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, 2020 or

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

Public Service Company of Colorado

(Exact name of registrant as specified in its charter)

Colorado	001-03280	84-0296600
(State or Other Jurisdiction of Incorporation or Organization)	(Commission File Number)	(IRS Employer Identification No.)

1800 Larimer, 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	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	Oct. 29, 2020
Common Stock, $0.01 par value	100 shares

Public Service Company of Colorado meets the conditions set forth in General Instruction 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 l —	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	20
Item 6 —	Exhibits	20
SIGNATURES		21
Certifications Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
Certifications Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

This Form 10-Q is filed by Public Service Company of Colorado (PSCo). PSCo is a wholly owned subsidiary of Xcel Energy Inc. Additional information on Xcel Energy is available in various filings with the Securities and Exchange Commission. 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 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
IRS	Internal Revenue Service
SEC	Securities and Exchange Commission

Electric, Purchased Gas and Resource Adjustment Clauses
DSM	Demand side management

Other
AFUDC	Allowance for funds used during construction
AGIS	Advanced Grid Intelligence and Security
ALJ	Administrative Law Judge
ASC	FASB Accounting Standards Codification
C&I	Commercial and Industrial
CCR	Coal combustion residual
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
CFO	Chief financial officer
COVID-19	Novel coronavirus
ETR	Effective tax rate
FASB	Financial Accounting Standards Board
GAAP	Generally accepted accounting principles
IPP	Independent power producing entity
MDL	Multi district litigation
MGP	Manufactured gas plant
NOL	Net operating loss
O&M	Operating and maintenance
PPA	Power purchase agreement
PTC	Production tax credit
ROE	Return on equity
VIE	Variable interest entity

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, 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 elsewhere in this Quarterly Report on Form 10-Q and in other filings with the SEC (including PSCo’s Annual Report on Form 10-K for the fiscal year ended Dec. 31, 2019 and subsequent filings), could cause actual results to differ materially from management expectations as suggested by such forward-looking information: uncertainty around the impacts and duration of the COVID-19 pandemic; operational safety; successful long-term operational planning; commodity risks associated with energy markets and production; rising energy prices and fuel costs; qualified employee work force and third-party contractor factors; ability to recover costs; changes in regulation; reductions in our credit ratings and the cost of maintaining certain contractual relationships; general economic conditions, including inflation rates, monetary fluctuations and their impact on capital expenditures and the ability of PSCo and its subsidiaries to obtain financing on favorable terms; availability or cost of capital; our customers’ and counterparties’ ability to pay their debts to us; assumptions and costs relating to funding our employee benefit plans and health care benefits; tax laws; effects of geopolitical events, including war and acts of terrorism; cyber security threats and data security breaches; seasonal weather patterns; changes in environmental laws and regulations; climate change and other weather; natural disaster and resource depletion, including compliance with any accompanying legislative and regulatory changes; and costs of potential regulatory penalties.

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
	2020		2019		2020		2019
Operating revenues
Electric	$	915.9	$	880.7	$	2,343.1	$	2,314.8
Natural gas	156.4		153.9		674.1		830.7
Other	8.8		9.7		31.7		31.8
Total operating revenues	1,081.1		1,044.3		3,048.9		3,177.3
Operating expenses
Electric fuel and purchased power	299.1		284.7		828.3		829.5
Cost of natural gas sold and transported	34.7		34.3		222.1		376.7
Cost of sales — steam and other	3.7		3.5		9.7		11.9
Operating and maintenance expenses	195.9		198.4		589.7		597.9
Demand side management expenses	35.6		36.6		107.3		100.9
Depreciation and amortization	164.4		153.5		478.9		448.6
Taxes (other than income taxes)	57.9		49.0		166.5		154.8
Total operating expenses	791.3		760.0		2,402.5		2,520.3
Operating income	289.8		284.3		646.4		657.0
Other (expense) income, net	(0.6)		1.4		(0.8)		1.9
Allowance for funds used during construction — equity	9.5		3.8		29.5		12.9
Interest charges and financing costs
Interest charges — includes other financing costs of $1.9, $1.6, $5.4 and $4.9, respectively	60.3		59.2		183.3		176.3
Allowance for funds used during construction — debt	(4.0)		(2.2)		(12.5)		(7.0)
Total interest charges and financing costs	56.3		57.0		170.8		169.3
Income before income taxes	242.4		232.5		504.3		502.5
Income tax expense	24.0		28.0		49.1		57.7
Net income	$	218.4	$	204.5	$	455.2	$	444.8

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
	2020		2019		2020		2019
Net income	$	218.4	$	204.5	$	455.2	$	444.8
Other comprehensive income
Derivative instruments:
Reclassification of loss to net income, net of tax of $0.1, $0.1, $0.3 and $0.3, respectively	0.3		0.3		0.9		0.9
Total other comprehensive income	0.3		0.3		0.9		0.9
Total comprehensive income	$	218.7	$	204.8	$	456.1	$	445.7

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
	2020		2019
Operating activities
Net income	$	455.2	$	444.8
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	482.2		452.2
Deferred income taxes	26.0		24.1
Amortization of investment tax credits	(1.9)		(1.9)
Allowance for equity funds used during construction	(29.5)		(12.9)
Provision for bad debts	16.1		11.4
Net realized and unrealized hedging and derivative transactions	(11.2)		64.5
Changes in operating assets and liabilities:
Accounts receivable	(19.3)		1.7
Accrued unbilled revenues	72.1		84.8
Inventories	(11.4)		(15.1)
Other current assets	(9.6)		(12.4)
Accounts payable	(50.5)		(96.0)
Net regulatory assets and liabilities	31.3		72.3
Other current liabilities	(40.9)		(66.3)
Pension and other employee benefit obligations	(44.9)		(44.4)
Other, net	(5.9)		(72.4)
Net cash provided by operating activities	857.8		834.4
Investing activities
Utility capital/construction expenditures	(1,292.9)		(1,098.6)
Investments in utility money pool arrangement	(366.0)		(397.0)
Repayments from utility money pool arrangement	366.0		397.0
Net cash used in investing activities	(1,292.9)		(1,098.6)
Financing activities
Repayments of short-term borrowings, net	—		(307.0)
Borrowings under utility money pool arrangement	1,382.0		58.0
Repayments under utility money pool arrangement	(1,360.0)		(58.0)
Proceeds from issuance of long-term debt	734.6		928.6
Repayments of long-term debt	(400.0)		(400.0)
Capital contributions from parent	787.7		632.7
Dividends paid to parent	(703.7)		(295.4)
Other, net	(0.3)		—
Net cash provided by financing activities	440.3		558.9
Net change in cash and cash equivalents	5.2		294.7
Cash and cash equivalents at beginning of period	11.4		33.4
Cash and cash equivalents at end of period	$	16.6	$	328.1
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	$	(183.6)	$	(173.4)
Cash paid for income taxes, net	(16.8)		(43.7)
Supplemental disclosure of non-cash investing and financing transactions:
Accrued property, plant and equipment additions	$	159.0	$	228.5
Inventory transfers to property, plant and equipment	26.4		24.4
Operating lease right-of-use assets	14.4		653.8
Allowance for equity funds used during construction	29.5		12.9

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, 2020		Dec. 31, 2019
Assets
Current assets
Cash and cash equivalents	$	16.6	$	11.4
Accounts receivable, net	324.9		303.9
Accounts receivable from affiliates	—		52.7
Accrued unbilled revenues	220.9		293.9
Inventories	177.0		192.0
Regulatory assets	96.0		64.0
Derivative instruments	19.0		7.2
Prepayments and other	77.2		55.9
Total current assets	931.6		981.0
Property, plant and equipment, net	17,204.5		16,155.0
Other assets
Regulatory assets	1,053.4		1,038.1
Derivative instruments	3.1		—
Operating lease right-of-use assets	520.5		574.0
Other	250.9		259.4
Total other assets	1,827.9		1,871.5
Total assets	$	19,964.0	$	19,007.5
Liabilities and Stockholder's Equity
Current liabilities
Current portion of long-term debt	$	—	$	400.0
Borrowings under utility money pool arrangement	61.0		39.0
Accounts payable	414.8		573.3
Accounts payable to affiliates	60.3		43.9
Regulatory liabilities	75.0		69.2
Taxes accrued	186.1		202.1
Accrued interest	35.8		53.4
Dividends payable to parent	102.9		111.5
Derivative instruments	20.8		8.7
Operating lease liabilities	92.1		85.8
Other	88.8		98.8
Total current liabilities	1,137.6		1,685.7
Deferred credits and other liabilities
Deferred income taxes	1,911.0		1,850.8
Deferred investment tax credits	21.0		22.8
Regulatory liabilities	2,316.9		2,036.8
Asset retirement obligations	359.2		324.0
Derivative instruments	42.5		52.5
Customer advances	170.1		173.6
Pension and employee benefit obligations	165.9		211.9
Operating lease liabilities	457.2		517.6
Other	149.2		150.9
Total deferred credits and other liabilities	5,593.0		5,340.9
Commitments and contingencies
Capitalization
Long-term debt	5,722.7		4,984.7
Common stock — 100 shares authorized of $0.01 par value; 100 shares outstanding at Sept. 30, 2020 and Dec. 31, 2019, respectively	—		—
Additional paid in capital	5,693.4		4,939.4
Retained earnings	1,843.0		2,083.4
Accumulated other comprehensive loss	(25.7)		(26.6)
Total common stockholder's equity	7,510.7		6,996.2
Total liabilities and stockholder's equity	$	19,964.0	$	19,007.5

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, 2020 and 2019
Balance at June 30, 2019	100	$	—	$	4,618.3	$	2,019.7	$	(24.9)	$	6,613.1
Net income						204.5				204.5
Other comprehensive income								0.3		0.3
Dividends declared to parent						(97.3)				(97.3)
Contribution of capital by parent				285.0						285.0
Balance at Sept. 30, 2019	100	$	—	$	4,903.3	$	2,126.9	$	(24.6)	$	7,005.6
Balance at June 30, 2020	100	$	—	$	5,693.7	$	1,752.4	$	(26.0)	$	7,420.1
Net income						218.4				218.4
Other comprehensive income								0.3		0.3
Dividends declared to parent						(127.8)				(127.8)
Contribution of capital by parent				(0.3)						(0.3)
Balance at Sept. 30, 2020	100	$	—	$	5,693.4	$	1,843.0	$	(25.7)	$	7,510.7
	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, 2020 and 2019
Balance at Dec. 31, 2018	100	$	—	$	4,340.5	$	1,983.2	$	(25.5)	$	6,298.2
Net income						444.8				444.8
Other comprehensive income								0.9		0.9
Dividends declared to parent						(301.1)				(301.1)
Contribution of capital by parent				562.8						562.8
Balance at Sept. 30, 2019	100	$	—	$	4,903.3	$	2,126.9	$	(24.6)	$	7,005.6
Balance at Dec. 31, 2019	100	$	—	$	4,939.4	$	2,083.4	$	(26.6)	$	6,996.2
Net income						455.2				455.2
Other comprehensive income								0.9		0.9
Dividends declared to parent						(694.9)				(694.9)
Contribution of capital by parent				754.0						754.0
Adoption of ASC Topic 326						(0.7)				(0.7)
Balance at Sept. 30, 2020	100	$	—	$	5,693.4	$	1,843.0	$	(25.7)	$	7,510.7
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 U.S. GAAP, the financial position of PSCo and its subsidiaries as of Sept. 30, 2020 and Dec. 31, 2019; the results of operations, including the components of net income, comprehensive income and changes in stockholder’s equity for the three and nine months ended Sept. 30, 2020 and 2019; and cash flows for the nine months ended Sept. 30, 2020 and 2019.

All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after Sept. 30, 2020, up to the date of issuance of these consolidated financial statements. These statements contain all necessary adjustments and disclosures resulting from that evaluation. The Dec. 31, 2019 balance sheet information has been derived from the audited 2019 consolidated financial statements included in the PSCo Annual Report on Form 10-K for the year ended Dec. 31, 2019.

These 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, 2019, filed with the SEC on Feb. 21, 2020. 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, 2019 appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

2. Accounting Pronouncements

Recently Adopted

Credit Losses — In 2016, the FASB issued Financial Instruments - Credit Losses, Topic 326 (ASC Topic 326), which changes how entities account for losses on receivables and certain other assets. The guidance requires use of a current expected credit loss model, which may result in earlier recognition of credit losses than under previous accounting standards.

PSCo implemented the guidance using a modified-retrospective approach, recognizing a cumulative effect charge of $0.7 million (after tax) to retained earnings on Jan. 1, 2020. Other than first-time recognition of an allowance for bad debts on accrued unbilled revenues, the Jan. 1, 2020, adoption of ASC Topic 326 did not have a significant impact on PSCo’s consolidated financial statements.

3. Selected Balance Sheet Data

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Accounts receivable, net
Accounts receivable	$	350.6	$	324.9
Less allowance for bad debts	(25.7)		(21.0)
Accounts receivable, net	$	324.9	$	303.9

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Inventories
Materials and supplies	$	63.9	$	62.6
Fuel	63.8		77.1
Natural gas	49.3		52.3
Total inventories	$	177.0	$	192.0

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Property, plant and equipment, net
Electric plant	$	15,512.7	$	14,361.9
Natural gas plant	4,894.2		4,631.4
Common and other property	1,157.3		1,113.5
Plant to be retired (a)	286.8		259.9
Construction work in progress	613.5		912.7
Total property, plant and equipment	22,464.5		21,279.4
Less accumulated depreciation	(5,260.0)		(5,124.4)
Property, plant and equipment, net	$	17,204.5	$	16,155.0

(a)In 2018, the CPUC approved early retirement of PSCo’s Comanche Units 1 and 2 in approximately 2022 and 2025, respectively. PSCo also expects Craig Unit 1 to be retired early in 2025. Amounts are presented net of accumulated depreciation.

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 Inc. 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 Inc. 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 Inc.

Money pool borrowings for PSCo were as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2020			Year Ended Dec. 31, 2019
Borrowing limit	$	250		$	250
Amount outstanding at period end	61			39
Average amount outstanding	4			7
Maximum amount outstanding	71			50
Weighted average interest rate, computed on a daily basis	0.09		%	2.29		%
Weighted average interest rate at period end	0.90			1.63		%

Commercial Paper — Commercial paper outstanding for PSCo was as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2020		Year Ended Dec. 31, 2019
Borrowing limit	$	700	$	700
Amount outstanding at period end	—		—
Average amount outstanding	—		154
Maximum amount outstanding	—		432
Weighted average interest rate, computed on a daily basis	N/A		2.67		%
Weighted average interest rate at period end	N/A		N/A

9

Letters of Credit — PSCo uses letters of credit, generally with terms of one year, to provide financial guarantees for certain operating obligations. There were $8 million and $9 million of letters of credit outstanding under the credit facility at Sept. 30, 2020 and Dec. 31, 2019, respectively. The contract amounts of these letters of credit approximate their fair value and are subject to fees.

Revolving Credit Facility — In order to use its commercial paper program to fulfill short-term funding needs, PSCo must have a revolving credit facility in place at least equal to the amount of its commercial paper borrowing limit and cannot issue commercial paper in an aggregate amount 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, 2020, PSCo had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)		Drawn (b)		Available
$	700	$	8	$	692

(a)    Expires in June 2024.

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

All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity under the credit facility. PSCo had no direct advances on the credit facility outstanding at Sept. 30, 2020 and Dec. 31, 2019.

Long-Term Borrowings

During the nine months ended Sept. 30, 2020, PSCo issued $375 million in 1.90% first mortgage bonds due Jan. 15, 2031 and $375 million of 2.70% first mortgage bonds due Jan. 15, 2051.

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, 2020
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	344.1	$	95.5	$	3.1	$	442.7
C&I	431.2		32.8		4.6		468.6
Other	11.3		—		—		11.3
Total retail	786.6		128.3		7.7		922.6
Wholesale	61.2		—		—		61.2
Transmission	17.8		—		—		17.8
Other	13.7		24.1		—		37.8
Total revenue from contracts with customers	879.3		152.4		7.7		1,039.4
Alternative revenue and other	36.6		4.0		1.1		41.7
Total revenues	$	915.9	$	156.4	$	8.8	$	1,081.1

	Three Months Ended Sept. 30, 2019
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	315.3	$	94.1	$	3.1	$	412.5
C&I	452.4		32.9		5.5		490.8
Other	11.8		—		—		11.8
Total retail	779.5		127.0		8.6		915.1
Wholesale	40.3		—		—		40.3
Transmission	16.4		—		—		16.4
Other	8.3		21.4		—		29.7
Total revenue from contracts with customers	844.5		148.4		8.6		1,001.5
Alternative revenue and other	36.2		5.5		1.1		42.8
Total revenues	$	880.7	$	153.9	$	9.7	$	1,044.3
	Nine Months Ended Sept. 30, 2020
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	825.4	$	430.6	$	9.0	$	1,265.0
C&I	1,134.7		149.7		19.4		1,303.8
Other	35.2		—		—		35.2
Total retail	1,995.3		580.3		28.4		2,604.0
Wholesale	150.0		—		—		150.0
Transmission	45.0		—		—		45.0
Other	43.0		77.3		—		120.3
Total revenue from contracts with customers	2,233.3		657.6		28.4		2,919.3
Alternative revenue and other	109.8		16.5		3.3		129.6
Total revenues	$	2,343.1	$	674.1	$	31.7	$	3,048.9
	Nine Months Ended Sept. 30, 2019
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	771.9	$	535.6	$	8.4	$	1,315.9
C&I	1,204.7		202.6		20.0		1,427.3
Other	36.1		—		—		36.1
Total retail	2,012.7		738.2		28.4		2,779.3
Wholesale	126.7		—		—		126.7
Transmission	41.4		—		—		41.4
Other	26.4		76.3		—		102.7
Total revenue from contracts with customers	2,207.2		814.5		28.4		3,050.1
Alternative revenue and other	107.6		16.2		3.4		127.2
Total revenues	$	2,314.8	$	830.7	$	31.8	$	3,177.3

10

6. Income Taxes

Note 7 to the consolidated financial statements included in PSCo’s Annual Report on Form 10-K for the year ended Dec. 31, 2019, represents, in all material respects, the current status of other income tax matters except to the extent noted below and are incorporated herein by reference.

The following table reconciles the difference between the statutory rate and the ETR:

	Nine Months Ended Sept. 30
	2020		2019
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	3.7		3.7
(Decreases) increases in tax from:
Wind PTCs	(8.5)		(7.7)
Plant regulatory differences (a)	(4.6)		(3.6)
Other tax credits, net NOL & tax credit allowances	(1.1)		(1.3)
Other (net)	(0.8)		(0.6)
Effective income tax rate	9.7	%	11.5	%

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

Federal Tax Loss Carryback Claims — In 2020, Xcel Energy identified certain expenses related to tax years 2009-2011 that qualify for an extended carryback claim. PSCo is not expected to accrue any income tax expense related to this adjustment.

Federal Audits — PSCo is a member of the Xcel Energy affiliated group that files a consolidated federal income tax return. Statute of limitations applicable to Xcel Energy’s federal income tax returns expire as follows:

Tax Years	Expiration
2014 — 2016	July 2021

Additionally, the statute of limitations related to the federal tax loss carryback claim referenced above has been extended. Xcel Energy has recognized its best estimate of income tax expense that will result from a final resolution of this issue; however, the outcome and timing of a resolution is unknown.

In 2017, the IRS concluded the audit of tax years 2012 and 2013 and proposed an adjustment that would impact Xcel Energy’s NOL and ETR. Xcel Energy filed a protest with the IRS. In April 2020, Xcel Energy and Office of Appeals reached an agreement and no material adjustments were required.

In 2018, the IRS began an audit of tax years 2014 - 2016. In July 2020, Xcel Energy and the IRS reached an agreement and the related benefit was recognized.

State Audits — PSCo is a member of the Xcel Energy affiliated group that files consolidated state income tax returns. As of Sept. 30, 2020, PSCo’s earliest open tax year subject to examination by state taxing authorities under applicable statutes of limitations is 2009. As of Sept. 30, 2020, there are no state income tax audits in progress.

Unrecognized Benefits — The unrecognized tax benefit balance includes permanent tax positions, which if recognized would affect the annual ETR. In addition, the unrecognized tax benefit balance includes temporary tax positions for which ultimate deductibility is highly certain but for which there is uncertainty about the timing of such deductibility. A change in the period of deductibility would not affect the ETR but would accelerate the payment to the taxing authority to an earlier period.

Unrecognized tax benefits — permanent vs temporary:

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Unrecognized tax benefit — Permanent tax positions	$	7.1	$	7.4
Unrecognized tax benefit — Temporary tax positions	1.3		4.6
Total unrecognized tax benefit	$	8.4	$	12.0

Unrecognized tax benefits were reduced by tax benefits associated with NOL and tax credit carryforwards:

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
NOL and tax credit carryforwards	$	(7.0)	$	(8.3)

Net deferred tax liability associated with the unrecognized tax benefit amounts and related NOLs and tax credit carryforwards were $5.7 million and $5.0 million for Sept. 30, 2020 and Dec. 31, 2019, respectively.

As the IRS and state audits resume, it is reasonably possible that the amount of unrecognized tax benefit could decrease up to approximately $2.8 million in the next 12 months.

Payable for interest related to unrecognized tax benefits is partially offset by the interest benefit associated with NOL and tax credit carryforwards.

Interest payable related to unrecognized tax benefits:

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Payable for interest related to unrecognized tax benefits at beginning of period	$	(1.1)	$	(0.7)
Interest benefit (expense) related to unrecognized tax benefits	1.1		(0.4)
Payable for interest related to unrecognized tax benefits at end of period	$	—	$	(1.1)

No amounts were accrued for penalties related to unrecognized tax benefits as of Sept. 30, 2020 and Dec. 31, 2019.

7. Fair Value of Financial Assets and Liabilities

Fair Value Measurements

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

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

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

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

11

Specific valuation methods include:

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

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

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

Derivative Instruments 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, utility commodity prices and vehicle fuel prices.

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

At Sept. 30, 2020, accumulated other comprehensive loss related to settled interest rate derivatives included $1.2 million of net losses expected to be reclassified into earnings during the next 12 months as the hedged transactions impact earnings, including forecasted amounts for unsettled hedges, as applicable.

Wholesale and Commodity Trading Risk — 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 activities governed by this policy.

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, as well as for trading purposes. This could include the purchase or sale of energy or energy-related products, natural gas to generate electric energy, natural gas for resale and vehicle fuel.

PSCo enters into derivative instruments that mitigate commodity price risk on behalf of electric and natural gas customers but may not be designated as qualifying hedging transactions. The classification as a regulatory asset or liability, if applicable, is based on approved regulatory recovery mechanisms.

As of Sept. 30, 2020, PSCo had no commodity contracts designated as cash flow hedges.

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

Gross notional amounts of commodity forwards and options:

(Amounts in Millions) (a)(b)	Sept. 30, 2020	Dec. 31, 2019
Megawatt hours of electricity	18.1	9.3
Million British thermal units of natural gas	92.8	32.2

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

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

Consideration of Credit Risk and Concentrations — PSCo continuously monitors the creditworthiness of the 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. The 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. At Sept. 30, 2020, five of PSCo’s 10 most significant counterparties for these activities, comprising $108.3 million, or 74%, of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings. Four of the 10 most significant counterparties, comprising $22.6 million, or 15%, of this credit exposure, were not rated by these external agencies, but based on PSCo’s internal analysis, had credit quality consistent with investment grade. One of these significant counterparties, comprising $2.9 million, or 2%, of this credit exposure, had credit quality less than investment grade, based on external analysis. Eight of these significant counterparties are independent system operators, municipal or cooperative electric entities, Regional Transmission Organizations or other utilities.

The impact of derivative activity:

	Pre-Tax Fair Value Gains (Losses) Recognized During the Period in:
(Millions of Dollars)	Accumulated Other Comprehensive Loss		Regulatory (Assets) and Liabilities
Three Months Ended Sept. 30, 2020
Other derivative instruments
Natural gas commodity	$	—	$	0.6
Total	$	—	$	0.6
Nine Months Ended Sept. 30, 2020
Other derivative instruments
Natural gas commodity	$	—	$	(2.2)
Total	$	—	$	(2.2)
Three Months Ended Sept. 30, 2019
Other derivative instruments
Natural gas commodity	$	—	$	(2.2)
Total	$	—	$	(2.2)
Nine Months Ended Sept. 30, 2019
Other derivative instruments
Natural gas commodity	$	—	$	(3.7)
Total	$	—	$	(3.7)

12

	Pre-Tax (Gains) Losses Reclassified into Income During the Period from:						Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Accumulated Other Comprehensive Loss			Regulatory Assets and (Liabilities)
Three Months Ended Sept. 30, 2020
Derivatives designated as cash flow hedges
Interest rate	$	0.4	(a)	$	—		$	—
Total	$	0.4		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	3.2	(b)
Total	$	—		$	—		$	3.2
Nine Months Ended Sept. 30, 2020
Derivatives designated as cash flow hedges
Interest rate	$	1.2	(a)	$	—		$	—
Total	$	1.2		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	(2.1)	(b)
Natural gas commodity	—			3.4		(c)	(3.4)		(c)
Total	$	—		$	3.4		$	(5.5)

(a)    Amounts are recorded to interest charges.

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

(c)    Amounts for the three and nine months ended Sept. 30, 2020, included no settlement gain or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining derivative settlement losses for the three and nine months ended Sept. 30, 2020, relate to natural gas operations and are recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.

	Pre-Tax (Gains) Losses Reclassified into Income During the Period from:						Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Accumulated Other Comprehensive Loss			Regulatory Assets and (Liabilities)
Three Months Ended Sept. 30, 2019
Derivatives designated as cash flow hedges
Interest rate	$	0.4	(a)	$	—		$	—
Total	$	0.4		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	0.6	(b)
Total	$	—		$	—		$	0.6
Nine Months Ended Sept. 30, 2019
Derivatives designated as cash flow hedges
Interest rate	$	1.2	(a)	$	—		$	—
Total	$	1.2		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	5.3	(b)
Natural gas commodity	—			(1.3)		(c)	(2.1)		(c)
Total	$	—		$	(1.3)		$	3.2

(a) Amounts are recorded to interest charges.

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

(c)    Amounts for the three and nine months ended Sept. 30, 2019, included no settlement gain or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining derivative settlement losses for the three and nine months ended Sept. 30, 2019, relate to natural gas operations and are recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.

PSCo had no derivative instruments designated as fair value hedges during the three and nine months ended Sept. 30, 2020 and 2019.

Credit Related Contingent Features — Contract provisions for derivative instruments that PSCo enters into, including those accounted for as normal purchase-normal sale contracts and therefore not reflected on the consolidated balance sheets, may require the posting of collateral or settlement of the contracts for various reasons, including if PSCo’s credit ratings are downgraded below its investment grade credit rating by any of the major credit rating agencies, or for cross-default contractual provisions if there was a failure under other financing arrangements related to payment terms or other covenants. At Sept. 30, 2020 and Dec. 31, 2019, there were $0.1 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, 2020 and Dec. 31, 2019.

13

Recurring Fair Value Measurements — PSCo’s derivative assets and liabilities measured at fair value on a recurring basis:

	Sept. 30, 2020												Dec. 31, 2019
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative assets
Other derivative instruments:
Commodity trading	$	7.0	$	27.6	$	1.0	$	35.6	$	(27.0)	$	8.6	$	1.9	$	11.1	$	0.9	$	13.9	$	(10.1)	$	3.8
Natural gas commodity	—		10.4		—		10.4		—		10.4		—		3.4		—		3.4		—		3.4
Total current derivative assets	$	7.0	$	38.0	$	1.0	$	46.0	$	(27.0)	$	19.0	$	1.9	$	14.5	$	0.9	$	17.3	$	(10.1)	$	7.2
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	1.6	$	9.1	$	2.5	$	13.2	$	(10.1)	$	3.1	$	0.4	$	8.1	$	1.1	$	9.6	$	(9.6)	$	—
Total noncurrent derivative assets	$	1.6	$	9.1	$	2.5	$	13.2	$	(10.1)	$	3.1	$	0.4	$	8.1	$	1.1	$	9.6	$	(9.6)	$	—

	Sept. 30, 2020												Dec. 31, 2019
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative liabilities
Other derivative instruments:
Commodity trading	$	7.0	$	31.6	$	6.3	$	44.9	$	(27.0)	$	17.9	$	1.7	$	16.7	$	—	$	18.4	$	(13.1)	$	5.3
Natural gas commodity	—		2.9		—		2.9		—		2.9		—		3.4		—		3.4		—		3.4
Total current derivative liabilities	$	7.0	$	34.5	$	6.3	$	47.8	$	(27.0)	$	20.8	$	1.7	$	20.1	$	—	$	21.8	$	(13.1)	$	8.7
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	0.9	$	21.4	$	35.5	$	57.8	$	(15.3)	$	42.5	$	0.4	$	47.0	$	14.7	$	62.1	$	(9.6)	$	52.5
Total noncurrent derivative assets	$	0.9	$	21.4	$	35.5	$	57.8	$	(15.3)	$	42.5	$	0.4	$	47.0	$	14.7	$	62.1	$	(9.6)	$	52.5

(a)PSCo nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at Sept. 30, 2020 and Dec. 31, 2019. At Sept. 30, 2020 and Dec. 31, 2019, derivative liabilities include no obligations to return cash collateral and the right to reclaim cash collateral of $5.2 million and $3.0 million, respectively. The 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)	2020		2019
Balance at July 1	$	(17.1)	$	0.2
Settlements	0.5		(0.5)
Net transactions recorded during the period:
(Losses) gains recognized in earnings (a)	(21.7)		0.5
Balance at Sept. 30	$	(38.3)	$	0.2
	Nine Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Balance at Jan. 1	$	(12.7)	$	0.1
Settlements	(0.6)		(1.4)
Net transactions recorded during the period:
(Losses) gains recognized in earnings (a)	(25.0)		1.5
Balance at Sept. 30	$	(38.3)	$	0.2

(a)Amounts relate to commodity derivatives held at the end of the period.

PSCo recognizes transfers between levels as of the beginning of each period. There were no transfers of amounts between levels for derivative instruments for the three and nine months ended Sept. 30, 2020 and 2019.

Fair Value of Long-Term Debt

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

	Sept. 30, 2020				Dec. 31, 2019
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	5,722.7	$	6,932.2	$	5,384.7	$	6,039.3

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, 2020 and Dec. 31, 2019 and given the observability of the inputs, fair values presented for long-term debt were assigned as Level 2.

14

8. Benefit Plans and Other Postretirement Benefits

Components of Net Periodic Benefit Cost (Credit)

	Three Months Ended Sept. 30
	2020		2019		2020		2019
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	7.6	$	6.4	$	0.1	$	0.1
Interest cost (a)	11.4		12.9		3.2		3.9
Expected return on plan assets (a)	(17.6)		(17.1)		(4.4)		(4.7)
Amortization of prior service credit (a)	(0.7)		(0.8)		(1.0)		(1.3)
Amortization of net loss (a)	7.5		6.3		0.4		0.7
Net periodic benefit cost (credit)	8.2		7.7		(1.7)		(1.3)
Effects of regulation	2.9		0.8		0.6		0.4
Net benefit cost (credit) recognized for financial reporting	$	11.1	$	8.5	$	(1.1)	$	(0.9)
	Nine Months Ended Sept. 30
	2020		2019		2020		2019
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	22.9	$	19.2	$	0.2	$	0.4
Interest cost (a)	34.3		38.7		9.5		11.7
Expected return on plan assets (a)	(52.9)		(51.4)		(13.1)		(14.2)
Amortization of prior service credit (a)	(2.1)		(2.5)		(2.8)		(4.1)
Amortization of net loss (a)	22.4		19.1		1.2		2.2
Net periodic benefit cost (credit)	24.6		23.1		(5.0)		(4.0)
Effects of regulation	3.3		4.4		2.2		0.9
Net benefit cost (credit) recognized for financial reporting	$	27.9	$	27.5	$	(2.8)	$	(3.1)

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

In January 2020, contributions of $150.0 million were made across four of Xcel Energy’s pension plans, of which $50.0 million was attributable to PSCo. Xcel Energy does not expect additional pension contributions during 2020.

9. Commitments and Contingencies

The following include commitments, contingencies and unresolved contingencies that are material to PSCo’s financial position.

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 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 financial statements. Unless otherwise required by GAAP, legal fees are expensed as incurred.

Gas Trading Litigation — e prime is a wholly owned subsidiary of Xcel Energy. e prime was in the business of natural gas trading and marketing but has not engaged in natural gas trading or marketing activities since 2003. Multiple lawsuits seeking monetary damages were commenced against e prime and its affiliates, including Xcel Energy Inc., between 2003 and 2009 alleging fraud and anticompetitive activities in conspiring to restrain the trade of natural gas and manipulate natural gas prices. Cases were all consolidated in the U.S. District Court in Nevada.

Two cases remain active which include an MDL matter consisting of a Colorado purported class (Breckenridge) and a Wisconsin purported class (Arandell Corp.).

Breckenridge/Colorado — In February 2019, the MDL panel remanded Breckenridge back to the U.S. District Court in Colorado.

Arandell Corp. — In February 2019, the case was remanded back to the U.S. District Court in Wisconsin. Plaintiffs are seeking class certification. It is uncertain when the court will rule on this issue.

Xcel Energy has concluded that a loss is remote for both remaining lawsuits.

Environmental

MGP, Landfill and Disposal Sites

PSCo is currently investigating, remediating or performing post-closure actions at three MGP, landfill or other disposal sites across its service territory.

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

Environmental Requirements — Water and Waste

Coal Ash Regulation — 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 CCR landfills and surface impoundments. Currently, PSCo has six regulated ash units in operation.

PSCo is conducting groundwater sampling and, where appropriate, implementing assessment of corrective measures at certain CCR landfills and surface impoundments. Groundwater monitoring consistent with the CCR Rule continued in 2020. Statistically significant increases above background concentrations were detected at four locations.

Subsequently, assessment monitoring samples were collected at these locations and, based on the results, PSCo is evaluating options for corrective action at two locations. At one location, monitoring results indicate potential offsite impacts to groundwater. Until PSCo completes its assessment, it is uncertain what impact, if any, there will be on the operations, financial condition or cash flows.

15

On Aug. 28, 2020, the EPA published its final rule to implement a cease receipt and initiate a closure date of April 11, 2021 for all CCR impoundments affected by an August 2018 D.C. Circuit ruling. The D.C. Circuit concluded that the EPA cannot allow utilities to continue to use unlined impoundments (including clay lined impoundments) for the storage or disposal of coal ash.

PSCo is pursuing options to provide alternative storage capacity consistent with the CCR Rule at one facility until the affected generating units are retired in 2025.

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

VIEs 

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 it purchases. These specific PPAs create a variable interest in the IPP.

PSCo had approximately 1,518 MW and 1,442 MW of capacity under long-term PPAs at Sept. 30, 2020 and Dec. 31, 2019, respectively, with entities that have been determined to be VIEs. PSCo concluded that these entities are not required to be consolidated in its consolidated financial statements because it does not have the power to direct the activities that most significantly impact the entities’ economic performance. The PPAs have expiration dates through 2032.

10. Other Comprehensive Income (Loss)

Changes in accumulated other comprehensive loss, net of tax, for the three and nine months ended Sept. 30, 2020 and 2019:

	Three Months Ended Sept. 30, 2020						Three Months Ended Sept. 30, 2019
(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	$	(23.5)	$	(2.5)	$	(26.0)	$	(24.7)	$	(0.2)	$	(24.9)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (net of taxes of $0.1, $—, $0.1 and $—, respectively) (a)	0.3		—		0.3		0.3		—		0.3
Net current period other comprehensive income	0.3		—		0.3		0.3		—		0.3
Accumulated other comprehensive loss at Sept. 30	$	(23.2)	$	(2.5)	$	(25.7)	$	(24.4)	$	(0.2)	$	(24.6)

(a)Included in interest charges.

	Nine Months Ended Sept. 30, 2020						Nine Months Ended Sept. 30, 2019
(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	$	(24.1)	$	(2.5)	$	(26.6)	$	(25.3)	$	(0.2)	$	(25.5)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (net of taxes of $0.3, $—, $0.3 and $—, respectively) (a)	0.9		—		0.9		0.9		—		0.9
Net current period other comprehensive income	0.9		—		0.9		0.9		—		0.9
Accumulated other comprehensive loss at Sept. 30	$	(23.2)	$	(2.5)	$	(25.7)	$	(24.4)	$	(0.2)	$	(24.6)

(a)Included in interest charges.

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. Regulated electric utility 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 presents 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.

To report income from operations for regulated electric and regulated natural gas utility segments, the majority of costs are directly assigned to each segment. However, some costs, such as common depreciation, common O&M expenses and interest expense are allocated based on cost causation allocators. A general allocator is used for certain general and administrative expenses, including office supplies, rent, property insurance and general advertising.

16

PSCo’s segment information for the three and nine months ended Sept. 30:

	Three Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Regulated Electric
Operating revenues	$	915.9	$	880.7
Intersegment revenue	0.1		0.1
Total revenues	$	916.0	$	880.8
Net income	214.5		204.7
Regulated Natural Gas
Operating revenues	$	156.4	$	153.9
Intersegment revenue	0.1		0.1
Total revenues	$	156.5	$	154.0
Net income	4.4		0.7
All Other
Operating revenues (a)	$	8.8	$	9.7
Net loss	(0.5)		(0.9)
Consolidated Total
Operating revenues (a)	$	1,081.3	$	1,044.5
Reconciling eliminations	(0.2)		(0.2)
Total operating revenues	$	1,081.1	$	1,044.3
Net income	218.4		204.5

(a)    Operating revenues include $1.1 million of other affiliate revenue for the three months ended Sept. 30, 2020 and 2019.

	Nine Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Regulated Electric
Operating revenues	$	2,343.1	$	2,314.8
Intersegment revenue	0.3		0.3
Total revenues	$	2,343.4	$	2,315.1
Net income	377.5		371.9
Regulated Natural Gas
Operating revenues	$	674.1	$	830.7
Intersegment revenues	—		0.2
Total revenues	$	674.1	$	830.9
Net income	72.5		77.5
All Other
Operating revenues (a)	$	31.7	$	31.8
Net income (loss)	5.2		(4.6)
Consolidated Total
Operating revenues (a)	$	3,049.2	$	3,177.8
Reconciling eliminations	(0.3)		(0.5)
Total operating revenues	$	3,048.9	$	3,177.3
Net income	455.2		444.8

(a)    Operating revenues include $3.3 million of other affiliate revenue for the nine months ended Sept. 30, 2020 and 2019.

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 instructions 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 electric margin, natural gas margin and ongoing earnings. Generally, a non-GAAP financial measure is a measure of a company’s financial performance, financial position or cash flows that excludes (or includes) amounts that are adjusted from measures calculated and presented in accordance with GAAP. PSCo’s management uses non-GAAP measures for financial planning and analysis, for reporting of results, 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.

Electric and Natural Gas Margins

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

Management believes electric and natural gas margins provide the most meaningful basis for evaluating our operations because they exclude the revenue impact of fluctuations in these expenses. These margins can be reconciled to operating income, a GAAP measure, by including other operating revenues, cost of sales-other, O&M expenses, conservation and DSM expenses, depreciation and amortization and taxes (other than income taxes).

Results of Operations

PSCo’s net income was $455.2 million year-to-date, compared with $444.8 million for the prior year. The increase in year-to-date earnings was driven by higher electric margin (regulatory outcomes offset lower sales due to COVID-19), increased AFUDC and reduced O&M expenses, partially offset by higher depreciation and interest expense.

Electric Margin

Electric revenues and fuel and purchased power expenses are impacted by fluctuations in the price of natural gas and coal used in the generation of electricity. However, these price fluctuations have minimal impact on electric margin due to fuel recovery mechanisms that recover fuel expenses. In addition, electric customers receive a credit for PTCs that are generated in a particular period.

Electric revenues and margin:

	Nine Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Electric revenues	$	2,343.1	$	2,314.8
Electric fuel and purchased power	(828.3)		(829.5)
Electric margin	$	1,514.8	$	1,485.3

17

Changes in electric margin:

(Millions of Dollars)	2020 vs. 2019
Regulatory rate outcome	$	49.0
Wholesale transmission revenue (net)	5.0
Conservation and demand side management	4.0
Sales and demand (a)	(37.0)
PTCs flowed back to customers (offset by lower ETR)	(3.1)
Other (net)	11.6
Total increase in electric margin	$	29.5

(a)     Sales decline excludes weather impact, net of decoupling.

Natural Gas Margin

Natural gas expense varies with changing sales and the cost of natural gas. However, fluctuations in the cost of natural gas have minimal impact on natural gas margin due to natural gas cost recovery mechanisms.

Natural gas revenues and margin:

	Nine Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Natural gas revenues	$	674.1	$	830.7
Cost of natural gas sold and transported	(222.1)		(376.7)
Natural gas margin	$	452.0	$	454.0

Changes in natural gas margin:

(Millions of Dollars)	2020 vs. 2019
Estimated impact of weather	$	(5.6)
Retail sales decline	(4.1)
Infrastructure and integrity riders	9.3
Other (net)	(1.6)
Total decrease in natural gas margin	$	(2.0)

Non-Fuel Operating Expenses and Other Items

O&M Expenses — O&M expenses decreased $8.2 million, or 1.4% year-to-date, largely reflecting management actions to reduce costs to offset the impact of lower sales from COVID-19. Management actions included allocation of workforce, material and supply management, timing of maintenance activities. In addition, O&M expense decreased due to the outcome of the CPUC's rehearing of the 2019 electric rate case.

Depreciation and Amortization — Depreciation and amortization expense increased $30.3 million, or 6.8% year-to-date. The increase was primarily due to normal system expansion, new electric rates implemented in March 2020 and the in-servicing of the Cheyenne Ridge wind farm, partially offset by a decrease in amortization of pension regulatory assets.

Income Taxes — Income tax expense decreased $8.6 million year-to-date. The decrease was primarily driven by an increase in plant regulatory differences and increased wind PTCs. Wind PTCs are credited to customers (recorded as a reduction to revenue) and do not have a material impact on net income. The ETR was 9.7% year-to-date compared with 11.5% for 2019, largely due to the items referenced above.

See Note 6 to the consolidated financial statements.

Public Utility Regulation

The FERC and various state and local regulatory commissions regulate PSCo. The electric and natural gas rates charged to PSCo’s customers are approved by the FERC or the regulatory commissions in the states in which they operate.

The rates are designed to recover plant investment, operating costs and an allowed return on investment. PSCo request changes in rates for utility services through filings with governing commissions.

Changes in operating costs can affect PSCo’s financial results, depending on the timing of rate case filings and implementation of final rates. Other factors affecting rate filings are new investments, sales, conservation and DSM 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 in Regulation above, 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, 2019 and in Item 2 of PSCo’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2020 and Form 10-Q for the quarterly period ended June 30, 2020, appropriately represent, in all material respects, the current status of public utility regulation and are incorporated by reference.

Pending and Recently Concluded Regulatory Proceedings

Proceeding	Amount (in millions)	Filing Date	Approval
2020 Natural Gas Rate Case	$127	February 2020	Received
2019 Electric Rate Case	$158	May 2019	Received
2019 Natural Gas Rate Case Appeal	N/A	April 2019	Pending
Wildfire Protection Rider	$325	July 2020	Pending
Advanced Grid Rider	$850	July 2020	Pending

Additional Information:

2020 Natural Gas Rate Case — In October 2020, the CPUC accepted a recommended decision by the ALJ to approve a comprehensive settlement without modification between PSCo, the CPUC Staff and various intervenors. The rate outcome results in a net increase to retail gas rates of $77 million, reflecting a $94 million increase in base rate revenue, partially offset by $17 million of costs previously authorized through the Pipeline Integrity rider. Rates will be implemented on April 1, 2021 and will be retroactively effective back to November 2020. The settlement is based on:

•A ROE of 9.20%;

•An equity ratio of 55.62%; and

•A historic test year as of Sept. 30, 2019, utilizing a year-end rate base, and incorporating a known and measurable adjustment for the Tungsten to Black Hawk pipeline.

2019 Electric Rate Case — In 2019, PSCo filed a request with the CPUC seeking a net rate increase of $108.4 million, based on a requested ROE of 10.2% and an equity ratio of 55.6%.

In February 2020, the CPUC issued a written decision, resulting in an estimated $34.9 million net base rate revenue increase. The CPUC decision included a 9.3% ROE, an equity ratio of 55.61%, based on a current test year ended Aug. 31, 2019, implementation of decoupling in 2020 and other items.

18

In May 2020, the CPUC deliberated on PSCo’s request for rehearing and revised its prior decision on the test year calculation, return on prepaid pension and medical assets, a disallowance of a capital investment for the Comanche Unit 3 superheater and Board compensation. In July 2020, the CPUC’s written decision was received. As a result, electric rates will increase approximately $12 million. In October 2020, the CPUC initiated a non-adjudicatory review of Comanche Unit 3’s performance to be handled by the CPUC Staff, consistent with what was signaled during the 2019 Electric Rate Case rehearing. A report is expected to be issued in the first half of 2021.

2019 Natural Gas Rate Case Appeal — In April 2019, PSCo filed an appeal seeking judicial review of the CPUC’s prior ruling regarding PSCo’s last natural gas rate case (approved in December 2018). The appeal requested review of the following: denial of a return on the prepaid pension and retiree medical assets; the use of a capital structure not based on the actual historical test year; and use of an average rate base methodology rather than a year-end rate base methodology.

In March 2020, The District Court of Denver County ruled in favor of allowing the prepaid pension assets to be included in rate base; but it upheld the CPUC treatment of the retiree medical assets and capital structure methodology. The CPUC did not appeal the decision allowing inclusion of the prepaid pension assets in rate base.

PSCo 2020 Rider Filings

In July 2020, PSCo filed rider requests with the CPUC instead of filing a comprehensive electric rate case in 2020.

Wildfire Protection Rider — Seeks to establish a rider to recover incremental costs associated with system investments to reduce wildfire risk. In August 2020, the CPUC referred it to an ALJ.

Procedural schedule:

•Answer testimony Nov. 20, 2020;

•Rebuttal testimony Dec. 18, 2020;

•Settlement by Jan. 8, 2021;

•Hearing Jan. 14, 2021 - Jan. 15, 2021; and

•Statutory deadline March 24, 2021.

The rider is expected to be effective in June 2021 and continue through 2025. Wildfire Protection capital investment is projected to be approximately $325 million. Forecasted annual revenue requirements from 2021 through 2025 are as follows:

(Millions of Dollars)	2021		2022		2023		2024		2025
Forecasted annual revenue requirement	$	17	$	24	$	29	$	32	$	34

Advanced Grid Rider — Seeks to establish a rider to recover incremental costs associated with the AGIS initiative. In August 2020, the CPUC referred the matter to an ALJ. In September 2020, the Office of Consumer Counsel filed a motion to dismiss the Advanced Grid Rider.

Procedural schedule:

•Answer testimony Dec. 9, 2020;

•Rebuttal Jan. 8, 2021;

•Settlement by Jan. 20, 2021;

•Hearing Jan. 25, 2021 - Jan 28, 2021; and

•Statutory deadline April 24, 2021.

The rider is expected to be effective in May 2021 and continue through 2025. The PSCo portion of the AGIS capital investment is projected to be approximately $850 million. Forecasted annual revenue requirements from 2021 through 2025 are as follows:

(Millions of Dollars)	2021		2022		2023		2024		2025
Forecasted annual revenue requirement	$	53	$	69	$	83	$	89	$	99

PSCo KEPCO Filing — In September 2020, PSCo filed with the CPUC for approval to terminate a solar PPA with KEPCO Solar of Alamosa, Inc. and establish a regulatory asset to recover transaction costs of approximately $41 million. By terminating the PPA, customers would save approximately $38 million over an 11-year period. A CPUC decision is expected in the second quarter of 2021.

PSCo — Comanche Unit 3

PSCo is part owner of Comanche Unit 3, a 750 MW, coal-fueled electric generating unit. PSCo is the operating agent under the joint ownership agreement. In June 2020, the unit experienced loss of turbine oil during start-up which damaged the plant. It is currently anticipated that Comanche Unit 3 will recommence operations in the fourth quarter of 2020. Replacement and repair of damaged systems in excess of a $2 million deductible are expected to be recovered through insurance policies. PSCo has obtained replacement power for a portion of the unit’s output through PPAs. In October 2020, the CPUC initiated a non-adjudicatory review of Comanche Unit 3’s performance to be handled by the CPUC Staff, consistent with what was signaled during the 2019 Electric Rate Case rehearing. A report is expected to be issued in the first half of 2021.

Boulder Municipalization

In 2011, Boulder passed a ballot measure authorizing the formation of an electric municipal utility, subject to certain conditions. Subsequently, there have been various legal proceedings in multiple venues.

In September 2020, the City Council voted to approve a settlement between PSCo and Boulder officials to end the city’s municipalization effort. The settlement would result in a 20-year franchise arrangement (with multiple opt-out conditions), an energy partnership and an undergrounding agreement. It also established the municipalization process if Boulder exercised an opt-out. The citizens of Boulder will vote on Nov. 3, 2020, whether to approve or deny the franchise agreement.

PSCo — Natural Gas LDC and Emission Reductions — In October 2020, the CPUC opened a docket to investigate topics related to natural gas emissions in relation to statewide emission reduction goals.

The first meeting will be scheduled in the fourth quarter of 2020, in which subject matter experts will discuss greenhouse emission reductions required from the natural gas industry in regard to the statewide goals.

Environmental

Environmental Regulation

In July 2019, the EPA adopted the Affordable Clean Energy rule, which requires states to develop plans for greenhouse gas reductions from coal-fired power plants. The state plans, due to the EPA in July 2022, will evaluate and potentially require heat rate improvements at existing coal-fired plants. It is not yet known how these state plans will affect our existing coal plants, but they could require substantial additional investment, even in plants slated for retirement. PSCo believes, based on prior state commission practice, the cost of these initiatives or replacement generation would be recoverable through rates.

19

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, 2020, 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 the 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 financial statements. Unless otherwise required by GAAP, legal fees are expensed as incurred.

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

ITEM 1A — RISK FACTORS

There have been no material changes from the risk factors disclosed in our Form 10-K for the year ended Dec. 31, 2019 except as follows:

We face risks related to health epidemics and other outbreaks, which may have a material effect on our financial condition, results of operations and cash flows.

The global outbreak of COVID-19 is currently impacting countries, communities, supply chains and markets. A high degree of uncertainty continues to exist regarding COVID-19, the duration and magnitude of business restrictions, re-shut downs, if any, and the level and pace of economic recovery. While we are implementing contingency plans, there are no guarantees these plans will be sufficient to offset the impact of COVID-19.

Although we do not expect the impact of COVID-19 to be material to the 2020 results, we cannot ultimately predict whether it will have a material impact on our future liquidity, financial condition, or results of operations. Nor can we predict the impact of the virus on the health of our employees, our supply chain or our ability to recover higher costs associated with managing through the pandemic.

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, 2019, which is incorporated herein by reference, as well as other information set forth in this report, which could have a material impact on our financial condition, results of operations and cash flows.

ITEM 6 — EXHIBITS

* Indicates incorporation by reference

Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	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	001-03280	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	001-03280	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	Certification 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)

20

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
Oct. 29, 2020	By:	/s/ JEFFREY S. SAVAGE
		Jeffrey S. Savage
		Senior Vice President, Controller
		(Principal Accounting Officer)
		/s/ BRIAN J. VAN ABEL
		Brian J. Van Abel
		Executive Vice President, Chief Financial Officer and Director
		(Principal Financial Officer)

21

EX-31.01

Exhibit 31.01

CERTIFICATION

I, Ben Fowke, 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: Oct. 29, 2020

/s/ BEN FOWKE

Ben Fowke

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: Oct. 29, 2020

/s/ BRIAN J. VAN ABEL

Brian J. Van Abel

Executive Vice President, Chief Financial Officer and Director

(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, 2020, 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: Oct. 29, 2020

/s/ BEN FOWKE

Ben Fowke

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 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

XML

Cover Page - shares	9 Months Ended
	Sep. 30, 2020	Oct. 29, 2020
Cover [Abstract]
Entity Central Index Key	0000081018
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3
Amendment Flag	false
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2020
Document Transition Report	false
Entity Registrant Name	Public Service Company of Colorado
Entity Incorporation, State or Country Code	CO
Entity File Number	001-03280
Entity Tax Identification Number	84-0296600
Entity Address, Address Line One	1800 Larimer, 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
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		100

XML

Management's Opinion

9 Months Ended

Sep. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Management's Opinion

In the opinion of management, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly, in accordance with U.S. GAAP, the financial position of PSCo and its subsidiaries as of Sept. 30, 2020 and Dec. 31, 2019; the results of operations, including the components of net income, comprehensive income and changes in stockholder’s equity for the three and nine months ended Sept. 30, 2020 and 2019; and cash flows for the nine months ended Sept. 30, 2020 and 2019.

All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after Sept. 30, 2020, up to the date of issuance of these consolidated financial statements. These statements contain all necessary adjustments and disclosures resulting from that evaluation. The Dec. 31, 2019 balance sheet information has been derived from the audited 2019 consolidated financial statements included in the PSCo Annual Report on Form 10-K for the year ended Dec. 31, 2019.

These 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, 2019, filed with the SEC on Feb. 21, 2020. 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.

XML

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	The significant accounting policies set forth in Note 1 to the consolidated financial statements in the PSCo Annual Report on Form 10-K for the year ended Dec. 31, 2019 appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

XML

Accounting Pronouncements

9 Months Ended

Sep. 30, 2020

Accounting Standards Update and Change in Accounting Principle [Abstract]

Accounting Pronouncements

Recently Adopted

Credit Losses — In 2016, the FASB issued Financial Instruments - Credit Losses, Topic 326 (ASC Topic 326), which changes how entities account for losses on receivables and certain other assets. The guidance requires use of a current expected credit loss model, which may result in earlier recognition of credit losses than under previous accounting standards.

PSCo implemented the guidance using a modified-retrospective approach, recognizing a cumulative effect charge of $0.7 million (after tax) to retained earnings on Jan. 1, 2020. Other than first-time recognition of an allowance for bad debts on accrued unbilled revenues, the Jan. 1, 2020, adoption of ASC Topic 326 did not have a significant impact on PSCo’s consolidated financial statements.

XML

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, 2018		100
Beginning Balance at Dec. 31, 2018	$ 6,298.2	$ 0.0	$ 4,340.5	$ 1,983.2	$ (25.5)
Increase (Decrease) in Stockholder's Equity
Net income	444.8			444.8
Total other comprehensive income	0.9				0.9
Dividends declared to parent	(301.1)			(301.1)
Contribution of capital by parent	562.8		562.8
Balance (in shares) at Sep. 30, 2019		100
Ending Balance at Sep. 30, 2019	7,005.6	$ 0.0	4,903.3	2,126.9	(24.6)
Balance (in shares) at Jun. 30, 2019		100
Beginning Balance at Jun. 30, 2019	6,613.1	$ 0.0	4,618.3	2,019.7	(24.9)
Increase (Decrease) in Stockholder's Equity
Net income	204.5			204.5
Total other comprehensive income	0.3				0.3
Dividends declared to parent	(97.3)			(97.3)
Contribution of capital by parent	285.0		285.0
Balance (in shares) at Sep. 30, 2019		100
Ending Balance at Sep. 30, 2019	$ 7,005.6	$ 0.0	4,903.3	2,126.9	(24.6)
Balance (in shares) at Dec. 31, 2019	100	100
Beginning Balance at Dec. 31, 2019	$ 6,996.2	$ 0.0	4,939.4	2,083.4	(26.6)
Increase (Decrease) in Stockholder's Equity
Net income	455.2			455.2
Total other comprehensive income	0.9				0.9
Dividends declared to parent	(694.9)			(694.9)
Contribution of capital by parent	754.0		754.0
Adoption of ASC Topic 326	$ (0.7)			(0.7)
Balance (in shares) at Sep. 30, 2020	100	100
Ending Balance at Sep. 30, 2020	$ 7,510.7	$ 0.0	5,693.4	1,843.0	(25.7)
Balance (in shares) at Jun. 30, 2020		100
Beginning Balance at Jun. 30, 2020	7,420.1	$ 0.0	5,693.7	1,752.4	(26.0)
Increase (Decrease) in Stockholder's Equity
Net income	218.4			218.4
Total other comprehensive income	0.3				0.3
Dividends declared to parent	(127.8)			(127.8)
Contribution of capital by parent	$ (0.3)		(0.3)
Balance (in shares) at Sep. 30, 2020	100	100
Ending Balance at Sep. 30, 2020	$ 7,510.7	$ 0.0	$ 5,693.4	$ 1,843.0	$ (25.7)

XML

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Operating revenues
Electric	$ 915.9	$ 880.7	$ 2,343.1	$ 2,314.8
Natural gas	156.4	153.9	674.1	830.7
Other	8.8	9.7	31.7	31.8
Total operating revenues	1,081.1	1,044.3	3,048.9	3,177.3
Operating expenses
Electric fuel and purchased power	299.1	284.7	828.3	829.5
Cost of natural gas sold and transported	34.7	34.3	222.1	376.7
Cost of sales — steam and other	3.7	3.5	9.7	11.9
Operating and maintenance expenses	195.9	198.4	589.7	597.9
Demand side management expenses	35.6	36.6	107.3	100.9
Depreciation and amortization	164.4	153.5	478.9	448.6
Taxes (other than income taxes)	57.9	49.0	166.5	154.8
Total operating expenses	791.3	760.0	2,402.5	2,520.3
Operating income	289.8	284.3	646.4	657.0
Other (expense) income, net	(0.6)	1.4	(0.8)	1.9
Allowance for funds used during construction — equity	9.5	3.8	29.5	12.9
Interest charges and financing costs
Interest charges — includes other financing costs of $1.9, $1.6, $5.4 and $4.9, respectively	60.3	59.2	183.3	176.3
Debt Related Commitment Fees and Debt Issuance Costs	1.9	1.6	5.4	4.9
Allowance for funds used during construction — debt	(4.0)	(2.2)	(12.5)	(7.0)
Total interest charges and financing costs	56.3	57.0	170.8	169.3
Income before income taxes	242.4	232.5	504.3	502.5
Income tax expense	24.0	28.0	49.1	57.7
Net income	$ 218.4	$ 204.5	$ 455.2	$ 444.8

XML

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Statement of Financial Position [Abstract]
Debt Related Commitment Fees and Debt Issuance Costs	$ 1.9	$ 1.6	$ 5.4	$ 4.9

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Comprehensive income:
Net income	$ 218.4	$ 204.5	$ 455.2	$ 444.8
Derivative instruments:
Reclassification of loss to net income, net of tax of $0.1, $0.1, $0.3 and $0.3, respectively	0.3	0.3	0.9	0.9
Tax	0.1	0.1	0.3	0.3
Total other comprehensive income	0.3	0.3	0.9	0.9
Total comprehensive income	$ 218.7	$ 204.8	$ 456.1	$ 445.7

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Operating activities
Net income	$ 455.2	$ 444.8
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	482.2	452.2
Deferred income taxes	26.0	24.1
Amortization of investment tax credits	(1.9)	(1.9)
Allowance for equity funds used during construction	(29.5)	(12.9)
Provision for bad debts	16.1	11.4
Net realized and unrealized hedging and derivative transactions	(11.2)	64.5
Changes in operating assets and liabilities:
Accounts receivable	(19.3)	1.7
Accrued unbilled revenues	72.1	84.8
Inventories	(11.4)	(15.1)
Other current assets	(9.6)	(12.4)
Accounts payable	(50.5)	(96.0)
Net regulatory assets and liabilities	31.3	72.3
Other current liabilities	(40.9)	(66.3)
Pension and other employee benefit obligations	(44.9)	(44.4)
Other, net	(5.9)	(72.4)
Net cash provided by operating activities	857.8	834.4
Investing activities
Utility capital/construction expenditures	(1,292.9)	(1,098.6)
Investments in utility money pool arrangement	(366.0)	(397.0)
Repayments from utility money pool arrangement	366.0	397.0
Net cash used in investing activities	(1,292.9)	(1,098.6)
Financing activities
Repayments of short-term borrowings, net	0.0	(307.0)
Borrowings under utility money pool arrangement	1,382.0	58.0
Repayments under utility money pool arrangement	(1,360.0)	(58.0)
Proceeds from issuance of long-term debt	734.6	928.6
Repayments of long-term debt	(400.0)	(400.0)
Capital contributions from parent	787.7	632.7
Dividends paid to parent	(703.7)	(295.4)
Other, net	(0.3)	0.0
Net cash provided by financing activities	440.3	558.9
Net change in cash and cash equivalents	5.2	294.7
Cash and cash equivalents at beginning of period	11.4
Cash and cash equivalents at end of period	16.6	328.1
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	(183.6)	(173.4)
Cash paid for income taxes, net	(16.8)	(43.7)
Supplemental disclosure of non-cash investing and financing transactions:
Accrued property, plant and equipment additions	159.0	228.5
Inventory transfers to property, plant and equipment	26.4	24.4
Operating lease right-of-use assets	14.4	653.8
Allowance for equity funds used during construction	$ 29.5	$ 12.9

XML

CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Current assets
Cash and cash equivalents at beginning of period	$ 16.6	$ 11.4
Accounts receivable, net	324.9	303.9
Accounts receivable from affiliates	0.0	52.7
Accrued unbilled revenues	220.9	293.9
Total inventories	177.0	192.0
Regulatory assets	96.0	64.0
Derivative instruments	19.0	7.2
Prepayments and other	77.2	55.9
Total current assets	931.6	981.0
Property, plant and equipment, net	17,204.5	16,155.0
Other assets
Regulatory assets	1,053.4	1,038.1
Derivative instruments	3.1	0.0
Operating lease right-of-use assets	520.5	574.0
Other	250.9	259.4
Total other assets	1,827.9	1,871.5
Total assets	19,964.0	19,007.5
Current liabilities
Current portion of long-term debt	0.0	400.0
Borrowings under utility money pool arrangement	61.0	39.0
Accounts payable	414.8	573.3
Accounts payable to affiliates	60.3	43.9
Regulatory liabilities	75.0	69.2
Taxes accrued	186.1	202.1
Accrued interest	35.8	53.4
Dividends payable to parent	102.9	111.5
Derivative instruments	20.8	8.7
Operating lease liabilities	92.1	85.8
Other	88.8	98.8
Total current liabilities	1,137.6	1,685.7
Deferred credits and other liabilities
Deferred income taxes	1,911.0	1,850.8
Deferred investment tax credits	21.0	22.8
Regulatory liabilities	2,316.9	2,036.8
Asset retirement obligations	359.2	324.0
Derivative instruments	42.5	52.5
Customer advances	170.1	173.6
Pension and employee benefit obligations	165.9	211.9
Operating lease liabilities	457.2	517.6
Other	149.2	150.9
Total deferred credits and other liabilities	5,593.0	5,340.9
Commitments and contingencies
Capitalization
Long-term debt	$ 5,722.7	$ 4,984.7
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, 2020 and Dec. 31, 2019, respectively	$ 0.0	$ 0.0
Additional paid in capital	5,693.4	4,939.4
Retained earnings	1,843.0	2,083.4
Accumulated other comprehensive loss	(25.7)	(26.6)
Total common stockholder's equity	7,510.7	6,996.2
Total liabilities and stockholder's equity	$ 19,964.0	$ 19,007.5

XML

Selected Balance Sheet Data

9 Months Ended

Sep. 30, 2020

Balance Sheet Related Disclosures [Abstract]

Selected Balance Sheet Data

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Accounts receivable, net
Accounts receivable	$	350.6	$	324.9
Less allowance for bad debts	(25.7)		(21.0)
Accounts receivable, net	$	324.9	$	303.9

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Inventories
Materials and supplies	$	63.9	$	62.6
Fuel	63.8		77.1
Natural gas	49.3		52.3
Total inventories	$	177.0	$	192.0

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Property, plant and equipment, net
Electric plant	$	15,512.7	$	14,361.9
Natural gas plant	4,894.2		4,631.4
Common and other property	1,157.3		1,113.5
Plant to be retired (a)	286.8		259.9
Construction work in progress	613.5		912.7
Total property, plant and equipment	22,464.5		21,279.4
Less accumulated depreciation	(5,260.0)		(5,124.4)
Property, plant and equipment, net	$	17,204.5	$	16,155.0

(a)In 2018, the CPUC approved early retirement of PSCo’s Comanche Units 1 and 2 in approximately 2022 and 2025, respectively. PSCo also expects Craig Unit 1 to be retired early in 2025. Amounts are presented net of accumulated depreciation.

XML

Borrowings and Other Financing Instruments

9 Months Ended

Sep. 30, 2020

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 Inc. 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 Inc. 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 Inc.

Money pool borrowings for PSCo were as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2020			Year Ended Dec. 31, 2019
Borrowing limit	$	250		$	250
Amount outstanding at period end	61			39
Average amount outstanding	4			7
Maximum amount outstanding	71			50
Weighted average interest rate, computed on a daily basis	0.09		%	2.29		%
Weighted average interest rate at period end	0.90			1.63		%

Commercial Paper — Commercial paper outstanding for PSCo was as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2020		Year Ended Dec. 31, 2019
Borrowing limit	$	700	$	700
Amount outstanding at period end	—		—
Average amount outstanding	—		154
Maximum amount outstanding	—		432
Weighted average interest rate, computed on a daily basis	N/A		2.67		%
Weighted average interest rate at period end	N/A		N/A

Letters of Credit — PSCo uses letters of credit, generally with terms of one year, to provide financial guarantees for certain operating obligations. There were $8 million and $9 million of letters of credit outstanding under the credit facility at Sept. 30, 2020 and Dec. 31, 2019, respectively. The contract amounts of these letters of credit approximate their fair value and are subject to fees.

Revolving Credit Facility — In order to use its commercial paper program to fulfill short-term funding needs, PSCo must have a revolving credit facility in place at least equal to the amount of its commercial paper borrowing limit and cannot issue commercial paper in an aggregate amount 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, 2020, PSCo had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)		Drawn (b)		Available
$	700	$	8	$	692

(a)    Expires in June 2024.

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

All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity under the credit facility. PSCo had no direct advances on the credit facility outstanding at Sept. 30, 2020 and Dec. 31, 2019.

Long-Term Borrowings

During the nine months ended Sept. 30, 2020, PSCo issued $375 million in 1.90% first mortgage bonds due Jan. 15, 2031 and $375 million of 2.70% first mortgage bonds due Jan. 15, 2051.

XML

Revenues

9 Months Ended

Sep. 30, 2020

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, 2020
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	344.1	$	95.5	$	3.1	$	442.7
C&I	431.2		32.8		4.6		468.6
Other	11.3		—		—		11.3
Total retail	786.6		128.3		7.7		922.6
Wholesale	61.2		—		—		61.2
Transmission	17.8		—		—		17.8
Other	13.7		24.1		—		37.8
Total revenue from contracts with customers	879.3		152.4		7.7		1,039.4
Alternative revenue and other	36.6		4.0		1.1		41.7
Total revenues	$	915.9	$	156.4	$	8.8	$	1,081.1

	Three Months Ended Sept. 30, 2019
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	315.3	$	94.1	$	3.1	$	412.5
C&I	452.4		32.9		5.5		490.8
Other	11.8		—		—		11.8
Total retail	779.5		127.0		8.6		915.1
Wholesale	40.3		—		—		40.3
Transmission	16.4		—		—		16.4
Other	8.3		21.4		—		29.7
Total revenue from contracts with customers	844.5		148.4		8.6		1,001.5
Alternative revenue and other	36.2		5.5		1.1		42.8
Total revenues	$	880.7	$	153.9	$	9.7	$	1,044.3
	Nine Months Ended Sept. 30, 2020
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	825.4	$	430.6	$	9.0	$	1,265.0
C&I	1,134.7		149.7		19.4		1,303.8
Other	35.2		—		—		35.2
Total retail	1,995.3		580.3		28.4		2,604.0
Wholesale	150.0		—		—		150.0
Transmission	45.0		—		—		45.0
Other	43.0		77.3		—		120.3
Total revenue from contracts with customers	2,233.3		657.6		28.4		2,919.3
Alternative revenue and other	109.8		16.5		3.3		129.6
Total revenues	$	2,343.1	$	674.1	$	31.7	$	3,048.9
	Nine Months Ended Sept. 30, 2019
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	771.9	$	535.6	$	8.4	$	1,315.9
C&I	1,204.7		202.6		20.0		1,427.3
Other	36.1		—		—		36.1
Total retail	2,012.7		738.2		28.4		2,779.3
Wholesale	126.7		—		—		126.7
Transmission	41.4		—		—		41.4
Other	26.4		76.3		—		102.7
Total revenue from contracts with customers	2,207.2		814.5		28.4		3,050.1
Alternative revenue and other	107.6		16.2		3.4		127.2
Total revenues	$	2,314.8	$	830.7	$	31.8	$	3,177.3

XML

Income Taxes

9 Months Ended

Sep. 30, 2020

Income Tax Disclosure [Abstract]

Income Taxes

Note 7 to the consolidated financial statements included in PSCo’s Annual Report on Form 10-K for the year ended Dec. 31, 2019, represents, in all material respects, the current status of other income tax matters except to the extent noted below and are incorporated herein by reference.

The following table reconciles the difference between the statutory rate and the ETR:

	Nine Months Ended Sept. 30
	2020		2019
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	3.7		3.7
(Decreases) increases in tax from:
Wind PTCs	(8.5)		(7.7)
Plant regulatory differences (a)	(4.6)		(3.6)
Other tax credits, net NOL & tax credit allowances	(1.1)		(1.3)
Other (net)	(0.8)		(0.6)
Effective income tax rate	9.7	%	11.5	%

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

Federal Tax Loss Carryback Claims — In 2020, Xcel Energy identified certain expenses related to tax years 2009-2011 that qualify for an extended carryback claim. PSCo is not expected to accrue any income tax expense related to this adjustment.

Federal Audits — PSCo is a member of the Xcel Energy affiliated group that files a consolidated federal income tax return. Statute of limitations applicable to Xcel Energy’s federal income tax returns expire as follows:

Tax Years	Expiration
2014 — 2016	July 2021

Additionally, the statute of limitations related to the federal tax loss carryback claim referenced above has been extended. Xcel Energy has recognized its best estimate of income tax expense that will result from a final resolution of this issue; however, the outcome and timing of a resolution is unknown.

In 2017, the IRS concluded the audit of tax years 2012 and 2013 and proposed an adjustment that would impact Xcel Energy’s NOL and ETR. Xcel Energy filed a protest with the IRS. In April 2020, Xcel Energy and Office of Appeals reached an agreement and no material adjustments were required.

In 2018, the IRS began an audit of tax years 2014 - 2016. In July 2020, Xcel Energy and the IRS reached an agreement and the related benefit was recognized.

State Audits — PSCo is a member of the Xcel Energy affiliated group that files consolidated state income tax returns. As of Sept. 30, 2020, PSCo’s earliest open tax year subject to examination by state taxing authorities under applicable statutes of limitations is 2009. As of Sept. 30, 2020, there are no state income tax audits in progress.

Unrecognized Benefits — The unrecognized tax benefit balance includes permanent tax positions, which if recognized would affect the annual ETR. In addition, the unrecognized tax benefit balance includes temporary tax positions for which ultimate deductibility is highly certain but for which there is uncertainty about the timing of such deductibility. A change in the period of deductibility would not affect the ETR but would accelerate the payment to the taxing authority to an earlier period.

Unrecognized tax benefits — permanent vs temporary:

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Unrecognized tax benefit — Permanent tax positions	$	7.1	$	7.4
Unrecognized tax benefit — Temporary tax positions	1.3		4.6
Total unrecognized tax benefit	$	8.4	$	12.0

Unrecognized tax benefits were reduced by tax benefits associated with NOL and tax credit carryforwards:

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
NOL and tax credit carryforwards	$	(7.0)	$	(8.3)

Net deferred tax liability associated with the unrecognized tax benefit amounts and related NOLs and tax credit carryforwards were $5.7 million and $5.0 million for Sept. 30, 2020 and Dec. 31, 2019, respectively.

As the IRS and state audits resume, it is reasonably possible that the amount of unrecognized tax benefit could decrease up to approximately $2.8 million in the next 12 months.

Payable for interest related to unrecognized tax benefits is partially offset by the interest benefit associated with NOL and tax credit carryforwards.

Interest payable related to unrecognized tax benefits:

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Payable for interest related to unrecognized tax benefits at beginning of period	$	(1.1)	$	(0.7)
Interest benefit (expense) related to unrecognized tax benefits	1.1		(0.4)
Payable for interest related to unrecognized tax benefits at end of period	$	—	$	(1.1)

No amounts were accrued for penalties related to unrecognized tax benefits as of Sept. 30, 2020 and Dec. 31, 2019.

XML

Fair Value of Financial Assets and Liabilities

9 Months Ended

Sep. 30, 2020

Fair Value Disclosures [Abstract]

Fair Value of Financial Assets and Liabilities

Fair Value Measurements

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

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

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

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

Specific valuation methods include:

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

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

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

Derivative Instruments 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, utility commodity prices and vehicle fuel prices.

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

At Sept. 30, 2020, accumulated other comprehensive loss related to settled interest rate derivatives included $1.2 million of net losses expected to be reclassified into earnings during the next 12 months as the hedged transactions impact earnings, including forecasted amounts for unsettled hedges, as applicable.

Wholesale and Commodity Trading Risk — 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 activities governed by this policy.

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, as well as for trading purposes. This could include the purchase or sale of energy or energy-related products, natural gas to generate electric energy, natural gas for resale and vehicle fuel.

PSCo enters into derivative instruments that mitigate commodity price risk on behalf of electric and natural gas customers but may not be designated as qualifying hedging transactions. The classification as a regulatory asset or liability, if applicable, is based on approved regulatory recovery mechanisms.

As of Sept. 30, 2020, PSCo had no commodity contracts designated as cash flow hedges.

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

Gross notional amounts of commodity forwards and options:

(Amounts in Millions) (a)(b)	Sept. 30, 2020	Dec. 31, 2019
Megawatt hours of electricity	18.1	9.3
Million British thermal units of natural gas	92.8	32.2

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

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

Consideration of Credit Risk and Concentrations — PSCo continuously monitors the creditworthiness of the 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. The 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. At Sept. 30, 2020, five of PSCo’s 10 most significant counterparties for these activities, comprising $108.3 million, or 74%, of this credit exposure, had investment grade credit ratings from S&P Global Ratings, Moody’s Investor Services or Fitch Ratings. Four of the 10 most significant counterparties, comprising $22.6 million, or 15%, of this credit exposure, were not rated by these external agencies, but based on PSCo’s internal analysis, had credit quality consistent with investment grade. One of these significant counterparties, comprising $2.9 million, or 2%, of this credit exposure, had credit quality less than investment grade, based on external analysis. Eight of these significant counterparties are independent system operators, municipal or cooperative electric entities, Regional Transmission Organizations or other utilities.

The impact of derivative activity:

	Pre-Tax Fair Value Gains (Losses) Recognized During the Period in:
(Millions of Dollars)	Accumulated Other Comprehensive Loss		Regulatory (Assets) and Liabilities
Three Months Ended Sept. 30, 2020
Other derivative instruments
Natural gas commodity	$	—	$	0.6
Total	$	—	$	0.6
Nine Months Ended Sept. 30, 2020
Other derivative instruments
Natural gas commodity	$	—	$	(2.2)
Total	$	—	$	(2.2)
Three Months Ended Sept. 30, 2019
Other derivative instruments
Natural gas commodity	$	—	$	(2.2)
Total	$	—	$	(2.2)
Nine Months Ended Sept. 30, 2019
Other derivative instruments
Natural gas commodity	$	—	$	(3.7)
Total	$	—	$	(3.7)

	Pre-Tax (Gains) Losses Reclassified into Income During the Period from:						Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Accumulated Other Comprehensive Loss			Regulatory Assets and (Liabilities)
Three Months Ended Sept. 30, 2020
Derivatives designated as cash flow hedges
Interest rate	$	0.4	(a)	$	—		$	—
Total	$	0.4		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	3.2	(b)
Total	$	—		$	—		$	3.2
Nine Months Ended Sept. 30, 2020
Derivatives designated as cash flow hedges
Interest rate	$	1.2	(a)	$	—		$	—
Total	$	1.2		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	(2.1)	(b)
Natural gas commodity	—			3.4		(c)	(3.4)		(c)
Total	$	—		$	3.4		$	(5.5)

(a)    Amounts are recorded to interest charges.

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

(c)    Amounts for the three and nine months ended Sept. 30, 2020, included no settlement gain or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining derivative settlement losses for the three and nine months ended Sept. 30, 2020, relate to natural gas operations and are recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.

	Pre-Tax (Gains) Losses Reclassified into Income During the Period from:						Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Accumulated Other Comprehensive Loss			Regulatory Assets and (Liabilities)
Three Months Ended Sept. 30, 2019
Derivatives designated as cash flow hedges
Interest rate	$	0.4	(a)	$	—		$	—
Total	$	0.4		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	0.6	(b)
Total	$	—		$	—		$	0.6
Nine Months Ended Sept. 30, 2019
Derivatives designated as cash flow hedges
Interest rate	$	1.2	(a)	$	—		$	—
Total	$	1.2		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	5.3	(b)
Natural gas commodity	—			(1.3)		(c)	(2.1)		(c)
Total	$	—		$	(1.3)		$	3.2

(a) Amounts are recorded to interest charges.

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

(c)    Amounts for the three and nine months ended Sept. 30, 2019, included no settlement gain or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining derivative settlement losses for the three and nine months ended Sept. 30, 2019, relate to natural gas operations and are recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.

PSCo had no derivative instruments designated as fair value hedges during the three and nine months ended Sept. 30, 2020 and 2019.

Credit Related Contingent Features — Contract provisions for derivative instruments that PSCo enters into, including those accounted for as normal purchase-normal sale contracts and therefore not reflected on the consolidated balance sheets, may require the posting of collateral or settlement of the contracts for various reasons, including if PSCo’s credit ratings are downgraded below its investment grade credit rating by any of the major credit rating agencies, or for cross-default contractual provisions if there was a failure under other financing arrangements related to payment terms or other covenants. At Sept. 30, 2020 and Dec. 31, 2019, there were $0.1 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, 2020 and Dec. 31, 2019.

Recurring Fair Value Measurements — PSCo’s derivative assets and liabilities measured at fair value on a recurring basis:

	Sept. 30, 2020												Dec. 31, 2019
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative assets
Other derivative instruments:
Commodity trading	$	7.0	$	27.6	$	1.0	$	35.6	$	(27.0)	$	8.6	$	1.9	$	11.1	$	0.9	$	13.9	$	(10.1)	$	3.8
Natural gas commodity	—		10.4		—		10.4		—		10.4		—		3.4		—		3.4		—		3.4
Total current derivative assets	$	7.0	$	38.0	$	1.0	$	46.0	$	(27.0)	$	19.0	$	1.9	$	14.5	$	0.9	$	17.3	$	(10.1)	$	7.2
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	1.6	$	9.1	$	2.5	$	13.2	$	(10.1)	$	3.1	$	0.4	$	8.1	$	1.1	$	9.6	$	(9.6)	$	—
Total noncurrent derivative assets	$	1.6	$	9.1	$	2.5	$	13.2	$	(10.1)	$	3.1	$	0.4	$	8.1	$	1.1	$	9.6	$	(9.6)	$	—

	Sept. 30, 2020												Dec. 31, 2019
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative liabilities
Other derivative instruments:
Commodity trading	$	7.0	$	31.6	$	6.3	$	44.9	$	(27.0)	$	17.9	$	1.7	$	16.7	$	—	$	18.4	$	(13.1)	$	5.3
Natural gas commodity	—		2.9		—		2.9		—		2.9		—		3.4		—		3.4		—		3.4
Total current derivative liabilities	$	7.0	$	34.5	$	6.3	$	47.8	$	(27.0)	$	20.8	$	1.7	$	20.1	$	—	$	21.8	$	(13.1)	$	8.7
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	0.9	$	21.4	$	35.5	$	57.8	$	(15.3)	$	42.5	$	0.4	$	47.0	$	14.7	$	62.1	$	(9.6)	$	52.5
Total noncurrent derivative assets	$	0.9	$	21.4	$	35.5	$	57.8	$	(15.3)	$	42.5	$	0.4	$	47.0	$	14.7	$	62.1	$	(9.6)	$	52.5

(a)PSCo nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at Sept. 30, 2020 and Dec. 31, 2019. At Sept. 30, 2020 and Dec. 31, 2019, derivative liabilities include no obligations to return cash collateral and the right to reclaim cash collateral of $5.2 million and $3.0 million, respectively. The 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)	2020		2019
Balance at July 1	$	(17.1)	$	0.2
Settlements	0.5		(0.5)
Net transactions recorded during the period:
(Losses) gains recognized in earnings (a)	(21.7)		0.5
Balance at Sept. 30	$	(38.3)	$	0.2
	Nine Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Balance at Jan. 1	$	(12.7)	$	0.1
Settlements	(0.6)		(1.4)
Net transactions recorded during the period:
(Losses) gains recognized in earnings (a)	(25.0)		1.5
Balance at Sept. 30	$	(38.3)	$	0.2

(a)Amounts relate to commodity derivatives held at the end of the period.

PSCo recognizes transfers between levels as of the beginning of each period. There were no transfers of amounts between levels for derivative instruments for the three and nine months ended Sept. 30, 2020 and 2019.

Fair Value of Long-Term Debt

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

	Sept. 30, 2020				Dec. 31, 2019
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	5,722.7	$	6,932.2	$	5,384.7	$	6,039.3

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, 2020 and Dec. 31, 2019 and given the observability of the inputs, fair values presented for long-term debt were assigned as Level 2.

XML

Benefit Plans and Other Postretirement Benefits

9 Months Ended

Sep. 30, 2020

Retirement Benefits [Abstract]

Benefit Plans and Other Postretirement Benefits

Components of Net Periodic Benefit Cost (Credit)

	Three Months Ended Sept. 30
	2020		2019		2020		2019
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	7.6	$	6.4	$	0.1	$	0.1
Interest cost (a)	11.4		12.9		3.2		3.9
Expected return on plan assets (a)	(17.6)		(17.1)		(4.4)		(4.7)
Amortization of prior service credit (a)	(0.7)		(0.8)		(1.0)		(1.3)
Amortization of net loss (a)	7.5		6.3		0.4		0.7
Net periodic benefit cost (credit)	8.2		7.7		(1.7)		(1.3)
Effects of regulation	2.9		0.8		0.6		0.4
Net benefit cost (credit) recognized for financial reporting	$	11.1	$	8.5	$	(1.1)	$	(0.9)
	Nine Months Ended Sept. 30
	2020		2019		2020		2019
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	22.9	$	19.2	$	0.2	$	0.4
Interest cost (a)	34.3		38.7		9.5		11.7
Expected return on plan assets (a)	(52.9)		(51.4)		(13.1)		(14.2)
Amortization of prior service credit (a)	(2.1)		(2.5)		(2.8)		(4.1)
Amortization of net loss (a)	22.4		19.1		1.2		2.2
Net periodic benefit cost (credit)	24.6		23.1		(5.0)		(4.0)
Effects of regulation	3.3		4.4		2.2		0.9
Net benefit cost (credit) recognized for financial reporting	$	27.9	$	27.5	$	(2.8)	$	(3.1)

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

In January 2020, contributions of $150.0 million were made across four of Xcel Energy’s pension plans, of which $50.0 million was attributable to PSCo. Xcel Energy does not expect additional pension contributions during 2020.

XML

Commitments and Contingencies

9 Months Ended

Sep. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

The following include commitments, contingencies and unresolved contingencies that are material to PSCo’s financial position.

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 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 financial statements. Unless otherwise required by GAAP, legal fees are expensed as incurred.

Gas Trading Litigation — e prime is a wholly owned subsidiary of Xcel Energy. e prime was in the business of natural gas trading and marketing but has not engaged in natural gas trading or marketing activities since 2003. Multiple lawsuits seeking monetary damages were commenced against e prime and its affiliates, including Xcel Energy Inc., between 2003 and 2009 alleging fraud and anticompetitive activities in conspiring to restrain the trade of natural gas and manipulate natural gas prices. Cases were all consolidated in the U.S. District Court in Nevada.

Two cases remain active which include an MDL matter consisting of a Colorado purported class (Breckenridge) and a Wisconsin purported class (Arandell Corp.).

Breckenridge/Colorado — In February 2019, the MDL panel remanded Breckenridge back to the U.S. District Court in Colorado.

Arandell Corp. — In February 2019, the case was remanded back to the U.S. District Court in Wisconsin. Plaintiffs are seeking class certification. It is uncertain when the court will rule on this issue.

Xcel Energy has concluded that a loss is remote for both remaining lawsuits.

Environmental

MGP, Landfill and Disposal Sites

PSCo is currently investigating, remediating or performing post-closure actions at three MGP, landfill or other disposal sites across its service territory.

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

Environmental Requirements — Water and Waste

Coal Ash Regulation — 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 CCR landfills and surface impoundments. Currently, PSCo has six regulated ash units in operation.

PSCo is conducting groundwater sampling and, where appropriate, implementing assessment of corrective measures at certain CCR landfills and surface impoundments. Groundwater monitoring consistent with the CCR Rule continued in 2020. Statistically significant increases above background concentrations were detected at four locations.

Subsequently, assessment monitoring samples were collected at these locations and, based on the results, PSCo is evaluating options for corrective action at two locations. At one location, monitoring results indicate potential offsite impacts to groundwater. Until PSCo completes its assessment, it is uncertain what impact, if any, there will be on the operations, financial condition or cash flows.

On Aug. 28, 2020, the EPA published its final rule to implement a cease receipt and initiate a closure date of April 11, 2021 for all CCR impoundments affected by an August 2018 D.C. Circuit ruling. The D.C. Circuit concluded that the EPA cannot allow utilities to continue to use unlined impoundments (including clay lined impoundments) for the storage or disposal of coal ash.

PSCo is pursuing options to provide alternative storage capacity consistent with the CCR Rule at one facility until the affected generating units are retired in 2025.

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

VIEs 

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 it purchases. These specific PPAs create a variable interest in the IPP.

PSCo had approximately 1,518 MW and 1,442 MW of capacity under long-term PPAs at Sept. 30, 2020 and Dec. 31, 2019, respectively, with entities that have been determined to be VIEs. PSCo concluded that these entities are not required to be consolidated in its consolidated financial statements because it does not have the power to direct the activities that most significantly impact the entities’ economic performance. The PPAs have expiration dates through 2032.

XML

Other Comprehensive Income (Loss)

9 Months Ended

Sep. 30, 2020

Stockholders' Equity Note [Abstract]

Other Comprehensive Income

Changes in accumulated other comprehensive loss, net of tax, for the three and nine months ended Sept. 30, 2020 and 2019:

	Three Months Ended Sept. 30, 2020						Three Months Ended Sept. 30, 2019
(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	$	(23.5)	$	(2.5)	$	(26.0)	$	(24.7)	$	(0.2)	$	(24.9)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (net of taxes of $0.1, $—, $0.1 and $—, respectively) (a)	0.3		—		0.3		0.3		—		0.3
Net current period other comprehensive income	0.3		—		0.3		0.3		—		0.3
Accumulated other comprehensive loss at Sept. 30	$	(23.2)	$	(2.5)	$	(25.7)	$	(24.4)	$	(0.2)	$	(24.6)

(a)Included in interest charges.

	Nine Months Ended Sept. 30, 2020						Nine Months Ended Sept. 30, 2019
(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	$	(24.1)	$	(2.5)	$	(26.6)	$	(25.3)	$	(0.2)	$	(25.5)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (net of taxes of $0.3, $—, $0.3 and $—, respectively) (a)	0.9		—		0.9		0.9		—		0.9
Net current period other comprehensive income	0.9		—		0.9		0.9		—		0.9
Accumulated other comprehensive loss at Sept. 30	$	(23.2)	$	(2.5)	$	(25.7)	$	(24.4)	$	(0.2)	$	(24.6)

(a)Included in interest charges.

XML

Segment Information

9 Months Ended

Sep. 30, 2020

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. Regulated electric utility 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 presents 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.

To report income from operations for regulated electric and regulated natural gas utility segments, the majority of costs are directly assigned to each segment. However, some costs, such as common depreciation, common O&M expenses and interest expense are allocated based on cost causation allocators. A general allocator is used for certain general and administrative expenses, including office supplies, rent, property insurance and general advertising.

PSCo’s segment information for the three and nine months ended Sept. 30:

	Three Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Regulated Electric
Operating revenues	$	915.9	$	880.7
Intersegment revenue	0.1		0.1
Total revenues	$	916.0	$	880.8
Net income	214.5		204.7
Regulated Natural Gas
Operating revenues	$	156.4	$	153.9
Intersegment revenue	0.1		0.1
Total revenues	$	156.5	$	154.0
Net income	4.4		0.7
All Other
Operating revenues (a)	$	8.8	$	9.7
Net loss	(0.5)		(0.9)
Consolidated Total
Operating revenues (a)	$	1,081.3	$	1,044.5
Reconciling eliminations	(0.2)		(0.2)
Total operating revenues	$	1,081.1	$	1,044.3
Net income	218.4		204.5

(a)    Operating revenues include $1.1 million of other affiliate revenue for the three months ended Sept. 30, 2020 and 2019.

	Nine Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Regulated Electric
Operating revenues	$	2,343.1	$	2,314.8
Intersegment revenue	0.3		0.3
Total revenues	$	2,343.4	$	2,315.1
Net income	377.5		371.9
Regulated Natural Gas
Operating revenues	$	674.1	$	830.7
Intersegment revenues	—		0.2
Total revenues	$	674.1	$	830.9
Net income	72.5		77.5
All Other
Operating revenues (a)	$	31.7	$	31.8
Net income (loss)	5.2		(4.6)
Consolidated Total
Operating revenues (a)	$	3,049.2	$	3,177.8
Reconciling eliminations	(0.3)		(0.5)
Total operating revenues	$	3,048.9	$	3,177.3
Net income	455.2		444.8

(a)    Operating revenues include $3.3 million of other affiliate revenue for the nine months ended Sept. 30, 2020 and 2019.

XML

Selected Balance Sheet Data (Tables)

9 Months Ended

Sep. 30, 2020

Balance Sheet Related Disclosures [Abstract]

Accounts Receivable, Net

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Accounts receivable, net
Accounts receivable	$	350.6	$	324.9
Less allowance for bad debts	(25.7)		(21.0)
Accounts receivable, net	$	324.9	$	303.9

Inventories

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Inventories
Materials and supplies	$	63.9	$	62.6
Fuel	63.8		77.1
Natural gas	49.3		52.3
Total inventories	$	177.0	$	192.0

Property, Plant and Equipment, Net

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Property, plant and equipment, net
Electric plant	$	15,512.7	$	14,361.9
Natural gas plant	4,894.2		4,631.4
Common and other property	1,157.3		1,113.5
Plant to be retired (a)	286.8		259.9
Construction work in progress	613.5		912.7
Total property, plant and equipment	22,464.5		21,279.4
Less accumulated depreciation	(5,260.0)		(5,124.4)
Property, plant and equipment, net	$	17,204.5	$	16,155.0

XML

Borrowings and Other Financing Instruments (Tables)

9 Months Ended

Sep. 30, 2020

Borrowings and Other Financing Instruments [Abstract]

Short-Term Borrowings

Commercial paper outstanding for PSCo was as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2020		Year Ended Dec. 31, 2019
Borrowing limit	$	700	$	700
Amount outstanding at period end	—		—
Average amount outstanding	—		154
Maximum amount outstanding	—		432
Weighted average interest rate, computed on a daily basis	N/A		2.67		%
Weighted average interest rate at period end	N/A		N/A

Credit Facilities

At Sept. 30, 2020, PSCo had the following committed revolving credit facility available (in millions of dollars):

Credit Facility (a)		Drawn (b)		Available
$	700	$	8	$	692

(a)    Expires in June 2024.

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

Money Pool

Borrowings and Other Financing Instruments [Abstract]

Short-Term Borrowings

Money pool borrowings for PSCo were as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended Sept. 30, 2020			Year Ended Dec. 31, 2019
Borrowing limit	$	250		$	250
Amount outstanding at period end	61			39
Average amount outstanding	4			7
Maximum amount outstanding	71			50
Weighted average interest rate, computed on a daily basis	0.09		%	2.29		%
Weighted average interest rate at period end	0.90			1.63		%

XML

Revenues (Tables)

9 Months Ended

Sep. 30, 2020

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

PSCo’s operating revenues consisted of the following:

	Three Months Ended Sept. 30, 2020
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	344.1	$	95.5	$	3.1	$	442.7
C&I	431.2		32.8		4.6		468.6
Other	11.3		—		—		11.3
Total retail	786.6		128.3		7.7		922.6
Wholesale	61.2		—		—		61.2
Transmission	17.8		—		—		17.8
Other	13.7		24.1		—		37.8
Total revenue from contracts with customers	879.3		152.4		7.7		1,039.4
Alternative revenue and other	36.6		4.0		1.1		41.7
Total revenues	$	915.9	$	156.4	$	8.8	$	1,081.1

	Three Months Ended Sept. 30, 2019
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	315.3	$	94.1	$	3.1	$	412.5
C&I	452.4		32.9		5.5		490.8
Other	11.8		—		—		11.8
Total retail	779.5		127.0		8.6		915.1
Wholesale	40.3		—		—		40.3
Transmission	16.4		—		—		16.4
Other	8.3		21.4		—		29.7
Total revenue from contracts with customers	844.5		148.4		8.6		1,001.5
Alternative revenue and other	36.2		5.5		1.1		42.8
Total revenues	$	880.7	$	153.9	$	9.7	$	1,044.3
	Nine Months Ended Sept. 30, 2020
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	825.4	$	430.6	$	9.0	$	1,265.0
C&I	1,134.7		149.7		19.4		1,303.8
Other	35.2		—		—		35.2
Total retail	1,995.3		580.3		28.4		2,604.0
Wholesale	150.0		—		—		150.0
Transmission	45.0		—		—		45.0
Other	43.0		77.3		—		120.3
Total revenue from contracts with customers	2,233.3		657.6		28.4		2,919.3
Alternative revenue and other	109.8		16.5		3.3		129.6
Total revenues	$	2,343.1	$	674.1	$	31.7	$	3,048.9
	Nine Months Ended Sept. 30, 2019
(Millions of Dollars)	Electric		Natural Gas		All Other		Total
Major revenue types
Revenue from contracts with customers:
Residential	$	771.9	$	535.6	$	8.4	$	1,315.9
C&I	1,204.7		202.6		20.0		1,427.3
Other	36.1		—		—		36.1
Total retail	2,012.7		738.2		28.4		2,779.3
Wholesale	126.7		—		—		126.7
Transmission	41.4		—		—		41.4
Other	26.4		76.3		—		102.7
Total revenue from contracts with customers	2,207.2		814.5		28.4		3,050.1
Alternative revenue and other	107.6		16.2		3.4		127.2
Total revenues	$	2,314.8	$	830.7	$	31.8	$	3,177.3

XML

Income Taxes (Tables)

9 Months Ended

Sep. 30, 2020

Income Tax Disclosure [Abstract]

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

The following table reconciles the difference between the statutory rate and the ETR:

	Nine Months Ended Sept. 30
	2020		2019
Federal statutory rate	21.0	%	21.0	%
State tax (net of federal tax effect)	3.7		3.7
(Decreases) increases in tax from:
Wind PTCs	(8.5)		(7.7)
Plant regulatory differences (a)	(4.6)		(3.6)
Other tax credits, net NOL & tax credit allowances	(1.1)		(1.3)
Other (net)	(0.8)		(0.6)
Effective income tax rate	9.7	%	11.5	%

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

Summary of Statute of Limitations Applicable to Open Tax Years [Table Text Block]

Federal Audits — PSCo is a member of the Xcel Energy affiliated group that files a consolidated federal income tax return. Statute of limitations applicable to Xcel Energy’s federal income tax returns expire as follows:

Tax Years	Expiration
2014 — 2016	July 2021

Reconciliation of Unrecognized Tax Benefits

Unrecognized tax benefits — permanent vs temporary:

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Unrecognized tax benefit — Permanent tax positions	$	7.1	$	7.4
Unrecognized tax benefit — Temporary tax positions	1.3		4.6
Total unrecognized tax benefit	$	8.4	$	12.0

Tax Benefits Associated with NOL and Tax Credit Carryforwards

Unrecognized tax benefits were reduced by tax benefits associated with NOL and tax credit carryforwards:

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
NOL and tax credit carryforwards	$	(7.0)	$	(8.3)

Interest Payable related to Unrecognized Tax Benefits [Table Text Block]

Interest payable related to unrecognized tax benefits:

(Millions of Dollars)	Sept. 30, 2020		Dec. 31, 2019
Payable for interest related to unrecognized tax benefits at beginning of period	$	(1.1)	$	(0.7)
Interest benefit (expense) related to unrecognized tax benefits	1.1		(0.4)
Payable for interest related to unrecognized tax benefits at end of period	$	—	$	(1.1)

XML

Fair Value of Financial Assets and Liabilities (Tables)

9 Months Ended

Sep. 30, 2020

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, 2020	Dec. 31, 2019
Megawatt hours of electricity	18.1	9.3
Million British thermal units of natural gas	92.8	32.2

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

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

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

	Pre-Tax Fair Value Gains (Losses) Recognized During the Period in:
(Millions of Dollars)	Accumulated Other Comprehensive Loss		Regulatory (Assets) and Liabilities
Three Months Ended Sept. 30, 2020
Other derivative instruments
Natural gas commodity	$	—	$	0.6
Total	$	—	$	0.6
Nine Months Ended Sept. 30, 2020
Other derivative instruments
Natural gas commodity	$	—	$	(2.2)
Total	$	—	$	(2.2)
Three Months Ended Sept. 30, 2019
Other derivative instruments
Natural gas commodity	$	—	$	(2.2)
Total	$	—	$	(2.2)
Nine Months Ended Sept. 30, 2019
Other derivative instruments
Natural gas commodity	$	—	$	(3.7)
Total	$	—	$	(3.7)

	Pre-Tax (Gains) Losses Reclassified into Income During the Period from:						Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Accumulated Other Comprehensive Loss			Regulatory Assets and (Liabilities)
Three Months Ended Sept. 30, 2020
Derivatives designated as cash flow hedges
Interest rate	$	0.4	(a)	$	—		$	—
Total	$	0.4		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	3.2	(b)
Total	$	—		$	—		$	3.2
Nine Months Ended Sept. 30, 2020
Derivatives designated as cash flow hedges
Interest rate	$	1.2	(a)	$	—		$	—
Total	$	1.2		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	(2.1)	(b)
Natural gas commodity	—			3.4		(c)	(3.4)		(c)
Total	$	—		$	3.4		$	(5.5)

(a)    Amounts are recorded to interest charges.

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

(c)    Amounts for the three and nine months ended Sept. 30, 2020, included no settlement gain or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining derivative settlement losses for the three and nine months ended Sept. 30, 2020, relate to natural gas operations and are recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.

	Pre-Tax (Gains) Losses Reclassified into Income During the Period from:						Pre-Tax Gains (Losses) Recognized During the Period in Income
(Millions of Dollars)	Accumulated Other Comprehensive Loss			Regulatory Assets and (Liabilities)
Three Months Ended Sept. 30, 2019
Derivatives designated as cash flow hedges
Interest rate	$	0.4	(a)	$	—		$	—
Total	$	0.4		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	0.6	(b)
Total	$	—		$	—		$	0.6
Nine Months Ended Sept. 30, 2019
Derivatives designated as cash flow hedges
Interest rate	$	1.2	(a)	$	—		$	—
Total	$	1.2		$	—		$	—
Other derivative instruments
Commodity trading	$	—		$	—		$	5.3	(b)
Natural gas commodity	—			(1.3)		(c)	(2.1)		(c)
Total	$	—		$	(1.3)		$	3.2

(a) Amounts are recorded to interest charges.

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

(c)    Amounts for the three and nine months ended Sept. 30, 2019, included no settlement gain or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining derivative settlement losses for the three and nine months ended Sept. 30, 2019, relate to natural gas operations and are recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.

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

	Sept. 30, 2020												Dec. 31, 2019
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative assets
Other derivative instruments:
Commodity trading	$	7.0	$	27.6	$	1.0	$	35.6	$	(27.0)	$	8.6	$	1.9	$	11.1	$	0.9	$	13.9	$	(10.1)	$	3.8
Natural gas commodity	—		10.4		—		10.4		—		10.4		—		3.4		—		3.4		—		3.4
Total current derivative assets	$	7.0	$	38.0	$	1.0	$	46.0	$	(27.0)	$	19.0	$	1.9	$	14.5	$	0.9	$	17.3	$	(10.1)	$	7.2
Noncurrent derivative assets
Other derivative instruments:
Commodity trading	$	1.6	$	9.1	$	2.5	$	13.2	$	(10.1)	$	3.1	$	0.4	$	8.1	$	1.1	$	9.6	$	(9.6)	$	—
Total noncurrent derivative assets	$	1.6	$	9.1	$	2.5	$	13.2	$	(10.1)	$	3.1	$	0.4	$	8.1	$	1.1	$	9.6	$	(9.6)	$	—

	Sept. 30, 2020												Dec. 31, 2019
	Fair Value						Fair Value Total		Netting (a)		Total		Fair Value						Fair Value Total		Netting (a)		Total
(Millions of Dollars)	Level 1		Level 2		Level 3								Level 1		Level 2		Level 3
Current derivative liabilities
Other derivative instruments:
Commodity trading	$	7.0	$	31.6	$	6.3	$	44.9	$	(27.0)	$	17.9	$	1.7	$	16.7	$	—	$	18.4	$	(13.1)	$	5.3
Natural gas commodity	—		2.9		—		2.9		—		2.9		—		3.4		—		3.4		—		3.4
Total current derivative liabilities	$	7.0	$	34.5	$	6.3	$	47.8	$	(27.0)	$	20.8	$	1.7	$	20.1	$	—	$	21.8	$	(13.1)	$	8.7
Noncurrent derivative liabilities
Other derivative instruments:
Commodity trading	$	0.9	$	21.4	$	35.5	$	57.8	$	(15.3)	$	42.5	$	0.4	$	47.0	$	14.7	$	62.1	$	(9.6)	$	52.5
Total noncurrent derivative assets	$	0.9	$	21.4	$	35.5	$	57.8	$	(15.3)	$	42.5	$	0.4	$	47.0	$	14.7	$	62.1	$	(9.6)	$	52.5

(a)PSCo nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at Sept. 30, 2020 and Dec. 31, 2019. At Sept. 30, 2020 and Dec. 31, 2019, derivative liabilities include no obligations to return cash collateral and the right to reclaim cash collateral of $5.2 million and $3.0 million, respectively. The 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)	2020		2019
Balance at July 1	$	(17.1)	$	0.2
Settlements	0.5		(0.5)
Net transactions recorded during the period:
(Losses) gains recognized in earnings (a)	(21.7)		0.5
Balance at Sept. 30	$	(38.3)	$	0.2
	Nine Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Balance at Jan. 1	$	(12.7)	$	0.1
Settlements	(0.6)		(1.4)
Net transactions recorded during the period:
(Losses) gains recognized in earnings (a)	(25.0)		1.5
Balance at Sept. 30	$	(38.3)	$	0.2

(a)Amounts relate to commodity derivatives held at the end of the period.

Carrying Amount and Fair Value of Long-term Debt

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

	Sept. 30, 2020				Dec. 31, 2019
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	5,722.7	$	6,932.2	$	5,384.7	$	6,039.3

XML

Benefit Plans and Other Postretirement Benefits (Tables)

9 Months Ended

Sep. 30, 2020

Retirement Benefits [Abstract]

Components of Net Periodic Benefit Cost (Credit)

Components of Net Periodic Benefit Cost (Credit)

	Three Months Ended Sept. 30
	2020		2019		2020		2019
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	7.6	$	6.4	$	0.1	$	0.1
Interest cost (a)	11.4		12.9		3.2		3.9
Expected return on plan assets (a)	(17.6)		(17.1)		(4.4)		(4.7)
Amortization of prior service credit (a)	(0.7)		(0.8)		(1.0)		(1.3)
Amortization of net loss (a)	7.5		6.3		0.4		0.7
Net periodic benefit cost (credit)	8.2		7.7		(1.7)		(1.3)
Effects of regulation	2.9		0.8		0.6		0.4
Net benefit cost (credit) recognized for financial reporting	$	11.1	$	8.5	$	(1.1)	$	(0.9)
	Nine Months Ended Sept. 30
	2020		2019		2020		2019
(Millions of Dollars)	Pension Benefits				Postretirement Health Care Benefits
Service cost	$	22.9	$	19.2	$	0.2	$	0.4
Interest cost (a)	34.3		38.7		9.5		11.7
Expected return on plan assets (a)	(52.9)		(51.4)		(13.1)		(14.2)
Amortization of prior service credit (a)	(2.1)		(2.5)		(2.8)		(4.1)
Amortization of net loss (a)	22.4		19.1		1.2		2.2
Net periodic benefit cost (credit)	24.6		23.1		(5.0)		(4.0)
Effects of regulation	3.3		4.4		2.2		0.9
Net benefit cost (credit) recognized for financial reporting	$	27.9	$	27.5	$	(2.8)	$	(3.1)

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

^[1]

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

XML

Other Comprehensive Income (Loss) (Tables)

9 Months Ended

Sep. 30, 2020

Stockholders' Equity Note [Abstract]

Changes in Accumulated Other Comprehensive Loss, Net of Tax

Changes in accumulated other comprehensive loss, net of tax, for the three and nine months ended Sept. 30, 2020 and 2019:

	Three Months Ended Sept. 30, 2020						Three Months Ended Sept. 30, 2019
(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	$	(23.5)	$	(2.5)	$	(26.0)	$	(24.7)	$	(0.2)	$	(24.9)
Losses reclassified from net accumulated other comprehensive loss:
Interest rate derivatives (net of taxes of $0.1, $—, $0.1 and $—, respectively) (a)	0.3		—		0.3		0.3		—		0.3
Net current period other comprehensive income	0.3		—		0.3		0.3		—		0.3
Accumulated other comprehensive loss at Sept. 30	$	(23.2)	$	(2.5)	$	(25.7)	$	(24.4)	$	(0.2)	$	(24.6)

XML

Segment Information (Tables)

9 Months Ended

Sep. 30, 2020

Segment Reporting [Abstract]

Results from Operations by Reportable Segment

PSCo’s segment information for the three and nine months ended Sept. 30:

	Three Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Regulated Electric
Operating revenues	$	915.9	$	880.7
Intersegment revenue	0.1		0.1
Total revenues	$	916.0	$	880.8
Net income	214.5		204.7
Regulated Natural Gas
Operating revenues	$	156.4	$	153.9
Intersegment revenue	0.1		0.1
Total revenues	$	156.5	$	154.0
Net income	4.4		0.7
All Other
Operating revenues (a)	$	8.8	$	9.7
Net loss	(0.5)		(0.9)
Consolidated Total
Operating revenues (a)	$	1,081.3	$	1,044.5
Reconciling eliminations	(0.2)		(0.2)
Total operating revenues	$	1,081.1	$	1,044.3
Net income	218.4		204.5

(a)    Operating revenues include $1.1 million of other affiliate revenue for the three months ended Sept. 30, 2020 and 2019.

	Nine Months Ended Sept. 30
(Millions of Dollars)	2020		2019
Regulated Electric
Operating revenues	$	2,343.1	$	2,314.8
Intersegment revenue	0.3		0.3
Total revenues	$	2,343.4	$	2,315.1
Net income	377.5		371.9
Regulated Natural Gas
Operating revenues	$	674.1	$	830.7
Intersegment revenues	—		0.2
Total revenues	$	674.1	$	830.9
Net income	72.5		77.5
All Other
Operating revenues (a)	$	31.7	$	31.8
Net income (loss)	5.2		(4.6)
Consolidated Total
Operating revenues (a)	$	3,049.2	$	3,177.8
Reconciling eliminations	(0.3)		(0.5)
Total operating revenues	$	3,048.9	$	3,177.3
Net income	455.2		444.8

(a)    Operating revenues include $3.3 million of other affiliate revenue for the nine months ended Sept. 30, 2020 and 2019

^[1],[2]

[1] Operating revenues include $1.1 million of other affiliate revenue for the three months ended Sept. 30, 2020 and 2019.

[2] Operating revenues include $3.3 million of other affiliate revenue for the nine months ended Sept. 30, 2020 and 2019.

XML

Accounting Pronouncements (Details) - USD ($) $ in Millions		9 Months Ended
	Jan. 01, 2020	Sep. 30, 2020
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Credit Losses, Topic 326 (ASC Topic 326)		$ 0.7
Retained Earnings
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Credit Losses, Topic 326 (ASC Topic 326)	$ 0.7	$ 0.7

XML

Selected Balance Sheet Data (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Accounts receivable, net
Accounts receivable	$ 350.6	$ 324.9
Less allowance for bad debts	(25.7)	(21.0)
Accounts receivable, net	$ 324.9	$ 303.9

XML

Selected Balance Sheet Data Balance Sheet Related Disclosures, Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Public Utilities, Inventory [Line Items]
Total inventories	$ 177.0	$ 192.0
Materials and supplies
Public Utilities, Inventory [Line Items]
Inventories	63.9	62.6
Fuel
Public Utilities, Inventory [Line Items]
Inventories	63.8	77.1
Natural gas
Public Utilities, Inventory [Line Items]
Inventories	$ 49.3	$ 52.3

XML

Selected Balance Sheet Data Balance Sheet Related Disclosures, Property, Plant and Equipment (Details) - USD ($) $ in Millions		Sep. 30, 2020	Dec. 31, 2019
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		$ 22,464.5	$ 21,279.4
Less accumulated depreciation		(5,260.0)	(5,124.4)
Property, plant and equipment, net		17,204.5	16,155.0
Electric plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		15,512.7	14,361.9
Natural gas plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		4,894.2	4,631.4
Common and other property
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		1,157.3	1,113.5
Plant to be retired
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	[1]	286.8	259.9
Construction work in progress
Public Utility, Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross		$ 613.5	$ 912.7

[1] In 2018, the CPUC approved early retirement of PSCo’s Comanche Units 1 and 2 in approximately 2022 and 2025, respectively. PSCo also expects Craig Unit 1 to be retired early in 2025. Amounts are presented net of accumulated depreciation.

XML

Borrowings and Other Financing Instruments - Short-Term Borrowings (Details) - USD ($)	3 Months Ended	12 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Money Pool
Short-term Debt [Line Items]
Borrowing limit	$ 250,000,000	$ 250,000,000
Short-term Debt	61,000,000	39,000,000
Average amount outstanding	4,000,000	7,000,000
Maximum amount outstanding	$ 71,000,000	$ 50,000,000
Weighted average interest rate, computed on a daily basis (percentage)	0.09%	2.29%
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.90%	1.63%
Commercial Paper
Short-term Debt [Line Items]
Borrowing limit	$ 700,000,000	$ 700,000,000
Short-term Debt	0	0
Average amount outstanding	0	154,000,000
Maximum amount outstanding	$ 0	$ 432,000,000
Weighted average interest rate, computed on a daily basis (percentage)		2.67%

XML

Borrowings and Other Financing Instruments - Letters of Credit (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Line of Credit Facility [Line Items]
Term of letters of credit (in years)	1 year
Letter of Credit
Line of Credit Facility [Line Items]
Short-term Debt	$ 8	$ 9
Letter of Credit | Letter of Credit
Line of Credit Facility [Line Items]
Term of letters of credit (in years)	1 year

XML

Borrowings and Other Financing Instruments - Credit Facility (Details)		9 Months Ended
		Sep. 30, 2020 USD ($) Plan	Dec. 31, 2019 USD ($)
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]	8,000,000
Available		692,000,000
Direct advances on the credit facility outstanding		$ 0	$ 0

[1] Expires in June 2024.

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

XML

Borrowings and Other Financing Instruments - Borrowings and Other Financing Instruments, Long-Term Borrowings and Other Financing Instruments (Details) - USD ($)	9 Months Ended
	Sep. 30, 2020	May 15, 2020
Debt Instrument [Line Items]
Term of letters of credit (in years)	1 year
Bonds [Member] | Series Due Jan. 15, 2051 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 375,000,000
Debt Instrument, Interest Rate, Stated Percentage		2.70%
Bonds [Member] | Series due Jan. 15, 2031 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 375,000,000
Debt Instrument, Interest Rate, Stated Percentage		1.90%

XML

Revenues (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ 1,039.4	$ 1,001.5	$ 2,919.3	$ 3,050.1
Retail
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	922.6	915.1	2,604.0	2,779.3
Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	442.7	412.5	1,265.0	1,315.9
Retail | Commercial and Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	468.6	490.8	1,303.8	1,427.3
Retail | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	11.3	11.8	35.2	36.1
Wholesale Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	61.2	40.3	150.0	126.7
Transmission Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	17.8	16.4	45.0	41.4
Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	37.8	29.7	120.3	102.7
Alternative and Other [Member]
Disaggregation of Revenue [Line Items]
Alternative revenue and other	41.7	42.8	129.6	127.2
Regulated Electric | Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	879.3	844.5	2,233.3	2,207.2
Regulated Electric | Retail
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	786.6	779.5	1,995.3	2,012.7
Regulated Electric | Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	344.1	315.3	825.4	771.9
Regulated Electric | Retail | Commercial and Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	431.2	452.4	1,134.7	1,204.7
Regulated Electric | Retail | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	11.3	11.8	35.2	36.1
Regulated Electric | Wholesale Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	61.2	40.3	150.0	126.7
Regulated Electric | Transmission Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	17.8	16.4	45.0	41.4
Regulated Electric | Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	13.7	8.3	43.0	26.4
Regulated Electric | Alternative and Other [Member]
Disaggregation of Revenue [Line Items]
Alternative revenue and other	36.6	36.2	109.8	107.6
Regulated Natural Gas | Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	152.4	148.4	657.6	814.5
Regulated Natural Gas | Retail
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	128.3	127.0	580.3	738.2
Regulated Natural Gas | Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	95.5	94.1	430.6	535.6
Regulated Natural Gas | Retail | Commercial and Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	32.8	32.9	149.7	202.6
Regulated Natural Gas | Retail | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0.0	0.0	0.0	0.0
Regulated Natural Gas | Wholesale Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0.0	0.0	0.0	0.0
Regulated Natural Gas | Transmission Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0.0	0.0	0.0	0.0
Regulated Natural Gas | Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	24.1	21.4	77.3	76.3
Regulated Natural Gas | Alternative and Other [Member]
Disaggregation of Revenue [Line Items]
Alternative revenue and other	4.0	5.5	16.5	16.2
All Other | Total revenue from contracts with customers
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	7.7	8.6	28.4	28.4
All Other | Retail
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	7.7	8.6	28.4	28.4
All Other | Retail | Residential
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	3.1	3.1	9.0	8.4
All Other | Retail | Commercial and Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	4.6	5.5	19.4	20.0
All Other | Retail | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0.0	0.0	0.0	0.0
All Other | Wholesale Distribution [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0.0	0.0	0.0	0.0
All Other | Transmission Services [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0.0	0.0	0.0	0.0
All Other | Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0.0	0.0	0.0	0.0
All Other | Alternative and Other [Member]
Disaggregation of Revenue [Line Items]
Alternative revenue and other	1.1	1.1	3.3	3.4
Total revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,081.1	1,044.3	3,048.9	3,177.3
Total revenues | Regulated Electric
Disaggregation of Revenue [Line Items]
Total operating revenues	915.9	880.7	2,343.1	2,314.8
Total revenues | Regulated Natural Gas
Disaggregation of Revenue [Line Items]
Total operating revenues	156.4	153.9	674.1	830.7
Total revenues | All Other
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 8.8	$ 9.7	$ 31.7	$ 31.8

XML

Income Taxes (Details) - USD ($) $ in Millions		3 Months Ended	9 Months Ended
		Mar. 31, 2020	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Unrecognized Tax Benefits			$ 8.4		$ 12.0
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			3.70%	3.70%
Effective Income Tax Rate Reconciliation, Tax Credit, Percent			(8.50%)	(7.70%)
Effective Income Tax Rate Reconciliation, Other Regulatory Items, Percent	[1]		(4.60%)	(3.60%)
Regulatory differences - reversal of prior quarters' ARAM deferral (b)			(1.10%)	(1.30%)
Effective Income Tax Rate Reconciliation, Other Adjustments, Percent			(0.80%)	(0.60%)
Effective Income Tax Rate Reconciliation, Percent			9.70%	11.50%
Federal income tax adjustment			$ 0.0
State income tax adjustment			0.0
Unrecognized Tax Benefits [Abstract]
Unrecognized tax benefit — Permanent tax positions			7.1		7.4
Unrecognized tax benefit — Temporary tax positions			1.3		4.6
Total unrecognized tax benefit			8.4		12.0
NOL and tax credit carryforwards			(7.0)		(8.3)
Net Deferred Tax Liability associated with the Unrecognized Tax Benefit Amounts and Related NOLs and Tax Credit Carryforwards			(5.7)		(5.0)
Upper bound of decrease in unrecognized tax benefit that is reasonably possible			2.8
Amounts accrued for penalties related to unrecognized tax benefits			0.0		$ 0.0
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Payable for interest related to unrecognized tax benefits at beginning of period		$ (1.1)	(1.1)	$ (0.7)
Interest benefit (expense) related to unrecognized tax benefits		$ (0.4)	(1.1)
Payable for interest related to unrecognized tax benefits at end of period			$ 0.0

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

XML

Interest Rate Derivatives (Details) $ in Millions	Sep. 30, 2020 USD ($)
Interest Rate Swap
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	$ 1.2

XML

Commodity Derivatives (Details) MWh in Millions, MMBTU in Millions, $ in Millions		Sep. 30, 2020 USD ($) MWh MMBTU	Dec. 31, 2019 MWh MMBTU
cash flow hedge commodity [Member]
Derivative [Line Items]
Commodity contracts designated as cash flow hedges | $		$ 0.0
Electric Commodity (in megawatt hours)
Derivative [Line Items]
Derivative, Nonmonetary Notional amount | MWh	[1],[2]	18.1	9.3
Natural Gas Commodity (in million British thermal units)
Derivative [Line Items]
Derivative, Nonmonetary Notional amount | MMBTU	[1],[2]	92.8	32.2

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

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

XML

Consideration of Credit Risk and Concentrations (Details) $ in Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2020 USD ($) Counterparty		Sep. 30, 2019 USD ($)		Sep. 30, 2020 USD ($) Counterparty		Sep. 30, 2019 USD ($)
Consideration of Credit Risk and Concentrations [Abstract]
Derivative instruments designated as fair value hedges	$ 0.0		$ 0.0		$ 0.0		$ 0.0
Other Derivative Instruments
Consideration of Credit Risk and Concentrations [Abstract]
Pre-tax fair value gains (losses) recognized during the period in accumulated other comprehensive loss	0.0		0.0		0.0		0.0
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities	0.6		(2.2)		(2.2)		(3.7)
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0.0		0.0		0.0		0.0
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)	0.0		0.0		(3.4)		(1.3)
Pre-tax gains (losses) recognized during the period in income	3.2		0.6		(5.5)		3.2
Other Derivative Instruments | Natural Gas Commodity
Consideration of Credit Risk and Concentrations [Abstract]
Pre-tax fair value gains (losses) recognized during the period in accumulated other comprehensive loss	0.0		0.0		0.0		0.0
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities	0.6		(2.2)		(2.2)		(3.7)
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)					(3.4)	[1]	(1.3)	[2]
Pre-tax gains (losses) recognized during the period in income					(3.4)	[1]	(2.1)	[2]
Other Derivative Instruments | Commodity Trading
Consideration of Credit Risk and Concentrations [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0.0		0.0		0.0		0.0
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)	0.0		0.0		0.0		0.0
Pre-tax gains (losses) recognized during the period in income	3.2	[3]	0.6	[4]	(2.1)	[3]	5.3	[4]
Other Derivative Instruments | Natural Gas [Member]
Consideration of Credit Risk and Concentrations [Abstract]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities	0.0		0.0		0.0		0.0
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	0.4		0.4		1.2		1.2
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)	0.0		0.0		0.0		0.0
Pre-tax gains (losses) recognized during the period in income	0.0		0.0		0.0		0.0
Designated as Hedging Instrument | Interest Rate | Cash Flow Hedges
Consideration of Credit Risk and Concentrations [Abstract]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0.4	[5]	0.4	[6]	1.2	[5]	1.2	[6]
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)	0.0		0.0		0.0		0.0
Pre-tax gains (losses) recognized during the period in income	$ 0.0		$ 0.0		$ 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	8				8
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	5				5
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties	$ 108.3				$ 108.3
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)	74.00%				74.00%
Credit Concentration Risk | No Investment Grade Ratings from External Credit Rating Agencies [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	$ 22.6				$ 22.6
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)	15.00%				15.00%
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	1				1
Wholesale, trading and non-trading commodity credit exposure for the most significant counterparties	$ 2.9				$ 2.9
Percentage of wholesale, trading and non-trading commodity credit exposure for the most significant counterparties (in hundredths)	2.00%				2.00%

[1] Amounts for the three and nine months ended Sept. 30, 2020, included no settlement gain or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining derivative settlement losses for the three and nine months ended Sept. 30, 2020, relate to natural gas operations and are recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.

[2] Amounts for the three and nine months ended Sept. 30, 2019, included no settlement gain or losses on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset, as appropriate. Remaining derivative settlement losses for the three and nine months ended Sept. 30, 2019, relate to natural gas operations and are recorded to cost of natural gas sold and transported. These gains and losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.

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

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

[5] Amounts are recorded to interest charges.

[6] Amounts are recorded to interest charges.

XML

Credit Related Contingent Features (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Derivative instruments in a gross liability position	$ 0.1	$ 0.0
Collateral posted related to adequate assurance clauses in derivative contracts	$ 0.0	$ 0.0

XML

Recurring Fair Value Measurements (Details) - USD ($) $ in Millions		Sep. 30, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Return Cash Collateral		$ 0.0	$ 0.0
Reclaim Cash Collateral		5.2	3.0
Fair Value Measured on a Recurring Basis | Other Current Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		46.0	17.3
Netting	[1]	(27.0)	(10.1)
Derivative Asset, Net		19.0	7.2
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		7.0	1.9
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		38.0	14.5
Fair Value Measured on a Recurring Basis | Other Current Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		1.0	0.9
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		35.6	13.9
Netting	[1]	(27.0)	(10.1)
Derivative Asset, Net		8.6	3.8
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		10.4	3.4
Netting	[1]	0.0	0.0
Derivative Asset, Net		10.4	3.4
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		7.0	1.9
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 1 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		0.0	0.0
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 2 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		27.6	11.1
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 2 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		10.4	3.4
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		1.0	0.9
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Level 3 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		0.0	0.0
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		13.2	9.6
Netting	[1]	(10.1)	(9.6)
Derivative Asset, Net		3.1	0.0
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 1
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		1.6	0.4
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 2
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		9.1	8.1
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Level 3
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		2.5	1.1
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		13.2	9.6
Netting	[1]	(10.1)	(9.6)
Derivative Asset, Net		3.1	0.0
Fair Value Measured on a Recurring Basis | Other Noncurrent Assets | Other Derivative Instruments | Level 1 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Asset, Gross		1.6	0.4
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		9.1	8.1
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		2.5	1.1
Fair Value Measured on a Recurring Basis | Other Current Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		47.8	21.8
Netting	[1]	(27.0)	(13.1)
Derivative Liability, Net		20.8	8.7
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		7.0	1.7
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		34.5	20.1
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		6.3	0.0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		44.9	18.4
Netting	[1]	(27.0)	(13.1)
Derivative Liability, Net		17.9	5.3
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		2.9	3.4
Netting	[1]	0.0	0.0
Derivative Liability, Net		2.9	3.4
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 1 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		7.0	1.7
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 1 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		0.0	0.0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 2 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		31.6	16.7
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 2 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		2.9	3.4
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 3 | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		6.3	0.0
Fair Value Measured on a Recurring Basis | Other Current Liabilities | Other Derivative Instruments | Level 3 | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		0.0	0.0
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		57.8	62.1
Netting	[1]	(15.3)	(9.6)
Derivative Liability, Net		42.5	52.5
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 1
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		0.9	0.4
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 2
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		21.4	47.0
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Level 3
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		35.5	14.7
Fair Value Measured on a Recurring Basis | Other Noncurrent Liabilities | Other Derivative Instruments | Commodity Trading
Derivatives, Fair Value [Line Items]
Derivative Liability, Gross		57.8	62.1
Netting	[1]	(15.3)	(9.6)
Derivative Liability, Net		42.5	52.5
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		0.9	0.4
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		21.4	47.0
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		$ 35.5	$ 14.7

[1] PSCo nets derivative instruments and related collateral on its consolidated balance sheets when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at Sept. 30, 2020 and Dec. 31, 2019. At Sept. 30, 2020 and Dec. 31, 2019, derivative liabilities include no obligations to return cash collateral and the right to reclaim cash collateral of $5.2 million and $3.0 million, respectively. The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.

XML

Changes in Level 3 Commodity Derivatives (Details) - Commodity Contract - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance		$ (17.1)	$ 0.2	$ (12.7)	$ 0.1
Settlements		0.5	(0.5)	(0.6)	(1.4)
(Losses) gains recognized in earnings	[1]	(21.7)	0.5	(25.0)	1.5
Ending Balance		(38.3)	0.2	(38.3)	0.2
Transfers Level 3, Net		$ 0.0	$ 0.0	$ 0.0	$ 0.0

[1] Amounts relate to commodity derivatives held at the end of the period.

XML

Fair Value of Long-Term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 5,722.7	$ 5,384.7
Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value	$ 6,932.2	$ 6,039.3

XML

Benefit Plans and Other Postretirement Benefits (Details) $ in Millions		1 Months Ended	3 Months Ended		9 Months Ended
		Jan. 31, 2020 USD ($) Plan	Sep. 30, 2020 USD ($)	Sep. 30, 2019 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2019 USD ($)
Pension Plan [Member]
Components of Net Periodic Benefit Cost (Credit) [Abstract]
Service cost			$ 7.6	$ 6.4	$ 22.9	$ 19.2
Interest Cost	[1]		11.4	12.9	34.3	38.7
Expected return on Plan Assets	[1]		(17.6)	(17.1)	(52.9)	(51.4)
Amortization of prior service credit	[1]		(0.7)	(0.8)	(2.1)	(2.5)
Amortization of net loss	[1]		7.5	6.3	22.4	19.1
Net periodic benefit cost (credit)			8.2	7.7	24.6	23.1
Effects of regulation			2.9	0.8	3.3	4.4
Net benefit cost (credit) recognized for financial reporting			11.1	8.5	27.9	27.5
Total contributions to the pension plans during the period		$ 50.0
Pension Plan [Member] | Xcel Energy Inc.
Components of Net Periodic Benefit Cost (Credit) [Abstract]
Total contributions to the pension plans during the period		$ 150.0
Number of Xcel Energy's pension plans to which contributions were made | Plan		4
Other Postretirement Benefits Plan [Member]
Components of Net Periodic Benefit Cost (Credit) [Abstract]
Service cost			0.1	0.1	0.2	0.4
Interest Cost	[1]		3.2	3.9	9.5	11.7
Expected return on Plan Assets	[1]		(4.4)	(4.7)	(13.1)	(14.2)
Amortization of prior service credit	[1]		(1.0)	(1.3)	(2.8)	(4.1)
Amortization of net loss	[1]		0.4	0.7	1.2	2.2
Net periodic benefit cost (credit)			(1.7)	(1.3)	(5.0)	(4.0)
Effects of regulation			0.6	0.4	2.2	0.9
Net benefit cost (credit) recognized for financial reporting			$ (1.1)	$ (0.9)	$ (2.8)	$ (3.1)

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

XML

Gas Trading Litigation (Details)	Sep. 30, 2020 Plan
Gas Trading Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number	2

XML

Commitments and Contingencies - MGP, Landfill and Disposal Sites (Details)	Sep. 30, 2020
Other MGP, Landfill, or Disposal Sites
Loss Contingencies [Line Items]
Number of identified MGP sites under current investigation and/or remediation	3

XML

Commitments and Contingencies - Environmental Requirements - Water and Waste (Details)	Sep. 30, 2020	Dec. 31, 2019
Federal Coal Ash Regulation
Site Contingency [Line Items]
Number of sites where regulated ash units will still be in operation at a specified date	6
Number of sites where statistically significant increases over established groundwater standards exist		4
Number of sites where corrective action options are being evaluated for locations with statistically significant increases above background concentrations	2
Number of sites where monitoring results indicate potential offsite impacts to groundwater	1
Federal Coal Ash Regulation [Domain]
Site Contingency [Line Items]
Number of facilities where alternative storage capacity options consistent with the CCR Rule are being pursued	1

XML

Commitments and Contingencies - Variable Interest Entities (Details) - MW	Sep. 30, 2020	Dec. 31, 2019
Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member]
Variable Interest Entity [Line Items]
Generating capacity under long term purchased power agreements (in MW)	1,518	1,442

XML

Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2020		Sep. 30, 2019		Sep. 30, 2020		Sep. 30, 2019
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period					$ 6,996.2
Income Tax Expense (Benefit)	$ 24.0		$ 28.0		49.1		$ 57.7
Accumulated other comprehensive loss at end of period	7,510.7				7,510.7
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	(23.5)		(24.7)		(24.1)		(25.3)
Net current period other comprehensive loss	0.3		0.3		0.9		0.9
Accumulated other comprehensive loss at end of period	(23.2)		(24.4)		(23.2)		(24.4)
Gains and Losses on Cash Flow Hedges | Reclassification out of Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Income Tax Expense (Benefit)	0.1		0.1		0.3		0.3
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	(0.3)	[1]	(0.3)	[1]	(0.9)	[2]	(0.9)	[2]
Defined Benefit and Postretirement Items
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period	(2.5)		(0.2)		(2.5)		(0.2)
Net current period other comprehensive loss	0.0		0.0		0.0		0.0
Accumulated other comprehensive loss at end of period	(2.5)		(0.2)		(2.5)		(0.2)
Defined Benefit and Postretirement Items | Reclassification out of Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Income Tax Expense (Benefit)	0.0		0.0		0.0		0.0
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	0.0	[1]	0.0	[1]	0.0	[2]	0.0	[2]
Total
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period	(26.0)		(24.9)		(26.6)		(25.5)
Net current period other comprehensive loss	0.3		0.3		0.9		0.9
Accumulated other comprehensive loss at end of period	(25.7)		(24.6)		(25.7)		(24.6)
Total | Interest Rate Swap
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Losses reclassified from net accumulated other comprehensive loss	$ (0.3)	[1]	$ (0.3)	[1]	$ (0.9)	[2]	$ (0.9)	[2]

[1] Included in interest charges.

[2] Included in interest charges.

XML

Segment Information (Details) - USD ($) $ in Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2020		Sep. 30, 2019		Sep. 30, 2020		Sep. 30, 2019
Segment Reporting Information [Line Items]
Net income	$ 218.4		$ 204.5		$ 455.2		$ 444.8
Regulated Operating Revenue, Electric	915.9		880.7		2,343.1		2,314.8
Regulated Operating Revenue, Gas	156.4		153.9		674.1		830.7
Unregulated Operating Revenue	8.8		9.7		31.7		31.8
Regulated and Unregulated Operating Revenue	1,081.1		1,044.3		3,048.9		3,177.3
Affiliate Revenue	1.1		1.1		3.3		3.3
Electric
Segment Reporting Information [Line Items]
Net income	214.5		204.7		377.5		371.9
Revenues Including Intersegment Revenues	916.0		880.8		2,343.4		2,315.1
Natural gas
Segment Reporting Information [Line Items]
Net income	4.4		0.7		72.5		77.5
Revenues Including Intersegment Revenues	156.5		154.0		674.1		830.9
All Other
Segment Reporting Information [Line Items]
Net income	(0.5)		(0.9)		5.2		(4.6)
Total revenues
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue	1,081.3	[1]	1,044.5	[1]	3,049.2	[2]	3,177.8	[2]
Total revenues | Electric
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Electric	915.9		880.7		2,343.1		2,314.8
Total revenues | Natural gas
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Gas	156.4		153.9		674.1		830.7
Total revenues | All Other
Segment Reporting Information [Line Items]
Unregulated Operating Revenue	8.8	[3]	9.7	[1]	31.7	[2]	31.8	[2]
Intersegment Eliminations
Segment Reporting Information [Line Items]
Regulated and Unregulated Operating Revenue	(0.2)		(0.2)		(0.3)		(0.5)
Intersegment Eliminations | Electric
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Electric	0.1		0.1		0.3		0.3
Intersegment Eliminations | Natural gas
Segment Reporting Information [Line Items]
Regulated Operating Revenue, Gas	$ 0.1		$ 0.1		$ 0.0		$ 0.2

[1] Operating revenues include $1.1 million of other affiliate revenue for the three months ended Sept. 30, 2020 and 2019.

[2] Operating revenues include $3.3 million of other affiliate revenue for the nine months ended Sept. 30, 2020 and 2019.

[3] Operating revenues include $1.1 million of other affiliate revenue for the three months ended Sept. 30, 2020 and 2019.