale | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Wholesale | All Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	132	131
Transmission | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	132	131
Transmission | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Transmission | All Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	49	52
Other | Regulated Electric
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	17	18
Other | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	32	34
Other | All Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Alternative revenue and other
Disaggregation of Revenue [Line Items]
Alternative revenue and other	137	101
Alternative revenue and other | Regulated Electric
Disaggregation of Revenue [Line Items]
Alternative revenue and other	117	88
Alternative revenue and other | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Alternative revenue and other	16	10
Alternative revenue and other | All Other
Disaggregation of Revenue [Line Items]
Alternative revenue and other	$ 4	$ 3

Short-Term Debt (Details)

Short-Term Debt (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Short-term Debt [Line Items]
Amount outstanding at period end	$ 1,765	$ 595
Commercial Paper
Short-term Debt [Line Items]
Borrowing limit	4,300	3,600
Amount outstanding at period end	1,765	595
Average amount outstanding	1,404	1,115
Maximum amount outstanding	$ 2,080	$ 1,780
Weighted average interest rate, computed on a daily basis	2.05%	2.72%
Weighted average interest rate at period end	1.96%	2.34%

Letters of Credit (Details)

Letters of Credit (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Line of Credit Facility [Line Items]
Amount outstanding at period end	$ 1,765	$ 595
Letter of Credit
Line of Credit Facility [Line Items]
Debt Instrument, Term	1 year
Amount outstanding at period end	$ 20	$ 20

Borrowings and Other Financin_3

Borrowings and Other Financing Instruments Revolving Credit Facilities (Details) - Revolving Credit Facility [Member] - USD ($) $ in Millions		Mar. 31, 2020	Dec. 31, 2019
Line of Credit Facility [Line Items]
Credit Facility	[1]	$ 3,100
Outstanding	[2]	585
Available		2,515
Direct advances on the credit facility outstanding		0	$ 0
PSCo
Line of Credit Facility [Line Items]
Credit Facility	[1]	700
Outstanding	[2]	8
Available		692
NSP-Minnesota
Line of Credit Facility [Line Items]
Credit Facility	[1]	500
Outstanding	[2]	10
Available		490
SPS
Line of Credit Facility [Line Items]
Credit Facility	[1]	500
Outstanding	[2]	42
Available		458
NSP-Wisconsin
Line of Credit Facility [Line Items]
Credit Facility	[1]	150
Outstanding	[2]	76
Available		74
Xcel Energy Inc.
Line of Credit Facility [Line Items]
Credit Facility	[1]	1,250
Outstanding	[2]	449
Available		$ 801
[1]	Expires in June 2024 .
[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	Mar. 23, 2020	Mar. 31, 2020	Dec. 31, 2019
Short-term Debt [Line Items]
Amount outstanding at period end		$ 1,765	$ 595
364-Day Term Loan [Member] | Xcel Energy Inc.
Short-term Debt [Line Items]
Line of Credit Facility, Expiration Period	364 days
364-Day Term Loan [Member] | Short-term Debt [Member] | Xcel Energy Inc.
Short-term Debt [Line Items]
Credit Facility	$ 700	1,200
Required debt to total capitalization ratio	65.00%
Basis points	60
Amount outstanding at period end		1,200
Available		$ 0

Borrowings and Other Financin_5

Borrowings and Other Financing Instruments Bilateral Credit Agreement (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Short-term Debt [Line Items]
Amount outstanding at period end	$ 1,765	$ 595
Letter of Credit
Short-term Debt [Line Items]
Debt Instrument, Term	1 year
Amount outstanding at period end	$ 20	$ 20
Bilateral Credit Agreement [Member] | NSP Minnesota [Member] | Letter of Credit
Short-term Debt [Line Items]
Debt Instrument, Term	1 year
Credit Facility	$ 75
Amount outstanding at period end	26
Available	$ 49

Borrowings and Other Financin_6

Borrowings and Other Financing Instruments Long-Term Borrowings (Details) - Bonds [Member] - XCEL ENERGY INC [Member] - Series Due June 1, 2030 - Subsequent Event [Member] $ in Millions	Apr. 01, 2020USD ($)
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 600
Debt Instrument, Interest Rate, Stated Percentage	3.40%

Borrowings and Other Financin_7

Borrowings and Other Financing Instruments Forward Equity Agreement (Details) - Forward Equity Agreements [Member] - USD ($) $ / shares in Units, shares in Millions, $ in Millions	Mar. 31, 2020	Nov. 04, 2019
Forward Contract Indexed to Issuer's Equity [Line Items]
Common Stock, Value, to be Issued through Forward Equity Agreement		$ 743
Common Stock, Shares to be Issued through forward Equity Agreement		11.8
Common stock, initial shares in an agreement		10.3
Common stock, additional shares in an agreement		1.5
Period End Settlement Price, In Shares		11.8
Period End Settlement Price, in Cash		$ 734
Period End Net Cash Settlement, Amount in Cash		$ 19
Period End Net Share Settlement, Amount in Shares		0.3
Common shares, price per share used in forward calculation		$ 62.69
Common stock, interest rate spread used in forward calculation		0.75%
Minimum [Member]
Forward Contract Indexed to Issuer's Equity [Line Items]
Expected settlement price	$ 720
Maximum [Member]
Forward Contract Indexed to Issuer's Equity [Line Items]
Expected settlement price	$ 735

Borrowings and Other Financin_8

Borrowings and Other Financing Instruments Other Equity (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
DRIP
Dividend Reinvestment Program [Line Items]
Stock Issued, Value	$ 10	$ 10

Income Taxes (Details)

Income Taxes (Details)		3 Months Ended
		Mar. 31, 2020	Mar. 31, 2019
Income Tax Disclosure [Abstract]
Federal statutory rate		21.00%	21.00%
State tax (net of federal tax effect)		4.90%	5.00%
Wind PTCs		(17.20%)	(8.60%)
Plant regulatory differences	[1]	(8.40%)	(5.70%)
Other tax credits, net NOL & tax credit allowances		(0.90%)	(2.70%)
Other (net)		(1.50%)	(1.60%)
Effective income tax rate		(2.10%)	7.40%
[1]	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 credits are offset by corresponding revenue reductions.

Income Taxes Federal Audits (De

Income Taxes Federal Audits (Details)	3 Months Ended
	Mar. 31, 2020USD ($)
Internal Revenue Service (IRS) [Member]
Income Tax Examination [Line Items]
Potential Tax Adjustments	$ 0

Income Taxes State Audits (Deta

Income Taxes State Audits (Details)	3 Months Ended
	Mar. 31, 2020USD ($)
WISCONSIN
Income Tax Examination [Line Items]
Potential Tax Adjustments	$ 0

Income Taxes Unrecognized Benef

Income Taxes Unrecognized Benefits (Details) - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Unrecognized tax benefit — Permanent tax positions	$ 36,000,000	$ 35,000,000
Unrecognized tax benefit — Temporary tax positions	10,000,000	9,000,000
Total unrecognized tax benefit	46,000,000	44,000,000
NOL and tax credit carryforwards	42,000,000	40,000,000
Net Deferred Tax Liability associated with the Unrecognized Tax Benefit Amounts and Related NOLs and Tax Credit Carryforwards	(30,000,000)	(29,000,000)
Decrease in Unrecognized Tax Benefits is Reasonably Possible	28,000,000
Unrecognized Tax Benefits, Income Tax Penalties Accrued	$ 0	$ 0

Common Stock Equivalents (Detai

Common Stock Equivalents (Details) - shares shares in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Earnings Per Share [Abstract]
Dilutive Effect of Contingently Issuable Shares	0.8	1.2

Non-Derivative Fair Value Measu

Non-Derivative Fair Value Measurements (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2020		Dec. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized Gain on Securities	$ 454		$ 706
Unrealized Loss on Securities	88		6
Nuclear decommissinoning fund [Abstract]
Equity investments in unconsolidated subsidiaries	158		155
Miscellaneous investments	129		136
Debt Securities, Available-for-sale, Fair Value, Fiscal Year Maturity [Abstract]
Due in one year or less	11
Due in 1 to 5 years	81
Due in 5 to 10 years	205
Due after 10 years	204
Total	501
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost
Nuclear decommissinoning fund [Abstract]
Decommissioning Fund Investments	1,776	[1]	1,740	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Cash equivalents
Nuclear decommissinoning fund [Abstract]
Cash equivalents	71	[1]	33	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Commingled funds
Nuclear decommissinoning fund [Abstract]
Commingled funds	756	[1]	733	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Debt securities
Nuclear decommissinoning fund [Abstract]
Debt securities	514	[1]	489	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Cost | Equity securities
Nuclear decommissinoning fund [Abstract]
Equity securities	435	[1]	485	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value
Nuclear decommissinoning fund [Abstract]
Alternative investment	843	[1]	935	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Cash equivalents
Nuclear decommissinoning fund [Abstract]
Cash equivalents	71	[1]	33	[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	843	[1]	935	[2]
Alternative investment	843	[1]	935	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Debt securities
Nuclear decommissinoning fund [Abstract]
Debt securities	501	[1]	508	[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	727	[1]	964	[2]
Alternative investment	0	[1]	0	[2]
Decommissioning Fund Investments	2,142	[1]	2,440	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1
Nuclear decommissinoning fund [Abstract]
Decommissioning Fund Investments	797	[1]	995	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Cash equivalents
Nuclear decommissinoning fund [Abstract]
Cash equivalents	71	[1]	33	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 1 | Commingled funds
Nuclear decommissinoning fund [Abstract]
Commingled funds	0	[1]	0	[2]
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	726	[1]	962	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2
Nuclear decommissinoning fund [Abstract]
Decommissioning Fund Investments	489	[1]	497	[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	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Debt securities
Nuclear decommissinoning fund [Abstract]
Debt securities	488	[1]	495	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 2 | Equity securities
Nuclear decommissinoning fund [Abstract]
Equity securities	1	[1]	2	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3
Nuclear decommissinoning fund [Abstract]
Decommissioning Fund Investments	13	[1]	13	[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	0	[1]	0	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Debt securities
Nuclear decommissinoning fund [Abstract]
Debt securities	13	[1]	13	[2]
Nuclear Decommissioning Fund | Fair Value Measured on a Recurring Basis | Fair Value | Level 3 | Equity securities
Nuclear decommissinoning fund [Abstract]
Equity securities	$ 0	[1]	$ 0	[2]
[1]	Reported in nuclear decommissioning fund and other investments on the consolidated balance sheet, which also includes $158 million of equity investments in unconsolidated subsidiaries and $129 million of rabbi trust assets and miscellaneous investments.
[2]	Reported in nuclear decommissioning fund and other investments on the consolidated balance sheet, which also includes $155 million of equity investments in unconsolidated subsidiaries and $136 million of rabbi trust assets and miscellaneous investments.

Fair Value of Financial Asset_3

Fair Value of Financial Assets and Liabilities Rabbi Trust (Details) - Rabbi Trust [Member] - Fair Value, Measured on a Recurring Basis - USD ($) $ in Millions		Mar. 31, 2020	Dec. 31, 2019
Cost
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi Trusts Assets at Fair Value	[1]	$ 74	$ 74
Cost | Cash Equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	[1]	17	17
Cost | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Mutual funds	[1]	57	57
Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi Trusts Assets at Fair Value	[1]	73	82
Fair Value | Cash Equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	[1]	17	17
Fair Value | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Mutual funds	[1]	56	65
Fair Value | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rabbi Trusts Assets at Fair Value	[1]	73	82
Fair Value | Level 1 | Cash Equivalents [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	[1]	17	17
Fair Value | Level 1 | Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Mutual funds	[1]	56	65
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 sheet.

Fair Value of Financial Asset_4

Fair Value of Financial Assets and Liabilities Interest Rate Derivatives (Details) - Interest rate derivatives $ in Millions	Mar. 31, 2020USD ($)
Derivative [Line Items]
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net	$ 5
Unsettled Interest Rate Swaps	$ 13

Fair Value of Financial Asset_5

Fair Value of Financial Assets and Liabilities Commodity Derivatives (Details) MWh in Millions, MMBTU in Millions, $ in Millions		Mar. 31, 2020USD ($)MMBTUMWh	Dec. 31, 2019MMBTUMWh
Cash Flow Hedge Commodity [Member]
Derivative [Line Items]
Commodity contracts designated as cash flow hedges | $		$ 0
Electric Commodity [Member]
Gross Notional Amounts of Commodity Forwards, Options and FTRs [Abstract]
Derivative, Nonmonetary Notional Amount | MWh	[1],[2]	79	95
Natural Gas Commodity
Gross Notional Amounts of Commodity Forwards, Options and FTRs [Abstract]
Derivative, Nonmonetary Notional Amount | MMBTU	[1],[2]	149	110
[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		12 Months Ended
		Mar. 31, 2020USD ($)Counterparty	Mar. 31, 2019USD ($)	Dec. 31, 2019USD ($)
Impact of Derivative Activity [Abstract]
Fair value hedges		$ 0	$ 0
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		(13,000,000)	(9,000,000)
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		0	0
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		2,000,000	1,000,000
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		0	0
Pre-tax gains (losses) recognized during the period in income		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		(13,000,000)	(9,000,000)
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		0	0
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	[1]	2,000,000	1,000,000
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		0	0
Pre-tax gains (losses) recognized during the period in income		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
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities			16,000,000
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)		(1,000,000)	0
Pre-tax gains (losses) recognized during the period in income		(5,000,000)	(2,000,000)
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
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities			12,000,000
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)	(1,000,000)
Pre-tax gains (losses) recognized during the period in income		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
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities			4,000,000
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)	[3]	(5,000,000)	(1,000,000)
Pre-tax gains (losses) recognized during the period in income	[3]	(6,000,000)	(3,000,000)
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
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		0	0
Pre-tax gains (losses) recognized during the period in income	[4]	1,000,000	$ 1,000,000
Other Derivative Instruments | Natural Gas Commodity for Electric Generation
Impact of Derivative Activity [Abstract]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		$ 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
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		8
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		6
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties		$ 154,000,000
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)		56.00%
Credit Concentration Risk | Internal Investment Grade [Member]
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		3
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties		$ 35,000,000
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)		13.00%
Credit Concentration Risk | External Credit Rating, Non Investment Grade [Member]
Derivative [Line Items]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		1
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties		$ 12,000,000
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)		4.00%
[1]	Recorded to interest charges.
[2]	Recorded to electric fuel and purchased power. These derivative settlement gains and losses are shared with electric customers through fuel and purchased energy cost-recovery mechanisms, and reclassified out of income as regulatory assets or liabilities, as appropriate.
[3]	Amounts for both the three months ended March 31, 2020 and 2019 included no settlement gains or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining settlement losses for the three months ended March 31, 2020 and 2019 related to natural gas operations and were recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.
[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.

Fair Value of Financial Asset_6

Fair Value of Financial Assets and Liabilities Credit Related Contingent Features (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Derivative, Gross Liability Position, Aggregate Fair Value	$ 11	$ 7
Collateral Already Posted Adequate Assurance Clauses Aggregate Fair Value	$ 0	$ 0

Recurring Fair Value Measuremen

Recurring Fair Value Measurements (Details) - USD ($)		3 Months Ended
		Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Return Cash Collateral		$ 32,000,000		$ 32,000,000
Reclaim Cash Collateral		6,000,000		11,000,000
Commodity Trading
Changes in Level 3 Commodity Derivatives [Roll Forward]
Balance at beginning of period		4,000,000	$ 29,000,000
Purchases		12,000,000	4,000,000
Settlements		(18,000,000)	(11,000,000)
Gains (losses) recognized in earnings	[1]	6,000,000	(18,000,000)
Net gains (losses) recognized as regulatory assets and liabilities		1,000,000	(11,000,000)
Balance at end of period		5,000,000	(7,000,000)
Transfers Level 3, Net		0	$ 0
Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Net		45,000,000		55,000,000
Other Noncurrent Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Net		39,000,000		22,000,000
Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Net		52,000,000		38,000,000
Other Noncurrent Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Net		183,000,000		175,000,000
Fair Value Measured on a Recurring Basis | Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		105,000,000		105,000,000
Netting	[2]	(63,000,000)		(53,000,000)
Derivative Asset, Net		42,000,000		52,000,000
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		8,000,000		3,000,000
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		63,000,000		57,000,000
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		34,000,000		45,000,000
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		87,000,000		78,000,000
Netting	[2]	(63,000,000)		(52,000,000)
Derivative Asset, Net		24,000,000		26,000,000
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		18,000,000		21,000,000
Netting	[2]	0		(1,000,000)
Derivative Asset, Net		18,000,000		20,000,000
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		0		6,000,000
Netting	[2]	0		0
Derivative Asset, Net		0		6,000,000
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		8,000,000		3,000,000
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
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
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		63,000,000		51,000,000
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
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 2 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		0		6,000,000
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		16,000,000		24,000,000
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		18,000,000		21,000,000
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
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		72,000,000		54,000,000
Netting	[2]	(45,000,000)		(45,000,000)
Derivative Asset, Net		27,000,000		9,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		10,000,000		9,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		38,000,000		38,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		24,000,000		7,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		70,000,000		54,000,000
Netting	[2]	(45,000,000)		(45,000,000)
Derivative Asset, Net		25,000,000		9,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		2,000,000		0
Netting	[2]	0		0
Derivative Asset, Net		2,000,000		0
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		10,000,000		9,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Level 1 | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		0		0
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		38,000,000		38,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Level 2 | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		0		0
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		22,000,000		7,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Level 3 | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		2,000,000		0
Fair Value Measured on a Recurring Basis | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		97,000,000		84,000,000
Netting	[2]	(63,000,000)		(64,000,000)
Derivative Liability, Net		34,000,000		20,000,000
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		8,000,000		4,000,000
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		75,000,000		64,000,000
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		14,000,000		16,000,000
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		84,000,000		78,000,000
Netting	[2]	(63,000,000)		(63,000,000)
Derivative Liability, Net		21,000,000		15,000,000
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Electric Commodity
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		0		1,000,000
Netting	[2]	0		(1,000,000)
Derivative Liability, Net		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		0		5,000,000
Netting	[2]	0		0
Derivative Liability, Net		0		5,000,000
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		8,000,000		4,000,000
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
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
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		62,000,000		59,000,000
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
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		0		5,000,000
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		14,000,000		15,000,000
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		0		1,000,000
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
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Designated as Hedging Instrument | Interest Rate Swap
Derivatives, Fair Value [Line Items]
Netting	[2]	0		0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Designated as Hedging Instrument | Cash Flow Hedges | Interest Rate Swap
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		13,000,000		0
Derivative Liability, Net		13,000,000		0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Designated as Hedging Instrument | Level 1 | Cash Flow Hedges | Interest Rate Swap
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		0		0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Designated as Hedging Instrument | Level 2 | Cash Flow Hedges | Interest Rate Swap
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		13,000,000		0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Designated as Hedging Instrument | Level 3 | Cash Flow Hedges | Interest Rate Swap
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		0		0
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		131,000,000		113,000,000
Netting	[2]	(19,000,000)		(13,000,000)
Derivative Liability, Net		112,000,000		100,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		3,000,000		2,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		89,000,000		79,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		39,000,000		32,000,000
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		131,000,000		113,000,000
Netting	[2]	(19,000,000)		(13,000,000)
Derivative Liability, Net		112,000,000		100,000,000
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		3,000,000		2,000,000
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		89,000,000		79,000,000
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		39,000,000		32,000,000
Fair Value, Measurements, Nonrecurring | Other Current Assets | PPAs
Derivatives, Fair Value [Line Items]
Derivative Asset, Net	[3]	3,000,000		3,000,000
Fair Value, Measurements, Nonrecurring | Other Noncurrent Assets | PPAs
Derivatives, Fair Value [Line Items]
Derivative Asset, Net	[3]	12,000,000		13,000,000
Fair Value, Measurements, Nonrecurring | Other Current Liabilities | PPAs
Derivatives, Fair Value [Line Items]
Derivative Liability, Net	[3]	18,000,000		18,000,000
Fair Value, Measurements, Nonrecurring | Other Noncurrent Liabilities | PPAs
Derivatives, Fair Value [Line Items]
Derivative Liability, Net	[3]	$ 71,000,000		$ 75,000,000
[1]	Amounts relate to commodity derivatives held at the end of the period.
[2]	Xcel Energy nets derivative instruments and related collateral in its consolidated balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at March 31, 2020 and Dec. 31, 2019 . At both March 31, 2020 and Dec. 31, 2019 , derivative assets and liabilities include $32 million of obligations to return cash collateral and rights to reclaim cash collateral of $6 million and $11 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.
[3]	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.

Fair Value of Long-Term Debt (D

Fair Value of Long-Term Debt (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Carrying Amount	$ 18,112	$ 18,109
Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	$ 19,864	$ 20,227

Benefit Plans and Other Postr_3

Benefit Plans and Other Postretirement Benefits (Details) $ in Millions		1 Months Ended	3 Months Ended
		Jan. 31, 2020USD ($)	Mar. 31, 2020USD ($)	Mar. 31, 2019USD ($)	Jan. 31, 2019Plan
Pension Plan [Member]
Components of Net Periodic Benefit Cost [Abstract]
Service cost			$ 24	$ 22
Interest cost	[1]		31	36
Expected return on plan assets	[1]		(52)	(51)
Amortization of prior service credit	[1]		(1)	(1)
Amortization of net loss	[1]		25	22
Net periodic benefit cost (credit)			27	28
Credits not recognized due to effects of regulation			2	1
Net benefit cost (credit) recognized for financial reporting			29	29
Pension Plan [Member] | Parent Company
Components of Net Periodic Benefit Cost [Abstract]
Contributions to Xcel Energy's pension plans		$ 150
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
Interest cost	[1]		5	6
Expected return on plan assets	[1]		(5)	(5)
Amortization of prior service credit	[1]		(2)	(3)
Amortization of net loss	[1]		1	1
Net periodic benefit cost (credit)			(1)	(1)
Credits not recognized due to effects of regulation			1	0
Net benefit cost (credit) recognized for financial reporting			$ 0	$ (1)
[1]	Components of net periodic cost other than the service cost component are included in the line item “other (expense) income, net” in the consolidated statement of income or capitalized on the consolidated balance sheet as a regulatory asset.

Gas Trading Litigation (Details

Gas Trading Litigation (Details)	Mar. 31, 2020
Gas Trading Litigation
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number	2

Commitments and Contingencies N

Commitments and Contingencies NSP-Minnesota - MEC Transactions (Details) - MEC Holdings LLC [Member] - Unregulated Operation [Member] $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020USD ($)	Dec. 31, 2019USD ($)MW
Public Utilities, General Disclosures [Line Items]
Facility Output | MW		760
PP&E Additions		$ 650
Southwest Generation [Domain]
Public Utilities, General Disclosures [Line Items]
PP&E Sale	$ 680

Commitments and Contingencies_2

Commitments and Contingencies NSP-Minnesota-Sherco (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2019	Dec. 31, 2018
General Electric (GE) [Domain]
Rate Matters [Abstract]
Percentage of Fault		52.00%
NSP-Minnesota
Rate Matters [Abstract]
Percentage of Fault		48.00%
Customer refund of previously recovered purchased power costs	$ 20

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		12 Months Ended	39 Months Ended
	Feb. 28, 2015	Nov. 30, 2013	Dec. 31, 2016	Dec. 31, 2019	Mar. 31, 2020
Public Utilities, General Disclosures [Line Items]
Public Utilities, Base Return On Equity Charged To Customers Through Transmission Formula Rates	12.38%	12.38%
Public Utilities, ROE Applicable To Transmission Formula Rates In The MISO Region, Recommended By Third Parties	8.67%	9.15%
Public Utilities, ROE Applicable To Transmission Formula Rates In The MISO Region, Approved			10.32%
Public Utilities, ROE Applicable To Transmission Formula Rates In The MISO Region, with RTO Adder, Approved			10.82%
Public Utilities, ROE developed with new approach				9.88%
Public Utilities, ROE developed with new approach, with RTO Adder, Approved				10.38%
Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Basis points					50
Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Basis points					100

SPP OATT Upgrade Costs (Details

SPP OATT Upgrade Costs (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
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

MGP, Landfill and Disposal Site

MGP, Landfill and Disposal Sites (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020USD ($)	Dec. 31, 2019USD ($)
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	11
NSP-Wisconsin | Ashland MGP Site
Manufactured Gas Plant (MGP) Site [Abstract]
Current Cost Estimate for Site Remediation	$ 199
Accrual for Environmental Loss Contingencies, Gross	$ 22	$ 23
Carrying cost percentage to be applied to unamortized regulatory asset	3.00%

Commitments and Contingencies E

Commitments and Contingencies Environmental Requirements - Water and Waste (Details) $ in Millions	Mar. 31, 2020USD ($)	Dec. 31, 2019
NSP Minnesota [Member]
Site Contingency [Line Items]
Number of sites where statistically significant increases over established groundwater standards exist		0
PSCo
Site Contingency [Line Items]
Number of sites where statistically significant increases over established groundwater standards exist		4
Number of sites where corrective action options are being evaluated for locations with statistically significant increases above background concentrations	2
Federal Coal Ash Regulation [Domain]
Site Contingency [Line Items]
Number of sites where regulated ash units will still be in operation at a specified date	9
Federal Coal Ash Regulation [Domain] | NSP Minnesota [Member]
Site Contingency [Line Items]
Number of impoundments where closure plans will be expedited		1
Estimated cost of closure of an impoundment	$ 4
Estimated cost of construction of a new impoundment	$ 8
Federal Coal Ash Regulation [Domain] | PSCo
Site Contingency [Line Items]
Number of impoundments where closure plans will be expedited		1

Leases (Details)

Leases (Details) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Operating Leases after Adoption of ASC Topic 842
Noncurrent operating and finance lease liabilities	$ 1,163	$ 1,549
Mankato Energy Center [Member] | PPAs | NSP Minnesota [Member]
Operating Leases after Adoption of ASC Topic 842
Noncurrent operating and finance lease liabilities		$ 400

Variable Interest Entities (Det

Variable Interest Entities (Details) - MW	Mar. 31, 2020	Dec. 31, 2019
Independent Power Producing Entities
Variable Interest Entity [Line Items]
Generating capacity under long term purchased power agreements (in MW)	3,266	3,986

Commitments and Contingencies G

Commitments and Contingencies Guarantees and Bond Indemnifications (Details) - USD ($)	Mar. 31, 2020	Dec. 31, 2019
Commitments and Contingencies, Guarantees and Indemnifications [Abstract]
Assets Held As Collateral For Guarantor Obligations	$ 0	$ 0
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 60,000,000	$ 62,000,000

Other Comprehensive Loss (Detai

Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020		Mar. 31, 2019
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss) at beginning of period	$ 13,239
Accumulated other comprehensive income (loss) at end of period	13,302
Other Comprehensive Income (Loss), Tax	(3)		$ (2)
Interest Rate Derivatives, Tax	(6)		25
Gains and Losses on Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss) at beginning of period	(80)		(60)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(10)		(7)
Losses reclassified from net accumulated other comprehensive loss	0	[1]	0	[2]
Net current period other comprehensive income (loss)	(8)		(6)
Accumulated other comprehensive income (loss) at end of period	(88)		(66)
Gains and Losses on Cash Flow Hedges | Reclassification out of Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Other Comprehensive Income (Loss), Tax	(3)		(2)
Interest Rate Derivatives, Tax	0		0
Amortization of Net Actuarial Loss, Tax	0		0
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	[3]	1	[4]
Defined Benefit Pension and Postretirement Items
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss) at beginning of period	(61)		(64)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0		2
Losses reclassified from net accumulated other comprehensive loss	1	[1]	1	[2]
Net current period other comprehensive income (loss)	1		3
Accumulated other comprehensive income (loss) at end of period	(60)		(61)
Defined Benefit Pension and Postretirement Items | Reclassification out of Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Other Comprehensive Income (Loss), Tax	0		1
Interest Rate Derivatives, Tax	0		0
Amortization of Net Actuarial Loss, Tax	0		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	0	[3]	0	[4]
Total
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive income (loss) at beginning of period	(141)		(124)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(10)		(5)
Losses reclassified from net accumulated other comprehensive loss	1	[1]	1	[2]
Net current period other comprehensive income (loss)	(7)		(3)
Accumulated other comprehensive income (loss) at end of period	(148)		(127)
Total | Interest Rate Swap
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Losses reclassified from net accumulated other comprehensive loss	$ 2	[3]	$ 1	[4]
[1]	Included in the computation of net periodic pension and postretirement benefit costs.
[2]	Included in the computation of net periodic pension and postretirement benefit costs.
[3]	Included in interest charges.
[4]	Included in interest charges.

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2019
Segment Reporting Information [Line Items]
Equity investments in unconsolidated subsidiaries	$ 158		$ 155
Regulated Operating Revenue, Electric	2,203	$ 2,325
Net income	295	315
Regulated Operating Revenue, Gas	583	794
Unregulated Operating Revenue	25	22
Regulated and Unregulated Operating Revenue	2,811	3,141
Electricity, US Regulated [Member]
Segment Reporting Information [Line Items]
Net income	227	234
Natural Gas, US Regulated [Member]
Segment Reporting Information [Line Items]
Equity investments in unconsolidated subsidiaries	158		$ 155
Net income	91	105
Revenues Including Intersegment Revenues	583	795
All Other
Segment Reporting Information [Line Items]
Net income	(23)	(24)
Operating Segments
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue	2,811	3,142
Operating Segments | Electricity, US Regulated [Member]
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Electric	2,203	2,325
Operating Segments | Natural Gas, US Regulated [Member]
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Gas	583	794
Operating Segments | All Other
Segment Reporting Information [Line Items]
Unregulated Operating Revenue	25	22
Intersegment Eliminations
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue	0	(1)
Intersegment Eliminations | Natural Gas, US Regulated [Member]
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Gas	$ 0	$ 1