10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C.  20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended Sept. 30, 2023

or

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

For the transition period from ____________ to ___________

Commission File Number: 001-03280

Public Service Company of Colorado

(Exact Name of Registrant as Specified in its Charter)

Colorado	84-0296600
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)

1800 Larimer Street, Suite 1100	Denver	CO			80202
(Address of Principal Executive Offices)					(Zip Code)
			(303)	571-7511
(Registrant’s Telephone Number, Including Area Code)

N/A

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

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

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

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

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

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

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

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

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

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

Class	Outstanding at October 27, 2023
Common Stock, $0.01 par value	100 shares

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

TABLE OF CONTENTS

PART I — FINANCIAL INFORMATION
Item 1 —	Financial Statements (unaudited)	4
	Consolidated Statements of Income	4
	Consolidated Statements of Comprehensive Income	5
	Consolidated Statements of Cash Flows	6
	Consolidated Balance Sheets	7
	Consolidated Statements of Common Stockholder’s Equity	8
	Notes to Consolidated Financial Statements	9
Item 2 —	Management’s Discussion and Analysis of Financial Condition and Results of Operations	17
Item 4 —	Controls and Procedures	20
PART II — OTHER INFORMATION
Item 1 —	Legal Proceedings	20
Item 1A —	Risk Factors	21
Item 5 —	Other Information	21
Item 6 —	Exhibits	21
SIGNATURES		22

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

Definitions of Abbreviations

Xcel Energy Inc.’s Subsidiaries and Affiliates (current and former)
e prime	e prime inc.
NSP-Minnesota	Northern States Power Company, a Minnesota corporation
NSP-Wisconsin	Northern States Power Company, a Wisconsin corporation
PSCo	Public Service Company of Colorado
SPS	Southwestern Public Service Company
Utility subsidiaries	NSP-Minnesota, NSP-Wisconsin, PSCo and SPS
Xcel Energy	Xcel Energy Inc. and its subsidiaries

Federal and State Regulatory Agencies
CPUC	Colorado Public Utilities Commission
D.C. Circuit	United States Court of Appeals for the District of Columbia Circuit
EPA	United States Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
SEC	Securities and Exchange Commission

Other
C&I	Commercial and Industrial
CCR	Coal combustion residuals
CCR Rule	Final rule (40 CFR 257.50 - 257.107) published by the EPA regulating the management, storage and disposal of CCRs as a nonhazardous waste
CEO	Chief executive officer
CERCLA	Comprehensive Environmental Response, Compensation, and Liability Act
CFO	Chief financial officer
CORE	CORE Electric Cooperative
CSPV	Crystalline Silicon Photovoltaic
ECA	Retail electric commodity adjustment
ETR	Effective Tax Rate
GAAP	United States generally accepted accounting principles
IPP	Independent power producing entity
MGP	Manufactured gas plant
O&M	Operating and maintenance
PFAS	Per- and Polyfluoroalkyl Substances
PPA	Power purchase agreement
PTC	Production tax credit
ROE	Return on equity
RFP	Request for proposal
TCA	Transmission cost adjustment
UCA	Colorado Office of the Utility Consumer Advocate

Measurements
MW	Megawatts

Forward-Looking Statements

Except for the historical statements contained in this report, the matters discussed herein are forward-looking statements that are subject to certain risks, uncertainties and assumptions. Such forward-looking statements, including those relating to future sales, future expenses, future tax rates, future operating performance, estimated base capital expenditures and financing plans, projected capital additions and forecasted annual revenue requirements with respect to rider filings, expected rate increases to customers, expectations and intentions regarding regulatory proceedings, and expected impact on our results of operations, financial condition and cash flows of resettlement calculations and credit losses relating to certain energy transactions, as well as assumptions and other statements are intended to be identified in this document by the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “objective,” “outlook,” “plan,” “project,” “possible,” “potential,” “should,” “will,” “would” and similar expressions. Actual results may vary materially. Forward-looking statements speak only as of the date they are made, and we expressly disclaim any obligation to update any forward-looking information. The following factors, in addition to those discussed in PSCo’s Annual Report on Form 10-K for the fiscal year ended Dec. 31, 2022, and subsequent filings with the SEC, could cause actual results to differ materially from management expectations as suggested by such forward-looking information: operational safety; successful long-term operational planning; commodity risks associated with energy markets and production; rising energy prices and fuel costs; qualified employee workforce and third-party contractor factors; violations of our Codes of Conduct; our ability to recover costs; changes in regulation; reductions in our credit ratings and the cost of maintaining certain contractual relationships; general economic conditions, including recessionary conditions, inflation rates, monetary fluctuations, supply chain constraints and their impact on capital expenditures and/or the ability of PSCo to obtain financing on favorable terms; availability or cost of capital; our customers’ and counterparties’ ability to pay their debts to us; assumptions and costs relating to funding our employee benefit plans and health care benefits; tax laws; uncertainty regarding epidemics, the duration and magnitude of business restrictions including shutdowns (domestically and globally), the potential impact on the workforce, including shortages of employees or third-party contractors due to quarantine policies, vaccination requirements or government restrictions, impacts on the transportation of goods and the generalized impact on the economy; effects of geopolitical events, including war and acts of terrorism; cybersecurity threats and data security breaches; seasonal weather patterns; changes in environmental laws and regulations; climate change and other weather events; natural disaster and resource depletion, including compliance with any accompanying legislative and regulatory changes; costs of potential regulatory penalties and wildfire damages in excess of liability insurance coverage; regulatory changes and/or limitations related to the use of natural gas as an energy source; challenging labor market conditions and our ability to attract and retain a qualified workforce; and our ability to execute on our strategies or achieve expectations related to environmental, social and governance matters including as a result of evolving legal, regulatory and other standards, processes, and assumptions, the pace of scientific and technological developments, increased costs, the availability of requisite financing, and changes in carbon markets.

PART I — FINANCIAL INFORMATION

ITEM 1 — FINANCIAL STATEMENTS

PUBLIC SERVICE CO. OF COLORADO AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

(amounts in millions)

	Three Months Ended Sept. 30				Nine Months Ended Sept. 30
	2023		2022		2023		2022
Operating revenues
Electric	$	1,113	$	1,137	$	2,877	$	2,849
Natural gas	165		235		1,247		1,087
Other	12		11		41		39
Total operating revenues	1,290		1,383		4,165		3,975
Operating expenses
Electric fuel and purchased power	356		399		1,055		1,075
Cost of natural gas sold and transported	44		98		660		549
Cost of sales — other	5		4		13		13
Operating and maintenance expenses	196		220		648		650
Demand side management expenses	39		32		106		97
Depreciation and amortization	235		219		693		627
Taxes (other than income taxes)	71		70		216		205
Loss on Comanche Unit 3 litigation	34		—		34		—
Total operating expenses	980		1,042		3,425		3,216
Operating income	310		341		740		759
Other income (expense), net	1		(4)		7		(4)
Allowance for funds used during construction — equity	12		8		25		22
Interest charges and financing costs
Interest charges — includes other financing costs of $2, $2, $6 and $6, respectively	79		70		228		199
Allowance for funds used during construction — debt	(6)		(3)		(13)		(8)
Total interest charges and financing costs	73		67		215		191
Income before income taxes	250		278		557		586
Income tax expense	21		31		21		31
Net income	$	229	$	247	$	536	$	555

See Notes to Consolidated Financial Statements

4

PUBLIC SERVICE CO. OF COLORADO AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

(amounts in millions)

	Three Months Ended Sept. 30				Nine Months Ended Sept. 30
	2023		2022		2023		2022
Net income	$	229	$	247	$	536	$	555
Other comprehensive income
Pension and retiree medical benefits:
Reclassification of loss to net income, net of tax of $—	(1)		—		—		—
Derivative instruments:
Reclassification of loss to net income, net of tax of $—	1		1		1		1
Total other comprehensive income	—		1		1		1
Total comprehensive income	$	229	$	248	$	537	$	556

See Notes to Consolidated Financial Statements

5

PUBLIC SERVICE CO. OF COLORADO AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(amounts in millions)

	Nine Months Ended Sept. 30
	2023		2022
Operating activities
Net income	$	536	$	555
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	697		631
Deferred income taxes	(122)		16
Allowance for equity funds used during construction	(25)		(22)
Provision for bad debts	25		22
Changes in operating assets and liabilities:
Accounts receivable	115		(77)
Accrued unbilled revenues	257		38
Inventories	48		(130)
Other current assets	38		(10)
Accounts payable	(184)		97
Net regulatory assets and liabilities	178		(43)
Other current liabilities	31		(58)
Pension and other employee benefit obligations	1		(14)
Other, net	(54)		(74)
Net cash provided by operating activities	1,541		931
Investing activities
Utility capital/construction expenditures	(1,631)		(1,384)
Investments in utility money pool arrangement	(367)		(45)
Repayments from utility money pool arrangement	367		45
Net cash used in investing activities	(1,631)		(1,384)
Financing activities
Repayments of short-term borrowings, net	(294)		(147)
Borrowings under utility money pool arrangement	355		1,042
Repayments under utility money pool arrangement	(167)		(877)
Proceeds from issuance of long-term debt	834		686
Repayments of long-term debt	(250)		(300)
Capital contributions from parent	118		399
Dividends paid to parent	(507)		(365)
Net cash provided by financing activities	89		438
Net change in cash, cash equivalents and restricted cash	(1)		(15)
Cash, cash equivalents and restricted cash at beginning of period	10		25
Cash, cash equivalents and restricted cash at end of period	$	9	$	10
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	$	(197)	$	(195)
Cash paid for income taxes, net	(119)		(70)
Supplemental disclosure of non-cash investing and financing transactions:
Accrued property, plant and equipment additions	$	168	$	144
Inventory transfers to property, plant and equipment	17		15
Operating lease right-of-use assets	17		16
Allowance for equity funds used during construction	25		22

See Notes to Consolidated Financial Statements

6

PUBLIC SERVICE CO. OF COLORADO AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (UNAUDITED)

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

	Sept. 30, 2023		Dec. 31, 2022
Assets
Current assets
Cash and cash equivalents	$	9	$	10
Accounts receivable, net	423		562
Accounts receivable from affiliates	—		11
Accrued unbilled revenues	262		519
Inventories	254		319
Regulatory assets	370		411
Derivative instruments	13		65
Prepayments and other	75		103
Total current assets	1,406		2,000
Property, plant and equipment, net	20,653		19,652
Other assets
Regulatory assets	1,252		1,277
Derivative instruments	13		22
Operating lease right-of-use assets	388		437
Other	305		231
Total other assets	1,958		1,967
Total assets	$	24,017	$	23,619
Liabilities and Equity
Current liabilities
Current portion of long-term debt	$	—	$	250
Borrowings under utility money pool arrangement	188		—
Short-term debt	—		294
Accounts payable	544		764
Accounts payable to affiliates	74		75
Regulatory liabilities	66		59
Taxes accrued	195		242
Accrued interest	69		59
Dividends payable to parent	146		120
Derivative instruments	9		30
Operating lease liabilities	97		80
Other	180		115
Total current liabilities	1,568		2,088
Deferred credits and other liabilities
Deferred income taxes	1,902		1,983
Regulatory liabilities	2,585		2,489
Asset retirement obligations	492		476
Derivative instruments	2		9
Customer advances	129		144
Pension and employee benefit obligations	14		13
Operating lease liabilities	315		379
Other	208		198
Total deferred credits and other liabilities	5,647		5,691
Commitments and contingencies
Capitalization
Long-term debt	7,449		6,610
Common stock — 100 shares authorized of $0.01 par value; 100 shares outstanding at Sept. 30, 2023 and Dec. 31, 2022, respectively	—		—
Additional paid in capital	7,111		6,992
Retained earnings	2,263		2,260
Accumulated other comprehensive loss	(21)		(22)
Total common stockholder's equity	9,353		9,230
Total liabilities and equity	$	24,017	$	23,619

See Notes to Consolidated Financial Statements

7

PUBLIC SERVICE CO. OF COLORADO AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER’S EQUITY (UNAUDITED)

(amounts in millions, except share data)

	Common Stock Issued					Retained Earnings		Accumulated Other Comprehensive Loss		Total Common Stockholder's Equity
	Shares	Par Value		Additional Paid In Capital
Three Months Ended Sept. 30, 2023 and 2022
Balance at June 30, 2022	100	$	—	$	6,623	$	2,087	$	(22)	$	8,688
Net income						247				247
Other comprehensive income								1		1
Dividends declared to parent						(127)				(127)
Contribution of capital by parent				190						190
Balance at Sept. 30, 2022	100	$	—	$	6,813	$	2,207	$	(21)	$	8,999
Balance at June 30, 2023	100	$	—	$	7,086	$	2,195	$	(21)	$	9,260
Net income						229				229
Dividends declared to parent						(161)				(161)
Contribution of capital by parent				25						25
Balance at Sept. 30, 2023	100	$	—	$	7,111	$	2,263	$	(21)	$	9,353
	Common Stock Issued					Retained Earnings		Accumulated Other Comprehensive Loss		Total Common Stockholder's Equity
	Shares	Par Value		Additional Paid In Capital
Nine Months Ended Sept. 30, 2023 and 2022
Balance at Dec. 31, 2021	100	$	—	$	6,426	$	2,040	$	(22)	$	8,444
Net income						555				555
Other comprehensive income								1		1
Dividends declared to parent						(388)				(388)
Contribution of capital by parent				387						387
Balance at Sept. 30, 2022	100	$	—	$	6,813	$	2,207	$	(21)	$	8,999
Balance at Dec. 31, 2022	100	$	—	$	6,992	$	2,260	$	(22)	$	9,230
Net income						536				536
Other comprehensive income								1		1
Dividends declared to parent						(533)				(533)
Contribution of capital by parent				119						119
Balance at Sept. 30, 2023	100	$	—	$	7,111	$	2,263	$	(21)	$	9,353

See Notes to Consolidated Financial Statements

8

PUBLIC SERVICE CO. OF COLORADO AND SUBSIDIARIES

Notes to Consolidated Financial Statements (UNAUDITED)

In the opinion of management, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly, in accordance with GAAP, the financial position of PSCo and its subsidiaries as of Sept. 30, 2023 and Dec. 31, 2022; the results of PSCo’s operations, including the components of net income, comprehensive income and changes in stockholder’s equity for the three and nine months ended Sept. 30, 2023 and 2022; and PSCo’s cash flows for the nine months ended Sept. 30, 2023 and 2022.

All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after Sept. 30, 2023, 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, 2022 balance sheet information has been derived from the audited 2022 consolidated financial statements included in the PSCo Annual Report on Form 10-K for the year ended Dec. 31, 2022.

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 PSCo Annual Report on Form 10-K for the year ended Dec. 31, 2022, filed with the SEC on Feb. 23, 2023. Due to the seasonality of PSCo’s electric and natural gas sales, interim results are not necessarily an appropriate base from which to project annual results.

1. Summary of Significant Accounting Policies

The significant accounting policies set forth in Note 1 to the consolidated financial statements in the PSCo Annual Report on Form 10-K for the year ended Dec. 31, 2022 appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

2. Accounting Pronouncements

As of Sept. 30, 2023, there was no material impact from the recent adoption of new accounting pronouncements, nor expected material impact from recently issued accounting pronouncements yet to be adopted, on PSCo’s consolidated financial statements.

3. Selected Balance Sheet Data

(Millions of Dollars)	Sept. 30, 2023		Dec. 31, 2022
Accounts receivable, net
Accounts receivable	$	480	$	616
Less allowance for bad debts	(57)		(54)
Accounts receivable, net	$	423	$	562

(Millions of Dollars)	Sept. 30, 2023		Dec. 31, 2022
Inventories
Materials and supplies	$	86	$	80
Fuel	78		68
Natural gas	90		171
Total inventories	$	254	$	319

(Millions of Dollars)	Sept. 30, 2023		Dec. 31, 2022
Property, plant and equipment, net
Electric plant	$	16,343	$	15,771
Natural gas plant	6,293		5,949
Common and other property	1,500		1,415
Plant to be retired (a)	1,242		1,305
Construction work in progress	1,288		877
Total property, plant and equipment	26,666		25,317
Less accumulated depreciation	(6,013)		(5,665)
Property, plant and equipment, net	$	20,653	$	19,652

(a)Amounts include Comanche Units 2 and 3, Craig Units 1 and 2, Hayden Units 1 and 2 and coal generation assets at Pawnee pending facility gas conversion. Amounts are presented net of accumulated depreciation.

4. Borrowings and Other Financing Instruments

Short-Term Borrowings

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

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

Money pool borrowings:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2023			Year Ended Dec. 31, 2022
Borrowing limit	$	250		$	250
Amount outstanding at period end	188			—
Average amount outstanding	27			29
Maximum amount outstanding	188			250
Weighted average interest rate, computed on a daily basis	5.26		%	1.66		%
Weighted average interest rate at period end	5.30			N/A

Commercial Paper — Commercial paper outstanding:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2023			Year Ended Dec. 31, 2022
Borrowing limit	$	700		$	700
Amount outstanding at period end	—			294
Average amount outstanding	5			71
Maximum amount outstanding	72			328
Weighted average interest rate, computed on a daily basis	5.45		%	2.56		%
Weighted average interest rate at period end	N/A			4.73

Letters of Credit — PSCo uses letters of credit, generally with terms of one year, to provide financial guarantees for certain obligations. At Sept. 30, 2023 and Dec. 31, 2022, there were $29 million and $27 million, respectively, of letters of credit outstanding under the credit facility. Amounts approximate their fair value and are subject to fees.

Revolving Credit Facility — In order to issue its commercial paper, PSCo must have a revolving credit facility equal to or greater than the amount of its commercial paper borrowing limit and cannot issue commercial paper exceeding available capacity under this credit facility.

9

The credit facility provides short-term financing in the form of notes payable to banks, letters of credit and back-up support for commercial paper borrowings.

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

At Sept. 30, 2023, PSCo had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)		Drawn (b)		Available
$	700	$	29	$	671

(a)    Expires in September 2027.

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

All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity under the credit facility. PSCo had no direct advances on the credit facility outstanding at Sept. 30, 2023 and Dec. 31, 2022.

Long-Term Borrowings

During the nine months ended Sept. 30, 2023, PSCo issued $850 million of 5.25% first mortgage bonds due April 1, 2053.

5. Revenues

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

	Three Months Ended Sept. 30, 2023
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	398	$	88	$	5	$	491
C&I	538		44		7		589
Other	13		—		—		13
Total retail	949		132		12		1,093
Wholesale	53		—		—		53
Transmission	25		—		—		25
Other	16		27		—		43
Total revenue from contracts with customers	1,043		159		12		1,214
Alternative revenue and other	70		6		—		76
Total revenues	$	1,113	$	165	$	12	$	1,290

	Three Months Ended Sept. 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	431	$	136	$	4	$	571
C&I	556		64		7		627
Other	13		—		—		13
Total retail	1,000		200		11		1,211
Wholesale	63		—		—		63
Transmission	25		—		—		25
Other	15		30		—		45
Total revenue from contracts with customers	1,103		230		11		1,344
Alternative revenue and other	34		5		—		39
Total revenues	$	1,137	$	235	$	11	$	1,383

	Nine Months Ended Sept. 30, 2023
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	1,003	$	790	$	14	$	1,807
C&I	1,403		335		27		1,765
Other	40		—		—		40
Total retail	2,446		1,125		41		3,612
Wholesale	170		—		—		170
Transmission	68		—		—		68
Other	44		99		—		143
Total revenue from contracts with customers	2,728		1,224		41		3,993
Alternative revenue and other	149		23		—		172
Total revenues	$	2,877	$	1,247	$	41	$	4,165
	Nine Months Ended Sept. 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	1,025	$	686	$	11	$	1,722
C&I	1,383		279		16		1,678
Other	38		—		—		38
Total retail	2,446		965		27		3,438
Wholesale	200		—		—		200
Transmission	65		—		—		65
Other	39		106		—		145
Total revenue from contracts with customers	2,750		1,071		27		3,848
Alternative revenue and other	99		16		12		127
Total revenues	$	2,849	$	1,087	$	39	$	3,975

6. Income Taxes

Reconciliation between the statutory rate and ETR:

	Nine Months Ended Sept. 30
	2023		2022
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	3.5		3.6
(Decreases) increases:
Wind PTCs (a)	(14.9)		(14.2)
Plant regulatory differences (b)	(5.4)		(4.4)
Other tax credits, net operating loss & tax credit allowances	(1.0)		(1.1)
Other (net)	0.6		0.4
Effective income tax rate	3.8	%	5.3	%

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

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

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7. Fair Value of Financial Assets and Liabilities

Fair Value Measurements

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

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

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

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

Specific valuation methods include:

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

Commodity derivatives — Methods used to measure the fair value of commodity derivative forwards and options utilize forward prices and volatilities, as well as pricing adjustments for specific delivery locations, and are generally assigned a Level 2 classification. When contracts relate to inactive delivery locations or extend to periods beyond those readily observable on active exchanges, the significance of the use of less observable inputs on a valuation is evaluated and may result in Level 3 classification.

Derivative Activities and Fair Value Measurements

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

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

As of Sept. 30, 2023, accumulated other comprehensive loss related to interest rate derivatives included $1 million of net losses expected to be reclassified into earnings during the next 12 months as the hedged transactions impact earnings. As of Sept. 30, 2023, PSCo had no unsettled interest rate derivatives.

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

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

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

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

As of Sept. 30, 2023, PSCo had no commodity contracts designated as cash flow hedges.

Gross notional amounts of commodity forwards and options:

(Amounts in Millions) (a)(b)	Sept. 30, 2023	Dec. 31, 2022
Megawatt hours of electricity	4	8
Million British thermal units of natural gas	28	43

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

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

As of Sept. 30, 2023, four of PSCo’s ten most significant counterparties for these activities, comprising $32 million, or 45%, of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings.

Six of the ten most significant counterparties, comprising $25 million, or 35%, of this credit exposure, were not rated by these external ratings agencies, but based on PSCo’s internal analysis, had credit quality consistent with investment grade.

None of these significant counterparties, had credit quality less than investment grade, based on internal analysis. Seven of these significant counterparties are independent system operators, municipal or cooperative electric entities, Regional Transmission Organizations or other utilities.

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

As of Sept. 30, 2023 and Dec. 31, 2022, there were no derivative liabilities position with such underlying contract provisions.

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

As of Sept. 30, 2023 and Dec. 31, 2022, there were $1 million and no 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. These provisions allow counterparties to seek performance assurance, including cash collateral, in the event that PSCo’s ability to fulfill its contractual obligations is reasonably expected to be impaired. PSCo had no collateral posted related to adequate assurance clauses in derivative contracts as of Sept. 30, 2023 and Dec. 31, 2022.

Recurring Derivative Fair Value Measurements

Changes in the fair value of natural gas commodity derivatives recognized as regulatory assets and liabilities included immaterial net gains and losses for the three and nine months ended Sept. 30, 2023 and 2022. The classification as a regulatory asset or liability is based on commission approved regulatory recovery mechanisms.

	Pre-Tax Losses Reclassified into Income During the Period from:						Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Accumulated Other Comprehensive Loss			Regulatory Assets and Liabilities
Three Months Ended Sept. 30, 2023
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	2	(a)
Total	$	—		$	—		$	2
Nine Months Ended Sept. 30, 2023
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	(3)	(a)
Natural gas commodity	—			10		(c)	(12)		(c)(d)
Total	$	—		$	10		$	(15)
Three Months Ended Sept. 30, 2022
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	2	(a)
Total	$	—		$	—		$	2
Nine Months Ended Sept. 30, 2022
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	3	(a)
Natural gas commodity	—			2		(c)	(11)		(c)(d)
Total	$	—		$	2		$	(8)

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

(b)Recorded to interest charges.

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

(d)Relates primarily to option premium amortization.

PSCo had no derivative instruments designated as fair value hedges during

the nine months ended Sept. 30, 2023 and 2022.

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

	Sept. 30, 2023												Dec. 31, 2022
	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	$	3	$	42	$	3	$	48	$	(37)	$	11	$	16	$	220	$	1	$	237	$	(184)	$	53
Natural gas commodity	—		2		—		2		—		2		—		12		—		12		—		12
Total current derivative assets	$	3	$	44	$	3	$	50	$	(37)	$	13	$	16	$	232	$	1	$	249	$	(184)	$	65
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	8	$	2	$	8	$	18	$	(5)	$	13	$	12	$	32	$	9	$	53	$	(31)	$	22
Total noncurrent derivative assets	$	8	$	2	$	8	$	18	$	(5)	$	13	$	12	$	32	$	9	$	53	$	(31)	$	22

	Sept. 30, 2023												Dec. 31, 2022
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative liabilities
Other derivative instruments:
Commodity trading	$	1	$	51	$	—	$	52	$	(43)	$	9	$	5	$	237	$	1	$	243	$	(223)	$	20
Natural gas commodity	—		—		—		—		—		—		—		10		—		10		—		10
Total current derivative liabilities	$	1	$	51	$	—	$	52	$	(43)	$	9	$	5	$	247	$	1	$	253	$	(223)	$	30
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	4	$	4	$	—	$	8	$	(6)	$	2	$	7	$	40	$	—	$	47	$	(38)	$	9
Total noncurrent derivative liabilities	$	4	$	4	$	—	$	8	$	(6)	$	2	$	7	$	40	$	—	$	47	$	(38)	$	9

(a)PSCo nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At Sept. 30, 2023 and Dec. 31, 2022, derivative assets and liabilities include no obligations to return cash collateral. At Sept. 30, 2023 and Dec. 31, 2022, derivative assets and liabilities include rights to reclaim cash collateral of $7 million and $46 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.

Changes in Level 3 commodity derivatives:

	Three Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Balance at July 1	$	9	$	(30)
Settlements (a)	—		5
Net transactions recorded during the period:
Gains recognized in earnings (a)	2		1
Balance at Sept. 30	$	11	$	(24)
	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Balance at Jan. 1	$	9	$	(63)
Settlements (a)	—		9
Net transactions recorded during the period:
Gains recognized in earnings (a)	2		30
Balance at Sept. 30	$	11	$	(24)

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

Fair Value of Long-Term Debt

As of Sept. 30, 2023, other financial instruments for which the carrying amount did not equal fair value:

	Sept. 30, 2023				Dec. 31, 2022
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	7,449	$	5,932	$	6,860	$	5,881

Fair value of PSCo’s long-term debt is estimated based on recent trades and observable spreads from benchmark interest rates for similar securities. Fair value estimates are based on information available to management as of Sept. 30, 2023 and Dec. 31, 2022, and given the observability of the inputs, fair values presented for long-term debt were assigned as Level 2.

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8. Benefit Plans and Other Postretirement Benefits

Components of Net Periodic Benefit Cost (Credit)

	Three Months Ended Sept. 30
	2023		2022		2023		2022
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	5	$	7	$	—	$	1
Interest cost (a)	14		10		4		2
Expected return on plan assets (a)	(19)		(19)		(3)		(4)
Amortization of prior service credit (a)	—		—		—		(1)
Amortization of net loss (a)	1		6		—		—
Settlement charge (b)	—		2		—		—
Net periodic benefit (credit) cost	1		6		1		(2)
Effects of regulation	3		(2)		—		1
Net benefit cost (credit) recognized for financial reporting	$	4	$	4	$	1	$	(1)
	Nine Months Ended Sept. 30
	2023		2022		2023		2022
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	14	$	22	$	—	$	1
Interest cost (a)	43		31		12		8
Expected return on plan assets (a)	(57)		(58)		(11)		(12)
Amortization of prior service credit (a)	—		—		—		(2)
Amortization of net loss (a)	2		17		1		1
Settlement charge (b)	—		2		—		—
Net periodic benefit (credit) cost	2		14		2		(4)
Effects of regulation	9		3		—		2
Net benefit cost (credit) recognized for financial reporting	$	11	$	17	$	2	$	(2)

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

(b)A settlement charge is required when the amount of all lump-sum distributions during the year is greater than the sum of the service and interest cost components of the annual net periodic pension cost. In the third quarter of 2022 as a result of lump-sum distributions during the 2022 plan year, PSCo recorded a pension settlement charge of $2 million, the majority of which was not recognized due to the effects of regulation.

In January 2023, contributions totaling $50 million were made across Xcel Energy’s pension plans, of which none was attributable to PSCo. Xcel Energy does not expect additional pension contributions during 2023.

9. Commitments and Contingencies

Legal

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

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

Comanche Unit 3 Litigation — In 2021, CORE filed a lawsuit in Denver County District Court, alleging PSCo breached ownership agreement terms by failing to operate Comanche Unit 3 in accordance with prudent utility practices. In April 2022, CORE filed a supplement to include damages related to a 2022 outage. Also in 2022, CORE sent notice of withdrawal from the ownership agreement based on the same alleged breaches.

In February 2023, the court granted PSCo’s motion precluding CORE from seeking damages related to its withdrawal as part of the lawsuit. In September 2023, the court denied PSCo’s motion for summary judgment on other categories of damages and allowed CORE to seek approximately $253 million at trial (before interest), including an alleged $187 million reduction in the value of CORE’s ownership interest in the Comanche 3 facility and $60 million of alleged lost power costs.

On Oct. 25, 2023, the jury awarded CORE lost power damages of $26 million. PSCo recognized $34 million for the verdict in the third quarter of 2023, including estimated interest and other costs. PSCo intends to file an appeal of this decision.

Marshall Wildfire

In December 2021, a wildfire ignited in Boulder County, Colorado (the “Marshall Fire”), which burned over 6,000 acres and destroyed or damaged over 1,000 structures. On June 8, 2023, the Boulder County Sheriff’s Office released its Marshall Fire Investigative Summary and Review and its supporting documents (the “Sheriff’s Report”). According to an October 2022 statement from the Colorado Insurance Commissioner, the Marshall Fire is estimated to have caused more than $2 billion in property losses.

According to the Sheriff’s Report, on Dec. 30, 2021, a fire ignited on a residential property in Boulder, Colorado, located in PSCo’s service territory, for reasons unrelated to PSCo’s power lines. According to the Sheriff’s Report, approximately one hour and 20 minutes after the first ignition, a second fire ignited just south of the Marshall Mesa Trailhead in unincorporated Boulder County, Colorado, also located in PSCo’s service territory. According to the Sheriff’s Report, the second ignition started approximately 80 to 110 feet away from PSCo’s power lines in the area.

The Sheriff’s Report states that the most probable cause of the second ignition was hot particles discharged from PSCo’s power lines after one of the power lines detached from its insulator in strong winds, and further states that it cannot be ruled out that the second ignition was caused by an underground coal fire. According to the Sheriff’s Report, no design, installation or maintenance defects or deficiencies were identified on PSCo’s electrical circuit in the area of the second ignition. PSCo disputes that its power lines caused the second ignition.

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As of Oct. 24, 2023, PSCo is aware of 14 complaints, certain of which have also named Xcel Energy Inc. as a defendant, on behalf of at least 675 plaintiffs relating to the Marshall Fire and expects that it may receive further complaints. The complaints generally allege that PSCo’s equipment ignited the Marshall Fire and assert various causes of action under Colorado law, including negligence, premises liability, trespass, nuisance, and inverse condemnation. In September 2023, the Boulder County District Court Judge consolidated eight lawsuits that were pending at that time into a single action for pretrial purposes and has subsequently consolidated additional lawsuits that have been filed.

Colorado courts do not apply strict liability in determining an electric utility company’s liability for fire-related damages. For inverse condemnation claims, Colorado courts assess whether a defendant acted with intent to take a plaintiff’s property or intentionally took an action which has the natural consequence of taking the property. For negligence claims, Colorado courts look to whether electric power companies have operated their system with a heightened duty of care consistent with the practical conduct of its business, and liability does not extend to occurrences that cannot be reasonably anticipated.

Under Colorado law, in a civil action other than a medical malpractice action, the total award for noneconomic loss is capped at $0.6 million per defendant for claims that accrued at the time of the Marshall Fire unless the court finds justification to exceed that amount by clear and convincing evidence, in which case the maximum doubles. Colorado law does not impose joint and several liability in tort actions. Instead, under Colorado law, a defendant is liable for the degree or percentage of the negligence or fault attributable to that defendant, except where the defendant conspired with another defendant. A jury’s verdict in a Colorado civil case must be unanimous.

Colorado law caps punitive or exemplary damages to an amount equal to the amount of the actual damages awarded to the injured party, except the court may increase any award of punitive damages to a sum up to three times the amount of actual damages if the conduct that is the subject of the claim has continued during the pendency of the case or the defendant has acted in a willful and wanton manner during the action which further aggravated plaintiff’s damages.

In the event Xcel Energy Inc. or PSCo was found liable related to this litigation and were required to pay damages, such amounts could exceed our insurance coverage of approximately $500 million and have a material adverse effect on our financial condition, results of operations or cash flows. However, due to uncertainty as to the cause of the fire and the extent and magnitude of potential damages, Xcel Energy Inc. and PSCo are unable to estimate the amount or range of possible losses in connection with the Marshall Fire.

Rate Matters

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

Environmental

MGP, Landfill and Disposal Sites

PSCo is investigating, remediating or performing post-closure actions at two MGP, landfill or other disposal sites across its service territory, excluding sites that are being addressed under coal ash regulations.

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

Environmental Requirements — Water and Waste

Coal Ash Regulation — PSCo’s operations are subject to federal and state regulations that impose requirements for handling, storage, treatment and disposal of solid waste. Under the CCR Rule, utilities are required to complete groundwater sampling around their applicable landfills and surface impoundments as well as perform corrective actions where offsite groundwater has been impacted.

As of Sept. 30, 2023, PSCo has five regulated ash units in operation.

PSCo has executed an agreement with a third party that will excavate and process ash for beneficial use (at two sites) at a cost of approximately $45 million. An estimated liability has been recorded and amounts are expected to be fully recoverable through regulatory mechanisms.

Investigation and feasibility studies for additional corrective action related to offsite groundwater are ongoing (at three sites). While the results are uncertain, additional costs are estimated to be at least $40 million. A liability has been recorded and is expected to be fully recoverable through regulatory mechanisms.

Leases

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

Components of lease expense:

	Three Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Operating leases
PPA capacity payments	$	23	$	22
Other operating leases (a)	5		3
Total operating lease expense (b)	$	28	$	25
Finance leases
Amortization of ROU assets	$	1	$	1
Interest expense on lease liability	4		4
Total finance lease expense	$	5	$	5

(a)Includes immaterial short-term lease expense for both 2023 and 2022.

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

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	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Operating leases
PPA capacity payments	$	68	$	70
Other operating leases (a)	15		13
Total operating lease expense (b)	$	83	$	83
Finance leases
Amortization of ROU assets	$	2	$	3
Interest expense on lease liability	12		12
Total finance lease expense	$	14	$	15

(a)Includes immaterial short-term lease expense for both 2023 and 2022.

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

Commitments under operating and finance leases as of Sept. 30, 2023:

(Millions of Dollars)	PPA Operating Leases		Other Operating Lease		Total Operating Leases		Finance Leases
Total minimum obligation	$	394	$	63	$	457	$	423
Interest component of obligation	(38)		(7)		(45)		(308)
Present value of minimum obligation	$	356	$	56	412		115
Less current portion					(97)		(3)
Noncurrent operating and finance lease liabilities					$	315	$	112

Variable Interest Entities 

Under certain PPAs, PSCo purchases power from IPPs for which PSCo is required to reimburse fuel costs, or to participate in tolling arrangements under which PSCo procures the natural gas required to produce the energy that they purchase. These specific PPAs create a variable interest in the IPP.

PSCo had approximately 1,509 MW and 1,442 MW of capacity under long-term PPAs at Sept. 30, 2023 and Dec. 31, 2022 with entities that have been determined to be variable interest entities. PSCo concluded that these entities are not required to be consolidated in its financial statements because it does not have the power to direct the activities that most significantly impact the entities’ economic performance. The PPAs have expiration dates through 2032.

10. Other Comprehensive Income

Changes in accumulated other comprehensive loss, net of tax:

	Three Months Ended Sept. 30, 2023						Three Months Ended Sept. 30, 2022
(Millions of Dollars)	Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total		Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total
Accumulated other comprehensive loss at July 1	$	(20)	$	(1)	$	(21)	$	(21)	$	(1)	$	(22)
Losses reclassified from net accumulated other comprehensive loss:
Amortization of net actuarial loss (a)	—		(1)		(1)		—		—		—
Interest rate derivatives (b)	1		—		1		1		—		1
Net current period other comprehensive income	1		(1)		—		1		—		1
Accumulated other comprehensive loss at Sept. 30	$	(19)	$	(2)	$	(21)	$	(20)	$	(1)	$	(21)

	Nine Months Ended Sept. 30, 2023						Nine Months Ended Sept. 30, 2022
(Millions of Dollars)	Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total		Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total
Accumulated other comprehensive loss at Jan. 1	$	(20)	$	(2)	$	(22)	$	(21)	$	(1)	$	(22)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (b)	1		—		1		1		—		1
Net current period other comprehensive income	1		—		1		1		—		1
Accumulated other comprehensive loss at Sept. 30	$	(19)	$	(2)	$	(21)	$	(20)	$	(1)	$	(21)

(a)Included in the computation of net periodic pension and postretirement benefit costs. See Note 8 for further information.

(b)Included in interest charges.

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11. Segment Information

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

PSCo has the following reportable segments:

•Regulated Electric — The regulated electric utility segment generates electricity which is transmitted and distributed in Colorado. 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 PSCo’s wholesale commodity and trading operations.

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

PSCo also presents All Other, which includes operating segments with revenues below the necessary quantitative thresholds. Those operating segments primarily include steam revenue, appliance repair services and non-utility real estate activities.

Asset and capital expenditure information is not provided for PSCo’s reportable segments because, as an integrated electric and natural gas utility, PSCo operates significant assets that are not dedicated to a specific business segment and 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.

PSCo’s segment information:

	Three Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Regulated Electric
Total revenues	$	1,113	$	1,137
Net income	247		243
Regulated Natural Gas
Total revenues	$	165	$	235
Net (loss) income	(16)		4
All Other
Total revenues (a)	$	12	$	11
Net loss	(2)		—
Consolidated Total
Total operating revenues (a)	$	1,290	$	1,383
Net income	229		247

(a)    Total revenues include $1 million and $2 million of other affiliate revenue for the three months ended Sept. 30, 2023 and 2022.

	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Regulated Electric
Total revenues	$	2,877	$	2,849
Net income	449		455
Regulated Natural Gas
Total revenues	$	1,247	$	1,087
Net income	81		99
All Other
Total revenues (a)	$	41	$	39
Net income	6		1
Consolidated Total
Total operating revenues (a)	$	4,165	$	3,975
Net income	536		555

(a)    Total revenues include $3 million and $4 million of other affiliate revenue for the nine months ended Sept. 30, 2023 and 2022.

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

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

Non-GAAP Financial Measures

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

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

Earnings Adjusted for Certain Items (Ongoing Earnings)

Ongoing earnings reflect adjustments to GAAP earnings (net income) for certain items.

We use this non-GAAP financial measure to evaluate and provide details of Xcel Energy’s core earnings and underlying performance. For instance, to present ongoing earnings, we may adjust the related GAAP amounts for certain items that are non-recurring in nature. We believe this measurement is useful to investors to evaluate the actual and projected financial performance and contribution of our subsidiaries. This non-GAAP financial measure should not be considered as an alternative to measures calculated and reported in accordance with GAAP.

17

The following table provides a reconciliation of GAAP earnings (net income) to ongoing earnings:

	Three Months Ended Sept. 30				Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022		2023		2022
GAAP net income	$	229	$	247	$	536	$	555
Loss on Comanche Unit 3 litigation	34		—		34		—
Less: tax effect of adjustment	(8)		—		(8)		—
Ongoing earnings	$	255	$	247	$	562	$	555

Comanche Unit 3 Litigation — As a result of an Oct. 25, 2023 jury verdict in Denver County District Court awarding CORE lost power damages and other costs, PSCo recognized a $34 million loss for the matter in the third quarter of 2023. Given the non-recurring nature of this specific item, it has been excluded from ongoing earnings.

Results of Operations

PSCo’s GAAP net income was $536 million for the nine months ended Sept. 30, 2023, compared to $555 million for the prior year. Ongoing net income was $562 million for the nine months ended Sept. 30, 2023, compared to $555 million for the prior year. The higher ongoing earnings primarily reflect higher recovery of infrastructure investment (electric and natural gas), which were offset by increased depreciation and interest charges.

Electric Margin

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

Electric revenues and fuel and purchased power expenses are impacted by fluctuations in the price of natural gas and coal. However, these fluctuations have minimal impact on margin due to fuel recovery mechanisms. In addition, electric customers receive a credit for PTCs generated, which reduce electric revenue and margin (offset by lower tax expense).

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

	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Electric revenues	$	2,877	$	2,849
Electric fuel and purchased power	(1,055)		(1,075)
Electric margin	$	1,822	$	1,774

(Millions of Dollars)	Nine Months Ended Sept. 30, 2023 vs. 2022
Regulatory rate outcomes	$	30
Non-fuel riders	19
Wholesale transmission (net)	8
Estimated impact of weather (net of decoupling)	(18)
Other, net	9
Total increase	$	48

Natural Gas Margin

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

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

	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Natural gas revenues	$	1,247	$	1,087
Cost of natural gas sold and transported	(660)		(549)
Natural gas margin	$	587	$	538

(Millions of Dollars)	Nine Months Ended Sept. 30, 2023 vs. 2022
Regulatory rate outcomes	$	47
Estimated impact of weather	16
Other, net	(14)
Total increase	$	49

Non-Fuel Operating Expenses and Other Items

Depreciation and Amortization — Depreciation and amortization expense increased $66 million year-to-date. The increase was primarily due to normal system expansion and new electric and natural gas depreciation rates.

Interest Charges — Interest charges increased $29 million year-to-date, largely due to higher interest rates and increased long-term debt levels to fund capital investments.

Public Utility Regulation and Other

The FERC and state and local regulatory commissions regulate PSCo. PSCo is subject to rate regulation by state utility regulatory agencies, which have jurisdiction with respect to the rates of electric and natural gas distribution companies in Colorado.

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

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

Except to the extent noted below, the circumstances set forth in Public Utility Regulation included in Item 7 of PSCo’s Annual Report on Form 10-K for the year ended Dec. 31, 2022, appropriately represent, in all material respects, the current status of public utility regulation and are incorporated herein by reference.

18

Pending and Recently Concluded Regulatory Proceedings

Colorado Electric Rate Case — In November 2022, PSCo filed a Colorado electric rate case seeking a net increase of $262 million, or 8.2%. The total request reflects a $312 million increase (subsequently adjusted to $303 million in rebuttal), which includes $50 million of authorized costs previously recovered through various rider mechanisms. The request was based on a 10.25% ROE, an equity ratio of 55.7% and a 2023 forecast test year with a 2023 average rate base of $11.3 billion.

In September 2023, the CPUC approved a settlement between PSCo and various parties, which included the following terms:

•Retail revenue increase (excluding rider roll-ins) of $95 million (increase of 2.96%), based on a 2022 historic test year using year-end rate base with forward looking known and measurable adjustments.

•Weighted-average cost of capital of 6.95% (based on 55.69% equity ratio and 9.3% ROE).

•Termination of the revenue decoupling pilot with implementation of new rates.

•Continuation of previously authorized trackers and deferrals.

•Collection of PSCo’s requested 2023 TCA revenues, previously suspended by the CPUC. Beginning in 2024, projects eligible for recovery will be limited to projects which increase transmission capacity or are part of an approved wildfire mitigation plan.

Rates became effective in September 2023.

Colorado Resource Plan — In August 2022, the CPUC approved a settlement for the Colorado Resource Plan among PSCo and various intervenors. This settlement provides for an expected carbon reduction and the retirement of PSCo’s remaining coal plant by the end of 2030.

In September 2023, PSCo filed its recommended Preferred Plan. The filing also includes several other alternative scenarios. PSCo’s Preferred Plan results in the exit of coal by the end of 2030, roughly doubling wind and solar energy from 2022 levels, and reduction of greenhouse gas emissions by more than 80% from 2005 levels. It also reflects an average annual rate impact of approximately 2.3% which is inclusive of generation and transmission network and interconnection costs.

The Preferred Plan includes the following resources:

Generation Resource (in MW)	Company Owned	PPAs	Total
Wind Resources	2,531	875	3,406
Solar	1,109	860	1,969
Storage	500	670	1,170
Natural Gas	628	—	628
Biomass	19	—	19
Total	4,787	2,405	7,192

If approved by the CPUC, Xcel Energy expects to invest $7.9 billion in generation resources. In addition, the plan requires approximately $2.9 billion of incremental investments in transmission capacity upgrades and new lines to fully integrate the renewable generation.

The CPUC is expected to render a decision on the recommended Preferred Plan by the end of 2023 or in early 2024.

ECA Fuel Recovery — In December 2022, PSCo filed its first quarter 2023 ECA Advice Letter, which sought to recover $123 million of under-recovered 2022 fuel costs over two quarters (instead of one quarter, as more typical). In December 2022, the CPUC found that the $123 million should be removed from the proposed ECA rates, and required PSCo to file a separate application to recover these costs.

In February 2023 and May 2023, PSCo submitted interim ECA filings which included $70 million and $25 million, respectively, of the 2022 under-recovered costs to be collected over the remainder of 2023.

In the third quarter, PSCo and CPUC Staff filed a settlement allowing for collection of the remaining amount, which after final adjustments was $37 million. This was opposed by the UCA. The ALJ held a hearing in October 2023 and is expected to issue a recommended decision in late 2023 or early 2024.

Colorado Legislation — In May 2023, Colorado Senate Bill 23-291 passed and was signed into law. The bill includes a number of topics including natural gas and electric fuel incentive mechanisms, natural gas planning rules, regulatory filing requirements, and non-recovery of certain expenses (e.g., certain organizational or membership dues, tax penalties or fines). This legislation will require additional rulemaking from the CPUC prior to implementation. In particular, the legislation calls for gas utilities to file a gas price risk management plan by Nov. 1, 2023. In addition, the legislation calls for the CPUC to adopt rules by Jan. 1, 2025 to establish fuel cost mechanisms to align the financial incentives of a utility with the interests of the utility’s customers.

Other

Supply Chain

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

Electric Meters and Transformers

Supply chain issues associated with semi-conductors have delayed the availability of advanced infrastructure meters, which led to a reduced number of meters deployed in 2022. While there have been improvements in the 2023 deployment plan, the supply chain challenges persist. As a result of delays, PSCo projects impacts to deployment schedules into 2025.

Additionally, the availability of certain transformers is an industry-wide issue that has significantly impacted and in some cases may result in delays in projects and new customer connections. Proposed governmental actions related to transformer efficiency standards may compound these delays in the future. PSCo continues to seek alternative suppliers and prioritize work plans to mitigate impacts of supply constraints.

Solar Resources

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

19

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

Environmental

Clean Air Act

Power Plant Greenhouse Gas Regulations — In May 2023, the EPA published proposed rules addressing control of CO2 emissions from the power sector. The rule proposed regulations for new natural gas generating units under Clean Air Act Section 111(b) and emission guidelines for existing coal and certain natural gas generation under Clean Air Act Section 111(d). The proposed rules create subcategories of coal units based on planned retirement date and subcategories of natural gas combustion turbines and combined cycle units based on utilization. The CO2 control requirements vary by subcategory. Until final rules are issued, it is not certain what the impact will be on PSCo. PSCo believes that the cost of these initiatives or replacement generation would be recoverable through rates based on prior state commission practices.

Coal Ash Regulation

In May 2023, the EPA published proposed rules to regulate legacy CCR surface impoundments at inactive facilities and previously exempt areas where CCR was placed directly on land at regulated CCR facilities under the CCR Rule for the first time. The proposed rule would subject these areas to the CCR Rule requirements, including groundwater monitoring, corrective action, closure, and post-closure care requirements, among other requirements, with several of the deadlines accelerated.

The EPA has committed to a May 2024 effective date for those new rules. It is also anticipated that the EPA may issue other CCR proposed rules in 2023 that further expand the scope of the CCR Rule. Until final rules are issued, it is not certain what the impact will be on PSCo. PSCo believes that the cost of these initiatives would be recoverable through rates based on prior state commission practices.

Emerging Contaminants of Concern

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

In September 2022, the EPA proposed to designate two types of PFAS as “hazardous substances” under the CERCLA.

In March 2023, the EPA published a proposed rule that would establish enforceable drinking water standards for certain PFAS chemicals.

PSCo provided comments related to both efforts described above through its regulatory coalitions. Final rules are expected in 2024. Costs are uncertain until a final rule is published.

The proposed rules could result in new obligations for investigation and cleanup. PSCo is monitoring changes to state laws addressing PFAS. The impact of these proposed regulations is uncertain.

Effluent Limitation Guidelines

In March 2023, the EPA released a proposed rule under the Clean Water Act, setting forth proposed Effluent Limitations Guidelines and Standards for steam generating coal plants. This proposed rule establishes more stringent wastewater discharge standards for bottom ash transport water, flue-gas desulfurization wastewater, and combustion residuals leachate from steam electric power plants, particularly coal-fired power plants. Comments to the proposed regulations were submitted on May 30, 2023. The impact of these proposed regulations is uncertain until a final rule is published.

ITEM 4 — CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

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

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

As of Sept. 30, 2023, based on an evaluation carried out under the supervision and with the participation of PSCo’s management, including the CEO and CFO, of the effectiveness of its disclosure controls and procedures, the CEO and CFO have concluded that PSCo’s disclosure controls and procedures were effective.

Internal Control Over Financial Reporting

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

PART II — OTHER INFORMATION

ITEM 1 — LEGAL PROCEEDINGS

PSCo 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 PSCo’s consolidated financial statements. Legal fees are generally expensed as incurred.

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

20

ITEM 1A — RISK FACTORS

PSCo’s risk factors are documented in Item 1A of Part I of its Annual Report on Form 10-K for the year ended Dec. 31, 2022, which is incorporated herein by reference. There have been no material changes from the risk factors previously disclosed in the Form 10-K.

ITEM 5 — OTHER INFORMATION

None of the Company’s directors or officers adopted, modified, or terminated a Rule 10b5-1 trading arrangement or a non-Rule 10b5-1 trading arrangement during the Company’s fiscal quarter ended Sept. 30, 2023.

ITEM 6 — EXHIBITS

* Indicates incorporation by reference

Exhibit Number	Description	Report or Registration Statement	Exhibit Reference
3.01*	Amended and Restated Articles of Incorporation, dated July 15, 1998	PSCo Form 10-Q for the quarter ended Sept. 30, 2017	3.01
3.02*	Amended and Restated Bylaws of PSCo, dated Jan. 25, 2019	PSCo Form 10-K for the year ended Dec. 31, 2018	3.02
31.01	Principal Executive Officer’s certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.02	Principal Financial Officer’s certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.01	Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH	Inline XBRL Schema
101.CAL	Inline XBRL Calculation
101.DEF	Inline XBRL Definition
101.LAB	Inline XBRL Label
101.PRE	Inline XBRL Presentation
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

21

SIGNATURES

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

		Public Service Company of Colorado
10/27/23	By:	/s/ BRIAN J. VAN ABEL
		Brian J. Van Abel
		Executive Vice President, Chief Financial Officer
		(Principal Accounting Officer and Principal Financial Officer)

22

EX-31.01

Exhibit 31.01

CERTIFICATION

I, Robert C. Frenzel, certify that:

1.I have reviewed this report on Form 10-Q of Public Service Company of Colorado;

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

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

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

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

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

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

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

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

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

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

Date: 10/27/23

/s/ ROBERT C. FRENZEL

Robert C. Frenzel

Chairman, Chief Executive Officer and Director

(Principal Executive Officer)

1

EX-31.02

Exhibit 31.02

CERTIFICATION

I, Brian J. Van Abel, certify that:

1.I have reviewed this report on Form 10-Q of Public Service Company of Colorado;

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

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

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

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

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

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

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

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

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

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

Date: 10/27/23

/s/ BRIAN J. VAN ABEL

Brian J. Van Abel

Executive Vice President, Chief Financial Officer and Director

(Principal Accounting Officer and Principal Financial Officer)

2

EX-32.01

Exhibit 32.01

OFFICER CERTIFICATION

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Public Service Company of Colorado (PSCo) on Form 10-Q for the quarter ended Sept. 30, 2023, as filed with the SEC on the date hereof (Form 10-Q), each of the undersigned officers of PSCo certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to such officer’s knowledge:

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

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

Date: 10/27/23

/s/ ROBERT C. FRENZEL

Robert C. Frenzel

Chairman, Chief Executive Officer and Director

(Principal Executive Officer)

/s/ BRIAN J. VAN ABEL

Brian J. Van Abel

Executive Vice President, Chief Financial Officer and Director

(Principal Accounting Officer and Principal Financial Officer)

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

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

1

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Cover Page - shares	9 Months Ended
	Sep. 30, 2023	Oct. 27, 2023
Cover [Abstract]
Entity Registrant Name	PUBLIC SERVICE CO OF COLORADO
Entity Central Index Key	0000081018
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q3
Amendment Flag	false
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
Document Transition Report	false
Entity File Number	001-03280
Entity Incorporation, State or Country Code	CO
Entity Tax Identification Number	84-0296600
Entity Address, Address Line One	1800 Larimer Street, Suite 1100
Entity Address, City or Town	Denver
Entity Address, State or Province	CO
Entity Address, Postal Zip Code	80202
City Area Code	(303)
Local Phone Number	571-7511
Entity Current Reporting Status	Yes
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Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
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CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Operating revenues
Electric	$ 1,113	$ 1,137	$ 2,877	$ 2,849
Natural gas	165	235	1,247	1,087
Other	12	11	41	39
Total operating revenues	1,290	1,383	4,165	3,975	[1]
Operating expenses
Electric fuel and purchased power	356	399	1,055	1,075
Cost of natural gas sold and transported	44	98	660	549
Cost of sales — other	5	4	13	13
Operating and maintenance expenses	196	220	648	650
Demand side management expenses	39	32	106	97
Depreciation and amortization	235	219	693	627
Taxes (other than income taxes)	71	70	216	205
Total operating expenses	980	1,042	3,425	3,216
Operating income	310	341	740	759
Other income (expense), net	1	(4)	7	(4)
Allowance for funds used during construction — equity	12	8	25	22
Interest charges and financing costs
Interest charges — includes other financing costs of $2, $2, $6 and $6, respectively	79	70	228	199
Allowance for funds used during construction — debt	(6)	(3)	(13)	(8)
Total interest charges and financing costs	73	67	215	191
Income before income taxes	250	278	557	586
Income tax expense	21	31	21	31
Net income	229	247	536	555
Gain (Loss) Related to Litigation Settlement	$ 34	$ 0	$ 34	$ 0

[1] Total revenues include $3 million and $4 million of other affiliate revenue for the nine months ended Sept. 30, 2023 and 2022.

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CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Statement of Financial Position [Abstract]
Other financing costs	$ 2	$ 2	$ 6	$ 6
Gain (Loss) Related to Litigation Settlement	$ 34	$ 0	$ 34	$ 0

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Comprehensive income:
Net income	$ 229	$ 247	$ 536	$ 555
Pension and retiree medical benefits:
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, after Tax	(1)	0	0	0
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, before Tax	(1)	(1)	(1)	(1)
Total comprehensive income	229	248	537	556
Total other comprehensive income	$ 0	$ 1	$ 1	$ 1

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Statement of Comprehensive Income [Abstract]
Amortization of losses included in net periodic benefit cost, tax	$ 0	$ 0	$ 0	$ 0
Tax	$ 0	$ 0	$ 0	$ 0

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CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Operating activities
Net income	$ 536	$ 555
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	697	631
Deferred income taxes	(122)	16
Allowance for equity funds used during construction	(25)	(22)
Provision for bad debts	25	22
Changes in operating assets and liabilities:
Accounts receivable	115	(77)
Accrued unbilled revenues	257	38
Inventories	48	(130)
Other current assets	38	(10)
Accounts payable	(184)	97
Net regulatory assets and liabilities	178	(43)
Other current liabilities	31	(58)
Pension and other employee benefit obligations	1	(14)
Other, net	(54)	(74)
Net cash provided by operating activities	1,541	931
Investing activities
Utility capital/construction expenditures	(1,631)	(1,384)
Investments in utility money pool arrangement	(367)	(45)
Repayments from utility money pool arrangement	367	45
Net cash used in investing activities	(1,631)	(1,384)
Financing activities
Repayments of short-term borrowings, net	(294)	(147)
Borrowings under utility money pool arrangement	355	1,042
Repayments under utility money pool arrangement	(167)	(877)
Proceeds from issuance of long-term debt	834	686
Repayments of long-term debt	(250)	(300)
Capital contributions from parent	118	399
Dividends paid to parent	(507)	(365)
Net cash provided by financing activities	89	438
Net change in cash, cash equivalents and restricted cash	(1)	(15)
Cash, cash equivalents and restricted cash at beginning of period	10	25
Cash, cash equivalents and restricted cash at end of period	9	10
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	(197)	(195)
Cash paid for income taxes, net	(119)	(70)
Supplemental disclosure of non-cash investing and financing transactions:
Accrued property, plant and equipment additions	168	144
Inventory transfers to property, plant and equipment	17	15
Operating lease right-of-use assets	17	16
Allowance for equity funds used during construction	$ 25	$ 22

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CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Current assets
Cash, cash equivalents and restricted cash at beginning of period	$ 9	$ 10
Accrued unbilled revenues	262	519
Inventories	254	319
Regulatory assets	370	411
Derivative instruments	13	65
Prepayments and other	75	103
Total current assets	1,406	2,000
Property, plant and equipment, net	20,653	19,652
Other assets
Regulatory assets	1,252	1,277
Derivative instruments	13	22
Operating lease right-of-use assets	388	437
Other	305	231
Total other assets	1,958	1,967
Total assets	24,017	23,619
Current liabilities
Current portion of long-term debt	0	250
Borrowings under utility money pool arrangement	188	0
Short-term debt	0	294
Regulatory liabilities	66	59
Taxes accrued	195	242
Accrued interest	69	59
Dividends payable to parent	146	120
Derivative instruments	9	30
Operating lease liabilities	97	80
Other	180	115
Total current liabilities	1,568	2,088
Deferred credits and other liabilities
Deferred income taxes	1,902	1,983
Regulatory liabilities	2,585	2,489
Asset retirement obligations	492	476
Derivative instruments	2	9
Customer advances	129	144
Pension and employee benefit obligations	14	13
Operating lease liabilities	315	379
Other	208	198
Total deferred credits and other liabilities	5,647	5,691
Commitments and contingencies
Capitalization
Long-term debt	$ 7,449	$ 6,610
Common Stock, Shares Authorized	100	100
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Common Stock, Shares, Outstanding	100	100
Common stock — 100 shares authorized of $0.01 par value; 100 shares outstanding at Sept. 30, 2023 and Dec. 31, 2022, respectively	$ 0	$ 0
Additional paid in capital	7,111	6,992
Retained earnings	2,263	2,260
Accumulated other comprehensive loss	(21)	(22)
Total common stockholder's equity	9,353	9,230
Total liabilities and equity	24,017	23,619
Related Party
Current assets
Accounts receivable, net	423	562
Current liabilities
Accounts payable	544	764
Affiliated Entity
Current assets
Accounts receivable, net	0	11
Current liabilities
Accounts payable	$ 74	$ 75

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CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY - USD ($) $ in Millions	Total	Common stock	Additional Paid In Capital	Retained Earnings	Accumulated Other Comprehensive Income (Loss)
Balance (in shares) at Dec. 31, 2021		100
Beginning Balance at Dec. 31, 2021	$ 8,444	$ 0	$ 6,426	$ 2,040	$ (22)
Increase (Decrease) in Stockholder's Equity
Net income	555
Total other comprehensive income	1				1
Dividends declared to parent	(388)			(388)
Contribution of capital by parent	387		387
Balance (in shares) at Sep. 30, 2022		100
Ending Balance at Sep. 30, 2022	8,999	$ 0	6,813	2,207	(21)
Balance (in shares) at Jun. 30, 2022		100
Beginning Balance at Jun. 30, 2022	8,688	$ 0	6,623	2,087	(22)
Increase (Decrease) in Stockholder's Equity
Net income	247			247
Total other comprehensive income	1				1
Dividends declared to parent	(127)			(127)
Contribution of capital by parent	190		190
Balance (in shares) at Sep. 30, 2022		100
Ending Balance at Sep. 30, 2022	$ 8,999	$ 0	6,813	2,207	(21)
Balance (in shares) at Dec. 31, 2022	100	100
Beginning Balance at Dec. 31, 2022	$ 9,230	$ 0	6,992	2,260	(22)
Increase (Decrease) in Stockholder's Equity
Net income	536
Total other comprehensive income	1				1
Dividends declared to parent	(533)			(533)
Contribution of capital by parent	$ 119		119
Balance (in shares) at Sep. 30, 2023	100	100
Ending Balance at Sep. 30, 2023	$ 9,353	$ 0	7,111	2,263	(21)
Balance (in shares) at Jun. 30, 2023		100
Beginning Balance at Jun. 30, 2023	9,260	$ 0	7,086	2,195	(21)
Increase (Decrease) in Stockholder's Equity
Net income	229			229
Total other comprehensive income	0
Dividends declared to parent	(161)			(161)
Contribution of capital by parent	$ 25		25
Balance (in shares) at Sep. 30, 2023	100	100
Ending Balance at Sep. 30, 2023	$ 9,353	$ 0	$ 7,111	$ 2,263	$ (21)

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Management's Opinion

9 Months Ended

Sep. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Management's Opinion

In the opinion of management, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly, in accordance with GAAP, the financial position of PSCo and its subsidiaries as of Sept. 30, 2023 and Dec. 31, 2022; the results of PSCo’s operations, including the components of net income, comprehensive income and changes in stockholder’s equity for the three and nine months ended Sept. 30, 2023 and 2022; and PSCo’s cash flows for the nine months ended Sept. 30, 2023 and 2022.

All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after Sept. 30, 2023, 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, 2022 balance sheet information has been derived from the audited 2022 consolidated financial statements included in the PSCo Annual Report on Form 10-K for the year ended Dec. 31, 2022.

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 PSCo Annual Report on Form 10-K for the year ended Dec. 31, 2022, filed with the SEC on Feb. 23, 2023. Due to the seasonality of PSCo’s electric and natural gas sales, interim results are not necessarily an appropriate base from which to project annual results.

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Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2023
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	The significant accounting policies set forth in Note 1 to the consolidated financial statements in the PSCo Annual Report on Form 10-K for the year ended Dec. 31, 2022 appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

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Accounting Pronouncements	9 Months Ended
	Sep. 30, 2023
Accounting Standards Update and Change in Accounting Principle [Abstract]
Accounting Pronouncements	As of Sept. 30, 2023, there was no material impact from the recent adoption of new accounting pronouncements, nor expected material impact from recently issued accounting pronouncements yet to be adopted, on PSCo’s consolidated financial statements.

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Selected Balance Sheet Data

9 Months Ended

Sep. 30, 2023

Balance Sheet Related Disclosures [Abstract]

Selected Balance Sheet Data

(Millions of Dollars)	Sept. 30, 2023		Dec. 31, 2022
Accounts receivable, net
Accounts receivable	$	480	$	616
Less allowance for bad debts	(57)		(54)
Accounts receivable, net	$	423	$	562

(Millions of Dollars)	Sept. 30, 2023		Dec. 31, 2022
Inventories
Materials and supplies	$	86	$	80
Fuel	78		68
Natural gas	90		171
Total inventories	$	254	$	319

(Millions of Dollars)	Sept. 30, 2023		Dec. 31, 2022
Property, plant and equipment, net
Electric plant	$	16,343	$	15,771
Natural gas plant	6,293		5,949
Common and other property	1,500		1,415
Plant to be retired (a)	1,242		1,305
Construction work in progress	1,288		877
Total property, plant and equipment	26,666		25,317
Less accumulated depreciation	(6,013)		(5,665)
Property, plant and equipment, net	$	20,653	$	19,652

(a)Amounts include Comanche Units 2 and 3, Craig Units 1 and 2, Hayden Units 1 and 2 and coal generation assets at Pawnee pending facility gas conversion. Amounts are presented net of accumulated depreciation.

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Borrowings and Other Financing Instruments

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Borrowings and Other Financing Instruments

Short-Term Borrowings

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

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

Money pool borrowings:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2023			Year Ended Dec. 31, 2022
Borrowing limit	$	250		$	250
Amount outstanding at period end	188			—
Average amount outstanding	27			29
Maximum amount outstanding	188			250
Weighted average interest rate, computed on a daily basis	5.26		%	1.66		%
Weighted average interest rate at period end	5.30			N/A

Commercial Paper — Commercial paper outstanding:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2023			Year Ended Dec. 31, 2022
Borrowing limit	$	700		$	700
Amount outstanding at period end	—			294
Average amount outstanding	5			71
Maximum amount outstanding	72			328
Weighted average interest rate, computed on a daily basis	5.45		%	2.56		%
Weighted average interest rate at period end	N/A			4.73

Letters of Credit — PSCo uses letters of credit, generally with terms of one year, to provide financial guarantees for certain obligations. At Sept. 30, 2023 and Dec. 31, 2022, there were $29 million and $27 million, respectively, of letters of credit outstanding under the credit facility. Amounts approximate their fair value and are subject to fees.

Revolving Credit Facility — In order to issue its commercial paper, PSCo must have a revolving credit facility equal to or greater than the amount of its commercial paper borrowing limit and cannot issue commercial paper exceeding available capacity under this credit facility.

The credit facility provides short-term financing in the form of notes payable to banks, letters of credit and back-up support for commercial paper borrowings.

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

At Sept. 30, 2023, PSCo had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)		Drawn (b)		Available
$	700	$	29	$	671

(a)    Expires in September 2027.

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

All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity under the credit facility. PSCo had no direct advances on the credit facility outstanding at Sept. 30, 2023 and Dec. 31, 2022.

Long-Term Borrowings

During the nine months ended Sept. 30, 2023, PSCo issued $850 million of 5.25% first mortgage bonds due April 1, 2053.

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Revenues

9 Months Ended

Sep. 30, 2023

Revenue from Contract with Customer [Abstract]

Revenues

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

	Three Months Ended Sept. 30, 2023
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	398	$	88	$	5	$	491
C&I	538		44		7		589
Other	13		—		—		13
Total retail	949		132		12		1,093
Wholesale	53		—		—		53
Transmission	25		—		—		25
Other	16		27		—		43
Total revenue from contracts with customers	1,043		159		12		1,214
Alternative revenue and other	70		6		—		76
Total revenues	$	1,113	$	165	$	12	$	1,290

	Three Months Ended Sept. 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	431	$	136	$	4	$	571
C&I	556		64		7		627
Other	13		—		—		13
Total retail	1,000		200		11		1,211
Wholesale	63		—		—		63
Transmission	25		—		—		25
Other	15		30		—		45
Total revenue from contracts with customers	1,103		230		11		1,344
Alternative revenue and other	34		5		—		39
Total revenues	$	1,137	$	235	$	11	$	1,383

	Nine Months Ended Sept. 30, 2023
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	1,003	$	790	$	14	$	1,807
C&I	1,403		335		27		1,765
Other	40		—		—		40
Total retail	2,446		1,125		41		3,612
Wholesale	170		—		—		170
Transmission	68		—		—		68
Other	44		99		—		143
Total revenue from contracts with customers	2,728		1,224		41		3,993
Alternative revenue and other	149		23		—		172
Total revenues	$	2,877	$	1,247	$	41	$	4,165
	Nine Months Ended Sept. 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	1,025	$	686	$	11	$	1,722
C&I	1,383		279		16		1,678
Other	38		—		—		38
Total retail	2,446		965		27		3,438
Wholesale	200		—		—		200
Transmission	65		—		—		65
Other	39		106		—		145
Total revenue from contracts with customers	2,750		1,071		27		3,848
Alternative revenue and other	99		16		12		127
Total revenues	$	2,849	$	1,087	$	39	$	3,975

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Income Taxes

9 Months Ended

Sep. 30, 2023

Income Tax Disclosure [Abstract]

Income Taxes

Reconciliation between the statutory rate and ETR:

	Nine Months Ended Sept. 30
	2023		2022
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	3.5		3.6
(Decreases) increases:
Wind PTCs (a)	(14.9)		(14.2)
Plant regulatory differences (b)	(5.4)		(4.4)
Other tax credits, net operating loss & tax credit allowances	(1.0)		(1.1)
Other (net)	0.6		0.4
Effective income tax rate	3.8	%	5.3	%

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

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

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Fair Value of Financial Assets and Liabilities

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Fair Value of Financial Assets and Liabilities

Fair Value Measurements

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

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

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

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

Specific valuation methods include:

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

Commodity derivatives — Methods used to measure the fair value of commodity derivative forwards and options utilize forward prices and volatilities, as well as pricing adjustments for specific delivery locations, and are generally assigned a Level 2 classification. When contracts relate to inactive delivery locations or extend to periods beyond those readily observable on active exchanges, the significance of the use of less observable inputs on a valuation is evaluated and may result in Level 3 classification.

Derivative Activities and Fair Value Measurements

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

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

As of Sept. 30, 2023, accumulated other comprehensive loss related to interest rate derivatives included $1 million of net losses expected to be reclassified into earnings during the next 12 months as the hedged transactions impact earnings. As of Sept. 30, 2023, PSCo had no unsettled interest rate derivatives.

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

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

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

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

As of Sept. 30, 2023, PSCo had no commodity contracts designated as cash flow hedges.

Gross notional amounts of commodity forwards and options:

(Amounts in Millions) (a)(b)	Sept. 30, 2023	Dec. 31, 2022
Megawatt hours of electricity	4	8
Million British thermal units of natural gas	28	43

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

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

As of Sept. 30, 2023, four of PSCo’s ten most significant counterparties for these activities, comprising $32 million, or 45%, of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings.

Six of the ten most significant counterparties, comprising $25 million, or 35%, of this credit exposure, were not rated by these external ratings agencies, but based on PSCo’s internal analysis, had credit quality consistent with investment grade.

None of these significant counterparties, had credit quality less than investment grade, based on internal analysis. Seven of these significant counterparties are independent system operators, municipal or cooperative electric entities, Regional Transmission Organizations or other utilities.

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

As of Sept. 30, 2023 and Dec. 31, 2022, there were no derivative liabilities position with such underlying contract provisions.

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

As of Sept. 30, 2023 and Dec. 31, 2022, there were $1 million and no 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. These provisions allow counterparties to seek performance assurance, including cash collateral, in the event that PSCo’s ability to fulfill its contractual obligations is reasonably expected to be impaired. PSCo had no collateral posted related to adequate assurance clauses in derivative contracts as of Sept. 30, 2023 and Dec. 31, 2022.

Recurring Derivative Fair Value Measurements

Changes in the fair value of natural gas commodity derivatives recognized as regulatory assets and liabilities included immaterial net gains and losses for the three and nine months ended Sept. 30, 2023 and 2022. The classification as a regulatory asset or liability is based on commission approved regulatory recovery mechanisms.

	Pre-Tax Losses Reclassified into Income During the Period from:						Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Accumulated Other Comprehensive Loss			Regulatory Assets and Liabilities
Three Months Ended Sept. 30, 2023
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	2	(a)
Total	$	—		$	—		$	2
Nine Months Ended Sept. 30, 2023
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	(3)	(a)
Natural gas commodity	—			10		(c)	(12)		(c)(d)
Total	$	—		$	10		$	(15)
Three Months Ended Sept. 30, 2022
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	2	(a)
Total	$	—		$	—		$	2
Nine Months Ended Sept. 30, 2022
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	3	(a)
Natural gas commodity	—			2		(c)	(11)		(c)(d)
Total	$	—		$	2		$	(8)

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

(b)Recorded to interest charges.

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

(d)Relates primarily to option premium amortization.

PSCo had no derivative instruments designated as fair value hedges during

the nine months ended Sept. 30, 2023 and 2022.

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

	Sept. 30, 2023												Dec. 31, 2022
	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	$	3	$	42	$	3	$	48	$	(37)	$	11	$	16	$	220	$	1	$	237	$	(184)	$	53
Natural gas commodity	—		2		—		2		—		2		—		12		—		12		—		12
Total current derivative assets	$	3	$	44	$	3	$	50	$	(37)	$	13	$	16	$	232	$	1	$	249	$	(184)	$	65
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	8	$	2	$	8	$	18	$	(5)	$	13	$	12	$	32	$	9	$	53	$	(31)	$	22
Total noncurrent derivative assets	$	8	$	2	$	8	$	18	$	(5)	$	13	$	12	$	32	$	9	$	53	$	(31)	$	22

	Sept. 30, 2023												Dec. 31, 2022
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative liabilities
Other derivative instruments:
Commodity trading	$	1	$	51	$	—	$	52	$	(43)	$	9	$	5	$	237	$	1	$	243	$	(223)	$	20
Natural gas commodity	—		—		—		—		—		—		—		10		—		10		—		10
Total current derivative liabilities	$	1	$	51	$	—	$	52	$	(43)	$	9	$	5	$	247	$	1	$	253	$	(223)	$	30
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	4	$	4	$	—	$	8	$	(6)	$	2	$	7	$	40	$	—	$	47	$	(38)	$	9
Total noncurrent derivative liabilities	$	4	$	4	$	—	$	8	$	(6)	$	2	$	7	$	40	$	—	$	47	$	(38)	$	9

(a)PSCo nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At Sept. 30, 2023 and Dec. 31, 2022, derivative assets and liabilities include no obligations to return cash collateral. At Sept. 30, 2023 and Dec. 31, 2022, derivative assets and liabilities include rights to reclaim cash collateral of $7 million and $46 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.

Changes in Level 3 commodity derivatives:

	Three Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Balance at July 1	$	9	$	(30)
Settlements (a)	—		5
Net transactions recorded during the period:
Gains recognized in earnings (a)	2		1
Balance at Sept. 30	$	11	$	(24)
	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Balance at Jan. 1	$	9	$	(63)
Settlements (a)	—		9
Net transactions recorded during the period:
Gains recognized in earnings (a)	2		30
Balance at Sept. 30	$	11	$	(24)

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

Fair Value of Long-Term Debt

As of Sept. 30, 2023, other financial instruments for which the carrying amount did not equal fair value:

	Sept. 30, 2023				Dec. 31, 2022
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	7,449	$	5,932	$	6,860	$	5,881

Fair value of PSCo’s long-term debt is estimated based on recent trades and observable spreads from benchmark interest rates for similar securities. Fair value estimates are based on information available to management as of Sept. 30, 2023 and Dec. 31, 2022, and given the observability of the inputs, fair values presented for long-term debt were assigned as Level 2.

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Benefit Plans and Other Postretirement Benefits

9 Months Ended

Sep. 30, 2023

Retirement Benefits [Abstract]

Benefit Plans and Other Postretirement Benefits

	Three Months Ended Sept. 30
	2023		2022		2023		2022
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	5	$	7	$	—	$	1
Interest cost (a)	14		10		4		2
Expected return on plan assets (a)	(19)		(19)		(3)		(4)
Amortization of prior service credit (a)	—		—		—		(1)
Amortization of net loss (a)	1		6		—		—
Settlement charge (b)	—		2		—		—
Net periodic benefit (credit) cost	1		6		1		(2)
Effects of regulation	3		(2)		—		1
Net benefit cost (credit) recognized for financial reporting	$	4	$	4	$	1	$	(1)
	Nine Months Ended Sept. 30
	2023		2022		2023		2022
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	14	$	22	$	—	$	1
Interest cost (a)	43		31		12		8
Expected return on plan assets (a)	(57)		(58)		(11)		(12)
Amortization of prior service credit (a)	—		—		—		(2)
Amortization of net loss (a)	2		17		1		1
Settlement charge (b)	—		2		—		—
Net periodic benefit (credit) cost	2		14		2		(4)
Effects of regulation	9		3		—		2
Net benefit cost (credit) recognized for financial reporting	$	11	$	17	$	2	$	(2)

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

(b)A settlement charge is required when the amount of all lump-sum distributions during the year is greater than the sum of the service and interest cost components of the annual net periodic pension cost. In the third quarter of 2022 as a result of lump-sum distributions during the 2022 plan year, PSCo recorded a pension settlement charge of $2 million, the majority of which was not recognized due to the effects of regulation.

In January 2023, contributions totaling $50 million were made across Xcel Energy’s pension plans, of which none was attributable to PSCo. Xcel Energy does not expect additional pension contributions during 2023.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Legal

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

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

Comanche Unit 3 Litigation — In 2021, CORE filed a lawsuit in Denver County District Court, alleging PSCo breached ownership agreement terms by failing to operate Comanche Unit 3 in accordance with prudent utility practices. In April 2022, CORE filed a supplement to include damages related to a 2022 outage. Also in 2022, CORE sent notice of withdrawal from the ownership agreement based on the same alleged breaches.

In February 2023, the court granted PSCo’s motion precluding CORE from seeking damages related to its withdrawal as part of the lawsuit. In September 2023, the court denied PSCo’s motion for summary judgment on other categories of damages and allowed CORE to seek approximately $253 million at trial (before interest), including an alleged $187 million reduction in the value of CORE’s ownership interest in the Comanche 3 facility and $60 million of alleged lost power costs.

On Oct. 25, 2023, the jury awarded CORE lost power damages of $26 million. PSCo recognized $34 million for the verdict in the third quarter of 2023, including estimated interest and other costs. PSCo intends to file an appeal of this decision.

Marshall Wildfire

In December 2021, a wildfire ignited in Boulder County, Colorado (the “Marshall Fire”), which burned over 6,000 acres and destroyed or damaged over 1,000 structures. On June 8, 2023, the Boulder County Sheriff’s Office released its Marshall Fire Investigative Summary and Review and its supporting documents (the “Sheriff’s Report”). According to an October 2022 statement from the Colorado Insurance Commissioner, the Marshall Fire is estimated to have caused more than $2 billion in property losses.

According to the Sheriff’s Report, on Dec. 30, 2021, a fire ignited on a residential property in Boulder, Colorado, located in PSCo’s service territory, for reasons unrelated to PSCo’s power lines. According to the Sheriff’s Report, approximately one hour and 20 minutes after the first ignition, a second fire ignited just south of the Marshall Mesa Trailhead in unincorporated Boulder County, Colorado, also located in PSCo’s service territory. According to the Sheriff’s Report, the second ignition started approximately 80 to 110 feet away from PSCo’s power lines in the area.

The Sheriff’s Report states that the most probable cause of the second ignition was hot particles discharged from PSCo’s power lines after one of the power lines detached from its insulator in strong winds, and further states that it cannot be ruled out that the second ignition was caused by an underground coal fire. According to the Sheriff’s Report, no design, installation or maintenance defects or deficiencies were identified on PSCo’s electrical circuit in the area of the second ignition. PSCo disputes that its power lines caused the second ignition.

As of Oct. 24, 2023, PSCo is aware of 14 complaints, certain of which have also named Xcel Energy Inc. as a defendant, on behalf of at least 675 plaintiffs relating to the Marshall Fire and expects that it may receive further complaints. The complaints generally allege that PSCo’s equipment ignited the Marshall Fire and assert various causes of action under Colorado law, including negligence, premises liability, trespass, nuisance, and inverse condemnation. In September 2023, the Boulder County District Court Judge consolidated eight lawsuits that were pending at that time into a single action for pretrial purposes and has subsequently consolidated additional lawsuits that have been filed.

Colorado courts do not apply strict liability in determining an electric utility company’s liability for fire-related damages. For inverse condemnation claims, Colorado courts assess whether a defendant acted with intent to take a plaintiff’s property or intentionally took an action which has the natural consequence of taking the property. For negligence claims, Colorado courts look to whether electric power companies have operated their system with a heightened duty of care consistent with the practical conduct of its business, and liability does not extend to occurrences that cannot be reasonably anticipated.

Under Colorado law, in a civil action other than a medical malpractice action, the total award for noneconomic loss is capped at $0.6 million per defendant for claims that accrued at the time of the Marshall Fire unless the court finds justification to exceed that amount by clear and convincing evidence, in which case the maximum doubles. Colorado law does not impose joint and several liability in tort actions. Instead, under Colorado law, a defendant is liable for the degree or percentage of the negligence or fault attributable to that defendant, except where the defendant conspired with another defendant. A jury’s verdict in a Colorado civil case must be unanimous.

Colorado law caps punitive or exemplary damages to an amount equal to the amount of the actual damages awarded to the injured party, except the court may increase any award of punitive damages to a sum up to three times the amount of actual damages if the conduct that is the subject of the claim has continued during the pendency of the case or the defendant has acted in a willful and wanton manner during the action which further aggravated plaintiff’s damages.

In the event Xcel Energy Inc. or PSCo was found liable related to this litigation and were required to pay damages, such amounts could exceed our insurance coverage of approximately $500 million and have a material adverse effect on our financial condition, results of operations or cash flows. However, due to uncertainty as to the cause of the fire and the extent and magnitude of potential damages, Xcel Energy Inc. and PSCo are unable to estimate the amount or range of possible losses in connection with the Marshall Fire.

Rate Matters

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

Environmental

MGP, Landfill and Disposal Sites

PSCo is investigating, remediating or performing post-closure actions at two MGP, landfill or other disposal sites across its service territory, excluding sites that are being addressed under coal ash regulations.

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

Environmental Requirements — Water and Waste

Coal Ash Regulation — PSCo’s operations are subject to federal and state regulations that impose requirements for handling, storage, treatment and disposal of solid waste. Under the CCR Rule, utilities are required to complete groundwater sampling around their applicable landfills and surface impoundments as well as perform corrective actions where offsite groundwater has been impacted.

As of Sept. 30, 2023, PSCo has five regulated ash units in operation.

PSCo has executed an agreement with a third party that will excavate and process ash for beneficial use (at two sites) at a cost of approximately $45 million. An estimated liability has been recorded and amounts are expected to be fully recoverable through regulatory mechanisms.

Investigation and feasibility studies for additional corrective action related to offsite groundwater are ongoing (at three sites). While the results are uncertain, additional costs are estimated to be at least $40 million. A liability has been recorded and is expected to be fully recoverable through regulatory mechanisms.

Leases

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

Components of lease expense:

	Three Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Operating leases
PPA capacity payments	$	23	$	22
Other operating leases (a)	5		3
Total operating lease expense (b)	$	28	$	25
Finance leases
Amortization of ROU assets	$	1	$	1
Interest expense on lease liability	4		4
Total finance lease expense	$	5	$	5

(a)Includes immaterial short-term lease expense for both 2023 and 2022.

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

	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Operating leases
PPA capacity payments	$	68	$	70
Other operating leases (a)	15		13
Total operating lease expense (b)	$	83	$	83
Finance leases
Amortization of ROU assets	$	2	$	3
Interest expense on lease liability	12		12
Total finance lease expense	$	14	$	15

(a)Includes immaterial short-term lease expense for both 2023 and 2022.

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

Commitments under operating and finance leases as of Sept. 30, 2023:

(Millions of Dollars)	PPA Operating Leases		Other Operating Lease		Total Operating Leases		Finance Leases
Total minimum obligation	$	394	$	63	$	457	$	423
Interest component of obligation	(38)		(7)		(45)		(308)
Present value of minimum obligation	$	356	$	56	412		115
Less current portion					(97)		(3)
Noncurrent operating and finance lease liabilities					$	315	$	112

Variable Interest Entities 

Under certain PPAs, PSCo purchases power from IPPs for which PSCo is required to reimburse fuel costs, or to participate in tolling arrangements under which PSCo procures the natural gas required to produce the energy that they purchase. These specific PPAs create a variable interest in the IPP.

PSCo had approximately 1,509 MW and 1,442 MW of capacity under long-term PPAs at Sept. 30, 2023 and Dec. 31, 2022 with entities that have been determined to be variable interest entities. PSCo concluded that these entities are not required to be consolidated in its financial statements because it does not have the power to direct the activities that most significantly impact the entities’ economic performance. The PPAs have expiration dates through 2032.

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Other Comprehensive Income

9 Months Ended

Sep. 30, 2023

Stockholders' Equity Note [Abstract]

Other Comprehensive Income

Changes in accumulated other comprehensive loss, net of tax:

	Three Months Ended Sept. 30, 2023						Three Months Ended Sept. 30, 2022
(Millions of Dollars)	Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total		Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total
Accumulated other comprehensive loss at July 1	$	(20)	$	(1)	$	(21)	$	(21)	$	(1)	$	(22)
Losses reclassified from net accumulated other comprehensive loss:
Amortization of net actuarial loss (a)	—		(1)		(1)		—		—		—
Interest rate derivatives (b)	1		—		1		1		—		1
Net current period other comprehensive income	1		(1)		—		1		—		1
Accumulated other comprehensive loss at Sept. 30	$	(19)	$	(2)	$	(21)	$	(20)	$	(1)	$	(21)

	Nine Months Ended Sept. 30, 2023						Nine Months Ended Sept. 30, 2022
(Millions of Dollars)	Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total		Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total
Accumulated other comprehensive loss at Jan. 1	$	(20)	$	(2)	$	(22)	$	(21)	$	(1)	$	(22)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (b)	1		—		1		1		—		1
Net current period other comprehensive income	1		—		1		1		—		1
Accumulated other comprehensive loss at Sept. 30	$	(19)	$	(2)	$	(21)	$	(20)	$	(1)	$	(21)

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Segment Information

9 Months Ended

Sep. 30, 2023

Segment Reporting [Abstract]

Segment Information

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

PSCo has the following reportable segments:

•Regulated Electric — The regulated electric utility segment generates electricity which is transmitted and distributed in Colorado. 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 PSCo’s wholesale commodity and trading operations.

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

PSCo also presents All Other, which includes operating segments with revenues below the necessary quantitative thresholds. Those operating segments primarily include steam revenue, appliance repair services and non-utility real estate activities.

Asset and capital expenditure information is not provided for PSCo’s reportable segments because, as an integrated electric and natural gas utility, PSCo operates significant assets that are not dedicated to a specific business segment and 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.

PSCo’s segment information:

	Three Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Regulated Electric
Total revenues	$	1,113	$	1,137
Net income	247		243
Regulated Natural Gas
Total revenues	$	165	$	235
Net (loss) income	(16)		4
All Other
Total revenues (a)	$	12	$	11
Net loss	(2)		—
Consolidated Total
Total operating revenues (a)	$	1,290	$	1,383
Net income	229		247

(a)    Total revenues include $1 million and $2 million of other affiliate revenue for the three months ended Sept. 30, 2023 and 2022.

	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Regulated Electric
Total revenues	$	2,877	$	2,849
Net income	449		455
Regulated Natural Gas
Total revenues	$	1,247	$	1,087
Net income	81		99
All Other
Total revenues (a)	$	41	$	39
Net income	6		1
Consolidated Total
Total operating revenues (a)	$	4,165	$	3,975
Net income	536		555

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Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Pay vs Performance Disclosure
Net income	$ 229	$ 247	$ 536	$ 555

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Insider Trading Arrangements	9 Months Ended
	Sep. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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Selected Balance Sheet Data (Tables)

9 Months Ended

Sep. 30, 2023

Balance Sheet Related Disclosures [Abstract]

Accounts Receivable, Net

(Millions of Dollars)	Sept. 30, 2023		Dec. 31, 2022
Accounts receivable, net
Accounts receivable	$	480	$	616
Less allowance for bad debts	(57)		(54)
Accounts receivable, net	$	423	$	562

Inventories

(Millions of Dollars)	Sept. 30, 2023		Dec. 31, 2022
Inventories
Materials and supplies	$	86	$	80
Fuel	78		68
Natural gas	90		171
Total inventories	$	254	$	319

Property, Plant and Equipment, Net

(Millions of Dollars)	Sept. 30, 2023		Dec. 31, 2022
Property, plant and equipment, net
Electric plant	$	16,343	$	15,771
Natural gas plant	6,293		5,949
Common and other property	1,500		1,415
Plant to be retired (a)	1,242		1,305
Construction work in progress	1,288		877
Total property, plant and equipment	26,666		25,317
Less accumulated depreciation	(6,013)		(5,665)
Property, plant and equipment, net	$	20,653	$	19,652

(a)Amounts include Comanche Units 2 and 3, Craig Units 1 and 2, Hayden Units 1 and 2 and coal generation assets at Pawnee pending facility gas conversion. Amounts are presented net of accumulated depreciation.

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Borrowings and Other Financing Instruments (Tables)

9 Months Ended

Sep. 30, 2023

Borrowings and Other Financing Instruments [Abstract]

Short-Term Borrowings

Commercial paper outstanding:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2023			Year Ended Dec. 31, 2022
Borrowing limit	$	700		$	700
Amount outstanding at period end	—			294
Average amount outstanding	5			71
Maximum amount outstanding	72			328
Weighted average interest rate, computed on a daily basis	5.45		%	2.56		%
Weighted average interest rate at period end	N/A			4.73

Credit Facilities

At Sept. 30, 2023, PSCo had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)		Drawn (b)		Available
$	700	$	29	$	671

(a)    Expires in September 2027.

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

Money Pool

Borrowings and Other Financing Instruments [Abstract]

Short-Term Borrowings

Money pool borrowings:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2023			Year Ended Dec. 31, 2022
Borrowing limit	$	250		$	250
Amount outstanding at period end	188			—
Average amount outstanding	27			29
Maximum amount outstanding	188			250
Weighted average interest rate, computed on a daily basis	5.26		%	1.66		%
Weighted average interest rate at period end	5.30			N/A

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Revenues (Tables)

9 Months Ended

Sep. 30, 2023

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

PSCo’s operating revenues consisted of the following:

	Three Months Ended Sept. 30, 2023
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	398	$	88	$	5	$	491
C&I	538		44		7		589
Other	13		—		—		13
Total retail	949		132		12		1,093
Wholesale	53		—		—		53
Transmission	25		—		—		25
Other	16		27		—		43
Total revenue from contracts with customers	1,043		159		12		1,214
Alternative revenue and other	70		6		—		76
Total revenues	$	1,113	$	165	$	12	$	1,290

	Three Months Ended Sept. 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	431	$	136	$	4	$	571
C&I	556		64		7		627
Other	13		—		—		13
Total retail	1,000		200		11		1,211
Wholesale	63		—		—		63
Transmission	25		—		—		25
Other	15		30		—		45
Total revenue from contracts with customers	1,103		230		11		1,344
Alternative revenue and other	34		5		—		39
Total revenues	$	1,137	$	235	$	11	$	1,383

	Nine Months Ended Sept. 30, 2023
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	1,003	$	790	$	14	$	1,807
C&I	1,403		335		27		1,765
Other	40		—		—		40
Total retail	2,446		1,125		41		3,612
Wholesale	170		—		—		170
Transmission	68		—		—		68
Other	44		99		—		143
Total revenue from contracts with customers	2,728		1,224		41		3,993
Alternative revenue and other	149		23		—		172
Total revenues	$	2,877	$	1,247	$	41	$	4,165
	Nine Months Ended Sept. 30, 2022
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	1,025	$	686	$	11	$	1,722
C&I	1,383		279		16		1,678
Other	38		—		—		38
Total retail	2,446		965		27		3,438
Wholesale	200		—		—		200
Transmission	65		—		—		65
Other	39		106		—		145
Total revenue from contracts with customers	2,750		1,071		27		3,848
Alternative revenue and other	99		16		12		127
Total revenues	$	2,849	$	1,087	$	39	$	3,975

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Income Taxes (Tables)

9 Months Ended

Sep. 30, 2023

Income Tax Disclosure [Abstract]

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

Reconciliation between the statutory rate and ETR:

	Nine Months Ended Sept. 30
	2023		2022
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	3.5		3.6
(Decreases) increases:
Wind PTCs (a)	(14.9)		(14.2)
Plant regulatory differences (b)	(5.4)		(4.4)
Other tax credits, net operating loss & tax credit allowances	(1.0)		(1.1)
Other (net)	0.6		0.4
Effective income tax rate	3.8	%	5.3	%

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

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

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Fair Value of Financial Assets and Liabilities (Tables)

9 Months Ended

Sep. 30, 2023

Fair Value Disclosures [Abstract]

Gross Notional Amounts of Commodity Forwards and Options

Gross notional amounts of commodity forwards and options:

(Amounts in Millions) (a)(b)	Sept. 30, 2023	Dec. 31, 2022
Megawatt hours of electricity	4	8
Million British thermal units of natural gas	28	43

(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

	Pre-Tax Losses Reclassified into Income During the Period from:						Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Accumulated Other Comprehensive Loss			Regulatory Assets and Liabilities
Three Months Ended Sept. 30, 2023
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	2	(a)
Total	$	—		$	—		$	2
Nine Months Ended Sept. 30, 2023
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	(3)	(a)
Natural gas commodity	—			10		(c)	(12)		(c)(d)
Total	$	—		$	10		$	(15)
Three Months Ended Sept. 30, 2022
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	2	(a)
Total	$	—		$	—		$	2
Nine Months Ended Sept. 30, 2022
Derivatives designated as cash flow hedges
Interest rate	$	1	(b)	$	—		$	—
Total	$	1		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	3	(a)
Natural gas commodity	—			2		(c)	(11)		(c)(d)
Total	$	—		$	2		$	(8)

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

(b)Recorded to interest charges.

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

(d)Relates primarily to option premium amortization.

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

	Sept. 30, 2023												Dec. 31, 2022
	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	$	3	$	42	$	3	$	48	$	(37)	$	11	$	16	$	220	$	1	$	237	$	(184)	$	53
Natural gas commodity	—		2		—		2		—		2		—		12		—		12		—		12
Total current derivative assets	$	3	$	44	$	3	$	50	$	(37)	$	13	$	16	$	232	$	1	$	249	$	(184)	$	65
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	8	$	2	$	8	$	18	$	(5)	$	13	$	12	$	32	$	9	$	53	$	(31)	$	22
Total noncurrent derivative assets	$	8	$	2	$	8	$	18	$	(5)	$	13	$	12	$	32	$	9	$	53	$	(31)	$	22

	Sept. 30, 2023												Dec. 31, 2022
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative liabilities
Other derivative instruments:
Commodity trading	$	1	$	51	$	—	$	52	$	(43)	$	9	$	5	$	237	$	1	$	243	$	(223)	$	20
Natural gas commodity	—		—		—		—		—		—		—		10		—		10		—		10
Total current derivative liabilities	$	1	$	51	$	—	$	52	$	(43)	$	9	$	5	$	247	$	1	$	253	$	(223)	$	30
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	4	$	4	$	—	$	8	$	(6)	$	2	$	7	$	40	$	—	$	47	$	(38)	$	9
Total noncurrent derivative liabilities	$	4	$	4	$	—	$	8	$	(6)	$	2	$	7	$	40	$	—	$	47	$	(38)	$	9

(a)PSCo nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At Sept. 30, 2023 and Dec. 31, 2022, derivative assets and liabilities include no obligations to return cash collateral. At Sept. 30, 2023 and Dec. 31, 2022, derivative assets and liabilities include rights to reclaim cash collateral of $7 million and $46 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.

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation

Changes in Level 3 commodity derivatives:

	Three Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Balance at July 1	$	9	$	(30)
Settlements (a)	—		5
Net transactions recorded during the period:
Gains recognized in earnings (a)	2		1
Balance at Sept. 30	$	11	$	(24)
	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Balance at Jan. 1	$	9	$	(63)
Settlements (a)	—		9
Net transactions recorded during the period:
Gains recognized in earnings (a)	2		30
Balance at Sept. 30	$	11	$	(24)

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

Carrying Amount and Fair Value of Long-term Debt

	Sept. 30, 2023				Dec. 31, 2022
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	7,449	$	5,932	$	6,860	$	5,881

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Benefit Plans and Other Postretirement Benefits (Tables)

9 Months Ended

Sep. 30, 2023

Retirement Benefits [Abstract]

Components of Net Periodic Benefit Cost (Credit)

	Three Months Ended Sept. 30
	2023		2022		2023		2022
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	5	$	7	$	—	$	1
Interest cost (a)	14		10		4		2
Expected return on plan assets (a)	(19)		(19)		(3)		(4)
Amortization of prior service credit (a)	—		—		—		(1)
Amortization of net loss (a)	1		6		—		—
Settlement charge (b)	—		2		—		—
Net periodic benefit (credit) cost	1		6		1		(2)
Effects of regulation	3		(2)		—		1
Net benefit cost (credit) recognized for financial reporting	$	4	$	4	$	1	$	(1)
	Nine Months Ended Sept. 30
	2023		2022		2023		2022
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	14	$	22	$	—	$	1
Interest cost (a)	43		31		12		8
Expected return on plan assets (a)	(57)		(58)		(11)		(12)
Amortization of prior service credit (a)	—		—		—		(2)
Amortization of net loss (a)	2		17		1		1
Settlement charge (b)	—		2		—		—
Net periodic benefit (credit) cost	2		14		2		(4)
Effects of regulation	9		3		—		2
Net benefit cost (credit) recognized for financial reporting	$	11	$	17	$	2	$	(2)

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

(b)A settlement charge is required when the amount of all lump-sum distributions during the year is greater than the sum of the service and interest cost components of the annual net periodic pension cost. In the third quarter of 2022 as a result of lump-sum distributions during the 2022 plan year, PSCo recorded a pension settlement charge of $2 million, the majority of which was not recognized due to the effects of regulation.

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Commitment and Contingencies (Tables)

9 Months Ended

Sep. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

Schedule of Components of Lease Expense

Components of lease expense:

	Three Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Operating leases
PPA capacity payments	$	23	$	22
Other operating leases (a)	5		3
Total operating lease expense (b)	$	28	$	25
Finance leases
Amortization of ROU assets	$	1	$	1
Interest expense on lease liability	4		4
Total finance lease expense	$	5	$	5

(a)Includes immaterial short-term lease expense for both 2023 and 2022.

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

	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Operating leases
PPA capacity payments	$	68	$	70
Other operating leases (a)	15		13
Total operating lease expense (b)	$	83	$	83
Finance leases
Amortization of ROU assets	$	2	$	3
Interest expense on lease liability	12		12
Total finance lease expense	$	14	$	15

(a)Includes immaterial short-term lease expense for both 2023 and 2022.

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

Schedule of Future Commitments under Operating Leases

Commitments under operating and finance leases as of Sept. 30, 2023:

(Millions of Dollars)	PPA Operating Leases		Other Operating Lease		Total Operating Leases		Finance Leases
Total minimum obligation	$	394	$	63	$	457	$	423
Interest component of obligation	(38)		(7)		(45)		(308)
Present value of minimum obligation	$	356	$	56	412		115
Less current portion					(97)		(3)
Noncurrent operating and finance lease liabilities					$	315	$	112

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Other Comprehensive Income (Tables)

9 Months Ended

Sep. 30, 2023

Stockholders' Equity Note [Abstract]

Changes in Accumulated Other Comprehensive Loss, Net of Tax

Changes in accumulated other comprehensive loss, net of tax:

	Three Months Ended Sept. 30, 2023						Three Months Ended Sept. 30, 2022
(Millions of Dollars)	Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total		Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total
Accumulated other comprehensive loss at July 1	$	(20)	$	(1)	$	(21)	$	(21)	$	(1)	$	(22)
Losses reclassified from net accumulated other comprehensive loss:
Amortization of net actuarial loss (a)	—		(1)		(1)		—		—		—
Interest rate derivatives (b)	1		—		1		1		—		1
Net current period other comprehensive income	1		(1)		—		1		—		1
Accumulated other comprehensive loss at Sept. 30	$	(19)	$	(2)	$	(21)	$	(20)	$	(1)	$	(21)

	Nine Months Ended Sept. 30, 2023						Nine Months Ended Sept. 30, 2022
(Millions of Dollars)	Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total		Gains and Losses on Cash Flow Hedges		Defined Benefit Pension and Postretirement Items		Total
Accumulated other comprehensive loss at Jan. 1	$	(20)	$	(2)	$	(22)	$	(21)	$	(1)	$	(22)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (b)	1		—		1		1		—		1
Net current period other comprehensive income	1		—		1		1		—		1
Accumulated other comprehensive loss at Sept. 30	$	(19)	$	(2)	$	(21)	$	(20)	$	(1)	$	(21)

(a)Included in the computation of net periodic pension and postretirement benefit costs. See Note 8 for further information.

(b)Included in interest charges.

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2023

Segment Reporting [Abstract]

Results from Operations by Reportable Segment

PSCo’s segment information:

	Three Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Regulated Electric
Total revenues	$	1,113	$	1,137
Net income	247		243
Regulated Natural Gas
Total revenues	$	165	$	235
Net (loss) income	(16)		4
All Other
Total revenues (a)	$	12	$	11
Net loss	(2)		—
Consolidated Total
Total operating revenues (a)	$	1,290	$	1,383
Net income	229		247

(a)    Total revenues include $1 million and $2 million of other affiliate revenue for the three months ended Sept. 30, 2023 and 2022.

	Nine Months Ended Sept. 30
(Millions of Dollars)	2023		2022
Regulated Electric
Total revenues	$	2,877	$	2,849
Net income	449		455
Regulated Natural Gas
Total revenues	$	1,247	$	1,087
Net income	81		99
All Other
Total revenues (a)	$	41	$	39
Net income	6		1
Consolidated Total
Total operating revenues (a)	$	4,165	$	3,975
Net income	536		555

(a)    Total revenues include $3 million and $4 million of other affiliate revenue for the nine months ended Sept. 30, 2023 and 2022.

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Selected Balance Sheet Data (Details) - Related Party - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Related Party Transaction [Line Items]
Accounts receivable	$ 480	$ 616
Accounts Receivable, Allowance for Credit Loss, Current	57	54
Accounts receivable, net	$ 423	$ 562

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Selected Balance Sheet Data Balance Sheet Related Disclosures, Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Public Utilities, Inventory [Line Items]
Total inventories	$ 254	$ 319
Materials and supplies
Public Utilities, Inventory [Line Items]
Inventories	86	80
Fuel
Public Utilities, Inventory [Line Items]
Inventories	78	68
Natural gas
Public Utilities, Inventory [Line Items]
Inventories	$ 90	$ 171

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Selected Balance Sheet Data Balance Sheet Related Disclosures, Property, Plant and Equipment (Details) - USD ($) $ in Millions		Sep. 30, 2023	Dec. 31, 2022
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		$ 26,666	$ 25,317
Less accumulated depreciation		(6,013)	(5,665)
Property, plant and equipment, net		20,653	19,652
Electric plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		16,343	15,771
Natural gas plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		6,293	5,949
Common and other property
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		1,500	1,415
Plant to be retired
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	[1]	1,242	1,305
Construction work in progress
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		$ 1,288	$ 877

[1] Amounts include Comanche Units 2 and 3, Craig Units 1 and 2, Hayden Units 1 and 2 and coal generation assets at Pawnee pending facility gas conversion. Amounts are presented net of accumulated depreciation.

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Borrowings and Other Financing Instruments - Short-Term Borrowings (Details) - USD ($)	3 Months Ended	12 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Short-term Debt [Line Items]
Short-term debt	$ 0	$ 294,000,000
Money Pool
Short-term Debt [Line Items]
Borrowing limit	250,000,000	250,000,000
Short-term debt	188,000,000	0
Average amount outstanding	27,000,000	29,000,000
Maximum amount outstanding	$ 188,000,000	$ 250,000,000
Weighted average interest rate, computed on a daily basis (percentage)	5.26%	1.66%
Short-term Debt, Weighted Average Interest Rate, at Point in Time	5.30%
Commercial Paper
Short-term Debt [Line Items]
Borrowing limit	$ 700,000,000	$ 700,000,000
Short-term debt	0	294,000,000
Average amount outstanding	5,000,000	71,000,000
Maximum amount outstanding	$ 72,000,000	$ 328,000,000
Weighted average interest rate, computed on a daily basis (percentage)	5.45%	2.56%
Short-term Debt, Weighted Average Interest Rate, at Point in Time		4.73%

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Borrowings and Other Financing Instruments - Letters of Credit (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Line of Credit Facility [Line Items]
Term of letters of credit (in years)	1 year
Short-term debt	$ 0	$ 294
Letter of Credit
Line of Credit Facility [Line Items]
Short-term debt	$ 29	$ 27
Letter of Credit | Letter of Credit
Line of Credit Facility [Line Items]
Term of letters of credit (in years)	1 year

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Borrowings and Other Financing Instruments - Credit Facility (Details)		9 Months Ended
		Sep. 30, 2023 USD ($) Plan	Dec. 31, 2022 USD ($)
Line of Credit Facility [Line Items]
Term of letters of credit (in years)		1 year
Number of extension you can request | Plan		2
Credit Facility
Line of Credit Facility [Line Items]
Credit Facility	[1]	$ 700,000,000
Drawn	[2]	29,000,000
Available		671,000,000
Direct advances on the credit facility outstanding		$ 0	$ 0

[1] Expires in September 2027.

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

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Borrowings and Other Financing Instruments - Borrowings and Other Financing Instruments, Long-Term Borrowings and Other Financing Instruments (Details) $ in Millions	9 Months Ended
	Sep. 30, 2023 USD ($)
Debt Instrument [Line Items]
Term of letters of credit (in years)	1 year
Bonds [Member] | Series Due April 1, 2053
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 850
Debt Instrument, Interest Rate, Stated Percentage	5.25%

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Revenues (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Retail
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ 1,093	$ 1,211	$ 3,612	$ 3,438
Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	491	571	1,807	1,722
Retail | Commercial and Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	589	627	1,765	1,678
Retail | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	13	13	40	38
Wholesale Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	53	63	170	200
Transmission Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	25	25	68	65
Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	43	45	143	145
Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,214	1,344	3,993	3,848
Alternative and Other [Member]
Disaggregation of Revenue [Line Items]
Alternative revenue and other	76	39	172	127
Regulated Electric | Retail
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	949	1,000	2,446	2,446
Regulated Electric | Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	398	431	1,003	1,025
Regulated Electric | Retail | Commercial and Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	538	556	1,403	1,383
Regulated Electric | Retail | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	13	13	40	38
Regulated Electric | Wholesale Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	53	63	170	200
Regulated Electric | Transmission Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	25	25	68	65
Regulated Electric | Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	16	15	44	39
Regulated Electric | Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,043	1,103	2,728	2,750
Regulated Electric | Alternative and Other [Member]
Disaggregation of Revenue [Line Items]
Alternative revenue and other	70	34	149	99
Regulated Natural Gas | Retail
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	132	200	1,125	965
Regulated Natural Gas | Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	88	136	790	686
Regulated Natural Gas | Retail | Commercial and Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	44	64	335	279
Regulated Natural Gas | Retail | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Regulated Natural Gas | Wholesale Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Regulated Natural Gas | Transmission Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Regulated Natural Gas | Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	27	30	99	106
Regulated Natural Gas | Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	159	230	1,224	1,071
Regulated Natural Gas | Alternative and Other [Member]
Disaggregation of Revenue [Line Items]
Alternative revenue and other	6	5	23	16
All Other | Retail
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	12	11	41	27
All Other | Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	5	4	14	11
All Other | Retail | Commercial and Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	7	7	27	16
All Other | Retail | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
All Other | Wholesale Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
All Other | Transmission Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
All Other | Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
All Other | Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	12	11	41	27
All Other | Alternative and Other [Member]
Disaggregation of Revenue [Line Items]
Alternative revenue and other	0	0	0	12
Total revenues
Disaggregation of Revenue [Line Items]
Total revenues	1,290	1,383	4,165	3,975
Total revenues | Regulated Electric
Disaggregation of Revenue [Line Items]
Total revenues	1,113	1,137	2,877	2,849
Total revenues | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Total revenues	165	235	1,247	1,087
Total revenues | All Other
Disaggregation of Revenue [Line Items]
Total revenues	$ 12	$ 11	$ 41	$ 39

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Income Taxes (Details)		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent		21.00%	21.00%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent		3.50%	3.60%
Effective Income Tax Rate Reconciliation, Tax Credit, Percent	[1]	(14.90%)	(14.20%)
Effective Income Tax Rate Reconciliation, Other Regulatory Items, Percent	[2]	(5.40%)	(4.40%)
Effective Income Tax Rate Reconciliation, Net Operating Loss Carryback, Percent		(1.00%)	(1.10%)
Effective Income Tax Rate Reconciliation, Other Adjustments, Percent		0.60%	0.40%
Effective Income Tax Rate Reconciliation, Percent		3.80%	5.30%

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

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

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Fair Value of Financial Assets and Liabilities - Interest Rate Derivatives (Details) $ in Millions	Sep. 30, 2023 USD ($)
Derivative [Line Items]
Amount of accumulated other comprehensive gains (losses) related to interest rate derivatives expected to be reclassified into earnings within the next twelve months	$ 1
Interest Rate Swap
Derivative [Line Items]
Derivative Liability, Notional Amount	$ 0

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Fair Value of Financial Assets and Liabilities - Commodity Derivatives (Details) MWh in Millions, MMBTU in Millions, $ in Millions		Sep. 30, 2023 USD ($) MWh MMBTU	Dec. 31, 2022 MMBTU MWh
cash flow hedge commodity [Member]
Derivative [Line Items]
Commodity contracts designated as cash flow hedges | $		$ 0
Electric Commodity (in megawatt hours)
Derivative [Line Items]
Derivative, Nonmonetary Notional amount | MWh	[1],[2]	4	8
Natural Gas Commodity (in million British thermal units)
Derivative [Line Items]
Derivative, Nonmonetary Notional amount | MMBTU	[1],[2]	28	43

[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.

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Fair Value of Financial Assets and Liabilities - Consideration of Credit Risk and Concentrations (Details) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023 USD ($) Counterparty	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) Counterparty	Sep. 30, 2022 USD ($)
Consideration of Credit Risk and Concentrations [Abstract]
Derivative instruments designated as fair value hedges		$ 0	$ 0	$ 0	$ 0
Other Derivative Instruments
Consideration of Credit Risk and Concentrations [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		0	0	0	0
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		0	0	(10)	2
Pre-tax gains (losses) recognized during the period in income		2	2	(15)	(8)
Designated as Hedging Instrument | Cash Flow Hedges
Consideration of Credit Risk and Concentrations [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		1	1	1	1
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		0	0	0	0
Pre-tax gains (losses) recognized during the period in income		0	0	0	0
Natural Gas Commodity | Other Derivative Instruments
Consideration of Credit Risk and Concentrations [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)	[1]			(10)	2
Pre-tax gains (losses) recognized during the period in income	[1],[2]			(12)	(11)
Commodity Trading | Other Derivative Instruments
Consideration of Credit Risk and Concentrations [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net		0	0	0	0
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		0	0	0	0
Pre-tax gains (losses) recognized during the period in income	[3]	2	2	(3)	3
Interest Rate | Designated as Hedging Instrument | Cash Flow Hedges
Consideration of Credit Risk and Concentrations [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	[4]	1	1	1	1
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		0	0	0	0
Pre-tax gains (losses) recognized during the period in income		$ 0	$ 0	$ 0	$ 0
Credit Concentration Risk
Consideration of Credit Risk and Concentrations [Abstract]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		10		10
Credit Concentration Risk | Municipal or Cooperative Entities or Other Utilities [Member]
Consideration of Credit Risk and Concentrations [Abstract]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		7		7
Credit Concentration Risk | External Credit Rating, Investment Grade [Member]
Consideration of Credit Risk and Concentrations [Abstract]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		4		4
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties		$ 32		$ 32
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)		45.00%		45.00%
Credit Concentration Risk | External Credit Rating, Non Investment Grade [Member]
Consideration of Credit Risk and Concentrations [Abstract]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		0		0
Credit Concentration Risk | Internal Investment Grade
Consideration of Credit Risk and Concentrations [Abstract]
Number of most significant counterparties for wholesale, trading and non-trading commodity activities with credit exposure | Counterparty		6		6
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties		$ 25		$ 25
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)		35.00%		35.00%

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

[2] Relates primarily to option premium amortization

[3] Recorded to electric revenues. Presented amounts do not reflect non-derivative transactions or margin sharing with customers.

[4] Recorded to interest charges.

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Fair Value of Financial Assets and Liabilities - Credit Related Contingent Features (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Derivative instruments in a gross liability position	$ 0	$ 0
Collateral posted related to adequate assurance clauses in derivative contracts	0	0
Derivative, Gross Liability with Cross Default Position, Aggregate Fair Value	$ 1	$ 0

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Fair Value of Financial Assets and Liabilities - Recurring Fair Value Measurements (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Derivatives, Fair Value [Line Items]
Return Cash Collateral		$ 0		$ 0		$ 0
Reclaim Cash Collateral		7		7		46
Other Derivative Instruments
Derivatives, Fair Value [Line Items]
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)		0	$ 0	(10)	$ 2
Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)	[1]			(10)	$ 2
Fair Value Measured on a Recurring Basis | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		2		2		12
Netting	[2]	0		0		0
Derivative Asset, Net		2		2		12
Derivative Liability, Gross		0		0		10
Netting	[2]	0		0		0
Derivative Liability, Net		0		0		10
Fair Value Measured on a Recurring Basis | Other Derivative Instruments | Level 1 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		0		0		0
Derivative Liability, Gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Derivative Instruments | Level 2 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		2		2		12
Derivative Liability, Gross		0		0		10
Fair Value Measured on a Recurring Basis | Other Derivative Instruments | Level 3 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		0		0		0
Derivative Liability, Gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		50		50		249
Netting	[2]	(37)		(37)		(184)
Derivative Asset, Net		13		13		65
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		3		3		16
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		44		44		232
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		3		3		1
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		48		48		237
Netting	[2]	(37)		(37)		(184)
Derivative Asset, Net		11		11		53
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		3		3		16
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		42		42		220
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		3		3		1
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		18		18		53
Netting	[2]	(5)		(5)		(31)
Derivative Asset, Net		13		13		22
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		8		8		12
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		2		2		32
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		8		8		9
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		18		18		53
Netting	[2]	(5)		(5)		(31)
Derivative Asset, Net		13		13		22
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		8		8		12
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		2		2		32
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		8		8		9
Fair Value Measured on a Recurring Basis | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		52		52		253
Netting	[2]	(43)		(43)		(223)
Derivative Liability, Net		9		9		30
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		1		1		5
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		51		51		247
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		0		0		1
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		52		52		243
Netting	[2]	(43)		(43)		(223)
Derivative Liability, Net		9		9		20
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		1		1		5
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		51		51		237
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		0		0		1
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		8		8		47
Netting	[2]	(6)		(6)		(38)
Derivative Liability, Net		2		2		9
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		4		4		7
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		4		4		40
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		0		0		0
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		8		8		47
Netting	[2]	(6)		(6)		(38)
Derivative Liability, Net		2		2		9
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		4		4		7
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		4		4		40
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		$ 0		$ 0		$ 0

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

[2] PSCo nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement. At Sept. 30, 2023 and Dec. 31, 2022, derivative assets and liabilities include no obligations to return cash collateral. At Sept. 30, 2023 and Dec. 31, 2022, derivative assets and liabilities include rights to reclaim cash collateral of $7 million and $46 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.

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Fair Value of Financial Assets and Liabilities - Changes in Level 3 Commodity Derivatives (Details) - Commodity Contract - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance		$ 9	$ (30)	$ 9	$ (63)
Settlements	[1]	0	5	0	9
(Losses) gains recognized in earnings	[1]	2	1	2	30
Ending Balance		$ 11	$ (24)	$ 11	$ (24)

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

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Fair Value of Financial Assets and Liabilities - Fair Value of Long-Term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 7,449	$ 6,860
Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value	$ 5,932	$ 5,881

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Benefit Plans and Other Postretirement Benefits (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended			9 Months Ended
		Jan. 31, 2023	Sep. 30, 2023	Sep. 30, 2022		Sep. 30, 2023	Sep. 30, 2022
Pension Plan [Member]
Components of Net Periodic Benefit Cost (Credit) [Abstract]
Service cost			$ 5	$ 7		$ 14	$ 22
Interest Cost	[1]		14	10		43	31
Expected return on Plan Assets	[1]		(19)	(19)		(57)	(58)
Amortization of prior service credit	[1]		0	0		0	0
Amortization of net loss	[1]		1	6		2	17
Net periodic benefit (credit) cost			1	6		2	14
Effects of regulation			3	(2)		9	3
Net benefit cost (credit) recognized for financial reporting			4	4		11	17
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement			0	2	[2]	0	2	[2]
Pension Plan [Member] | Xcel Energy Inc.
Components of Net Periodic Benefit Cost (Credit) [Abstract]
Total contributions to the pension plans during the period		$ 50
Other Postretirement Benefits Plan [Member]
Components of Net Periodic Benefit Cost (Credit) [Abstract]
Service cost			0	1		0	1
Interest Cost	[1]		4	2		12	8
Expected return on Plan Assets	[1]		(3)	(4)		(11)	(12)
Amortization of prior service credit	[1]		0	(1)		0	(2)
Amortization of net loss	[1]		0	0		1	1
Net periodic benefit (credit) cost			1	(2)		2	(4)
Effects of regulation			0	1		0	2
Net benefit cost (credit) recognized for financial reporting			1	(1)		2	(2)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement			$ 0	$ 0		$ 0	$ 0

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

[2] A settlement charge is required when the amount of all lump-sum distributions during the year is greater than the sum of the service and interest cost components of the annual net periodic pension cost. In the third quarter of 2022 as a result of lump-sum distributions during the 2022 plan year, PSCo recorded a pension settlement charge of $2 million, the majority of which was not recognized due to the effects of regulation

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Commitments and Contingencies - MGP, Landfill and Disposal Sites (Details)	Sep. 30, 2023
Other MGP, Landfill, or Disposal Sites
Loss Contingencies [Line Items]
Number of identified MGP sites under current investigation and/or remediation	2

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Commitments and Contingencies - Environmental Requirements - Water and Waste (Details) $ in Millions	Sep. 30, 2023 USD ($) sites
Site Contingency [Line Items]
Number of sites that will excavate and process ash for beneficial use | sites	2
Number of sites where investigation and feasibility studies for additional corrective action related to offsite groundwater are ongoing | sites	3
Federal Coal Ash Regulation
Site Contingency [Line Items]
Number of sites where regulated ash units will still be in operation at a specified date	5
Estimated cost to remediate groundwater sampling results | $	$ 40
Federal Coal Ash Regulation | Maximum [Member]
Site Contingency [Line Items]
Cost of Beneficial Use Coal Ash Project | $	$ 45

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Commitments and Contingencies - Leases (Details) - USD ($) $ in Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2023		Sep. 30, 2022		Sep. 30, 2023		Sep. 30, 2022		Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Operating Lease, Cost	$ 28	[1]	$ 25	[1]	$ 83	[2]	$ 83	[2]
Finance Lease, Right-of-Use Asset, Amortization	1		1		2		3
Finance Lease, Interest Expense	4		4		12		12
Finance Lease, Cost	5		5		14		15
Lessee, Operating Lease, Liability, Payments, Due	457				457
Total minimum obligation	423				423
Interest component of obligation	(45)				(45)
Finance Lease, Liability, Undiscounted Excess Amount	(308)				(308)
Operating Lease, Liability	412				412
Finance Lease, Liability	115				115
Less current portion	(97)				(97)				$ (80)
Less current portion	(3)				(3)
Operating lease liabilities	315				315				$ 379
Noncurrent operating and finance lease liabilities	112				112
PPAs
Lessee, Lease, Description [Line Items]
Operating Lease, Cost	23		22		68		70
Lessee, Operating Lease, Liability, Payments, Due	394				394
Interest component of obligation	(38)				(38)
Operating Lease, Liability	356				356
Other
Lessee, Lease, Description [Line Items]
Operating Lease, Cost	5	[3]	$ 3	[3]	15	[4]	$ 13	[4]
Lessee, Operating Lease, Liability, Payments, Due	63				63
Interest component of obligation	(7)				(7)
Operating Lease, Liability	$ 56				$ 56

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

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

[3] Includes immaterial short-term lease expense for both 2023 and 2022.

[4] Includes immaterial short-term lease expense for both 2023 and 2022.

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VIEs (Details) - MW	Sep. 30, 2023	Dec. 31, 2022
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member]
Other Commitments [Line Items]
Generating capacity under long term purchased power agreements (in MW)	1,509	1,442

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Commitments and Contingencies - Comanche Unit 3 Litigation (Details) $ in Millions	9 Months Ended
	Sep. 30, 2023 USD ($)
Other Commitments [Line Items]
Cap of noneconomic loss in a civil action (CORE)	$ 253
Cap of noneconomic loss in a civil action (CORE withdrawal)	187
CORE outcome excluding interest	26
CORE outcome total	$ 34

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Commitments and Contingencies - Marshall Wildfire (Details) $ in Millions	Sep. 30, 2023 USD ($)	Jul. 24, 2023 numberOfPlaintiffs complaint
Commitments and Contingencies Disclosure [Abstract]
Estimated property losses caused by Marshall Wildfire	$ 2,000.0
Number of complaints related to the Marshall Wildfire | complaint		14
Number of plaintiffs related to the Marshall Wildfire | numberOfPlaintiffs		675
Cap of noneconomic loss in a civil action other than a medical malpractice under Colorado law	0.6
Amount of insurance coverage	$ 500.0

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Other Comprehensive Income (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period				$ 9,230
Accumulated other comprehensive loss at end of period		$ 9,353		9,353
Income Tax Expense (Benefit)		21	$ 31	21	$ 31
Gains and Losses on Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period		(20)	(21)	(20)	(21)
Losses reclassified from net accumulated other comprehensive loss		0	0
Net current period other comprehensive loss		1	1	1	1
Accumulated other comprehensive loss at end of period		(19)	(20)	(19)	(20)
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	[1]	(1)	(1)	(1)	(1)
Defined Benefit and Postretirement Items
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period		(1)	(1)	(2)	(1)
Losses reclassified from net accumulated other comprehensive loss		1	0
Net current period other comprehensive loss		(1)	0	0	0
Accumulated other comprehensive loss at end of period		(2)	(1)	(2)	(1)
Defined Benefit and Postretirement Items | Interest Rate Swap
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Losses reclassified from net accumulated other comprehensive loss	[1]	0	0	0	0
Total
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period		(21)	(22)	(22)	(22)
Losses reclassified from net accumulated other comprehensive loss		1	0
Net current period other comprehensive loss		0	1	1	1
Accumulated other comprehensive loss at end of period		(21)	(21)	(21)	(21)
Total | Interest Rate Swap
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Losses reclassified from net accumulated other comprehensive loss	[1]	$ (1)	$ (1)	$ (1)	$ (1)

[1] Included in interest charges.

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Segment Information (Details) - USD ($) $ in Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2023		Sep. 30, 2022		Sep. 30, 2023		Sep. 30, 2022
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Electric	$ 1,113		$ 1,137		$ 2,877		$ 2,849
Net income	229		247		536		555
Unregulated Operating Revenue	12		11		41		39
Regulated and Unregulated Operating Revenue	1,290		1,383		4,165		3,975	[1]
Affiliate Revenue	1		2		3		4
Total revenues
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue			1,290		4,165	[1]
Regulated Electric
Segment Reporting Information [Line Items]
Revenues Including Intersegment Revenues	1,113		1,137		2,877		2,849
Net income	247		243		449		455
Regulated Natural Gas
Segment Reporting Information [Line Items]
Revenues Including Intersegment Revenues	165		235		1,247		1,087
Net income	(16)		4		81		99
All Other
Segment Reporting Information [Line Items]
Net income	(2)		0		6		1
All Other | Total revenues
Segment Reporting Information [Line Items]
Unregulated Operating Revenue	$ 12	[2]	$ 11	[2]	$ 41	[1]	$ 39	[1]

[1] Total revenues include $3 million and $4 million of other affiliate revenue for the nine months ended Sept. 30, 2023 and 2022.

[2] Total revenues include $1 million and $2 million of other affiliate revenue for the three months ended Sept. 30, 2023 and 2022.