10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended June 30, 2023.

OR

☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from __________ to __________.

Commission file number  001-36108

ONE Gas, Inc.

(Exact name of registrant as specified in its charter)

Oklahoma		46-3561936
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)
15 East Fifth Street
Tulsa,	OK	74103
(Address of principal executive offices)		(Zip Code)

Registrant’s telephone number, including area code   (918) 947-7000

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

Title of each class	Trading Symbol	Name of exchange on which registered
Common Stock, par value $0.01 per share	OGS	New York Stock Exchange

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, 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  ☒

On July 24, 2023, the Company had 55,449,300 shares of common stock outstanding.

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ONE Gas, Inc.

TABLE OF CONTENTS

Part I.	Financial Information	Page No.
Item 1.	Consolidated Financial Statements (Unaudited)	6
	Consolidated Statements of Income - Three and Six Months Ended June 30, 2023 and 2022	6
	Consolidated Statements of Comprehensive Income - Three and Six Months Ended June 30, 2023 and 2022	7
	Consolidated Balance Sheets - June 30, 2023 and December 31, 2022	8
	Consolidated Statements of Cash Flows - Six Months Ended June 30, 2023 and 2022	10
	Consolidated Statements of Equity - Three and Six Months Ended June 30, 2023 and 2022	11
	Notes to Consolidated Financial Statements	12
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	37
Item 4.	Controls and Procedures	37
Part II.	Other Information	38
Item 1.	Legal Proceedings	38
Item 1A.	Risk Factors	38
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	38
Item 3.	Defaults Upon Senior Securities	38
Item 4.	Mine Safety Disclosures	38
Item 5.	Other Information	38
Item 6.	Exhibits	38
Signature		40

As used in this Quarterly Report, references to “we,” “our,” “us” or the “Company” refer to ONE Gas, Inc., an Oklahoma corporation, and its predecessors and subsidiaries, unless the context indicates otherwise.

The statements in this Quarterly Report that are not historical information, including statements concerning plans and objectives of management for future operations, economic performance or related assumptions, are forward-looking statements. Forward-looking statements may include words such as “will,” “anticipate,” “estimate,” “expect,” “project,” “intend,” “plan,” “believe,” “should,” “goal,” “forecast,” “guidance,” “could,” “may,” “continue,” “might,” “potential,” “scheduled,” “likely” and other words and terms of similar meaning. Although we believe that our expectations regarding future events are based on reasonable assumptions, we can give no assurance that such expectations and assumptions will be achieved. Important factors that could cause actual results to differ materially from those in the forward-looking statements are described under Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations, “Forward-Looking Statements,” and Part II, Item 1A, “Risk Factors” in this Quarterly Report and under Part I, Item IA, “Risk Factors,” in our Annual Report.

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AVAILABLE INFORMATION

We make available, free of charge, on our website (www.onegas.com) our Annual Reports, Quarterly Reports, Current Reports on Form 8-K, amendments to those reports filed or furnished to the SEC pursuant to Section 13(a) or 15(d) of the Exchange Act and reports of holdings of our securities filed by our officers and directors under Section 16 of the Exchange Act. Such materials are available as soon as reasonably practicable after filing such material electronically or otherwise furnishing it to the SEC, which also makes these materials available on its website (www.sec.gov). Our Code of Business Conduct and Ethics, Corporate Governance Guidelines, Certificate of Incorporation, bylaws, the written charters of our Audit Committee, Executive Compensation Committee, Corporate Governance Committee and Executive Committee and our ESG Report are also available on our website, and copies of these documents are available upon request.

In addition to filings with the SEC and materials posted on our website, we also use social media platforms as channels of information distribution to reach investors and other stakeholders. Information contained on our website and posted on or disseminated through our social media accounts is not incorporated by reference into this report.

4

GLOSSARY - The abbreviations, acronyms and industry terminology used in this Quarterly Report are defined as follows:

AAO	Accounting Authority Order
ADIT	Accumulated deferred income taxes
Annual Report	Annual Report on Form 10-K for the year ended December 31, 2022
ASC	Accounting Standards Codification
Bcf	Billion cubic feet
CAA	Federal Clean Air Act, as amended
Dth	Dekatherm
EDIT	Excess deferred income taxes resulting from a change in enacted tax rates
EPS	Earnings per share
ESG	Environmental, social and governance
Exchange Act	Securities Exchange Act of 1934, as amended
GAAP	Accounting principles generally accepted in the United States of America
GRIP	Gas Reliability Infrastructure Program
HDD	Heating degree day is a measure designed to reflect the demand for energy needed for heating based on the extent to which the daily average temperature falls below a reference temperature for which no heating is required, usually 65 degrees Fahrenheit
IT	Information Technology
KCC	Kansas Corporation Commission
KDHE	Kansas Department of Health and Environment
KGSS-I	Kansas Gas Service Securitization I, L.L.C.
LDC	Local distribution company
MGP	Manufactured gas plant
MMcf	Million cubic feet
Moody’s	Moody’s Investors Service, Inc.
NYSE	New York Stock Exchange
OCC	Oklahoma Corporation Commission
ONE Gas	ONE Gas, Inc.
ONE Gas Credit Agreement	ONE Gas’ $1.0 billion revolving credit agreement, as amended
PBRC	Performance-Based Rate Change
PHMSA	United States Department of Transportation Pipeline and Hazardous Materials Safety Administration
PIPES Act	Protecting Our Infrastructure of Pipelines and Enhancing Safety (PIPES) Act of 2020
Quarterly Report(s)	Quarterly Report(s) on Form 10-Q
RNG	Renewable natural gas
RRC	Railroad Commission of Texas
S&P	Standard & Poor’s Ratings Services
SEC	Securities and Exchange Commission
Securities Act	Securities Act of 1933, as amended
Securitized Utility Tariff Bonds	Series 2022-A Senior Secured Securitized Utility Tariff Bonds, Tranche A
Senior Notes	ONE Gas’ registered unsecured notes consisting of $300 million of 3.61 percent senior notes due February 2024, $473 million of 1.10 percent senior notes due March 2024, $300 million of 2.00 percent senior notes due May 2030, $300 million of 4.25 percent senior notes due September 2032, $600 million of 4.66 percent senior notes due February 2044 and $400 million of 4.50 percent senior notes due November 2048
TCEQ	Texas Commission on Environmental Quality
TNG Corporation	Texas Natural Gas Securitization Finance Corporation
TPFA	Texas Public Finance Authority
WNA	Weather normalization adjustment(s)
XBRL	eXtensible Business Reporting Language

5

PART I - FINANCIAL INFORMATION

ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS

ONE Gas, Inc.
CONSOLIDATED STATEMENTS OF INCOME
	Three Months Ended				Six Months Ended
	June 30,				June 30,
(Unaudited)	2023		2022		2023		2022
	(Thousands of dollars, except per share amounts)
Total revenues	$	398,114	$	428,975	$	1,430,257	$	1,400,434
Cost of natural gas	130,241		188,251		796,040		828,197
Operating expenses
Operations and maintenance	118,614		110,579		245,298		225,674
Depreciation and amortization	67,547		55,043		138,811		112,180
General taxes	17,690		16,533		36,856		35,057
Total operating expenses	203,851		182,155		420,965		372,911
Operating income	64,022		58,569		213,252		199,326
Other income (expense), net	2,174		(3,983)		4,755		(8,128)
Interest expense, net	(27,485)		(16,320)		(57,600)		(31,915)
Income before income taxes	38,711		38,266		160,407		159,283
Income taxes	(6,022)		(6,191)		(25,097)		(28,274)
Net income	$	32,689	$	32,075	$	135,310	$	131,009
Earnings per share
Basic	$	0.59	$	0.59	$	2.43	$	2.42
Diluted	$	0.58	$	0.59	$	2.42	$	2.42
Average shares (thousands)
Basic	55,566		54,262		55,552		54,092
Diluted	55,914		54,335		55,857		54,183
Dividends declared per share of stock	$	0.65	$	0.62	$	1.30	$	1.24

See accompanying Notes to Consolidated Financial Statements.

6

ONE Gas, Inc.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
	Three Months Ended				Six Months Ended
	June 30,				June 30,
(Unaudited)	2023		2022		2023		2022
	(Thousands of dollars)
Net income	$	32,689	$	32,075	$	135,310	$	131,009
Other comprehensive income, net of tax
Change in pension and other postemployment benefit plan liability, net of tax of $—, $(10), $— and $(29), respectively	—		30		—		99
Total other comprehensive income, net of tax	—		30		—		99
Comprehensive income	$	32,689	$	32,105	$	135,310	$	131,108

See accompanying Notes to Consolidated Financial Statements.

7

ONE Gas, Inc.
CONSOLIDATED BALANCE SHEETS
	June 30,		December 31,
(Unaudited)	2023		2022
Assets	(Thousands of dollars)
Property, plant and equipment
Property, plant and equipment	$	8,117,663	$	7,834,557
Accumulated depreciation and amortization	2,261,035		2,205,717
Net property, plant and equipment	5,856,628		5,628,840
Current assets
Cash and cash equivalents	7,332		9,681
Restricted cash and cash equivalents	32,006		8,446
Total cash, cash equivalents and restricted cash and cash equivalents	39,338		18,127
Accounts receivable, net	234,409		553,834
Materials and supplies	72,594		70,873
Natural gas in storage	144,742		269,205
Regulatory assets	64,912		275,572
Other current assets	31,294		29,997
Total current assets	587,289		1,217,608
Goodwill and other assets
Regulatory assets	304,614		330,831
Securitized intangible asset, net	309,569		323,838
Goodwill	157,953		157,953
Other assets	119,069		117,326
Total goodwill and other assets	891,205		929,948
Total assets	$	7,335,122	$	7,776,396

See accompanying Notes to Consolidated Financial Statements.

8

ONE Gas, Inc.
CONSOLIDATED BALANCE SHEETS
(Continued)
	June 30,		December 31,
(Unaudited)	2023		2022
Equity and Liabilities	(Thousands of dollars)
Equity and long-term debt
Common stock, $0.01 par value: authorized 250,000,000 shares; issued and outstanding 55,446,841 shares at June 30, 2023; issued and outstanding 55,349,954 shares at December 31, 2022	$	554	$	553
Paid-in capital	1,940,446		1,932,714
Retained earnings	714,530		651,863
Accumulated other comprehensive loss	(704)		(704)
Total equity	2,654,826		2,584,426
Other long-term debt, excluding current maturities, net of issuance costs	1,580,263		2,352,400
Securitized utility tariff bonds, excluding current maturities, net of issuance costs	295,949		309,343
Total long-term debt, excluding current maturities, net of issuance costs	1,876,212		2,661,743
Total equity and long-term debt	4,531,038		5,246,169
Current liabilities
Current maturities of other long-term debt	772,838		12
Current maturities of securitized utility tariff bonds	34,201		20,716
Notes payable	217,100		552,000
Accounts payable	154,121		360,493
Accrued taxes other than income	54,400		78,352
Regulatory liabilities	79,686		47,867
Customer deposits	54,635		57,854
Other current liabilities	87,110		72,125
Total current liabilities	1,454,091		1,189,419
Deferred credits and other liabilities
Deferred income taxes	727,184		698,456
Regulatory liabilities	512,633		529,441
Employee benefit obligations	19,620		19,587
Other deferred credits	90,556		93,324
Total deferred credits and other liabilities	1,349,993		1,340,808
Commitments and contingencies
Total liabilities and equity	$	7,335,122	$	7,776,396

See accompanying Notes to Consolidated Financial Statements.

9

ONE Gas, Inc.
CONSOLIDATED STATEMENTS OF CASH FLOWS
	Six Months Ended
	June 30,
(Unaudited)	2023		2022
	(Thousands of dollars)
Operating activities
Net income	$	135,310	$	131,009
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	138,811		112,180
Deferred income taxes	11,912		(18,780)
Share-based compensation expense	6,305		5,699
Provision for doubtful accounts	4,880		2,511
Proceeds from government securitization of winter weather event costs	197,366		—
Changes in assets and liabilities:
Accounts receivable	314,545		100,955
Materials and supplies	(1,721)		(7,927)
Natural gas in storage	124,463		(18,660)
Asset removal costs	(32,551)		(20,919)
Accounts payable	(198,968)		(92,887)
Accrued taxes other than income	(23,952)		(8,852)
Customer deposits	(3,219)		(2,177)
Regulatory assets and liabilities - current	35,633		43,697
Regulatory assets and liabilities - noncurrent	26,217		56,135
Other assets and liabilities - current	12,156		8,234
Other assets and liabilities - noncurrent	1,555		(3,541)
Cash provided by operating activities	748,742		286,677
Investing activities
Capital expenditures	(322,231)		(251,060)
Other investing expenditures	(1,647)		(1,332)
Other investing receipts	2,462		891
Cash used in investing activities	(321,416)		(251,501)
Financing activities
Repayments of notes payable, net	(334,900)		(3,900)
Issuance of common stock	3,175		37,104
Dividends paid	(72,006)		(66,821)
Tax withholdings related to net share settlements of stock compensation	(2,384)		(3,026)
Cash used in financing activities	(406,115)		(36,643)
Change in cash, cash equivalents, restricted cash and restricted cash equivalents	21,211		(1,467)
Cash, cash equivalents, restricted cash and restricted cash equivalents at beginning of period	18,127		8,852
Cash, cash equivalents, restricted cash and restricted cash equivalents at end of period	$	39,338	$	7,385
Supplemental cash flow information:
Cash paid for interest, net of amounts capitalized	$	47,773	$	41,600
Cash paid for income taxes, net	$	9,174	$	16,200

See accompanying Notes to Consolidated Financial Statements.

10

ONE Gas, Inc.
CONSOLIDATED STATEMENTS OF EQUITY
(Unaudited)	Common Stock Issued	Common Stock		Paid-in Capital		Retained Earnings		Accumulated Other Comprehensive Income/(Loss)		Total Equity
	(Shares)	(Thousands of dollars)
January 1, 2023	55,349,954	$	553	$	1,932,714	$	651,863	$	(704)	$	2,584,426
Net income	—	—		—		102,621		—		102,621
Common stock issued and other	39,096			435		—		—		435
Common stock dividends - $0.65 per share	—	—		319		(36,321)		—		(36,002)
March 31, 2023	55,389,050	$	553	$	1,933,468	$	718,163	$	(704)	$	2,651,480
Net income	—	—		—		32,689		—		32,689
Common stock issued and other	57,791	1		6,660		—		—		6,661
Common stock dividends - $0.65 per share	—	—		318		(36,322)		—		(36,004)
June 30, 2023	55,446,841	$	554	$	1,940,446	$	714,530	$	(704)	$	2,654,826
January 1, 2022	53,633,210	$	536	$	1,790,362	$	565,161	$	(6,527)	$	2,349,532
Net income	—	—		—		98,934		—		98,934
Other comprehensive income	—	—		—		—		69		69
Common stock issued and other	456,607	5		34,135		—		—		34,140
Common stock dividends - $0.62 per share	—	—		274		(33,559)		—		(33,285)
March 31, 2022	54,089,817	$	541	$	1,824,771	$	630,536	$	(6,458)	$	2,449,390
Net income	—	—		—		32,075		—		32,075
Other comprehensive income	—	—		—		—		30		30
Common stock issued and other	47,400	—		5,636		—		—		5,636
Common stock dividends - $0.62 per share	—	—		271		(33,806)		—		(33,535)
June 30, 2022	54,137,217	$	541	$	1,830,678	$	628,805	$	(6,428)	$	2,453,596

See accompanying Notes to Consolidated Financial Statements.

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ONE Gas, Inc.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1.SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Our accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. These statements also have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair statement of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2022 year-end consolidated balance sheet data was derived from audited consolidated financial statements but does not include all disclosures required by GAAP. These unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and footnotes in our Annual Report. Our significant accounting policies are described in Note 1 of our Notes to Consolidated Financial Statements in our Annual Report. The preparation of these financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts and disclosures in the financial statements. Although management believes these estimates are reasonable, actual results could differ materially from these estimates. Due to the seasonal nature of our business, the results of operations for the six months ended June 30, 2023, are not necessarily indicative of the results that may be expected for a 12-month period.

We provide natural gas distribution services to approximately 2.3 million customers in Oklahoma, Kansas and Texas through our three divisions, Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively. We primarily serve residential, commercial and transportation customers in all three states.

Segments - We operate in one reportable business segment: regulated public utilities that deliver natural gas primarily to residential, commercial and transportation customers. Our accounting policies are the same as those described in Note 1 of the Notes to Consolidated Financial Statements in our Annual Report. We evaluate our financial performance principally on net income. For the three and six months ended June 30, 2023 and 2022, we had no single external customer from which we received 10 percent or more of our gross revenues.

Property, Plant and Equipment and Asset Removal Costs - Accounts payable for construction work in progress and asset removal costs decreased by approximately $7.9 million and $7.8 million for the six months ended June 30, 2023 and 2022, respectively. Such amounts are not included in capital expenditures or asset removal costs in our consolidated statements of cash flows.

Accounts Receivable, net - Accounts receivable represent valid claims against nonaffiliated customers for natural gas sold or services rendered. We assess the creditworthiness of our customers. Those customers who do not meet minimum standards may be required to provide security, including deposits and other forms of collateral, when appropriate and allowed by our tariffs. With approximately 2.3 million customers across three states, we are not exposed materially to a concentration of credit risk. We maintain an allowance for doubtful accounts based upon factors surrounding the credit risk of customers, historical trends, consideration of the current environment and other information. We recover natural gas costs related to accounts written off when they are deemed uncollectible through the purchased-gas cost adjustment mechanisms in each of our jurisdictions. At June 30, 2023 and December 31, 2022, our allowance for doubtful accounts was $17.0 million and $16.7 million, respectively.

Reclassifications -A reclassification has been made in the prior-year financial statements to conform to the current-year presentation. We have updated our consolidated balance sheet at December 31, 2022, to disaggregate “current maturities of other long-term debt,” which had previously been included in “other current liabilities,” to conform to our current-year presentation.

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2.REVENUE

The following table sets forth our revenues disaggregated by source for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(Thousands of dollars)
Natural gas sales to customers	$	346,734	$	393,292	$	1,313,093	$	1,318,449
Transportation revenues	29,022		28,000		67,549		64,316
Securitization customer charges (Note 14)	11,807		—		23,740		—
Miscellaneous revenues	6,313		5,128		12,211		9,624
Total revenues from contracts with customers	393,876		426,420		1,416,593		1,392,389
Other revenues - natural gas sales related	1,614		(115)		7,404		2,231
Other revenues	2,624		2,670		6,260		5,814
Total other revenues	4,238		2,555		13,664		8,045
Total revenues	$	398,114	$	428,975	$	1,430,257	$	1,400,434

Accrued unbilled natural gas sales revenues at June 30, 2023 and December 31, 2022, were $64.5 million and $269.5 million, respectively, and are included in accounts receivable on our consolidated balance sheets.

3.    REGULATORY ASSETS AND LIABILITIES

The tables below present a summary of regulatory assets and liabilities, net of amortization, for the periods indicated:

	June 30, 2023
	Current		Noncurrent		Total
	(Thousands of dollars)
Winter weather event costs	$	22,633	$	26,117	$	48,750
Pension and postemployment benefit costs	4,603		239,975		244,578
Reacquired debt costs	812		2,985		3,797
MGP remediation costs	98		31,891		31,989
Ad-valorem tax	12,125		—		12,125
WNA	7,809		—		7,809
Customer credit deferrals	13,820		—		13,820
Other	3,012		3,646		6,658
Total regulatory assets, net of amortization	64,912		304,614		369,526
Income tax rate changes	—		(512,633)		(512,633)
Over-recovered purchased-gas costs	(79,686)		—		(79,686)
Total regulatory liabilities	(79,686)		(512,633)		(592,319)
Net regulatory assets and liabilities	$	(14,774)	$	(208,019)	$	(222,793)

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	December 31, 2022
	Current		Noncurrent		Total
	(Thousands of dollars)
Winter weather event costs	$	221,926	$	36,291	$	258,217
Under-recovered purchased-gas costs	19,755		—		19,755
Pension and postemployment benefit costs	—		258,257		258,257
Reacquired debt costs	812		3,347		4,159
MGP remediation costs	98		29,743		29,841
Ad-valorem tax	13,359		—		13,359
WNA	8,474		—		8,474
Customer credit deferrals	9,504		—		9,504
Other	1,644		3,193		4,837
Total regulatory assets, net of amortization	275,572		330,831		606,403
Pension and other postemployment benefit costs	(8,228)		—		(8,228)
Income tax rate changes	—		(529,441)		(529,441)
Over-recovered purchased-gas costs	(39,639)		—		(39,639)
Total regulatory liabilities	(47,867)		(529,441)		(577,308)
Net regulatory assets and liabilities	$	227,705	$	(198,610)	$	29,095

Regulatory assets in our consolidated balance sheets, as authorized by various regulatory authorities, are probable of recovery. Base rates and certain riders are designed to provide a recovery of costs during the period such rates are in effect, but do not generally provide for a return on investment for amounts we have deferred as regulatory assets. All of our regulatory assets are subject to review by the respective regulatory authorities during future regulatory proceedings. We are not aware of any evidence that these costs will not be recoverable through either riders, base rates, or securitization.

Winter weather event costs - In February 2021, the U.S. experienced Winter Storm Uri, a historic winter weather event impacting supply, market pricing and demand for natural gas in a number of states, including our service territories of Oklahoma, Kansas, and Texas. During this time, the governors of Oklahoma, Kansas, and Texas each declared a state of emergency, and certain regulatory agencies issued emergency orders that impacted the utility and natural gas industries, including statewide utility curtailment programs and orders requiring jurisdictional natural gas and electric utilities to do all things possible and necessary to ensure that natural gas and electricity utility services continued to be provided to their customers. Due to the historic nature of this winter weather event, we experienced unforeseeable and unprecedented market pricing for natural gas in our Oklahoma, Kansas, and Texas jurisdictions, which resulted in aggregated natural gas purchases for the month of February 2021 of approximately $2.1 billion.

Each state enacted securitization legislation to allow for recovery of the extraordinary gas costs, as well as other authorized expenses related to Winter Storm Uri. Securitization proceeds were received for Oklahoma and Kansas in 2022, and for Texas in 2023. See our Annual Report for more discussion of events surrounding Winter Storm Uri and the securitization of the related regulatory assets.

Texas - Pursuant to securitization legislation enacted in Texas as a result of Winter Storm Uri and a June 2021 RRC Notice to Gas Utilities, Texas Gas Service submitted an application to the RRC in July 2021, for an order authorizing the amount of extraordinary costs for recovery and other such specifications necessary for the issuance of securitized bonds.

In February 2022, the RRC issued a single financing order for Texas Gas Service and other natural gas utilities in Texas participating in the securitization process, which included a determination that the approved costs will be collected from customers over a period of not more than 30 years. The TPFA formed the TNG Corporation, a new independent public authority, to issue the securitized bonds.

In March 2023, the TNG Corporation completed the issuance of the Customer Rate Relief (Winter Storm Uri), Taxable Series 2023 Bonds and we received our portion of the net proceeds, which was approximately $197 million. The proceeds were used to repay certain indebtedness and for general corporate purposes. Interest costs that exceeded the amount securitized have been deferred and will be addressed in the next general rate proceeding in each jurisdiction in Texas.

At June 30, 2023, Texas Gas Service had deferred approximately $31.2 million in extraordinary costs associated with Winter Storm Uri attributable to its former West Texas service area. Pursuant to the approved settlement order, Texas Gas Service began collecting the extraordinary costs, including carrying costs, from those customers in January 2022.

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The deferred winter weather event costs also include invoiced costs for natural gas purchases during Winter Storm Uri that have not been paid as we work with our suppliers for Kansas and Texas to resolve discrepancies in invoiced amounts. These amounts may be adjusted as the differences with suppliers are resolved. Settlements of these amounts are recoverable through the purchased gas cost mechanisms in the respective state. Future adjustments to the amounts are not expected to have a material impact on earnings.

Other regulatory assets and liabilities - Purchased-gas costs represent the natural gas costs that have been over- or under-recovered from customers through the purchased-gas cost adjustment mechanisms, and includes natural gas utilized in our operations and premiums paid and any cash settlements received from our purchased natural gas call options.

The OCC, KCC and regulatory authorities in Texas have approved the recovery of pension costs and other postemployment benefits costs through rates for Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively. The costs recovered through rates are based on the net periodic benefit cost for defined benefit pension and other postemployment costs. Differences, if any, between the net periodic benefit cost, net of deferrals, and the amount recovered through rates are reflected in earnings. We historically have recovered defined benefit pension and other postemployment benefit costs through rates. We believe it is probable that regulators will continue to include the net periodic pension and other postemployment benefit costs in our cost of service.

We amortize reacquired debt costs in accordance with the accounting guidelines prescribed by the OCC and the KCC.

See Note 12 for additional information regarding our regulatory assets for MGP remediation costs.

Ad-valorem tax represents the difference in Kansas Gas Service’s taxes incurred each year above or below the amount approved in base rates. This difference is deferred as a regulatory asset or liability for a 12-month period. Kansas Gas Service then applies an adjustment to customers’ bills to refund the over-collected revenue or bill the under-collected revenue over the subsequent 12 months.

Weather normalization represents revenue over- or under-recovered through the WNA rider in Kansas. This amount is deferred as a regulatory asset or liability for a 12-month period. Kansas Gas Service then applies an adjustment to the customers’ bills for 12 months to refund the over-collected revenue or bill the under-collected revenue.

The customer credit deferrals and the noncurrent regulatory liability for income tax rate changes represents deferral of the effects of enacted federal and state income tax rate changes on our ADIT and the effects of these changes on our rates. See Note 10 for additional information regarding the impact of income tax rate changes.

Recovery through rates resulted in amortization of regulatory assets of approximately $2.5 million and $1.6 million for the three months ended June 30, 2023 and 2022, respectively, and approximately $9.5 million and $6.0 million for the six months ended June 30, 2023 and 2022, respectively.

4.CREDIT FACILITY AND SHORT-TERM DEBT

In March 2023, we entered into an extension agreement related to the ONE Gas Credit Agreement that extended the maturity date to March 16, 2028, from March 16, 2027. All other terms and conditions of the ONE Gas Credit Agreement remain in full force and effect.

The ONE Gas Credit Agreement provides for a $1.0 billion revolving unsecured credit facility and includes a $20 million letter of credit subfacility. We can request an increase in commitments of up to an additional

$500 million upon satisfaction of customary conditions, including receipt of commitments from either new lenders or increased commitments from existing lenders. The ONE Gas Credit Agreement is available to provide liquidity for working capital, capital expenditures, acquisitions and mergers, the issuance of letters of credit and for other general corporate purposes.

The ONE Gas Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining ONE Gas’ total debt-to-capital ratio of no more than 70 percent at the end of any calendar quarter. At June 30, 2023, our total debt-to-capital ratio was 52 percent and we were in compliance with all covenants under the ONE Gas Credit Agreement. We may reduce the unutilized portion of the ONE Gas Credit Agreement in whole or in part without premium or penalty. The ONE Gas Credit Agreement contains customary events of default. Upon the occurrence of certain events of default, the obligations under the ONE Gas Credit Agreement may be accelerated and the commitments may be terminated.

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At June 30, 2023, we had $1.2 million in letters of credit issued and no borrowings under the ONE Gas Credit Agreement, with $998.8 million of remaining credit, which is available to repay our commercial paper borrowings.

We have a commercial paper program under which we may issue unsecured commercial paper up to a maximum amount of $1.0 billion to fund short-term borrowing needs. The maturities of the commercial paper vary but may not exceed 270 days from the date of issue. Commercial paper is generally sold at par less a discount representing an interest factor. At June 30, 2023 and December 31, 2022, we had $217.1 million and $552.0 million of commercial paper outstanding with a weighted-average interest rate of 5.43 percent and 4.75 percent, respectively.

5.LONG-TERM DEBT

The table below presents a summary of our long-term debt outstanding for the periods indicated:

	Interest rate at June 30, 2023	June 30, 2023		December 31, 2022
		(Thousands of dollars)
Senior Notes due:
February 2024	3.610%	$	300,000	$	300,000
March 2024	1.100%	473,000		473,000
May 2030	2.000%	300,000		300,000
September 2032	4.250%	300,000		300,000
February 2044	4.658%	600,000		600,000
November 2048	4.500%	400,000		400,000
Total Senior Notes		2,373,000		2,373,000
KGSS-I Securitized Utility Tariff Bonds	5.486%	336,000		336,000
Other	8.000%	1,244		1,250
Unamortized discounts on long-term debt		(7,422)		(7,636)
Debt issuance costs (a)		(19,571)		(20,143)
Total long-term debt, net		2,683,251		2,682,471
Less: current maturities of securitized utility tariff bonds		34,201		20,716
Less: current maturities of other long-term debt, net		772,838		12
Noncurrent portion of long-term debt, net		$	1,876,212	$	2,661,743

(a) Includes $5.8 million of issuance costs for the KGSS-I Securitized Utility Tariff Bonds.

Senior Notes - The indenture governing our Senior Notes includes an event of default upon the acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding Senior Notes to declare those Senior Notes immediately due and payable in full.

Depending on the series, we may redeem our Senior Notes at par, plus accrued and unpaid interest to the redemption date, starting three months or six months before their maturity dates. Prior to these dates, we may redeem these Senior Notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective Senior Note plus accrued and unpaid interest to the redemption date. Our $473 million of 1.10 percent senior notes due March 2024 can be called at par with a 30-day notice. Our Senior Notes are senior unsecured obligations, ranking equally in right of payment with all of our existing and future unsecured senior indebtedness.

Securitized Utility Tariff Bonds - The KGSS-I Securitized Utility Tariff Bonds are governed by an indenture between KGSS-I and the indenture trustee. The indenture contains certain covenants that restrict KGSS-I’s ability to sell, transfer, convey, exchange, or otherwise dispose of its assets. See Note 14 for additional discussion of the Kansas securitization transaction.

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6.EQUITY

Equity Forward Agreement - In March 2023, we entered into an underwriting agreement and a forward sale agreement for 2.0 million shares of our common stock. The forward sale agreement provides for settlement on a date, or dates, to be specified at our discretion, but which will occur no later than December 29, 2023, for 1.4 million shares of common stock and by December 31, 2024, for the remaining balance.

At-the-Market Equity Program - In February 2023, we entered into an at-the-market equity distribution agreement under which we may issue and sell shares of our common stock with an aggregate offering price up to $300 million (including any shares of common stock that may be sold pursuant to the master forward sale confirmation entered into in connection with the equity distribution agreement and the related supplemental confirmations). This at-the-market equity program replaced our previous at-the-market equity program, which began in February 2020, and expired in February 2023. The program allows us to offer and sell our common stock at prices we deem appropriate. Sales of common stock are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. At June 30, 2023, we had $226.1 million of equity available for issuance under the program.

For the six months ended June 30, 2023, we executed forward sale agreements under our current at-the-market equity program for 926,465 shares of our common stock.

The following table summarizes all of our outstanding forward sale agreements at June 30, 2023:

Maturity	Shares Sold	Net Proceeds Available (in thousands)		Forward Price
At-the-Market Equity Program
December 29, 2023	289,403	$	21,780	$	75.26
December 31, 2024	926,465	73,906		$	79.77
Total At-the-Market Equity Program	1,215,868	95,686		$	78.70
Equity Forward Agreement
December 29, 2023	1,400,000	107,095		$	76.50
December 31, 2024	600,000	45,898		$	76.50
Total Equity Forward Agreement	2,000,000	152,993		$	76.50
Total forward sale agreements	3,215,868	$	248,679	$	77.33

For the six months ended June 30, 2022, we executed forward sale agreements for 591,736 shares of our common stock. On December 30, 2022, we settled these forward sale agreements for net proceeds of $48.0 million.

For the six months ended June 30, 2022, we issued and sold 403,792 shares of our common stock for $35.0 million, generating net proceeds of $34.7 million.

Dividends Declared - In July 2023, we declared a dividend of $0.65 per share ($2.60 per share on an annualized basis) for shareholders of record as of August 16, 2023, payable on September 1, 2023.

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7.ACCUMULATED OTHER COMPREHENSIVE LOSS

The following table sets forth the effect of reclassifications from accumulated other comprehensive loss in our consolidated statements of income for the periods indicated:

	Three Months Ended				Six Months Ended				Affected Line Item in the
Details About Accumulated Other	June 30,				June 30,				Consolidated Statements
Comprehensive Loss Components	2023		2022		2023		2022		of Income
	(Thousands of dollars)
Pension and other postemployment benefit plan obligations (a)
Amortization of net loss	$	490	$	4,252	$	980	$	12,453
Amortization of unrecognized prior service cost (credit)	131		72		262		82
	621		4,324		1,242		12,535
Regulatory adjustments (b)	(621)		(4,265)		(1,242)		(12,388)
	—		59		—		147		Income before income taxes
	—		(15)		—		(34)		Income tax expense
Total reclassifications for the period	$	—	$	44	$	—	$	113	Net income

(a) These components of accumulated other comprehensive loss are included in the computation of net periodic benefit cost. See Note 9 for additional detail of our net periodic benefit cost.

(b) Regulatory adjustments represent pension and other postemployment benefit costs expected to be recovered through rates and are deferred as part of our regulatory assets. See Note 3 for additional disclosures of regulatory assets and liabilities.

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8.EARNINGS PER SHARE

Basic EPS is calculated by dividing net income by the daily weighted-average number of common shares outstanding during the periods presented, which includes fully vested stock awards that have not yet been issued as common stock. Diluted EPS is based on shares outstanding for the calculation of basic EPS, plus unvested stock awards granted under our compensation plans and equity forward sale agreements, but only to the extent these instruments dilute earnings per share.

The following tables set forth the computation of basic and diluted EPS from continuing operations for the periods indicated:

	Three Months Ended June 30, 2023
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	32,689	55,566	$	0.59
Diluted EPS Calculation
Effect of dilutive securities	—		348
Net income available for common stock and common stock equivalents	$	32,689	55,914	$	0.58
	Three Months Ended June 30, 2022
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	32,075	54,262	$	0.59
Diluted EPS Calculation
Effect of dilutive securities	—		73
Net income available for common stock and common stock equivalents	$	32,075	54,335	$	0.59
	Six Months Ended June 30, 2023
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	135,310	55,552	$	2.43
Diluted EPS Calculation
Effect of dilutive securities	—		305
Net income available for common stock and common stock equivalents	$	135,310	55,857	$	2.42
	Six Months Ended June 30, 2022
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	131,009	54,092	$	2.42
Diluted EPS Calculation
Effect of dilutive securities	—		91
Net income available for common stock and common stock equivalents	$	131,009	54,183	$	2.42

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9.EMPLOYEE BENEFIT PLANS

The following tables set forth the components of net periodic benefit cost for our pension and other postemployment benefit plans for the periods indicated:

	Pension Benefits
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2023		2022		2023		2022
	(Thousands of dollars)
Components of net periodic benefit cost (credit)
Service cost		$	1,811	$	2,592	$	3,622	$	5,686
Interest cost		10,607		9,037		21,214		16,841
Expected return on assets		(14,879)		(14,632)		(29,758)		(29,245)
Amortization of unrecognized prior service cost		93		62		186		62
Amortization of net loss		502		4,198		1,004		12,345
Net periodic benefit cost (credit)		$	(1,866)	$	1,257	$	(3,732)	$	5,689

	Other Postemployment Benefits
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(Thousands of dollars)
Components of net periodic benefit cost (credit)
Service cost	$	183	$	318	$	366	$	636
Interest cost	2,288		1,612		4,576		3,224
Expected return on assets	(2,432)		(3,295)		(4,864)		(6,590)
Amortization of unrecognized prior service cost	38		10		76		20
Amortization of net (gain) loss	(12)		54		(24)		108
Net periodic benefit cost (credit)	$	65	$	(1,301)	$	130	$	(2,602)

We recover qualified pension benefit plan and other postemployment benefit plan costs through rates charged to our customers. Certain regulatory authorities require that the recovery of these costs be based on specific guidelines. The difference between these regulatory-based amounts and the periodic benefit cost calculated pursuant to GAAP is deferred as a regulatory asset or liability and amortized to expense over periods in which this difference will be recovered in rates, as authorized by the applicable regulatory authorities. For the six months ended June 30, 2023 and 2022, regulatory deferrals related to net periodic benefit cost were not material.

We capitalize all eligible service cost and non-service cost components under the accounting requirements of ASC Topic 980 (Regulated Operations) for rate-regulated entities. Capitalized non-service costs reflected as a regulatory asset in our consolidated balance sheets were not material at June 30, 2023, and were $2.8 million at December 31, 2022. See Note 3 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional information.

10.INCOME TAXES

We use an estimated annual effective tax rate for purposes of determining the income tax provision during interim reporting periods. In calculating our estimated annual effective tax rate, we consider forecasted annual pre-tax income and estimated permanent book versus tax differences, as well as tax credits. Adjustments to the effective tax rate and estimates will occur as information and assumptions change.

At June 30, 2023, we have no uncertain tax positions. Changes in tax laws or tax rates are recognized in the financial reporting period that includes the enactment date. We are no longer subject to income tax examination for years prior to 2018.

Income tax expense reflects credits for the amortization of the regulatory liability associated with EDIT that was returned to customers of $3.1 million and $3.0 million for the three months ended June 30, 2023 and 2022, respectively, and credits of $13.0 million and $10.9 million for the six months ended June 30, 2023 and 2022, respectively.

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11. OTHER INCOME AND OTHER EXPENSE

The following table sets forth the components of other income and other expense for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(Thousands of dollars)
Net periodic benefit credit other than service cost	$	963	$	1,366	$	1,871	$	778
Earnings (losses) on investments associated with nonqualified employee benefit plans	1,274		(4,619)		2,887		(7,452)
Other, net	(63)		(730)		(3)		(1,454)
Total other income (expense), net	$	2,174	$	(3,983)	$	4,755	$	(8,128)

12.COMMITMENTS AND CONTINGENCIES

Environmental Matters - We are subject to multiple laws and regulations regarding protection of the environment and natural and cultural resources, which affect many aspects of our present and future operations. Regulated activities include, but are not limited to, those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, wetland preservation, plant and wildlife protection, hazardous materials use, storage and transportation, and pipeline and facility construction. These laws and regulations require us to obtain and/or comply with a wide variety of environmental clearances, registrations, licenses, permits and other approvals. Failure to comply with these laws, regulations, licenses and permits or the discovery of presently unknown environmental conditions may expose us to fines, penalties and/or interruptions in our operations that could be material to our results of operations. In addition, emission controls and/or other regulatory or permitting mandates under the CAA and other similar federal and state laws could require unexpected capital expenditures. We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to us. Revised or additional statutes or regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition and results of operations. Our expenditures for environmental investigation and remediation compliance to-date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three and six months ended June 30, 2023 and 2022.

We own or retain legal responsibility for certain environmental conditions at 12 former MGP sites in Kansas. These sites contain contaminants generally associated with MGP sites and are subject to control or remediation under various environmental laws and regulations. A consent agreement with the KDHE governs all environmental investigation and remediation work at these sites. The terms of the consent agreement require us to investigate these sites and set remediation activities based upon the results of the investigations and risk analysis. Remediation typically involves the management of contaminated soils and may involve removal of structures and monitoring and/or remediation of groundwater. Regulatory closure has been achieved at five of the 12 sites, but these sites remain subject to potential future requirements that may result in additional costs.

We have an AAO that allows Kansas Gas Service to defer and seek recovery of costs necessary for investigation and remediation at, and nearby, these 12 former MGP sites that are incurred after January 1, 2017, up to a cap of $15.0 million, net of any related insurance recoveries. Costs approved for recovery in a future rate proceeding would then be amortized over a 15-year period. The unamortized amounts will not be included in rate base or accumulate carrying charges. Following a determination that future investigation and remediation work approved by the KDHE is expected to exceed $15.0 million, net of any related insurance recoveries, Kansas Gas Service will be required to file an application with the KCC for approval to increase the $15.0 million cap. At June 30, 2023 and December 31, 2022, we have deferred $32.0 million for accrued investigation and remediation costs pursuant to our AAO. Kansas Gas Service expects to file an application as soon as practicable after the KDHE approves the plans we have submitted.

We have completed or are addressing removal of the source of soil contamination at all 12 sites and continue to monitor groundwater at seven of the 12 sites according to plans approved by the KDHE. In 2019, we completed a project to remove a source of contamination and associated contaminated materials at the twelfth site where no active soil remediation had previously occurred. In 2022, we completed a remediation project to remove a source of contamination and contaminated materials at one of the MGP sites. In June 2023, we submitted a revised draft remediation plan to the KDHE for review following receipt of agency comments and public feedback.

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We also own or retain legal responsibility for certain environmental conditions at a former MGP site in Texas. At the request of the TCEQ, we began investigating the level and extent of contamination associated with the site under their Texas Risk Reduction Program. A preliminary site investigation revealed that this site contains contaminants generally associated with MGP sites and is subject to control or remediation under various environmental laws and regulations. Impacts have been identified in the soil and groundwater at the site with limited impacts observed in surrounding areas. In April 2022, we submitted a remediation work plan to address the areas impacted to the TCEQ. At June 30, 2023, estimated costs associated with expected remediation activities for this site are not material.

Our expenditures for environmental evaluation, mitigation, remediation and compliance to date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three and six months ended June 30, 2023 and 2022. The reserve for remediation of our MGP sites was $14.8 million and $12.7 million at June 30, 2023 and December 31, 2022, respectively.

Pipeline Safety - We are subject to regulation under federal pipeline safety statutes and any analogous state regulations. These include safety requirements for the design, construction, operation, and maintenance of pipelines, including transmission and distribution pipelines. At the federal level, we are regulated by PHMSA. PHMSA regulations require the following for certain pipelines: inspection and maintenance plans; integrity management programs, including the determination of pipeline integrity risks and periodic assessments on certain pipeline segments; an operator qualification program, which includes certain trainings; a public awareness program that provides certain information; and a control room management plan.

As part of the Consolidated Appropriations Act, 2021, the PIPES Act reauthorized PHMSA through 2023 and directed the agency to move forward with several regulatory actions, including the “Pipeline Safety: Class Location Change Requirements” and the “Pipeline Safety: Safety of Gas Transmission and Gathering Pipelines” proposed rulemakings. Congress has also instructed PHMSA to issue final regulations that will require operators of new and existing transmission and distribution pipeline facilities to conduct certain leak detection and repair programs and to require facility inspection and maintenance plans to align with those regulations. To the extent such rulemakings impose more stringent requirements on our facilities, we may be required to incur expenditures that may be material.

Legal Proceedings - We are a party to various litigation matters and claims that have arisen in the normal course of our operations. While the results of litigation and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable outcome of such matters will not have a material adverse effect on our results of operations, financial position or cash flows.

13.DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS

Accounting Treatment - We record all derivative instruments at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it, or if regulatory requirements impose a different accounting treatment.

If certain conditions are met, we may elect to designate a derivative instrument as a hedge of exposure to changes in fair values or cash flows. We have not elected to designate any of our derivative instruments as hedges.

The table below summarizes the various ways in which we account for our derivative instruments and the impact on our consolidated financial statements:

		Recognition and Measurement
Accounting Treatment		Balance Sheet		Income Statement
Normal purchases and normal sales	-	Fair value not recorded	-	Change in fair value not recognized in earnings
Mark-to-market	-	Recorded at fair value	-	Change in fair value recognized in, and recoverable through, the purchased-gas cost adjustment mechanisms

Fair Value Measurements - We define fair value as the price that would be received from the sale of an asset or the transfer of a liability in an orderly transaction between market participants at the measurement date. We use the market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are

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executed. We measure the fair value of a group of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.

Fair Value Hierarchy - At each balance sheet date, we utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in our consolidated financial statements based on the observability of inputs used to estimate such fair value. The levels of the hierarchy are described below:

•Level 1 - Unadjusted quoted prices in active markets for identical assets or liabilities;

•Level 2 - Significant observable pricing inputs other than quoted prices included within Level 1 that are, either directly or indirectly, observable as of the reporting date. Essentially, this represents inputs that are derived principally from or corroborated by observable market data; and

•Level 3 - May include one or more unobservable inputs that are significant in establishing a fair value estimate. These unobservable inputs are developed based on the best information available and may include our own internal data.

We recognize transfers into and out of the levels as of the end of each reporting period.

Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. We categorize derivatives for which fair value is determined using multiple inputs within a single level, based on the lowest level input that is significant to the fair value measurement in its entirety.

Derivative Instruments - Our derivatives are comprised of over-the-counter natural gas fixed price swaps and call options.

Swaps - At June 30, 2023, we held over-the-counter natural gas fixed-price swaps for the heating season ending March 2024, with a total notional amount of 7.7 Bcf. We did not hold any swaps at December 31, 2022.

Options - At June 30, 2023, we held natural gas call options for the heating season ending March 2024, with total notional amounts of 0.7 Bcf, for which we paid premiums of $0.8 million. At December 31, 2022, we held purchased natural gas call options for the heating season ended March 2023, with total notional amounts of 19.4 Bcf, for which we paid premiums of $14.1 million.

We have not designated any of our derivative instruments as accounting hedges. These contracts are included in, and recoverable through, our purchased-gas cost adjustment mechanisms. Additionally, premiums paid, changes in fair value and any settlements received associated with these contracts are deferred as part of our unrecovered purchased-gas costs in our consolidated balance sheets. There were no transfers between levels for the periods presented.

Other Financial Instruments - The approximate fair value of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable is equal to book value, due to the short-term nature of these items. Commercial paper is due upon demand and, therefore, the carrying amounts approximate fair value.

The following tables summarize, by level within the fair value hierarchy, our derivative and other assets and liabilities that were accounted for at fair value on a recurring basis at June 30, 2023 and December 31, 2022:

	June 30, 2023
	Level 1		Level 2		Netting (c)		Total
	(Thousands of dollars)
Assets:
Derivative instruments - swaps (a)	$	—	$	616	$	(616)	$	—
Derivative instruments - options (a)	—		452		—		452
United States treasury notes (b)	4,020		—		—		4,020
Corporate bonds (b)	—		9,544		—		9,544
Total assets	$	4,020	$	10,612	$	(616)	$	14,016
Liabilities:
Derivative instruments - swaps (a)	$	—	$	3,747	$	(616)	$	3,131

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	December 31, 2022
	Level 1		Level 2		Total
	(Thousands of dollars)
Assets:
United States treasury notes (b)	$	4,695	$	—	$	4,695
Corporate bonds (b)	—		9,710		9,710
Total assets	$	4,695	$	9,710	$	14,405

(a) The fair value is included in other current assets and other current liabilities in our consolidated balance sheets.

(b) The fair value is included in other current and noncurrent assets and other current and noncurrent liabilities in our consolidated balance sheets.

(c) Our over-the-counter natural gas fixed-price swaps are subject to netting arrangements.

The estimated fair value of our long-term debt, including current maturities, was $2.5 billion at June 30, 2023 and December 31, 2022. The estimated fair value of our long-term debt was determined using quoted market prices, and is classified as Level 2.

14.VARIABLE INTEREST ENTITY

KGSS-I is a special-purpose, wholly owned subsidiary of ONE Gas that was formed for the purpose of issuing securitized bonds to recover extraordinary costs incurred by Kansas Gas Service resulting from Winter Storm Uri. On November 18, 2022, the securitized financing was complete. KGSS-I’s assets cannot be used to settle ONE Gas’ obligations and the holders of the Securitized Utility Tariff Bonds have no recourse against ONE Gas. See Note 5 for additional information about the securitization financing.

KGSS-I is considered to be a variable interest entity. As a result, KGSS-I is included in the consolidated financial statements of ONE Gas. No gain or loss was recognized upon initial consolidation.

The following table summarizes the impact of KGSS-I on our consolidated balance sheets, for the periods indicated:

	June 30,		December 31,
	2023		2022
	(Thousands of dollars)
Restricted cash and cash equivalents	$	32,006	$	8,446
Accounts receivable	3,157		4,862
Securitized intangible asset, net	309,569		323,838
Current maturities of securitized utility tariff bonds	34,201		20,716
Accounts payable	1,483		3,204
Accrued interest	11,418		2,202
Securitized utility tariff bonds, excluding current maturities, net of $5.9 million of discounts and issuance costs	295,949		309,343
Equity	1,681		1,681

The following table summarizes the impact of KGSS-I on our consolidated statements of income, for the period indicated:

	Three Months Ended		Six Months Ended
	June 30, 2023		June 30, 2023
	(Thousands of dollars)
Operating revenues	$	11,807	$	23,740
Operating expense	(109)		(219)
Amortization expense	(7,180)		(14,269)
Interest income	226		301
Interest expense	(4,744)		(9,553)
Income before income taxes	$	—	$	—

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

The following discussion and analysis should be read in conjunction with our unaudited consolidated financial statements and the Notes to Consolidated Financial Statements in this Quarterly Report, as well as our Annual Report. Due to the seasonal nature of our business, the results of operations for the three and six months ended June 30, 2023, are not necessarily indicative of the results that may be expected for a 12-month period.

RECENT DEVELOPMENTS

Securitization transaction - In March 2023, the TNG Corporation completed the issuance of the Customer Rate Relief (Winter Storm Uri), Taxable Series 2023 Bonds. On March 23, 2023, we received our portion of the net proceeds, which was approximately $197 million. The proceeds were used to repay certain indebtedness and for general corporate purposes.

See “Regulatory Activities,” and Note 3 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional discussion of the securitization transaction.

Equity forward agreement - In March 2023, we entered into an underwriting agreement and a forward sale agreement for 2.0 million shares of our common stock. The forward sale agreement provides for settlement on a date, or dates, to be specified at our discretion, but which will occur no later than December 29, 2023, for 1.4 million shares of common stock and by December 31, 2024, for the remaining balance. Had we fully settled this forward sale agreement as of June 30, 2023, we would have generated net proceeds of approximately $153.0 million.

At-the-market equity program - In February 2023, we entered into an at-the-market equity distribution agreement under which we may issue and sell shares of our common stock with an aggregate offering price up to $300 million (including any shares of common stock that may be sold pursuant to the master forward sale confirmation entered into in connection with the equity distribution agreement and the related supplemental confirmations). This at-the-market equity program replaced our previous at-the-market equity program, which began in February 2020, and expired in February 2023. The program allows us to offer and sell our common stock at prices we deem appropriate. Sales of common stock are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. At June 30, 2023, we had $226.1 million of equity available for issuance under the program.

For the six months ended June 30, 2023, we executed forward sale agreements under our current at-the-market equity program for 926,465 shares of our common stock. Had we fully settled all 1,215,868 shares sold under our at-the-market equity programs, as of June 30, 2023, we would have generated net proceeds of approximately $95.7 million.

ONE Gas Credit Agreement - In March 2023, we entered into an extension agreement related to the ONE Gas Credit Agreement that extends the maturity date to March 16, 2028, from March 16, 2027. All other terms and conditions of the ONE Gas Credit Agreement remain in full force and effect.

Dividend - In July 2023, we declared a dividend of $0.65 per share ($2.60 per share on an annualized basis) for shareholders of record as of August 16, 2023, payable on September 1, 2023.

REGULATORY ACTIVITIES

Oklahoma - As required, PBRC filings are made annually on or before March 15 until the next general rate case, which is required to be filed on or before June 30, 2027. In March 2023, Oklahoma Natural Gas filed its required PBRC application for the year ended December 2022. The filed request included a $27.6 million base rate revenue increase, $2.5 million energy efficiency incentive, and $11.9 million of estimated EDIT to be credited to customers in 2024. On June 13, 2023, a settlement in the case was filed with a proposed revenue increase of $26.3 million, $2.5 million energy efficiency incentive, and $12.6 million EDIT credit. Pursuant to its tariff, Oklahoma Natural Gas placed new rates into effect on June 29, 2023. In July 2023, the OCC issued an order approving the settlement.

In December 2022, Oklahoma Natural Gas filed a request for an RNG Pilot Program and Voluntary Tariff pursuant to the requirement in the rate case order approved in 2021. The proposed tariff will allow all residential, small commercial and industrial sales customers to voluntarily purchase the environmental attributes of RNG up to the equivalent of 10 Dth per month. If approved, the tariff will be in effect through 2027. Assessment of the tariff and pilot program will be made in the rate case required to be filed on or before June 30, 2027. An order is expected no earlier than the third quarter of 2023.

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Texas - Pursuant to securitization legislation enacted in Texas as a result of Winter Storm Uri and a June 2021 RRC Notice to Gas Utilities, Texas Gas Service submitted an application to the RRC in July 2021 for an order authorizing the amount of extraordinary costs for recovery and other such specifications necessary for the issuance of securitized bonds.

In February 2022, the RRC issued a single financing order for Texas Gas Service and other natural gas utilities in Texas participating in the securitization process, which included a determination that the approved costs will be collected from customers over a period of not more than 30 years. The TPFA formed the TNG Corporation, a new independent public authority, to issue the securitized bonds.

In March 2023, the TNG Corporation completed the issuance of the Customer Rate Relief (Winter Storm Uri), Taxable Series 2023 Bonds and we received our portion of the net proceeds, which was approximately $197 million. The proceeds were used to repay certain indebtedness and for general corporate purposes. Interest costs that exceeded the amount securitized have been deferred and will be addressed in the next general rate proceeding in each jurisdiction in Texas.

Central-Gulf Service Area - In February 2023, Texas Gas Service made GRIP filings for all customers in the Central-Gulf service area, requesting an $11.5 million increase to be effective in June 2023. All municipalities, and the RRC, approved the increase or allowed it to take effect with no action, in June 2023.

West-North Service Area - In March 2023, Texas Gas Service made GRIP filings for all customers in the West-North service area, requesting a $7.4 million increase to be effective in July 2023. In June 2023, El Paso, Socorro and Anthony denied the requested increase. Texas Gas Service appealed the municipalities’ actions to the RRC. All other municipalities, and the RRC, approved an increase of $7.3 million or allowed it to take effect with no action. Texas Gas Service implemented the new rates in June 2023, subject to adjustment depending upon the outcome of the appeal.

In June 2022, Texas Gas Service filed a rate case seeking to consolidate its West Texas, North Texas and Borger/Skellytown service areas into a single West-North service area and requesting a rate increase of $13.0 million. In January 2023, the RRC approved the consolidation and a rate increase of $8.8 million premised on a return on equity of 9.6 percent and a common equity ratio of 59.74 percent equity. The new rates were implemented in February 2023.

Rio Grande Valley Service Area - In June 2023, Texas Gas Service filed a rate case for all customers in the Rio Grande Valley service area, requesting a $9.8 million increase. New rates are expected to take effect in late 2023 or early 2024.

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FINANCIAL RESULTS AND OPERATING INFORMATION

We operate in one reportable business segment: regulated public utilities that deliver natural gas to residential, commercial and transportation customers. Our accounting policies are the same as described in Note 1 of the Notes to Consolidated Financial Statements in our Annual Report. We evaluate our financial performance principally on net income.

Selected Financial Results - For the three months ended June 30, 2023, net income was $32.7 million, or $0.58 per diluted share, compared with $32.1 million, or $0.59 per diluted share, in the same period last year. For the six months ended June 30, 2023, net income was $135.3 million, or $2.42 per diluted share, compared with $131.0 million, or $2.42 per diluted share, in the same period last year.

The following table sets forth certain selected financial results for our operations for the periods indicated:

	Three Months Ended				Six Months Ended				June 30, 2023				Six Months
	June 30,				June 30,				2023 vs. 2022				2023 vs. 2022
Financial Results	2023		2022		2023		2022		Increase (Decrease)				Increase (Decrease)
	(Millions of dollars, except percentages)
Natural gas sales	$	348.3	$	393.2	$	1,320.0	$	1,320.2	$	(44.9)	(11)	%	$	(0.2)	—	%
Transportation revenues	29.1		28.0		68.0		64.8		1.1		4	%	3.2		5	%
Securitization customer charges	11.8		—		23.7		—		11.8		100	%	23.7		100	%
Other revenues	8.9		7.8		18.6		15.4		1.1		14	%	3.2		21	%
Total revenues	398.1		429.0		1,430.3		1,400.4		(30.9)		(7)	%	29.9		2	%
Cost of natural gas	130.2		188.3		796.0		828.2		(58.1)		(31)	%	(32.2)		(4)	%
Operating costs	136.4		127.1		282.2		260.7		9.3		7	%	21.5		8	%
Depreciation and amortization	67.5		55.0		138.8		112.2		12.5		23	%	26.6		24	%
Operating income	$	64.0	$	58.6	$	213.3	$	199.3	$	5.4	9	%	$	14.0	7	%
Capital expenditures and asset removal costs	$	190.2	$	149.1	$	354.8	$	272.0	$	41.1	28	%	$	82.8	30	%

Natural gas sales to customers represent revenue from contracts with customers through implied contracts established by our tariffs and rates approved by regulatory authorities, as well as revenues from regulatory mechanisms related to natural gas sales. Additionally, natural gas sales include recovery of the cost of natural gas.

Our natural gas sales include fixed and variable charges related to the delivery of natural gas and gas costs that are passed through to our customers in accordance with our cost of natural gas regulatory mechanisms. Fixed charges reflect the portion of our natural gas sales attributable to the monthly fixed customer charge component of our rates, which does not fluctuate based on customer usage in each period. Variable charges reflect the portion of our natural gas sales that fluctuate with the volumes delivered and billed and the effects of weather normalization.

Securitization customer charges represent revenue from contracts with customers through implied contracts established by the financing order approved by the KCC, related to the securitization of extraordinary costs incurred during Winter Storm Uri in the state of Kansas. See Note 14 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional discussion of the securitization transaction in Kansas.

Transportation revenues represent revenue from contracts with customers through implied contracts established by our tariffs and rates approved by regulatory authorities, as well as tariff-based negotiated contracts.

Other revenues include primarily miscellaneous service charges, which represent implied contracts with customers established by our tariffs and rates approved by regulatory authorities and other revenues from regulatory mechanisms.

Cost of natural gas includes commodity purchases, fuel, storage, transportation, hedging costs and settlement proceeds for natural gas price volatility mitigation programs approved by our regulators and other gas purchase costs recovered through our cost of natural gas regulatory mechanisms and does not include an allocation of general operating costs or depreciation and amortization. These regulatory mechanisms provide a method of recovering natural gas costs on an ongoing basis without a profit. Therefore, although our revenues will fluctuate with the cost of natural gas that we pass-through to our customers, operating income is not affected by fluctuations in the cost of natural gas.

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Operating income increased $5.4 million for the three months ended June 30, 2023, compared with the same period last year, due primarily to the following:

•an increase of $14.1 million from new rates; and

•an increase of $1.1 million in residential sales due primarily to net customer growth in Oklahoma and Texas.

These increases were offset partially by:

•an increase of $6.7 million in employee-related costs; and

•a decrease of $1.7 million due to lower sales volumes, net of the impact of weather normalization mechanisms.

Operating income increased $14.0 million for the six months ended June 30, 2023, compared with the same period last year, due primarily to the following:

•an increase of $31.4 million from new rates; and

•an increase of $3.1 million in residential sales due primarily to net customer growth in Oklahoma and Texas.

These increases were offset partially by:

•an increase of $10.8 million in employee-related costs;

•a decrease of $3.3 million due to lower sales volumes, net of the impact of weather normalization mechanisms; and

•an increase of $2.4 million in bad debt expense.

Weather across our service territories was 6.6 percent warmer than the prior year for the three months ended June 30, 2023 and 13.7 percent warmer than the prior year for the six months ended June 30, 2023. The impact on operating income was mitigated by our weather normalization mechanisms.

Revenues for the three months ended June 30, 2023, include an increase of $11.8 million associated with KGSS-I, which is offset by $7.3 million in amortization and operating expense and $4.5 million in net interest expense. Revenues for the six months ended June 30, 2023, include an increase of $23.7 million associated with KGSS-I, which is offset by $14.5 million in amortization and operating expense and $9.2 million in net interest expense. Revenues for the three and six months ended June 30, 2023, also include an increase of $0.8 million and $3.3 million, respectively, due to the annual adjustment of the ad-valorem rider for Kansas Gas Service, which is offset in amortization expense.

Other Factors Affecting Net Income - Other factors that affected net income for the three months ended June 30, 2023, compared with the same period last year, include an increase of $6.2 million in other income due primarily to a $5.9 million increase in the market value of investments associated with our nonqualified employee benefit plans.

Other factors that affected net income for the six months ended June 30, 2023, compared with the same period last year, include an increase of $12.9 million in other income due primarily to a $10.3 million increase in the market value of investments associated with our nonqualified employee benefit plans and a $1.1 million decrease in net periodic benefit costs other than service costs.

Additionally, net income for the three and six months ended June 30, 2023, includes an increase in interest expense of $11.2 million and $25.7 million, respectively. The increase in interest expense is due primarily to an increase in the weighted average interest rate on our commercial paper and the issuance of $300 million of 4.25 percent senior notes in August 2022 and $336 million of 5.486 percent Securitized Utility Tariff Bonds in November 2022.

EDIT - Income tax expense reflects credits for the amortization of the regulatory liability associated with EDIT that was returned to customers of $3.1 million and $3.0 million for the three months ended June 30, 2023 and 2022, respectively, and credits of $13.0 million and $10.9 million for the six months ended June 30, 2023 and 2022, respectively.

Capital Expenditures and Asset Removal Costs - Our capital expenditures program includes expenditures for pipeline integrity, extending service to new areas, increasing system capabilities, pipeline replacements, automated meter reading, government-mandated pipeline relocations, fleet, facilities, IT assets and cybersecurity. It is our practice to maintain and upgrade our infrastructure, facilities and systems to ensure safe, reliable and efficient operations. Asset removal costs include expenditures associated with the replacement or retirement of long-lived assets that result from the construction, development and/or normal use of our assets, primarily our pipeline assets.

Capital expenditures and asset removal costs were $41.1 million and $82.8 million higher for the three and six months ended June 30, 2023, compared with the same periods last year, due primarily to expenditures for system integrity and extension of service to new areas. Our full-year capital expenditures and asset removal costs are expected to be approximately $675 million for 2023.

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Selected Operating Information - The following tables set forth certain selected operating information for the periods indicated:

	Three Months Ended								Variances
	June 30,								2023 vs. 2022
(in thousands)	2023				2022				Increase (Decrease)
Average Number of Customers	OK	KS	TX	Total	OK	KS	TX	Total	OK	KS	TX	Total
Residential	837	593	660	2,090	833	593	658	2,084	4	—	2	6
Commercial and industrial	77	50	36	163	77	51	35	163	—	(1)	1	—
Other	—	—	3	3	—	—	3	3	—	—	—	—
Transportation	5	6	1	12	5	6	1	12	—	—	—	—
Total customers	919	649	700	2,268	915	650	697	2,262	4	(1)	3	6
	Six Months Ended								Variances
	June 30,								2023 vs. 2022
(in thousands)	2023				2022				Increase (Decrease)
Average Number of Customers	OK	KS	TX	Total	OK	KS	TX	Total	OK	KS	TX	Total
Residential	839	596	660	2,095	834	595	656	2,085	5	1	4	10
Commercial and industrial	78	50	36	164	77	51	36	164	1	(1)	—	—
Other	—	—	3	3	—	—	3	3	—	—	—	—
Transportation	5	6	1	12	5	6	1	12	—	—	—	—
Total customers	922	652	700	2,274	916	652	696	2,264	6	—	4	10

The increase in the average number of customers for the periods presented is due primarily to the connection of new customers resulting from the extension and expansion of our system in our service areas. For the three months ended June 30, 2023, our average customer count includes approximately 4,900 new customer connections during the period. For the six months ended June 30, 2023, our average customer count includes approximately 10,700 new customer connections during the period. For the year ended December 31, 2022, our average customer count included approximately 27,100 new customer connections.

The following table reflects total volumes delivered, excluding the effects of WNA mechanisms on sales volumes:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
Volumes (MMcf)	2023	2022	2023	2022
Natural gas sales
Residential	12,823	13,790	67,426	74,440
Commercial and industrial	5,746	6,188	23,889	25,557
Other	363	564	1,451	1,675
Total sales volumes delivered	18,932	20,542	92,766	101,672
Transportation	52,823	53,392	117,757	120,463
Total volumes delivered	71,755	73,934	210,523	222,135

The impact of weather on residential and commercial natural gas sales is mitigated by WNA mechanisms in all jurisdictions.

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The following table sets forth the HDDs by state for the periods indicated:

	Three Months Ended
	June 30,
	2023		2022		2023 vs. 2022		2023		2022
HDDs	Actual	Normal	Actual	Normal	Actual Variance		Actual as a percent of Normal
Oklahoma	234	228	219	228	7	%	103	%	96	%
Kansas	316	394	399	394	(21)	%	80	%	101	%
Texas	43	45	17	50	153	%	96	%	34	%
	Six Months Ended
	June 30,
	2023		2022		2023 vs. 2022		2023		2022
HDDs	Actual	Normal	Actual	Normal	Actual Variance		Actual as a percent of Normal
Oklahoma	1,953	2,020	2,204	2,020	(11)	%	97	%	109	%
Kansas	2,567	2,854	2,931	2,855	(12)	%	90	%	103	%
Texas	945	1,030	1,199	1,049	(21)	%	92	%	114	%

Normal HDDs are established through rate proceedings in each of our jurisdictions for use primarily in weather normalization billing calculations. See further discussion on weather normalization in our Regulatory Overview section in Part 1, Item 1, “Business,” of our Annual Report. Normal HDDs disclosed above are based on:

•Oklahoma - A 10-year weighted average as of June 30, 2021, as calculated using 11 weather stations across Oklahoma and weighted on average customer count.

•Kansas - A 30-year rolling average for years 1988-2017 calculated using three weather stations across Kansas and weighted on HDDs by weather station and customers.

•Texas - An average of HDDs authorized in our most recent rate proceeding in each jurisdiction and weighted using a rolling 10-year average of actual natural gas distribution sales volumes by service area.

Actual HDDs are based on the quarter-to-date weighted average of:

•11 weather stations and customers by month for Oklahoma;

•3 weather stations and customers by month for Kansas; and

•9 weather stations and natural gas distribution sales volumes by service area for Texas.

CONTINGENCIES

We are a party to various litigation matters and claims that have arisen in the normal course of our operations. While the results of litigation and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable outcome of such matters will not have a material adverse effect on our results of operations, financial position or cash flows.

LIQUIDITY AND CAPITAL RESOURCES

General - We have relied primarily on operating cash flow and commercial paper for our liquidity and capital resource requirements. We fund operating expenses, working capital requirements, including purchases of natural gas, and capital expenditures primarily with cash from operations and commercial paper.

We believe that the combination of the significant residential component of our customer base, the fixed-charge component of our natural gas sales revenues and our rate mechanisms that we have in place result in a stable cash flow profile and historically has generated stable earnings. Additionally, we have rate mechanisms in place in our jurisdictions that reduce the lag in earning a return on our capital expenditures and provide for recovery of certain changes in our cost of service by allowing for adjustments to rates between rate cases. We anticipate that our cash flow generated from operations and our expected short- and

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long-term financing arrangements will enable us to maintain our current and planned level of operations and provide us flexibility to finance our infrastructure investments. Our ability to access capital markets for debt and equity financing under reasonable terms depends on market conditions, our financial condition and credit ratings.

Short-term Debt - In March 2023, we entered into an extension agreement related to the ONE Gas Credit Agreement that extends the maturity date to March 16, 2028, from March 16, 2027. All other terms and conditions of the ONE Gas Credit Agreement remain in full force and effect.

The ONE Gas Credit Agreement provides for a $1.0 billion revolving unsecured credit facility and includes a $20 million letter of credit subfacility. We can request an increase in commitments of up to an additional $500 million upon satisfaction of customary conditions, including receipt of commitments from either new lenders or increased commitments from existing lenders. The ONE Gas Credit Agreement is available to provide liquidity for working capital, capital expenditures, acquisitions and mergers, the issuance of letters of credit and for other general corporate purposes.

The ONE Gas Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining ONE Gas’ total debt-to-capital ratio of no more than 70 percent at the end of any calendar quarter. At June 30, 2023, our total debt-to-capital ratio was 52 percent and we were in compliance with all covenants under the ONE Gas Credit Agreement. Excluding the debt of KGSS-I, which is non-recourse to us, our total debt-to-capital ratio was 49 percent. We may reduce the unutilized portion of the ONE Gas Credit Agreement in whole or in part without premium or penalty. The ONE Gas Credit Agreement contains customary events of default. Upon the occurrence of certain events of default, the obligations under the ONE Gas Credit Agreement may be accelerated and the commitments may be terminated.

We have a commercial paper program under which we may issue unsecured commercial paper up to a maximum amount of $1.0 billion to fund short-term borrowing needs. The maturities of the commercial paper vary but may not exceed 270 days from the date of issue. Commercial paper is generally sold at par less a discount representing an interest factor. At June 30, 2023 and December 31, 2022, we had $217.1 million and $552.0 million of commercial paper outstanding with a weighted-average interest rate of 5.43 percent and 4.75 percent, respectively.

At June 30, 2023, we had $1.2 million in letters of credit issued and no borrowings under the ONE Gas Credit Agreement, with $998.8 million of remaining credit, which is available to repay our commercial paper borrowings.

Senior Notes - At June 30, 2023, we had outstanding $2.4 billion of Senior Notes with $772.8 million due within the next year. The indenture governing our Senior Notes includes an event of default upon the acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding Senior Notes to declare those Senior Notes immediately due and payable in full.

Depending on the series, we may redeem our Senior Notes at par, plus accrued and unpaid interest to the redemption date, starting three months or six months before their maturity dates. Prior to these dates, we may redeem these Senior Notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective Senior Note plus accrued and unpaid interest to the redemption date. Our $473 million of 1.10 percent senior notes due March 2024 can be called at par with a 30-day notice. Our Senior Notes are senior unsecured obligations, ranking equally in right of payment with all of our existing and future unsecured senior indebtedness.

Securitized Utility Tariff Bonds - At June 30, 2023, we had outstanding $336.0 million of 5.486 percent KGSS-I Securitized Utility Tariff Bonds with $34.2 million due within the next year. The bonds are governed by an indenture between KGSS-I and the indenture trustee. The indenture contains certain covenants that restrict KGSS-I’s ability to sell, transfer, convey, exchange, or otherwise dispose of its assets.

At June 30, 2023, our long-term debt-to-capital ratio was 50 percent. Excluding the debt of KGSS-I, which is non-recourse to us, our long-term debt-to-capital ratio was 47 percent.

Credit Ratings - Our credit ratings at June 30, 2023, were:

Rating Agency	Rating	Outlook
Moody’s	A3	Stable
S&P	A-	Stable

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At June 30, 2023, our commercial paper was rated Prime-2 by Moody’s and A-2 by S&P. We intend to maintain credit metrics at a level that supports our balanced approach to capital investment and a return of capital to shareholders via a dividend that we believe will be competitive with our peer group.

Equity forward agreement - In March 2023, we entered into an underwriting agreement and a forward sale agreement for 2.0 million shares of our common stock. The forward sale agreement provides for settlement on a date, or dates, to be specified at our discretion, but which will occur no later than December 29, 2023, for 1.4 million shares of common stock and by December 31, 2024, for the remaining balance.

At-the-market equity program - In February 2023, we entered into an at-the-market equity distribution agreement under which we may issue and sell shares of our common stock with an aggregate offering price up to $300 million (including any shares of common stock that may be sold pursuant to the master forward sale confirmation entered into in connection with the equity distribution agreement and the related supplemental confirmations). This at-the-market equity program replaced our previous at-the-market equity program, which began in February 2020, and expired in February 2023. The program allows us to offer and sell our common stock at prices we deem appropriate. Sales of common stock are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. At June 30, 2023, we had $226.1 million of equity available for issuance under the program.

For the six months ended June 30, 2023, we executed forward sale agreements under our current at-the-market equity program for 926,465 shares of our common stock.

The following table summarizes all of our outstanding forward sale agreements at June 30, 2023:

Maturity	Shares Sold	Net Proceeds Available (in thousands)		Forward Price
At-the-Market Equity Program
December 29, 2023	289,403	$	21,780	$	75.26
December 31, 2024	926,465	73,906		$	79.77
Total At-the-Market Equity Program	1,215,868	95,686		$	78.70
Equity Forward Agreement
December 29, 2023	1,400,000	107,095		$	76.50
December 31, 2024	600,000	45,898		$	76.50
Total Equity Forward Agreement	2,000,000	152,993		$	76.50
Total forward sale agreements	3,215,868	$	248,679	$	77.33

Pension and Other Postemployment Benefit Plans - In 2023, our contributions are expected to be approximately $1.4 million to our defined benefit pension plans, and no contributions are expected to be made to our other postemployment benefit plans. We use a December 31 measurement date for our plans.

Information about our pension and other postemployment benefits plans is included under Note 14 of the Notes to Consolidated Financial Statements in our Annual Report. See Note 9 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional information.

CASH FLOW ANALYSIS

We use the indirect method to prepare our consolidated statements of cash flows. Under this method, we reconcile net income to cash flows provided by operating activities by adjusting net income for those items that impact net income but may not result in actual cash receipts or payments and changes in our assets and liabilities not classified as investing or financing activities during the period. Items that impact net income but may not result in actual cash receipts or payments include, but are not limited to, depreciation and amortization, deferred income taxes, share-based compensation expense and provision for doubtful accounts.

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The following table sets forth the changes in cash flows by operating, investing and financing activities for the periods indicated:

	Six Months Ended
	June 30,				Variance
	2023		2022		2023 vs. 2022
	(Millions of dollars)
Total cash provided by (used in):
Operating activities	$	748.7	$	286.7	$	462.0
Investing activities	(321.4)		(251.5)		(69.9)
Financing activities	(406.1)		(36.7)		(369.4)
Change in cash, cash equivalents, restricted cash and restricted cash equivalents	21.2		(1.5)		22.7
Cash, cash equivalents, restricted cash and restricted cash equivalents at beginning of period	18.1		8.9		9.2
Cash, cash equivalents, restricted cash and restricted cash equivalents at end of period	$	39.3	$	7.4	$	31.9

Operating Cash Flows - Changes in cash flows from operating activities are due primarily to changes in sales revenues, natural gas costs and operating expenses discussed in Financial Results and Operating Information, the effects of Winter Storm Uri discussed in Regulatory Activities and changes in working capital. Changes in natural gas prices and demand for our services or natural gas, whether because of general economic conditions, variations in weather not mitigated by WNAs, changes in supply or increased competition from other service providers, could affect our earnings and operating cash flows. Typically, our cash flows from operations are greater in the first half of the year compared with the second half of the year.

Operating cash flows were higher for the six months ended June 30, 2023, compared with the prior period, due primarily to recovery of the winter weather event regulatory asset for Texas Gas Service through securitization and working capital changes related to accounts receivable which were impacted by new rates in the current period compared with the same period in 2022.

Investing Cash Flows - Cash used in investing activities increased for the six months ended June 30, 2023, due primarily to an increase in capital expenditures for system integrity and extension of service to new areas.

Financing Cash Flows - Cash used in financing activities increased for the six months ended June 30, 2023, compared with the prior period, due primarily to increased repayments of notes payable.

ENVIRONMENTAL, SAFETY AND REGULATORY MATTERS

Environmental Matters - We are subject to multiple laws and regulations regarding protection of the environment and natural and cultural resources, which affect many aspects of our present and future operations. Regulated activities include, but are not limited to, those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, wetland preservation, plant and wildlife protection, hazardous materials use, storage and transportation, and pipeline and facility construction. These laws and regulations require us to obtain and/or comply with a wide variety of environmental clearances, registrations, licenses, permits and other approvals. Failure to comply with these laws, regulations, licenses and permits or the discovery of presently unknown environmental conditions may expose us to fines, penalties and/or interruptions in our operations that could be material to our results of operations. In addition, emission controls and/or other regulatory or permitting mandates under the CAA and other similar federal and state laws could require unexpected capital expenditures. We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to us. Revised or additional statutes or regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition and results of operations. Our expenditures for environmental investigation and remediation compliance to-date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three and six months ended June 30, 2023 and 2022.

We own or retain legal responsibility for certain environmental conditions at 12 former MGP sites in Kansas. These sites contain contaminants generally associated with MGP sites and are subject to control or remediation under various environmental laws and regulations. A consent agreement with the KDHE governs all environmental investigation and remediation work at these sites. The terms of the consent agreement require us to investigate these sites and set remediation activities based upon the results of the investigations and risk analysis. Remediation typically involves the management of contaminated soils and may involve removal of structures and monitoring and/or remediation of groundwater. Regulatory

33

closure has been achieved at five of the 12 sites, but these sites remain subject to potential future requirements that may result in additional costs.

We have an AAO that allows Kansas Gas Service to defer and seek recovery of costs necessary for investigation and remediation at, and nearby, these 12 former MGP sites that are incurred after January 1, 2017, up to a cap of $15.0 million, net of any related insurance recoveries. Costs approved for recovery in a future rate proceeding would then be amortized over a 15-year period. The unamortized amounts will not be included in rate base or accumulate carrying charges. Following a determination that future investigation and remediation work approved by the KDHE is expected to exceed $15.0 million, net of any related insurance recoveries, Kansas Gas Service will be required to file an application with the KCC for approval to increase the $15.0 million cap. At June 30, 2023 and December 31, 2022, we have deferred $32.0 million for accrued investigation and remediation costs pursuant to our AAO. Kansas Gas Service expects to file an application as soon as practicable after the KDHE approves the plans we have submitted.

We have completed or are addressing removal of the source of soil contamination at all 12 sites and continue to monitor groundwater at seven of the 12 sites according to plans approved by the KDHE. In 2019, we completed a project to remove a source of contamination and associated contaminated materials at the twelfth site where no active soil remediation had previously occurred. In June 2023, we submitted a revised draft remediation plan to the KDHE for review following receipt of agency comments and public feedback.

We also own or retain legal responsibility for certain environmental conditions at a former MGP site in Texas. At the request of the TCEQ, we began investigating the level and extent of contamination associated with the site under their Texas Risk Reduction Program. A preliminary site investigation revealed that this site contains contaminants generally associated with MGP sites and is subject to control or remediation under various environmental laws and regulations. Impacts have been identified in the soil and groundwater at the site with limited impacts observed in surrounding areas. In April 2022, we submitted a remediation work plan to address the areas impacted to the TCEQ. At June 30, 2023, estimated costs associated with expected remediation activities for this site are not material.

Our expenditures for environmental evaluation, mitigation, remediation and compliance to date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three months ended June 30, 2023 and 2022. The reserve for remediation of our MGP sites was $14.8 million and 12.7 million at June 30, 2023 and December 31, 2022, respectively.

Environmental Footprint - We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to us. Revised or additional regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition and results of operations. Our expenditures for environmental investigation, and remediation compliance to-date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows for the three months ended June 30, 2023 and 2022.

Pipeline Safety - We are subject to regulation under federal pipeline safety statutes and any analogous state regulations. These include safety requirements for the design, construction, operation, and maintenance of pipelines, including transmission and distribution pipelines. At the federal level, we are regulated by PHMSA. PHMSA regulations require the following for certain pipelines: inspection and maintenance plans; integrity management programs, including the determination of pipeline integrity risks and periodic assessments on certain pipeline segments; an operator qualification program, which includes certain trainings; a public awareness program that provides certain information; and a control room management plan.

As part of the Consolidated Appropriations Act, 2021, the PIPES Act reauthorized PHMSA through 2023 and directed the agency to move forward with several regulatory actions, including the “Pipeline Safety: Class Location Change Requirements” and the “Pipeline Safety: Safety of Gas Transmission and Gathering Pipelines” proposed rulemakings. Congress has also instructed PHMSA to issue final regulations that will require operators of non-rural gas gathering lines and new and existing transmission and distribution pipeline facilities to conduct certain leak detection and repair programs and to require facility inspection and maintenance plans to align with those regulations. To the extent such rulemakings impose more stringent requirements on our facilities, we may be required to incur expenditures that may be material.

Regulatory - Several regulatory initiatives impacted the earnings and future earnings potential of our business. See additional information regarding our regulatory initiatives in the “Regulatory Activities” section of Management’s Discussion and Analysis of Financial Condition and Results of Operations.

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IMPACT OF NEW ACCOUNTING STANDARDS

Information about the impact of new accounting standards, if any, is included in Note 1 of the Notes to Consolidated Financial Statements in this Quarterly Report.

CRITICAL ESTIMATES AND ACCOUNTING POLICIES

The preparation of our consolidated financial statements and related disclosures in accordance with GAAP requires us to make estimates and assumptions with respect to values or conditions that cannot be known with certainty that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements. These estimates and assumptions also affect the reported amounts of revenues and expenses during the reporting period. Although we believe these estimates and assumptions are reasonable, actual results could differ from our estimates.

Information about our estimates and critical accounting policies is included under Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations, “Estimates and Critical Accounting Policies,” in our Annual Report.

FORWARD-LOOKING STATEMENTS

Some of the statements contained and incorporated in this Quarterly Report are forward-looking statements within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act. The forward-looking statements relate to our anticipated financial performance, liquidity, management’s plans and objectives for our future operations, our business prospects, the outcome of regulatory and legal proceedings, market conditions and other matters. We make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. The following discussion is intended to identify important factors that could cause future outcomes to differ materially from those set forth in the forward-looking statements.

Forward-looking and other statements in this Quarterly Report regarding our environmental, social and other sustainability plans and goals are not an indication that these statements are necessarily material to investors or required to be disclosed in our filings with the SEC. In addition, historical, current, and forward-looking environmental, social and sustainability-related statements may be based on standards for measuring progress that are still developing, internal controls and processes that continue to evolve, and assumptions that are subject to change in the future.

Forward-looking statements include the items identified in the preceding paragraph, the information concerning possible or assumed future results of our operations and other statements contained or incorporated in this Quarterly Report identified by words such as “anticipate,” “estimate,” “expect,” “project,” “intend,” “plan,” “believe,” “should,” “goal,” “forecast,” “guidance,” “could,” “may,” “continue,” “might,” “potential,” “scheduled,” “likely,” and other words and terms of similar meaning.

One should not place undue reliance on forward-looking statements, which are applicable only as of the date of this Quarterly Report. Known and unknown risks, uncertainties and other factors may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by forward-looking statements. Those factors may affect our operations, costs, liquidity, markets, products, services and prices. In addition to any assumptions and other factors referred to specifically in connection with the forward-looking statements, factors that could cause our actual results to differ materially from those contemplated in any forward-looking statement include, among others, the following:

•our ability to recover costs, income taxes and amounts equivalent to the cost of property, plant and equipment, regulatory assets and our allowed rate of return in our regulated rates or other recovery mechanisms;

•cyber-attacks, which, according to experts, continue to increase in volume and sophistication, or breaches of technology systems that could disrupt our operations or result in the loss or exposure of confidential or sensitive customer, employee or Company information; further, increased remote working arrangements have required enhancements and modifications to our IT infrastructure (e.g. Internet, Virtual Private Network, remote collaboration systems, etc.), and any failures of the technologies, including third-party service providers, that facilitate working remotely could limit our ability to conduct ordinary operations or expose us to increased risk or effect of an attack;

•our ability to manage our operations and maintenance costs;

•the concentration of our operations in Oklahoma, Kansas, and Texas;

•changes in regulation of natural gas distribution services, particularly those in Oklahoma, Kansas and Texas;

•the economic climate and, particularly, its effect on the natural gas requirements of our residential and commercial customers;

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•the length and severity of a pandemic or other health crisis which could significantly disrupt or prevent us from operating our business in the ordinary course for an extended period;

•competition from alternative forms of energy, including, but not limited to, electricity, solar power, wind power, geothermal energy and biofuels;

•adverse weather conditions and variations in weather, including seasonal effects on demand and/or supply, the occurrence of severe storms in the territories in which we operate, and climate change, and the related effects on supply, demand, and costs;

•indebtedness could make us more vulnerable to general adverse economic and industry conditions, limit our ability to borrow additional funds and/or place us at competitive disadvantage compared with competitors;

•our ability to secure reliable, competitively priced and flexible natural gas transportation and supply, including decisions by natural gas producers to reduce production or shut-in producing natural gas wells and expiration of existing supply and transportation and storage arrangements that are not replaced with contracts with similar terms and pricing;

•our ability to complete necessary or desirable expansion or infrastructure development projects, which may delay or prevent us from serving our customers or expanding our business;

•operational and mechanical hazards or interruptions;

•adverse labor relations;

•the effectiveness of our strategies to reduce earnings lag, revenue protection strategies and risk mitigation strategies, which may be affected by risks beyond our control such as commodity price volatility, counterparty performance or creditworthiness and interest rate risk;

•the capital-intensive nature of our business, and the availability of and access to, in general, funds to meet our debt obligations prior to or when they become due and to fund our operations and capital expenditures, either through (i) cash on hand, (ii) operating cash flow, or (iii) access to the capital markets and other sources of liquidity;

•our ability to obtain capital on commercially reasonable terms, or on terms acceptable to us, or at all;

•limitations on our operating flexibility, earnings and cash flows due to restrictions in our financing arrangements;

•cross-default provisions in our borrowing arrangements, which may lead to our inability to satisfy all of our outstanding obligations in the event of a default on our part;

•changes in the financial markets during the periods covered by the forward-looking statements, particularly those affecting the availability of capital and our ability to refinance existing debt and fund investments and acquisitions to execute our business strategy;

•actions of rating agencies, including the ratings of debt, general corporate ratings and changes in the rating agencies’ ratings criteria;

•changes in inflation and interest rates;

•our ability to recover the costs of natural gas purchased for our customers and any related financing required to support our purchase of natural gas supply;

•impact of potential impairment charges;

•volatility and changes in markets for natural gas and our ability to secure additional and sufficient liquidity on reasonable commercial terms to cover costs associated with such volatility;

•possible loss of LDC franchises or other adverse effects caused by the actions of municipalities;

•payment and performance by counterparties and customers as contracted and when due, including our counterparties maintaining ordinary course terms of supply and payments;

•changes in existing or the addition of new environmental, safety, tax and other laws to which we and our subsidiaries are subject, including those that may require significant expenditures, significant increases in operating costs or, in the case of noncompliance, substantial fines or penalties;

•the effectiveness of our risk-management policies and procedures, and employees violating our risk-management policies;

•the uncertainty of estimates, including accruals and costs of environmental remediation;

•advances in technology, including technologies that increase efficiency or that improve electricity’s competitive position relative to natural gas;

•population growth rates and changes in the demographic patterns of the markets we serve, and economic conditions in these areas’ housing markets;

•acts of nature and the potential effects of threatened or actual terrorism and war, including recent events in Europe;

•the sufficiency of insurance coverage to cover losses;

•the effects of our strategies to reduce tax payments;

•changes in accounting standards;

•changes in corporate governance standards;

•existence of material weaknesses in our internal controls;

•our ability to comply with all covenants in our indentures and the ONE Gas Credit Agreement, a violation of which, if not cured in a timely manner, could trigger a default of our obligations;

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•our ability to attract and retain talented employees, management and directors, and shortage of skilled-labor;

•unexpected increases in the costs of providing health care benefits, along with pension and postemployment health care benefits, as well as declines in the discount rates on, declines in the market value of the debt and equity securities of, and increases in funding requirements for, our defined benefit plans; and

•our ability to successfully complete merger, acquisition or divestiture plans, regulatory or other limitations imposed as a result of a merger, acquisition or divestiture, and the success of the business following a merger, acquisition or divestiture.

These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other factors could also have material adverse effects on our future results. These and other risks are described in greater detail in Part 1, Item 1A, Risk Factors, in our Annual Report. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these factors. Other than as required under securities laws, we undertake no obligation to update publicly any forward-looking statement whether as a result of new information, subsequent events or change in circumstances, expectations or otherwise.

ITEM 3.    QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our quantitative and qualitative disclosures about market risk are consistent with those discussed in Part II, Item 7A, Quantitative and Qualitative Disclosures About Market Risk, in our Annual Report.

Commodity Price Risk

Our commodity price risk, driven primarily by fluctuations in the price of natural gas, is mitigated by our purchased-gas cost adjustment mechanisms through which we pass-through natural gas costs to our customers without profit. We may use derivative instruments to hedge the cost of a portion of our anticipated natural gas purchases during the winter heating months to reduce the impact on our customers of upward market price volatility of natural gas. Additionally, we inject natural gas into storage during the warmer months, when natural gas prices are typically lower, and withdraw the natural gas during the colder months of the year. Gains or losses associated with these derivative instruments and storage activities are included in, and recoverable through our purchased-gas cost adjustment mechanisms, which are subject to review by regulatory authorities.

Interest-Rate Risk

We are exposed to interest-rate risk primarily associated with commercial paper borrowings, borrowings under our credit agreement, and new debt financing needed to fund capital requirements, including future contractual obligations and maturities of long-term and short-term debt. We may manage interest-rate risk on future borrowings through the use of fixed-rate debt, floating-rate debt and, at times, interest-rate swaps. Fixed-rate swaps may be used to reduce our risk of increased interest costs during periods of rising interest rates. Floating-rate swaps may be used to convert the fixed rates of long-term borrowings into short-term variable rates.

Counterparty Credit Risk

We assess the creditworthiness of our customers. Those customers who do not meet minimum standards are required to provide security, including deposits or other forms of collateral, when appropriate and allowed by tariff. With approximately 2.3 million customers across three states, we are not exposed materially to a concentration of credit risk. We maintain a provision for doubtful accounts based upon factors surrounding the credit risk of customers, historical trends, consideration of the current credit environment and other information. We are able to recover the fuel-related portion of bad debts through our purchased-gas cost adjustment mechanisms.

ITEM 4.CONTROLS AND PROCEDURES

Quarterly Evaluation of Disclosure Controls and Procedures - Our Chief Executive Officer (Principal Executive Officer) and Chief Financial Officer (Principal Financial Officer) have concluded that our disclosure controls and procedures were effective as of the end of the period covered by this report based on the evaluation of the controls and procedures required by Rules 13(a)-15(b) of the Exchange Act.

Changes in Internal Control Over Financial Reporting - There have been no changes in our internal control over financial reporting during the second quarter ended June 30, 2023, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II - OTHER INFORMATION

ITEM 1.    LEGAL PROCEEDINGS

We are a party to various litigation matters and claims that have arisen in the normal course of our operations. While the results of litigation and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable final outcome of such matters will not have a material adverse effect on our results of operations, financial position or cash flows.

ITEM 1A.    RISK FACTORS

Our investors should consider the risks set forth in Part I, Item 1A, Risk Factors, of our Annual Report that could affect us and our business. Although we have tried to discuss key factors, our investors need to be aware that other risks may prove to be important in the future. New risks may emerge at any time, and we cannot predict such risks or estimate the extent to which they may affect our financial performance. Investors should carefully consider the discussion of risks and the other information included or incorporated by reference in this Quarterly Report, including “Forward-Looking Statements,” which are included in Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations.

ITEM 2.UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Not applicable.

ITEM 3.    DEFAULTS UPON SENIOR SECURITIES

Not applicable.

ITEM 4.    MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5.    OTHER INFORMATION

Not applicable.

ITEM 6.    EXHIBITS

Readers of this report should not rely on or assume the accuracy of any representation or warranty or the validity of any opinion contained in any agreement filed as an exhibit to this Quarterly Report, because such representation, warranty or opinion may be subject to exceptions and qualifications contained in separate disclosure schedules, may represent an allocation of risk between parties in the particular transaction, may be qualified by materiality standards that differ from what may be viewed as material for securities law purposes, or may no longer continue to be true as of any given date. All exhibits attached to this Quarterly Report are included for the purpose of complying with requirements of the SEC. Other than the certifications made by our officers pursuant to the Sarbanes-Oxley Act of 2002 included as exhibits to this Quarterly Report, all exhibits are included only to provide information to investors regarding their respective terms and should not be relied upon as constituting or providing any factual disclosures about us, any other persons, any state of affairs or other matters.

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The following exhibits are filed as part of this Quarterly Report:

Exhibit No.		Exhibit Description
	3.1	Amended Certificate of Incorporation of ONE Gas, Inc., dated May 24, 2018 (incorporated by reference to Exhibit 3.1 to ONE Gas, Inc.’s Current Report on Form 8-K filed on May 30, 2018 (File No. 1-36108)).
	3.2	Amended and Restated By-Laws of ONE Gas, Inc. dated February 21, 2023 (incorporated by reference to Exhibit 3.1 to ONE Gas, Inc.’s Current Report on Form 8-K filed on February 21, 2023 (File No. 1-36108)).
	31.1	Certification of Robert S. McAnnally pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
	31.2	Certification of Caron A. Lawhorn pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
	32.1	Certification of Robert S. McAnnally pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished only pursuant to Rule 13a-14(b)).
	32.2	Certification of Caron A. Lawhorn pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished only pursuant to Rule 13a-14(b)).

101.INS	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	XBRL Schema Document.
101.CAL	XBRL Calculation Linkbase Document.
101.LAB	XBRL Label Linkbase Document.
101.PRE	XBRL Presentation Linkbase Document.
101.DEF	XBRL Extension Definition Linkbase Document.
104	Cover Page Interactive Data File (embedded within the Inline XBRL document and contained in Exhibit 101).

Attached as Exhibit 101 to this Quarterly Report are the following XBRL-related documents: (i) Document and Entity Information; (ii) Consolidated Statements of Income for the three and six months ended June 30, 2023 and 2022; (iii) Consolidated Statements of Comprehensive Income for the three and six months ended June 30, 2023 and 2022; (iv) Consolidated Balance Sheets at June 30, 2023 and December 31, 2022; (v) Consolidated Statements of Cash Flows for the six months ended June 30, 2023 and 2022; (vi) Consolidated Statements of Equity for the three and six months ended June 30, 2023 and 2022; and (vii) Notes to Consolidated Financial Statements.

We also make available on our website the Interactive Data Files submitted as Exhibit 101 to this Quarterly Report.

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SIGNATURE

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

Date: August 1, 2023		ONE Gas, Inc.
		Registrant
	By:	/s/ Caron A. Lawhorn
		Caron A. Lawhorn
		Senior Vice President and
		Chief Financial Officer
		(Principal Financial Officer)

40

EX-31.1

Exhibit 31.1

Certification

I, Robert S. McAnnally, certify that:

I have reviewed this quarterly report on Form 10-Q of ONE Gas, Inc.;

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;

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;

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

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:

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: August 1, 2023

/s/ Robert S. McAnnally

Robert S. McAnnally

Chief Executive Officer

EX-31.2

Exhibit 31.2

Certification

I, Caron A. Lawhorn, certify that:

I have reviewed this quarterly report on Form 10-Q of ONE Gas, Inc.;

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;

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;

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

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:

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: August 1, 2023

/s/ Caron A. Lawhorn

Caron A. Lawhorn

Chief Financial Officer

EX-32.1

Exhibit 32.1

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 on Form 10-Q of ONE Gas, Inc. (the “Registrant”) for the period ending June 30, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Robert S. McAnnally, Chief Executive Officer of the Registrant, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)the Report 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 Report fairly presents, in all material respects, the financial condition of the Registrant and results of operations of the Registrant.

/s/ Robert S. McAnnally

Robert S. McAnnally

Chief Executive Officer

August 1, 2023

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 ONE Gas, Inc. and will be retained by ONE Gas, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

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 on Form 10-Q of ONE Gas, Inc. (the “Registrant”) for the period ending June 30, 2023, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Caron A. Lawhorn, Chief Financial Officer of the Registrant, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)the Report 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 Report fairly presents, in all material respects, the financial condition and the results of operations of the Registrant.

/s/ Caron A. Lawhorn

Caron A. Lawhorn

Chief Financial Officer

August 1, 2023

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 ONE Gas, Inc. and will be retained by ONE Gas, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.

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Cover Page - shares	6 Months Ended
	Jun. 30, 2023	Jul. 24, 2023
Document Information [Line Items]
Document Type	10-Q
Document Period End Date	Jun. 30, 2023
Entity Registrant Name	ONE Gas, Inc.
Entity Central Index Key	0001587732
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Information [Line Items]
Document Quarterly Report	true
Document Transition Report	false
Entity File Number	001-36108
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	46-3561936
Entity Address, Address Line One	15 East Fifth Street
Entity Address, City or Town	Tulsa,
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	74103
City Area Code	(918)
Local Phone Number	947-7000
Title of 12(b) Security	Common Stock, par value $0.01 per share
Trading Symbol	OGS
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		55,449,300

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STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Regulated Operating Revenue	$ 398,114	$ 428,975	$ 1,430,257	$ 1,400,434
Cost of natural gas	130,241	188,251	796,040	828,197
Operating expenses
Operations and maintenance	118,614	110,579	245,298	225,674
Depreciation and amortization	67,547	55,043	138,811	112,180
General taxes	17,690	16,533	36,856	35,057
Total operating expenses	203,851	182,155	420,965	372,911
Operating income	64,022	58,569	213,252	199,326
Other Nonoperating Income (Expense)	2,174	(3,983)	4,755	(8,128)
Interest expense, net	(27,485)	(16,320)	(57,600)	(31,915)
Income before income taxes	38,711	38,266	160,407	159,283
Income taxes	(6,022)	(6,191)	(25,097)	(28,274)
Net income	$ 32,689	$ 32,075	$ 135,310	$ 131,009
Earnings per share
Basic	$ 0.59	$ 0.59	$ 2.43	$ 2.42
Diluted	$ 0.58	$ 0.59	$ 2.42	$ 2.42
Weighted Average Number of Shares Outstanding, Basic [Abstract]
Basic	55,566	54,262	55,552	54,092
Weighted Average Number of Shares Outstanding, Diluted [Abstract]
Diluted	55,914	54,335	55,857	54,183
Common Stock, Dividends, Per Share, Declared	$ 0.65	$ 0.62	$ 1.30	$ 1.24

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STATEMENTS OF COMPREHENSIVE INCOME STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Net income	$ 32,689	$ 32,075	$ 135,310	$ 131,009
Change in pension and other postemployment benefit plan liability, net of tax of $—, $(10), $— and $(29), respectively	0	30	0	99
Other comprehensive income, net of tax	0	30	0	99
Comprehensive income	32,689	32,105	135,310	131,108
Pension and other postemployment benefit plans, tax	$ 0	$ (10)	$ 0	$ (29)

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STATEMENTS OF COMPREHENSIVE INCOME STATEMENTS OF COMPREHENSIVE INCOME Parenthetical - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Pension and other postemployment benefit plans, tax	$ 0	$ (10)	$ 0	$ (29)

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BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Property, plant and equipment
Property, plant and equipment	$ 8,117,663	$ 7,834,557
Accumulated depreciation and amortization	2,261,035	2,205,717
Net property, plant and equipment	5,856,628	5,628,840
Cash and Cash Equivalents	7,332	9,681
Restricted Cash and Cash Equivalents	32,006	8,446
Cash, cash equivalents, restricted cash and restricted cash equivalents	39,338	18,127
Current assets
Accounts receivable, net	234,409	553,834
Materials and supplies	72,594	70,873
Natural Gas in Storage	144,742	269,205
Regulatory assets, Current	64,912	275,572
Other current assets	31,294	29,997
Total current assets	587,289	1,217,608
Goodwill and other assets
Regulatory assets, Noncurrent	304,614	330,831
Other Intangible Assets, Net	309,569	323,838
Goodwill	157,953	157,953
Other assets	119,069	117,326
Total goodwill and other assets	891,205	929,948
Total assets	7,335,122	7,776,396
Equity and long-term debt
Common stock, $0.01 par value: authorized 250,000,000 shares; issued and outstanding 55,446,841 shares at June 30, 2023; issued and outstanding 55,349,954 shares at December 31, 2022	554	553
Paid-in Capital	1,940,446	1,932,714
Retained earnings	714,530	651,863
Accumulated other comprehensive loss	(704)	(704)
Total equity	2,654,826	2,584,426
Other Long-Term Debt, Noncurrent	1,580,263	2,352,400
Securitized utility tariff bonds, excluding current maturities, net of issuance costs	295,949	309,343
Long-Term Debt, Excluding Current Maturities, Total	1,876,212	2,661,743
Total equity and long-term debt	4,531,038	5,246,169
Current liabilities
Long-term Debt, Current Maturities	772,838	12
Current maturities of securitized utility tariff bonds	34,201	20,716
Short-term debt	217,100	552,000
Accounts payable	154,121	360,493
Accrued taxes other than income	54,400	78,352
Regulatory Liability, Current	79,686	47,867
Customer deposits	54,635	57,854
Other current liabilities	87,110	72,125
Total current liabilities	1,454,091	1,189,419
Deferred credits and other liabilities
Deferred income taxes	727,184	698,456
Regulatory Liability, Noncurrent	512,633	529,441
Employee benefit obligations	19,620	19,587
Other deferred credits	90,556	93,324
Liabilities, Other than Long-term Debt, Noncurrent	1,349,993	1,340,808
Commitments and contingencies
Total liabilities and equity	$ 7,335,122	$ 7,776,396

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BALANCE SHEETS BALANCE SHEETS Parenthetical - $ / shares	Jun. 30, 2023	Dec. 31, 2022
Common Stock, Par or Stated Value Per Share	$ 0.01
Common Stock, Shares Authorized	250,000,000
Common Stock, Shares, Issued	55,446,841	55,349,954
Common Stock, Shares, Outstanding	55,446,841	55,349,954

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STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Operating activities
Net income	$ 135,310	$ 131,009
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	138,811	112,180
Deferred income taxes	11,912	(18,780)
Share-based compensation expense	6,305	5,699
Provision for doubtful accounts	4,880	2,511
Proceeds from Securitization Bonds, Operating Activities	197,366	0
Changes in assets and liabilities:
Accounts receivable	314,545	100,955
Materials and supplies	(1,721)	(7,927)
Natural gas in storage	124,463	(18,660)
Payments for Removal Costs	(32,551)	(20,919)
Accounts payable	(198,968)	(92,887)
Accrued taxes other than income	(23,952)	(8,852)
Customer deposits	(3,219)	(2,177)
Increase (Decrease) In Regulatory Assets And Liabilities Current, net	35,633	43,697
Increase (Decrease) In Regulatory Assets And Liabilities Noncurrent, net	26,217	56,135
Increase (Decrease) in Other Current Assets and Liabilities, Net	12,156	8,234
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net	1,555	(3,541)
Cash provided by operating activities	748,742	286,677
Investing activities
Capital expenditures	(322,231)	(251,060)
Payments for Other Investing Activities	(1,647)	(1,332)
Proceeds from Sale of Other Assets, Investing Activities	2,462	891
Cash used in investing activities	(321,416)	(251,501)
Financing activities
Borrowings (repayments) of short-term debt, net	(334,900)	(3,900)
Proceeds from Issuance of Common Stock	3,175	37,104
Dividends paid	(72,006)	(66,821)
Payment, Tax Withholding, Share-based Payment Arrangement	(2,384)	(3,026)
Cash used in financing activities	(406,115)	(36,643)
Change in cash and cash equivalents	21,211	(1,467)
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Beginning Balance	18,127	8,852
Cash, cash equivalents, restricted cash and restricted cash equivalents at end of period	39,338	7,385
Interest Paid, Excluding Capitalized Interest, Operating Activities	47,773	41,600
Income Taxes Paid, Net	$ 9,174	$ 16,200

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STATEMENT OF CHANGES IN EQUITY - USD ($) $ in Thousands	Total	Common Stock [Member]	Paid-in Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]
Shares issued, beginning balance at Dec. 31, 2021		53,633,210
Common stock issued, shares		456,607
Shares issued, ending balance at Mar. 31, 2022		54,089,817
Equity, beginning balance at Dec. 31, 2021	$ 2,349,532	$ 536	$ 1,790,362	$ 565,161	$ (6,527)
Net income	98,934	0	0	98,934	0
Other comprehensive income	69	0	0	0	69
Common stock issued, value	$ 34,140	5	34,135	0	0
Dividends paid per share of stock	$ 0.62
Dividends, Common Stock	$ (33,285)	0	274	(33,559)	0
Equity, ending balance at Mar. 31, 2022	2,449,390	$ 541	1,824,771	630,536	(6,458)
Shares issued, beginning balance at Dec. 31, 2021		53,633,210
Shares issued, ending balance at Jun. 30, 2022		54,137,217
Equity, beginning balance at Dec. 31, 2021	2,349,532	$ 536	1,790,362	565,161	(6,527)
Net income	131,009
Other comprehensive income	99
Equity, ending balance at Jun. 30, 2022	2,453,596	$ 541	1,830,678	628,805	(6,428)
Shares issued, beginning balance at Mar. 31, 2022		54,089,817
Common stock issued, shares		47,400
Shares issued, ending balance at Jun. 30, 2022		54,137,217
Equity, beginning balance at Mar. 31, 2022	2,449,390	$ 541	1,824,771	630,536	(6,458)
Net income	32,075	0	0	32,075	0
Other comprehensive income	30	0	0	0	30
Common stock issued, value	$ 5,636	0	5,636	0	0
Dividends paid per share of stock	$ 0.62
Dividends, Common Stock	$ (33,535)	0	271	(33,806)	0
Equity, ending balance at Jun. 30, 2022	$ 2,453,596	$ 541	1,830,678	628,805	(6,428)
Shares issued, beginning balance at Dec. 31, 2022	55,349,954	55,349,954
Common stock issued, shares		39,096
Shares issued, ending balance at Mar. 31, 2023		55,389,050
Equity, beginning balance at Dec. 31, 2022	$ 2,584,426	$ 553	1,932,714	651,863	(704)
Net income	102,621	0	0	102,621	0
Common stock issued, value	$ 435		435	0	0
Dividends paid per share of stock	$ 0.65
Dividends, Common Stock	$ (36,002)	0	319	(36,321)	0
Equity, ending balance at Mar. 31, 2023	$ 2,651,480	$ 553	1,933,468	718,163	(704)
Shares issued, beginning balance at Dec. 31, 2022	55,349,954	55,349,954
Shares issued, ending balance at Jun. 30, 2023	55,446,841	55,446,841
Equity, beginning balance at Dec. 31, 2022	$ 2,584,426	$ 553	1,932,714	651,863	(704)
Net income	135,310
Other comprehensive income	0
Equity, ending balance at Jun. 30, 2023	$ 2,654,826	$ 554	1,940,446	714,530	(704)
Shares issued, beginning balance at Mar. 31, 2023		55,389,050
Common stock issued, shares		57,791
Shares issued, ending balance at Jun. 30, 2023	55,446,841	55,446,841
Equity, beginning balance at Mar. 31, 2023	$ 2,651,480	$ 553	1,933,468	718,163	(704)
Net income	32,689	0	0		0
Other comprehensive income	0
Common stock issued, value	$ 6,661	1	6,660	0	0
Dividends paid per share of stock	$ 0.65
Dividends, Common Stock	$ (36,004)	0	318	(36,322)	0
Equity, ending balance at Jun. 30, 2023	$ 2,654,826	$ 554	$ 1,940,446	$ 714,530	$ (704)

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Notes)

6 Months Ended

Jun. 30, 2023

Significant Accounting Policies [Line Items]

SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Our accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. These statements also have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair statement of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2022 year-end consolidated balance sheet data was derived from audited consolidated financial statements but does not include all disclosures required by GAAP. These unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and footnotes in our Annual Report. Our significant accounting policies are described in Note 1 of our Notes to Consolidated Financial Statements in our Annual Report. The preparation of these financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts and disclosures in the financial statements. Although management believes these estimates are reasonable, actual results could differ materially from these estimates. Due to the seasonal nature of our business, the results of operations for the six months ended June 30, 2023, are not necessarily indicative of the results that may be expected for a 12-month period.

We provide natural gas distribution services to approximately 2.3 million customers in Oklahoma, Kansas and Texas through our three divisions, Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively. We primarily serve residential, commercial and transportation customers in all three states.

Segments - We operate in one reportable business segment: regulated public utilities that deliver natural gas primarily to residential, commercial and transportation customers. Our accounting policies are the same as those described in Note 1 of the Notes to Consolidated Financial Statements in our Annual Report. We evaluate our financial performance principally on net income. For the three and six months ended June 30, 2023 and 2022, we had no single external customer from which we received 10 percent or more of our gross revenues.

Property, Plant and Equipment and Asset Removal Costs - Accounts payable for construction work in progress and asset removal costs decreased by approximately $7.9 million and $7.8 million for the six months ended June 30, 2023 and 2022, respectively. Such amounts are not included in capital expenditures or asset removal costs in our consolidated statements of cash flows.

Accounts Receivable, net - Accounts receivable represent valid claims against nonaffiliated customers for natural gas sold or services rendered. We assess the creditworthiness of our customers. Those customers who do not meet minimum standards may be required to provide security, including deposits and other forms of collateral, when appropriate and allowed by our tariffs. With approximately 2.3 million customers across three states, we are not exposed materially to a concentration of credit risk. We maintain an allowance for doubtful accounts based upon factors surrounding the credit risk of customers, historical trends, consideration of the current environment and other information. We recover natural gas costs related to accounts written off when they are deemed uncollectible through the purchased-gas cost adjustment mechanisms in each of our jurisdictions. At June 30, 2023 and December 31, 2022, our allowance for doubtful accounts was $17.0 million and $16.7 million, respectively.

Reclassifications -A reclassification has been made in the prior-year financial statements to conform to the current-year presentation. We have updated our consolidated balance sheet at December 31, 2022, to disaggregate “current maturities of other long-term debt,” which had previously been included in “other current liabilities,” to conform to our current-year presentation.

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REVENUE (Notes)

6 Months Ended

Jun. 30, 2023

Revenue from Contract with Customer

REVENUE

The following table sets forth our revenues disaggregated by source for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(Thousands of dollars)
Natural gas sales to customers	$	346,734	$	393,292	$	1,313,093	$	1,318,449
Transportation revenues	29,022		28,000		67,549		64,316
Securitization customer charges (Note 14)	11,807		—		23,740		—
Miscellaneous revenues	6,313		5,128		12,211		9,624
Total revenues from contracts with customers	393,876		426,420		1,416,593		1,392,389
Other revenues - natural gas sales related	1,614		(115)		7,404		2,231
Other revenues	2,624		2,670		6,260		5,814
Total other revenues	4,238		2,555		13,664		8,045
Total revenues	$	398,114	$	428,975	$	1,430,257	$	1,400,434

Accrued unbilled natural gas sales revenues at June 30, 2023 and December 31, 2022, were $64.5 million and $269.5 million, respectively, and are included in accounts receivable on our consolidated balance sheets.

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REGULATORY ASSETS AND LIABILITIES (Notes)

6 Months Ended

Jun. 30, 2023

SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]

Schedule of Regulatory Assets and Liabilities

REGULATORY ASSETS AND LIABILITIES

The tables below present a summary of regulatory assets and liabilities, net of amortization, for the periods indicated:

	June 30, 2023
	Current		Noncurrent		Total
	(Thousands of dollars)
Winter weather event costs	$	22,633	$	26,117	$	48,750
Pension and postemployment benefit costs	4,603		239,975		244,578
Reacquired debt costs	812		2,985		3,797
MGP remediation costs	98		31,891		31,989
Ad-valorem tax	12,125		—		12,125
WNA	7,809		—		7,809
Customer credit deferrals	13,820		—		13,820
Other	3,012		3,646		6,658
Total regulatory assets, net of amortization	64,912		304,614		369,526
Income tax rate changes	—		(512,633)		(512,633)
Over-recovered purchased-gas costs	(79,686)		—		(79,686)
Total regulatory liabilities	(79,686)		(512,633)		(592,319)
Net regulatory assets and liabilities	$	(14,774)	$	(208,019)	$	(222,793)

	December 31, 2022
	Current		Noncurrent		Total
	(Thousands of dollars)
Winter weather event costs	$	221,926	$	36,291	$	258,217
Under-recovered purchased-gas costs	19,755		—		19,755
Pension and postemployment benefit costs	—		258,257		258,257
Reacquired debt costs	812		3,347		4,159
MGP remediation costs	98		29,743		29,841
Ad-valorem tax	13,359		—		13,359
WNA	8,474		—		8,474
Customer credit deferrals	9,504		—		9,504
Other	1,644		3,193		4,837
Total regulatory assets, net of amortization	275,572		330,831		606,403
Pension and other postemployment benefit costs	(8,228)		—		(8,228)
Income tax rate changes	—		(529,441)		(529,441)
Over-recovered purchased-gas costs	(39,639)		—		(39,639)
Total regulatory liabilities	(47,867)		(529,441)		(577,308)
Net regulatory assets and liabilities	$	227,705	$	(198,610)	$	29,095

Regulatory assets in our consolidated balance sheets, as authorized by various regulatory authorities, are probable of recovery. Base rates and certain riders are designed to provide a recovery of costs during the period such rates are in effect, but do not generally provide for a return on investment for amounts we have deferred as regulatory assets. All of our regulatory assets are subject to review by the respective regulatory authorities during future regulatory proceedings. We are not aware of any evidence that these costs will not be recoverable through either riders, base rates, or securitization.

Winter weather event costs - In February 2021, the U.S. experienced Winter Storm Uri, a historic winter weather event impacting supply, market pricing and demand for natural gas in a number of states, including our service territories of Oklahoma, Kansas, and Texas. During this time, the governors of Oklahoma, Kansas, and Texas each declared a state of emergency, and certain regulatory agencies issued emergency orders that impacted the utility and natural gas industries, including statewide utility curtailment programs and orders requiring jurisdictional natural gas and electric utilities to do all things possible and necessary to ensure that natural gas and electricity utility services continued to be provided to their customers. Due to the historic nature of this winter weather event, we experienced unforeseeable and unprecedented market pricing for natural gas in our Oklahoma, Kansas, and Texas jurisdictions, which resulted in aggregated natural gas purchases for the month of February 2021 of approximately $2.1 billion.

Each state enacted securitization legislation to allow for recovery of the extraordinary gas costs, as well as other authorized expenses related to Winter Storm Uri. Securitization proceeds were received for Oklahoma and Kansas in 2022, and for Texas in 2023. See our Annual Report for more discussion of events surrounding Winter Storm Uri and the securitization of the related regulatory assets.

Texas - Pursuant to securitization legislation enacted in Texas as a result of Winter Storm Uri and a June 2021 RRC Notice to Gas Utilities, Texas Gas Service submitted an application to the RRC in July 2021, for an order authorizing the amount of extraordinary costs for recovery and other such specifications necessary for the issuance of securitized bonds.

In February 2022, the RRC issued a single financing order for Texas Gas Service and other natural gas utilities in Texas participating in the securitization process, which included a determination that the approved costs will be collected from customers over a period of not more than 30 years. The TPFA formed the TNG Corporation, a new independent public authority, to issue the securitized bonds.

In March 2023, the TNG Corporation completed the issuance of the Customer Rate Relief (Winter Storm Uri), Taxable Series 2023 Bonds and we received our portion of the net proceeds, which was approximately $197 million. The proceeds were used to repay certain indebtedness and for general corporate purposes. Interest costs that exceeded the amount securitized have been deferred and will be addressed in the next general rate proceeding in each jurisdiction in Texas.

At June 30, 2023, Texas Gas Service had deferred approximately $31.2 million in extraordinary costs associated with Winter Storm Uri attributable to its former West Texas service area. Pursuant to the approved settlement order, Texas Gas Service began collecting the extraordinary costs, including carrying costs, from those customers in January 2022.

The deferred winter weather event costs also include invoiced costs for natural gas purchases during Winter Storm Uri that have not been paid as we work with our suppliers for Kansas and Texas to resolve discrepancies in invoiced amounts. These amounts may be adjusted as the differences with suppliers are resolved. Settlements of these amounts are recoverable through the purchased gas cost mechanisms in the respective state. Future adjustments to the amounts are not expected to have a material impact on earnings.

Other regulatory assets and liabilities - Purchased-gas costs represent the natural gas costs that have been over- or under-recovered from customers through the purchased-gas cost adjustment mechanisms, and includes natural gas utilized in our operations and premiums paid and any cash settlements received from our purchased natural gas call options.

The OCC, KCC and regulatory authorities in Texas have approved the recovery of pension costs and other postemployment benefits costs through rates for Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively. The costs recovered through rates are based on the net periodic benefit cost for defined benefit pension and other postemployment costs. Differences, if any, between the net periodic benefit cost, net of deferrals, and the amount recovered through rates are reflected in earnings. We historically have recovered defined benefit pension and other postemployment benefit costs through rates. We believe it is probable that regulators will continue to include the net periodic pension and other postemployment benefit costs in our cost of service.

We amortize reacquired debt costs in accordance with the accounting guidelines prescribed by the OCC and the KCC.

See Note 12 for additional information regarding our regulatory assets for MGP remediation costs.

Ad-valorem tax represents the difference in Kansas Gas Service’s taxes incurred each year above or below the amount approved in base rates. This difference is deferred as a regulatory asset or liability for a 12-month period. Kansas Gas Service then applies an adjustment to customers’ bills to refund the over-collected revenue or bill the under-collected revenue over the subsequent 12 months.

Weather normalization represents revenue over- or under-recovered through the WNA rider in Kansas. This amount is deferred as a regulatory asset or liability for a 12-month period. Kansas Gas Service then applies an adjustment to the customers’ bills for 12 months to refund the over-collected revenue or bill the under-collected revenue.

The customer credit deferrals and the noncurrent regulatory liability for income tax rate changes represents deferral of the effects of enacted federal and state income tax rate changes on our ADIT and the effects of these changes on our rates. See Note 10 for additional information regarding the impact of income tax rate changes.

Recovery through rates resulted in amortization of regulatory assets of approximately $2.5 million and $1.6 million for the three months ended June 30, 2023 and 2022, respectively, and approximately $9.5 million and $6.0 million for the six months ended June 30, 2023 and 2022, respectively.

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CREDIT FACILITIES (Notes)

6 Months Ended

Jun. 30, 2023

Short-term Debt [Line Items]

Short-term Debt [Text Block]

CREDIT FACILITY AND SHORT-TERM DEBT

In March 2023, we entered into an extension agreement related to the ONE Gas Credit Agreement that extended the maturity date to March 16, 2028, from March 16, 2027. All other terms and conditions of the ONE Gas Credit Agreement remain in full force and effect.

The ONE Gas Credit Agreement provides for a $1.0 billion revolving unsecured credit facility and includes a $20 million letter of credit subfacility. We can request an increase in commitments of up to an additional

$500 million upon satisfaction of customary conditions, including receipt of commitments from either new lenders or increased commitments from existing lenders. The ONE Gas Credit Agreement is available to provide liquidity for working capital, capital expenditures, acquisitions and mergers, the issuance of letters of credit and for other general corporate purposes.

The ONE Gas Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining ONE Gas’ total debt-to-capital ratio of no more than 70 percent at the end of any calendar quarter. At June 30, 2023, our total debt-to-capital ratio was 52 percent and we were in compliance with all covenants under the ONE Gas Credit Agreement. We may reduce the unutilized portion of the ONE Gas Credit Agreement in whole or in part without premium or penalty. The ONE Gas Credit Agreement contains customary events of default. Upon the occurrence of certain events of default, the obligations under the ONE Gas Credit Agreement may be accelerated and the commitments may be terminated.

At June 30, 2023, we had $1.2 million in letters of credit issued and no borrowings under the ONE Gas Credit Agreement, with $998.8 million of remaining credit, which is available to repay our commercial paper borrowings.

We have a commercial paper program under which we may issue unsecured commercial paper up to a maximum amount of $1.0 billion to fund short-term borrowing needs. The maturities of the commercial paper vary but may not exceed 270 days from the date of issue. Commercial paper is generally sold at par less a discount representing an interest factor. At June 30, 2023 and December 31, 2022, we had $217.1 million and $552.0 million of commercial paper outstanding with a weighted-average interest rate of 5.43 percent and 4.75 percent, respectively.

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LONG-TERM DEBT (Notes)

6 Months Ended

Jun. 30, 2023

Long-Term Debt, Unclassified [Abstract]

Long-term Debt [Text Block]

LONG-TERM DEBT

The table below presents a summary of our long-term debt outstanding for the periods indicated:

	Interest rate at June 30, 2023	June 30, 2023		December 31, 2022
		(Thousands of dollars)
Senior Notes due:
February 2024	3.610%	$	300,000	$	300,000
March 2024	1.100%	473,000		473,000
May 2030	2.000%	300,000		300,000
September 2032	4.250%	300,000		300,000
February 2044	4.658%	600,000		600,000
November 2048	4.500%	400,000		400,000
Total Senior Notes		2,373,000		2,373,000
KGSS-I Securitized Utility Tariff Bonds	5.486%	336,000		336,000
Other	8.000%	1,244		1,250
Unamortized discounts on long-term debt		(7,422)		(7,636)
Debt issuance costs (a)		(19,571)		(20,143)
Total long-term debt, net		2,683,251		2,682,471
Less: current maturities of securitized utility tariff bonds		34,201		20,716
Less: current maturities of other long-term debt, net		772,838		12
Noncurrent portion of long-term debt, net		$	1,876,212	$	2,661,743

(a) Includes $5.8 million of issuance costs for the KGSS-I Securitized Utility Tariff Bonds.

Senior Notes - The indenture governing our Senior Notes includes an event of default upon the acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding Senior Notes to declare those Senior Notes immediately due and payable in full.

Depending on the series, we may redeem our Senior Notes at par, plus accrued and unpaid interest to the redemption date, starting three months or six months before their maturity dates. Prior to these dates, we may redeem these Senior Notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective Senior Note plus accrued and unpaid interest to the redemption date. Our $473 million of 1.10 percent senior notes due March 2024 can be called at par with a 30-day notice. Our Senior Notes are senior unsecured obligations, ranking equally in right of payment with all of our existing and future unsecured senior indebtedness.

Securitized Utility Tariff Bonds - The KGSS-I Securitized Utility Tariff Bonds are governed by an indenture between KGSS-I and the indenture trustee. The indenture contains certain covenants that restrict KGSS-I’s ability to sell, transfer, convey, exchange, or otherwise dispose of its assets. See Note 14 for additional discussion of the Kansas securitization transaction.

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EQUITY (Notes)

6 Months Ended

Jun. 30, 2023

Class of Stock [Line Items]

Stockholders' Equity Note Disclosure [Text Block]

EQUITY

Equity Forward Agreement - In March 2023, we entered into an underwriting agreement and a forward sale agreement for 2.0 million shares of our common stock. The forward sale agreement provides for settlement on a date, or dates, to be specified at our discretion, but which will occur no later than December 29, 2023, for 1.4 million shares of common stock and by December 31, 2024, for the remaining balance.

At-the-Market Equity Program - In February 2023, we entered into an at-the-market equity distribution agreement under which we may issue and sell shares of our common stock with an aggregate offering price up to $300 million (including any shares of common stock that may be sold pursuant to the master forward sale confirmation entered into in connection with the equity distribution agreement and the related supplemental confirmations). This at-the-market equity program replaced our previous at-the-market equity program, which began in February 2020, and expired in February 2023. The program allows us to offer and sell our common stock at prices we deem appropriate. Sales of common stock are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. At June 30, 2023, we had $226.1 million of equity available for issuance under the program.

For the six months ended June 30, 2023, we executed forward sale agreements under our current at-the-market equity program for 926,465 shares of our common stock.

The following table summarizes all of our outstanding forward sale agreements at June 30, 2023:

Maturity	Shares Sold	Net Proceeds Available (in thousands)		Forward Price
At-the-Market Equity Program
December 29, 2023	289,403	$	21,780	$	75.26
December 31, 2024	926,465	73,906		$	79.77
Total At-the-Market Equity Program	1,215,868	95,686		$	78.70
Equity Forward Agreement
December 29, 2023	1,400,000	107,095		$	76.50
December 31, 2024	600,000	45,898		$	76.50
Total Equity Forward Agreement	2,000,000	152,993		$	76.50
Total forward sale agreements	3,215,868	$	248,679	$	77.33

For the six months ended June 30, 2022, we executed forward sale agreements for 591,736 shares of our common stock. On December 30, 2022, we settled these forward sale agreements for net proceeds of $48.0 million.

For the six months ended June 30, 2022, we issued and sold 403,792 shares of our common stock for $35.0 million, generating net proceeds of $34.7 million.

Dividends Declared - In July 2023, we declared a dividend of $0.65 per share ($2.60 per share on an annualized basis) for shareholders of record as of August 16, 2023, payable on September 1, 2023.

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Notes)

6 Months Ended

Jun. 30, 2023

Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]

Comprehensive Income (Loss) Note

ACCUMULATED OTHER COMPREHENSIVE LOSS

The following table sets forth the effect of reclassifications from accumulated other comprehensive loss in our consolidated statements of income for the periods indicated:

	Three Months Ended				Six Months Ended				Affected Line Item in the
Details About Accumulated Other	June 30,				June 30,				Consolidated Statements
Comprehensive Loss Components	2023		2022		2023		2022		of Income
	(Thousands of dollars)
Pension and other postemployment benefit plan obligations (a)
Amortization of net loss	$	490	$	4,252	$	980	$	12,453
Amortization of unrecognized prior service cost (credit)	131		72		262		82
	621		4,324		1,242		12,535
Regulatory adjustments (b)	(621)		(4,265)		(1,242)		(12,388)
	—		59		—		147		Income before income taxes
	—		(15)		—		(34)		Income tax expense
Total reclassifications for the period	$	—	$	44	$	—	$	113	Net income

(a) These components of accumulated other comprehensive loss are included in the computation of net periodic benefit cost. See Note 9 for additional detail of our net periodic benefit cost.

(b) Regulatory adjustments represent pension and other postemployment benefit costs expected to be recovered through rates and are deferred as part of our regulatory assets. See Note 3 for additional disclosures of regulatory assets and liabilities.

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EARNINGS PER SHARE (Notes)

6 Months Ended

Jun. 30, 2023

EARNINGS PER SHARE [Line Items]

Earnings Per Share [Text Block]

EARNINGS PER SHARE

Basic EPS is calculated by dividing net income by the daily weighted-average number of common shares outstanding during the periods presented, which includes fully vested stock awards that have not yet been issued as common stock. Diluted EPS is based on shares outstanding for the calculation of basic EPS, plus unvested stock awards granted under our compensation plans and equity forward sale agreements, but only to the extent these instruments dilute earnings per share.

The following tables set forth the computation of basic and diluted EPS from continuing operations for the periods indicated:

	Three Months Ended June 30, 2023
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	32,689	55,566	$	0.59
Diluted EPS Calculation
Effect of dilutive securities	—		348
Net income available for common stock and common stock equivalents	$	32,689	55,914	$	0.58
	Three Months Ended June 30, 2022
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	32,075	54,262	$	0.59
Diluted EPS Calculation
Effect of dilutive securities	—		73
Net income available for common stock and common stock equivalents	$	32,075	54,335	$	0.59
	Six Months Ended June 30, 2023
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	135,310	55,552	$	2.43
Diluted EPS Calculation
Effect of dilutive securities	—		305
Net income available for common stock and common stock equivalents	$	135,310	55,857	$	2.42
	Six Months Ended June 30, 2022
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	131,009	54,092	$	2.42
Diluted EPS Calculation
Effect of dilutive securities	—		91
Net income available for common stock and common stock equivalents	$	131,009	54,183	$	2.42

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EMPLOYEE BENEFIT PLANS (Notes)

6 Months Ended

Jun. 30, 2023

Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]

Employee Benefit Plans (Notes)

EMPLOYEE BENEFIT PLANS

The following tables set forth the components of net periodic benefit cost for our pension and other postemployment benefit plans for the periods indicated:

	Pension Benefits
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2023		2022		2023		2022
	(Thousands of dollars)
Components of net periodic benefit cost (credit)
Service cost		$	1,811	$	2,592	$	3,622	$	5,686
Interest cost		10,607		9,037		21,214		16,841
Expected return on assets		(14,879)		(14,632)		(29,758)		(29,245)
Amortization of unrecognized prior service cost		93		62		186		62
Amortization of net loss		502		4,198		1,004		12,345
Net periodic benefit cost (credit)		$	(1,866)	$	1,257	$	(3,732)	$	5,689

	Other Postemployment Benefits
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(Thousands of dollars)
Components of net periodic benefit cost (credit)
Service cost	$	183	$	318	$	366	$	636
Interest cost	2,288		1,612		4,576		3,224
Expected return on assets	(2,432)		(3,295)		(4,864)		(6,590)
Amortization of unrecognized prior service cost	38		10		76		20
Amortization of net (gain) loss	(12)		54		(24)		108
Net periodic benefit cost (credit)	$	65	$	(1,301)	$	130	$	(2,602)

We recover qualified pension benefit plan and other postemployment benefit plan costs through rates charged to our customers. Certain regulatory authorities require that the recovery of these costs be based on specific guidelines. The difference between these regulatory-based amounts and the periodic benefit cost calculated pursuant to GAAP is deferred as a regulatory asset or liability and amortized to expense over periods in which this difference will be recovered in rates, as authorized by the applicable regulatory authorities. For the six months ended June 30, 2023 and 2022, regulatory deferrals related to net periodic benefit cost were not material.

We capitalize all eligible service cost and non-service cost components under the accounting requirements of ASC Topic 980 (Regulated Operations) for rate-regulated entities. Capitalized non-service costs reflected as a regulatory asset in our consolidated balance sheets were not material at June 30, 2023, and were $2.8 million at December 31, 2022. See Note 3 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional information.

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INCOME TAXES (Notes)

6 Months Ended

Jun. 30, 2023

Income Tax Disclosure [Abstract]

Income Tax Disclosure

INCOME TAXES

We use an estimated annual effective tax rate for purposes of determining the income tax provision during interim reporting periods. In calculating our estimated annual effective tax rate, we consider forecasted annual pre-tax income and estimated permanent book versus tax differences, as well as tax credits. Adjustments to the effective tax rate and estimates will occur as information and assumptions change.

At June 30, 2023, we have no uncertain tax positions. Changes in tax laws or tax rates are recognized in the financial reporting period that includes the enactment date. We are no longer subject to income tax examination for years prior to 2018.

Income tax expense reflects credits for the amortization of the regulatory liability associated with EDIT that was returned to customers of $3.1 million and $3.0 million for the three months ended June 30, 2023 and 2022, respectively, and credits of $13.0 million and $10.9 million for the six months ended June 30, 2023 and 2022, respectively.

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OTHER INCOME AND OTHER EXPENSE (Notes)

6 Months Ended

Jun. 30, 2023

Other Income and Other Expense Disclosure [Text Block]

OTHER INCOME AND OTHER EXPENSE

The following table sets forth the components of other income and other expense for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(Thousands of dollars)
Net periodic benefit credit other than service cost	$	963	$	1,366	$	1,871	$	778
Earnings (losses) on investments associated with nonqualified employee benefit plans	1,274		(4,619)		2,887		(7,452)
Other, net	(63)		(730)		(3)		(1,454)
Total other income (expense), net	$	2,174	$	(3,983)	$	4,755	$	(8,128)

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COMMITMENTS AND CONTINGENCIES (Notes)

6 Months Ended

Jun. 30, 2023

Commitments and Contingencies [Line Items]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

Environmental Matters - We are subject to multiple laws and regulations regarding protection of the environment and natural and cultural resources, which affect many aspects of our present and future operations. Regulated activities include, but are not limited to, those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, wetland preservation, plant and wildlife protection, hazardous materials use, storage and transportation, and pipeline and facility construction. These laws and regulations require us to obtain and/or comply with a wide variety of environmental clearances, registrations, licenses, permits and other approvals. Failure to comply with these laws, regulations, licenses and permits or the discovery of presently unknown environmental conditions may expose us to fines, penalties and/or interruptions in our operations that could be material to our results of operations. In addition, emission controls and/or other regulatory or permitting mandates under the CAA and other similar federal and state laws could require unexpected capital expenditures. We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to us. Revised or additional statutes or regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition and results of operations. Our expenditures for environmental investigation and remediation compliance to-date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three and six months ended June 30, 2023 and 2022.

We own or retain legal responsibility for certain environmental conditions at 12 former MGP sites in Kansas. These sites contain contaminants generally associated with MGP sites and are subject to control or remediation under various environmental laws and regulations. A consent agreement with the KDHE governs all environmental investigation and remediation work at these sites. The terms of the consent agreement require us to investigate these sites and set remediation activities based upon the results of the investigations and risk analysis. Remediation typically involves the management of contaminated soils and may involve removal of structures and monitoring and/or remediation of groundwater. Regulatory closure has been achieved at five of the 12 sites, but these sites remain subject to potential future requirements that may result in additional costs.

We have an AAO that allows Kansas Gas Service to defer and seek recovery of costs necessary for investigation and remediation at, and nearby, these 12 former MGP sites that are incurred after January 1, 2017, up to a cap of $15.0 million, net of any related insurance recoveries. Costs approved for recovery in a future rate proceeding would then be amortized over a 15-year period. The unamortized amounts will not be included in rate base or accumulate carrying charges. Following a determination that future investigation and remediation work approved by the KDHE is expected to exceed $15.0 million, net of any related insurance recoveries, Kansas Gas Service will be required to file an application with the KCC for approval to increase the $15.0 million cap. At June 30, 2023 and December 31, 2022, we have deferred $32.0 million for accrued investigation and remediation costs pursuant to our AAO. Kansas Gas Service expects to file an application as soon as practicable after the KDHE approves the plans we have submitted.

We have completed or are addressing removal of the source of soil contamination at all 12 sites and continue to monitor groundwater at seven of the 12 sites according to plans approved by the KDHE. In 2019, we completed a project to remove a source of contamination and associated contaminated materials at the twelfth site where no active soil remediation had previously occurred. In 2022, we completed a remediation project to remove a source of contamination and contaminated materials at one of the MGP sites. In June 2023, we submitted a revised draft remediation plan to the KDHE for review following receipt of agency comments and public feedback.

We also own or retain legal responsibility for certain environmental conditions at a former MGP site in Texas. At the request of the TCEQ, we began investigating the level and extent of contamination associated with the site under their Texas Risk Reduction Program. A preliminary site investigation revealed that this site contains contaminants generally associated with MGP sites and is subject to control or remediation under various environmental laws and regulations. Impacts have been identified in the soil and groundwater at the site with limited impacts observed in surrounding areas. In April 2022, we submitted a remediation work plan to address the areas impacted to the TCEQ. At June 30, 2023, estimated costs associated with expected remediation activities for this site are not material.

Our expenditures for environmental evaluation, mitigation, remediation and compliance to date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three and six months ended June 30, 2023 and 2022. The reserve for remediation of our MGP sites was $14.8 million and $12.7 million at June 30, 2023 and December 31, 2022, respectively.

Pipeline Safety - We are subject to regulation under federal pipeline safety statutes and any analogous state regulations. These include safety requirements for the design, construction, operation, and maintenance of pipelines, including transmission and distribution pipelines. At the federal level, we are regulated by PHMSA. PHMSA regulations require the following for certain pipelines: inspection and maintenance plans; integrity management programs, including the determination of pipeline integrity risks and periodic assessments on certain pipeline segments; an operator qualification program, which includes certain trainings; a public awareness program that provides certain information; and a control room management plan.

As part of the Consolidated Appropriations Act, 2021, the PIPES Act reauthorized PHMSA through 2023 and directed the agency to move forward with several regulatory actions, including the “Pipeline Safety: Class Location Change Requirements” and the “Pipeline Safety: Safety of Gas Transmission and Gathering Pipelines” proposed rulemakings. Congress has also instructed PHMSA to issue final regulations that will require operators of new and existing transmission and distribution pipeline facilities to conduct certain leak detection and repair programs and to require facility inspection and maintenance plans to align with those regulations. To the extent such rulemakings impose more stringent requirements on our facilities, we may be required to incur expenditures that may be material.

Legal Proceedings - We are a party to various litigation matters and claims that have arisen in the normal course of our operations. While the results of litigation and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable outcome of such matters will not have a material adverse effect on our results of operations, financial position or cash flows.

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DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS (Notes)

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

Fair Value Disclosures

DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS

Accounting Treatment - We record all derivative instruments at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it, or if regulatory requirements impose a different accounting treatment.

If certain conditions are met, we may elect to designate a derivative instrument as a hedge of exposure to changes in fair values or cash flows. We have not elected to designate any of our derivative instruments as hedges.

The table below summarizes the various ways in which we account for our derivative instruments and the impact on our consolidated financial statements:

		Recognition and Measurement
Accounting Treatment		Balance Sheet		Income Statement
Normal purchases and normal sales	-	Fair value not recorded	-	Change in fair value not recognized in earnings
Mark-to-market	-	Recorded at fair value	-	Change in fair value recognized in, and recoverable through, the purchased-gas cost adjustment mechanisms

Fair Value Measurements - We define fair value as the price that would be received from the sale of an asset or the transfer of a liability in an orderly transaction between market participants at the measurement date. We use the market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are

executed. We measure the fair value of a group of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.

Fair Value Hierarchy - At each balance sheet date, we utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in our consolidated financial statements based on the observability of inputs used to estimate such fair value. The levels of the hierarchy are described below:

•Level 1 - Unadjusted quoted prices in active markets for identical assets or liabilities;

•Level 2 - Significant observable pricing inputs other than quoted prices included within Level 1 that are, either directly or indirectly, observable as of the reporting date. Essentially, this represents inputs that are derived principally from or corroborated by observable market data; and

•Level 3 - May include one or more unobservable inputs that are significant in establishing a fair value estimate. These unobservable inputs are developed based on the best information available and may include our own internal data.

We recognize transfers into and out of the levels as of the end of each reporting period.

Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. We categorize derivatives for which fair value is determined using multiple inputs within a single level, based on the lowest level input that is significant to the fair value measurement in its entirety.

Derivative Instruments - Our derivatives are comprised of over-the-counter natural gas fixed price swaps and call options.

Swaps - At June 30, 2023, we held over-the-counter natural gas fixed-price swaps for the heating season ending March 2024, with a total notional amount of 7.7 Bcf. We did not hold any swaps at December 31, 2022.

Options - At June 30, 2023, we held natural gas call options for the heating season ending March 2024, with total notional amounts of 0.7 Bcf, for which we paid premiums of $0.8 million. At December 31, 2022, we held purchased natural gas call options for the heating season ended March 2023, with total notional amounts of 19.4 Bcf, for which we paid premiums of $14.1 million.

We have not designated any of our derivative instruments as accounting hedges. These contracts are included in, and recoverable through, our purchased-gas cost adjustment mechanisms. Additionally, premiums paid, changes in fair value and any settlements received associated with these contracts are deferred as part of our unrecovered purchased-gas costs in our consolidated balance sheets. There were no transfers between levels for the periods presented.

Other Financial Instruments - The approximate fair value of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable is equal to book value, due to the short-term nature of these items. Commercial paper is due upon demand and, therefore, the carrying amounts approximate fair value.

The following tables summarize, by level within the fair value hierarchy, our derivative and other assets and liabilities that were accounted for at fair value on a recurring basis at June 30, 2023 and December 31, 2022:

	June 30, 2023
	Level 1		Level 2		Netting (c)		Total
	(Thousands of dollars)
Assets:
Derivative instruments - swaps (a)	$	—	$	616	$	(616)	$	—
Derivative instruments - options (a)	—		452		—		452
United States treasury notes (b)	4,020		—		—		4,020
Corporate bonds (b)	—		9,544		—		9,544
Total assets	$	4,020	$	10,612	$	(616)	$	14,016
Liabilities:
Derivative instruments - swaps (a)	$	—	$	3,747	$	(616)	$	3,131

	December 31, 2022
	Level 1		Level 2		Total
	(Thousands of dollars)
Assets:
United States treasury notes (b)	$	4,695	$	—	$	4,695
Corporate bonds (b)	—		9,710		9,710
Total assets	$	4,695	$	9,710	$	14,405

(a) The fair value is included in other current assets and other current liabilities in our consolidated balance sheets.

(b) The fair value is included in other current and noncurrent assets and other current and noncurrent liabilities in our consolidated balance sheets.

(c) Our over-the-counter natural gas fixed-price swaps are subject to netting arrangements.

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VARIABLE INTEREST ENTITES (Notes)

6 Months Ended

Jun. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Variable Interest Entity Disclosure

VARIABLE INTEREST ENTITY

KGSS-I is a special-purpose, wholly owned subsidiary of ONE Gas that was formed for the purpose of issuing securitized bonds to recover extraordinary costs incurred by Kansas Gas Service resulting from Winter Storm Uri. On November 18, 2022, the securitized financing was complete. KGSS-I’s assets cannot be used to settle ONE Gas’ obligations and the holders of the Securitized Utility Tariff Bonds have no recourse against ONE Gas. See Note 5 for additional information about the securitization financing.

KGSS-I is considered to be a variable interest entity. As a result, KGSS-I is included in the consolidated financial statements of ONE Gas. No gain or loss was recognized upon initial consolidation.

The following table summarizes the impact of KGSS-I on our consolidated balance sheets, for the periods indicated:

	June 30,		December 31,
	2023		2022
	(Thousands of dollars)
Restricted cash and cash equivalents	$	32,006	$	8,446
Accounts receivable	3,157		4,862
Securitized intangible asset, net	309,569		323,838
Current maturities of securitized utility tariff bonds	34,201		20,716
Accounts payable	1,483		3,204
Accrued interest	11,418		2,202
Securitized utility tariff bonds, excluding current maturities, net of $5.9 million of discounts and issuance costs	295,949		309,343
Equity	1,681		1,681

The following table summarizes the impact of KGSS-I on our consolidated statements of income, for the period indicated:

	Three Months Ended		Six Months Ended
	June 30, 2023		June 30, 2023
	(Thousands of dollars)
Operating revenues	$	11,807	$	23,740
Operating expense	(109)		(219)
Amortization expense	(7,180)		(14,269)
Interest income	226		301
Interest expense	(4,744)		(9,553)
Income before income taxes	$	—	$	—

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
	Jun. 30, 2023
Significant Accounting Policies [Line Items]
Segments	Segments - We operate in one reportable business segment: regulated public utilities that deliver natural gas primarily to residential, commercial and transportation customers. Our accounting policies are the same as those described in Note 1 of the Notes to Consolidated Financial Statements in our Annual Report. We evaluate our financial performance principally on net income. For the three and six months ended June 30, 2023 and 2022, we had no single external customer from which we received 10 percent or more of our gross revenues.
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block]	Accounts Receivable, net - Accounts receivable represent valid claims against nonaffiliated customers for natural gas sold or services rendered. We assess the creditworthiness of our customers. Those customers who do not meet minimum standards may be required to provide security, including deposits and other forms of collateral, when appropriate and allowed by our tariffs. With approximately 2.3 million customers across three states, we are not exposed materially to a concentration of credit risk. We maintain an allowance for doubtful accounts based upon factors surrounding the credit risk of customers, historical trends, consideration of the current environment and other information. We recover natural gas costs related to accounts written off when they are deemed uncollectible through the purchased-gas cost adjustment mechanisms in each of our jurisdictions. At June 30, 2023 and December 31, 2022, our allowance for doubtful accounts was $17.0 million and $16.7 million, respectively.
Reclassification, Comparability Adjustment	Reclassifications -A reclassification has been made in the prior-year financial statements to conform to the current-year presentation. We have updated our consolidated balance sheet at December 31, 2022, to disaggregate “current maturities of other long-term debt,” which had previously been included in “other current liabilities,” to conform to our current-year presentation.

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DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS (Policies)

6 Months Ended

Jun. 30, 2023

Accounting Policies [Abstract]

Derivatives

Accounting Treatment - We record all derivative instruments at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it, or if regulatory requirements impose a different accounting treatment.

If certain conditions are met, we may elect to designate a derivative instrument as a hedge of exposure to changes in fair values or cash flows. We have not elected to designate any of our derivative instruments as hedges.

The table below summarizes the various ways in which we account for our derivative instruments and the impact on our consolidated financial statements:

		Recognition and Measurement
Accounting Treatment		Balance Sheet		Income Statement
Normal purchases and normal sales	-	Fair value not recorded	-	Change in fair value not recognized in earnings
Mark-to-market	-	Recorded at fair value	-	Change in fair value recognized in, and recoverable through, the purchased-gas cost adjustment mechanisms

Fair Value Measurement

Fair Value Measurements - We define fair value as the price that would be received from the sale of an asset or the transfer of a liability in an orderly transaction between market participants at the measurement date. We use the market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are

executed. We measure the fair value of a group of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.

Fair Value Hierarchy - At each balance sheet date, we utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in our consolidated financial statements based on the observability of inputs used to estimate such fair value. The levels of the hierarchy are described below:

•Level 1 - Unadjusted quoted prices in active markets for identical assets or liabilities;

•Level 2 - Significant observable pricing inputs other than quoted prices included within Level 1 that are, either directly or indirectly, observable as of the reporting date. Essentially, this represents inputs that are derived principally from or corroborated by observable market data; and

•Level 3 - May include one or more unobservable inputs that are significant in establishing a fair value estimate. These unobservable inputs are developed based on the best information available and may include our own internal data.

We recognize transfers into and out of the levels as of the end of each reporting period.

Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. We categorize derivatives for which fair value is determined using multiple inputs within a single level, based on the lowest level input that is significant to the fair value measurement in its entirety.

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REVENUE (Tables)

6 Months Ended

Jun. 30, 2023

Revenues Disaggregated by Source [Table]

The following table sets forth our revenues disaggregated by source for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(Thousands of dollars)
Natural gas sales to customers	$	346,734	$	393,292	$	1,313,093	$	1,318,449
Transportation revenues	29,022		28,000		67,549		64,316
Securitization customer charges (Note 14)	11,807		—		23,740		—
Miscellaneous revenues	6,313		5,128		12,211		9,624
Total revenues from contracts with customers	393,876		426,420		1,416,593		1,392,389
Other revenues - natural gas sales related	1,614		(115)		7,404		2,231
Other revenues	2,624		2,670		6,260		5,814
Total other revenues	4,238		2,555		13,664		8,045
Total revenues	$	398,114	$	428,975	$	1,430,257	$	1,400,434

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REGULATORY ASSETS AND LIABILITIES (Tables)

6 Months Ended

Jun. 30, 2023

SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]

SCHEDULE OF REGULATED ASSETS AND LIABILITIES

The tables below present a summary of regulatory assets and liabilities, net of amortization, for the periods indicated:

	June 30, 2023
	Current		Noncurrent		Total
	(Thousands of dollars)
Winter weather event costs	$	22,633	$	26,117	$	48,750
Pension and postemployment benefit costs	4,603		239,975		244,578
Reacquired debt costs	812		2,985		3,797
MGP remediation costs	98		31,891		31,989
Ad-valorem tax	12,125		—		12,125
WNA	7,809		—		7,809
Customer credit deferrals	13,820		—		13,820
Other	3,012		3,646		6,658
Total regulatory assets, net of amortization	64,912		304,614		369,526
Income tax rate changes	—		(512,633)		(512,633)
Over-recovered purchased-gas costs	(79,686)		—		(79,686)
Total regulatory liabilities	(79,686)		(512,633)		(592,319)
Net regulatory assets and liabilities	$	(14,774)	$	(208,019)	$	(222,793)

	December 31, 2022
	Current		Noncurrent		Total
	(Thousands of dollars)
Winter weather event costs	$	221,926	$	36,291	$	258,217
Under-recovered purchased-gas costs	19,755		—		19,755
Pension and postemployment benefit costs	—		258,257		258,257
Reacquired debt costs	812		3,347		4,159
MGP remediation costs	98		29,743		29,841
Ad-valorem tax	13,359		—		13,359
WNA	8,474		—		8,474
Customer credit deferrals	9,504		—		9,504
Other	1,644		3,193		4,837
Total regulatory assets, net of amortization	275,572		330,831		606,403
Pension and other postemployment benefit costs	(8,228)		—		(8,228)
Income tax rate changes	—		(529,441)		(529,441)
Over-recovered purchased-gas costs	(39,639)		—		(39,639)
Total regulatory liabilities	(47,867)		(529,441)		(577,308)
Net regulatory assets and liabilities	$	227,705	$	(198,610)	$	29,095

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LONG-TERM DEBT (Tables)

6 Months Ended

Jun. 30, 2023

Long-Term Debt, Unclassified [Abstract]

Schedule of Long-Term Debt Instruments

The table below presents a summary of our long-term debt outstanding for the periods indicated:

	Interest rate at June 30, 2023	June 30, 2023		December 31, 2022
		(Thousands of dollars)
Senior Notes due:
February 2024	3.610%	$	300,000	$	300,000
March 2024	1.100%	473,000		473,000
May 2030	2.000%	300,000		300,000
September 2032	4.250%	300,000		300,000
February 2044	4.658%	600,000		600,000
November 2048	4.500%	400,000		400,000
Total Senior Notes		2,373,000		2,373,000
KGSS-I Securitized Utility Tariff Bonds	5.486%	336,000		336,000
Other	8.000%	1,244		1,250
Unamortized discounts on long-term debt		(7,422)		(7,636)
Debt issuance costs (a)		(19,571)		(20,143)
Total long-term debt, net		2,683,251		2,682,471
Less: current maturities of securitized utility tariff bonds		34,201		20,716
Less: current maturities of other long-term debt, net		772,838		12
Noncurrent portion of long-term debt, net		$	1,876,212	$	2,661,743

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Equity (Tables)

6 Months Ended

Jun. 30, 2023

Equity [Abstract]

Schedule of Forward Contracts Indexed to Issuer's Equity

The following table summarizes all of our outstanding forward sale agreements at June 30, 2023:

Maturity	Shares Sold	Net Proceeds Available (in thousands)		Forward Price
At-the-Market Equity Program
December 29, 2023	289,403	$	21,780	$	75.26
December 31, 2024	926,465	73,906		$	79.77
Total At-the-Market Equity Program	1,215,868	95,686		$	78.70
Equity Forward Agreement
December 29, 2023	1,400,000	107,095		$	76.50
December 31, 2024	600,000	45,898		$	76.50
Total Equity Forward Agreement	2,000,000	152,993		$	76.50
Total forward sale agreements	3,215,868	$	248,679	$	77.33

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables)

6 Months Ended

Jun. 30, 2023

Accumulated Other Comprehensive Income (Loss) [Line Items]

Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]

The following table sets forth the effect of reclassifications from accumulated other comprehensive loss in our consolidated statements of income for the periods indicated:

	Three Months Ended				Six Months Ended				Affected Line Item in the
Details About Accumulated Other	June 30,				June 30,				Consolidated Statements
Comprehensive Loss Components	2023		2022		2023		2022		of Income
	(Thousands of dollars)
Pension and other postemployment benefit plan obligations (a)
Amortization of net loss	$	490	$	4,252	$	980	$	12,453
Amortization of unrecognized prior service cost (credit)	131		72		262		82
	621		4,324		1,242		12,535
Regulatory adjustments (b)	(621)		(4,265)		(1,242)		(12,388)
	—		59		—		147		Income before income taxes
	—		(15)		—		(34)		Income tax expense
Total reclassifications for the period	$	—	$	44	$	—	$	113	Net income

(a) These components of accumulated other comprehensive loss are included in the computation of net periodic benefit cost. See Note 9 for additional detail of our net periodic benefit cost.

(b) Regulatory adjustments represent pension and other postemployment benefit costs expected to be recovered through rates and are deferred as part of our regulatory assets. See Note 3 for additional disclosures of regulatory assets and liabilities.

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EARNINGS PER SHARE (Tables)

6 Months Ended

Jun. 30, 2023

EARNINGS PER SHARE [Line Items]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

The following tables set forth the computation of basic and diluted EPS from continuing operations for the periods indicated:

	Three Months Ended June 30, 2023
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	32,689	55,566	$	0.59
Diluted EPS Calculation
Effect of dilutive securities	—		348
Net income available for common stock and common stock equivalents	$	32,689	55,914	$	0.58
	Three Months Ended June 30, 2022
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	32,075	54,262	$	0.59
Diluted EPS Calculation
Effect of dilutive securities	—		73
Net income available for common stock and common stock equivalents	$	32,075	54,335	$	0.59
	Six Months Ended June 30, 2023
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	135,310	55,552	$	2.43
Diluted EPS Calculation
Effect of dilutive securities	—		305
Net income available for common stock and common stock equivalents	$	135,310	55,857	$	2.42
	Six Months Ended June 30, 2022
	Income		Shares	Per Share Amount
	(Thousands, except per share amounts)
Basic EPS Calculation
Net income available for common stock	$	131,009	54,092	$	2.42
Diluted EPS Calculation
Effect of dilutive securities	—		91
Net income available for common stock and common stock equivalents	$	131,009	54,183	$	2.42

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EMPLOYEE BENEFIT PLANS (Tables)

6 Months Ended

Jun. 30, 2023

Employee Benefit Plans [Line Items]

Schedule of Net Benefit Costs [Table Text Block]

The following tables set forth the components of net periodic benefit cost for our pension and other postemployment benefit plans for the periods indicated:

	Pension Benefits
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2023		2022		2023		2022
	(Thousands of dollars)
Components of net periodic benefit cost (credit)
Service cost		$	1,811	$	2,592	$	3,622	$	5,686
Interest cost		10,607		9,037		21,214		16,841
Expected return on assets		(14,879)		(14,632)		(29,758)		(29,245)
Amortization of unrecognized prior service cost		93		62		186		62
Amortization of net loss		502		4,198		1,004		12,345
Net periodic benefit cost (credit)		$	(1,866)	$	1,257	$	(3,732)	$	5,689

	Other Postemployment Benefits
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(Thousands of dollars)
Components of net periodic benefit cost (credit)
Service cost	$	183	$	318	$	366	$	636
Interest cost	2,288		1,612		4,576		3,224
Expected return on assets	(2,432)		(3,295)		(4,864)		(6,590)
Amortization of unrecognized prior service cost	38		10		76		20
Amortization of net (gain) loss	(12)		54		(24)		108
Net periodic benefit cost (credit)	$	65	$	(1,301)	$	130	$	(2,602)

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OTHER INCOME AND OTHER EXPENSE (Tables)

6 Months Ended

Jun. 30, 2023

Schedule of Other Nonoperating Income (Expense)

The following table sets forth the components of other income and other expense for the periods indicated:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
	(Thousands of dollars)
Net periodic benefit credit other than service cost	$	963	$	1,366	$	1,871	$	778
Earnings (losses) on investments associated with nonqualified employee benefit plans	1,274		(4,619)		2,887		(7,452)
Other, net	(63)		(730)		(3)		(1,454)
Total other income (expense), net	$	2,174	$	(3,983)	$	4,755	$	(8,128)

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DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2023

Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]

Fair Value Measurements, Recurring and Nonrecurring

The following tables summarize, by level within the fair value hierarchy, our derivative and other assets and liabilities that were accounted for at fair value on a recurring basis at June 30, 2023 and December 31, 2022:

	June 30, 2023
	Level 1		Level 2		Netting (c)		Total
	(Thousands of dollars)
Assets:
Derivative instruments - swaps (a)	$	—	$	616	$	(616)	$	—
Derivative instruments - options (a)	—		452		—		452
United States treasury notes (b)	4,020		—		—		4,020
Corporate bonds (b)	—		9,544		—		9,544
Total assets	$	4,020	$	10,612	$	(616)	$	14,016
Liabilities:
Derivative instruments - swaps (a)	$	—	$	3,747	$	(616)	$	3,131

	December 31, 2022
	Level 1		Level 2		Total
	(Thousands of dollars)
Assets:
United States treasury notes (b)	$	4,695	$	—	$	4,695
Corporate bonds (b)	—		9,710		9,710
Total assets	$	4,695	$	9,710	$	14,405

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VARIABLE INTEREST ENTITES (Tables)

6 Months Ended

Jun. 30, 2023

Kansas Gas Service Securitization I LLC

Variable Interest Entity [Line Items]

Schedule of Variable Interest Entities

The following table summarizes the impact of KGSS-I on our consolidated balance sheets, for the periods indicated:

	June 30,		December 31,
	2023		2022
	(Thousands of dollars)
Restricted cash and cash equivalents	$	32,006	$	8,446
Accounts receivable	3,157		4,862
Securitized intangible asset, net	309,569		323,838
Current maturities of securitized utility tariff bonds	34,201		20,716
Accounts payable	1,483		3,204
Accrued interest	11,418		2,202
Securitized utility tariff bonds, excluding current maturities, net of $5.9 million of discounts and issuance costs	295,949		309,343
Equity	1,681		1,681

The following table summarizes the impact of KGSS-I on our consolidated statements of income, for the period indicated:

	Three Months Ended		Six Months Ended
	June 30, 2023		June 30, 2023
	(Thousands of dollars)
Operating revenues	$	11,807	$	23,740
Operating expense	(109)		(219)
Amortization expense	(7,180)		(14,269)
Interest income	226		301
Interest expense	(4,744)		(9,553)
Income before income taxes	$	—	$	—

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) number in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)
Significant Accounting Policies [Line Items]
Number of natural gas distribution services customers	2.3
Segment Reporting, Disclosure of Major Customers	no	no
Capital Expenditures Incurred but Not yet Paid	$ 7.9	$ 7.8
Allowance for Doubtful Accounts, Premiums and Other Receivables	$ 17.0		$ 16.7

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REVENUE (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Regulated Operating Revenue, Gas	$ 393,876	$ 426,420	$ 1,416,593	$ 1,392,389
Regulated Operating Revenue, Other	4,238	2,555	13,664	8,045
Regulated Operating Revenue	398,114	428,975	1,430,257	1,400,434
Unbilled Receivables, Current	64,500		64,500		$ 269,500
Natural gas sales to customers [Member]
Regulated Operating Revenue, Gas	346,734	393,292	1,313,093	1,318,449
Transportation revenues [Member]
Regulated Operating Revenue, Gas	29,022	28,000	67,549	64,316
Securitization Customer Charges
Regulated Operating Revenue, Gas	11,807	0	23,740	0
Miscellaneous revenues [Member]
Regulated Operating Revenue, Gas	6,313	5,128	12,211	9,624
Other revenues - natural gas sales related [Member]
Regulated Operating Revenue, Other	1,614	(115)	7,404	2,231
Other revenues [Member]
Regulated Operating Revenue, Other	$ 2,624	$ 2,670	$ 6,260	$ 5,814

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REGULATORY ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022	Feb. 28, 2021
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current	$ 64,912		$ 64,912		$ 275,572
Regulatory Assets, Noncurrent	304,614		304,614		330,831
Regulatory Assets	369,526		369,526		606,403
Regulatory Liability, Current	(79,686)		(79,686)		(47,867)
Regulatory Liability, Noncurrent	(512,633)		(512,633)		(529,441)
Regulatory Liabilities	(592,319)		(592,319)		(577,308)
Net regulatory assets (liabilities), current	(14,774)		(14,774)		227,705
Net regulatory assets (liabilities), noncurrent	(208,019)		(208,019)		(198,610)
Net Regulatory Assets	(222,793)		(222,793)		29,095
February 2021 Natural Gas Purchases						$ 2,100,000
TGS Proceeds from Securitization Bonds			197,000
Amortization of Rate Deferral	2,500	$ 1,600	9,500	$ 6,000
West Texas Service Area
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
TGS Deferred Extraordinary Costs from 2021 Winter Storm Uri	31,200		31,200
Pension and postretirement benefit costs [Member]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Liability, Current					(8,228)
Regulatory Liability, Noncurrent					0
Regulatory Liabilities					(8,228)
Income tax rate changes [Member] [Domain]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Liability, Current	0		0		0
Regulatory Liability, Noncurrent	(512,633)		(512,633)		(529,441)
Regulatory Liabilities	(512,633)		(512,633)		(529,441)
Over-recovered purchased-gas costs [Member]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Liability, Current	(79,686)		(79,686)		(39,639)
Regulatory Liability, Noncurrent	0		0		0
Regulatory Liabilities	(79,686)		(79,686)		(39,639)
Winter weather event costs
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current	22,633		22,633		221,926
Regulatory Assets, Noncurrent	26,117		26,117		36,291
Regulatory Assets	48,750		48,750		258,217
Under-recovered purchased-gas costs [Member]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current					19,755
Regulatory Assets, Noncurrent					0
Regulatory Assets					19,755
Pension and postretirement benefit costs [Member]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current	4,603		4,603		0
Regulatory Assets, Noncurrent	239,975		239,975		258,257
Regulatory Assets	244,578		244,578		258,257
Reacquired debt costs [Member]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current	812		812		812
Regulatory Assets, Noncurrent	2,985		2,985		3,347
Regulatory Assets	3,797		3,797		4,159
MGP Costs [Member] [Member]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current	98		98		98
Regulatory Assets, Noncurrent	31,891		31,891		29,743
Regulatory Assets	31,989		31,989		29,841
Ad valorem tax [Member]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current	12,125		12,125		13,359
Regulatory Assets, Noncurrent	0		0		0
Regulatory Assets	12,125		12,125		13,359
Weather normalization [Member]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current	7,809		7,809		8,474
Regulatory Assets, Noncurrent	0		0		0
Regulatory Assets	7,809		7,809		8,474
Customer credit deferrals
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current	13,820		13,820		9,504
Regulatory Assets, Noncurrent	0		0		0
Regulatory Assets	13,820		13,820		9,504
Other regulatory assets [Member]
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items]
Regulatory Assets, Current	3,012		3,012		1,644
Regulatory Assets, Noncurrent	3,646		3,646		3,193
Regulatory Assets	$ 6,658		$ 6,658		$ 4,837

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CREDIT FACILITIES (Details) $ in Thousands	Jun. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)
Short-term Debt [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,000,000
Line of Credit Facility Sublimit	20,000
Line of Credit Facility Option to Increase Borrowing Capacity	$ 500,000
Approved Debt to Capital Ratio	0.70
Ratio of Indebtedness to Net Capital	0.52
Commercial paper maximum borrowing capacity	$ 1,000,000
Commercial Paper	$ 217,100	$ 552,000
Short-Term Debt, Weighted Average Interest Rate, at Point in Time	5.43%	4.75%
Letters of Credit Outstanding, Amount	$ 1,200
Line of Credit Facility, Remaining Borrowing Capacity	$ 998,800

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LONG-TERM DEBT (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount	$ (7,422)	$ (7,636)
Debt Issuance Costs, Net	(19,571)	(20,143)
Long-Term Debt and Lease Obligation, Including Current Maturities	2,683,251	2,682,471
Current maturities of securitized utility tariff bonds	34,201	20,716
Long-term Debt, Current Maturities	772,838	12
Long-term Debt, excluding current maturities	1,876,212	2,661,743
Debt Instrument, Covenant Compliance, Default Provision, Indebtnedness Threshold	$ 100,000
Debt Instrument, Covenant Compliance, Default Provision, Debt Holders	25.00%
Debt Instrument, Redemption Price, Percentage	100.00%
3.61% Senior Unsecured Notes Due 2024
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.61%
Long-term Debt, Gross	$ 300,000	300,000
1.10% Senior Unsecured Notes Due 2024
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.10%
Long-term Debt, Gross	$ 473,000	473,000
2.00% Senior Unsecured Notes Due 2024
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.00%
Long-term Debt, Gross	$ 300,000	300,000
4.25% Senior Unsecured Notes Due 2032
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.25%
Long-term Debt, Gross	$ 300,000	300,000
4.658% Senior Unsecured Notes Due 2044
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.658%
Long-term Debt, Gross	$ 600,000	600,000
4.50% Senior Unsecured Notes Due 2048
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.50%
Long-term Debt, Gross	$ 400,000	400,000
Total Senior Unsecured Notes
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 2,373,000	2,373,000
5.486% KGSS-I Securitized Utility Tariff Bonds Due 2032
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.486%
Long-term Debt, Gross	$ 336,000	336,000
Debt Issuance Costs, Net	(5,800)
Current maturities of securitized utility tariff bonds	$ 34,201	20,716
8.00% Other Long Term Debt
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	8.00%
Long-term Debt, Gross	$ 1,244	$ 1,250

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EQUITY (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended					6 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2023	Jun. 30, 2022
Common stock issued, value		$ 6,661	$ 435	$ 5,636	$ 34,140
Proceeds from Issuance of Common Stock						$ 3,175	$ 37,104
Forward Contract Indexed to Issuer's Equity, Indexed Shares		3,215,868				3,215,868
Forward Contract Indexed to Equity, Settlement, Cash, Amount		$ 248,679				$ 248,679
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share						$ 77.33
Common Stock, Dividends, Per Share, Declared		$ 0.65		$ 0.62		$ 1.30	$ 1.24
Subsequent Event [Member]
Common Stock, Dividends, Per Share, Declared	$ 0.65
Common Stock, Dividends, Declared, Annualized Basis	$ 2.60
Dividends Payable, Date of Record	Aug. 16, 2023
Dividends Payable, Date to be Paid	Sep. 01, 2023
At-The-Market Program
Aggregate Offering Price Limit		$ 300,000				$ 300,000
Common stock issued, shares							403,792
Common stock issued, value							$ 35,000
Proceeds from Issuance of Common Stock							$ 34,700
Equity Available for Issuance		$ 226,100				$ 226,100
Forward Contract Indexed to Issuer's Equity, Indexed Shares		1,215,868				1,215,868
Forward Contract Indexed to Equity, Settlement, Cash, Amount		$ 95,686				$ 95,686
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share						$ 78.70
At-The-Market Program | December 29, 2023
Forward Contract Indexed to Issuer's Equity, Indexed Shares		289,403				289,403
Forward Contract Indexed to Equity, Settlement, Cash, Amount		$ 21,780				$ 21,780
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share						$ 75.26
At-The-Market Program | December 31, 2024
Forward Contract Indexed to Issuer's Equity, Indexed Shares		926,465				926,465
Forward Contract Indexed to Equity, Settlement, Cash, Amount		$ 73,906				$ 73,906
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share						$ 79.77
At-The-Market Program | December 30, 2022
Common stock issued, shares							591,736
Proceeds from Issuance of Common Stock							$ 48,000
March 2023 Equity Forward Agreement
Forward Contract Indexed to Issuer's Equity, Indexed Shares		2,000,000				2,000,000
Forward Contract Indexed to Equity, Settlement, Cash, Amount		$ 152,993				$ 152,993
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share						$ 76.50
March 2023 Equity Forward Agreement | December 29, 2023
Forward Contract Indexed to Issuer's Equity, Indexed Shares		1,400,000				1,400,000
Forward Contract Indexed to Equity, Settlement, Cash, Amount		$ 107,095				$ 107,095
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share						$ 76.50
March 2023 Equity Forward Agreement | December 31, 2024
Forward Contract Indexed to Issuer's Equity, Indexed Shares		600,000				600,000
Forward Contract Indexed to Equity, Settlement, Cash, Amount		$ 45,898				$ 45,898
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share						$ 76.50

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amortization of net (gain) loss	$ 490	$ 4,252	$ 980	$ 12,453
Amortization of unrecognized prior service cost	131	72	262	82
Reclassification adjustment, before tax and regulatory adjustments	621	4,324	1,242	12,535
Regulatory adjustments	(621)	(4,265)	(1,242)	(12,388)
Reclassification adjustment, before tax	0	59	0	147
Reclassification adjustment, Tax	0	(15)	0	(34)
Reclassification adjustment, net of tax	$ 0	$ 44	$ 0	$ 113

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EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2023	Mar. 31, 2023	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2023	Jun. 30, 2022
Basic EPS Calculation
Net income available for common stock	$ 32,689	$ 102,621	$ 32,075	$ 98,934	$ 135,310	$ 131,009
Weighted Average Number of Shares Outstanding, Basic	55,566		54,262		55,552	54,092
Earnings Per Share, Basic	$ 0.59		$ 0.59		$ 2.43	$ 2.42
Diluted EPS Calculation
Net Income (Loss) Available to Common Stockholders, Diluted	$ 32,689		$ 32,075		$ 135,310	$ 131,009
Effect of dilutive securities on shares	348		73		305	91
Weighted Average Number of Shares Outstanding, Diluted	55,914		54,335		55,857	54,183
Earnings Per Share, Diluted	$ 0.58		$ 0.59		$ 2.42	$ 2.42

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EMPLOYEE BENEFIT PLANS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Components of net periodic benefit cost:
Amortization of unrecognized prior service cost	$ (131)	$ (72)	$ (262)	$ (82)
Amortization of net (gain) loss	(490)	(4,252)	(980)	(12,453)
Capitalized non-service cost components as a regulatory asset					$ 2,800
ONE Gas Pension Plans [Member]
Components of net periodic benefit cost:
Service cost	1,811	2,592	3,622	5,686
Interest cost	10,607	9,037	21,214	16,841
Expected return on assets	(14,879)	(14,632)	(29,758)	(29,245)
Amortization of unrecognized prior service cost	93	62	186	62
Amortization of net (gain) loss	502	4,198	1,004	12,345
Net periodic benefit cost	(1,866)	1,257	(3,732)	5,689
ONE Gas Postretirement Benefit Plans [Member]
Components of net periodic benefit cost:
Service cost	183	318	366	636
Interest cost	2,288	1,612	4,576	3,224
Expected return on assets	(2,432)	(3,295)	(4,864)	(6,590)
Amortization of unrecognized prior service cost	38	10	76	20
Amortization of net (gain) loss	(12)	54	(24)	108
Net periodic benefit cost	$ 65	$ (1,301)	$ 130	$ (2,602)

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INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Tax Disclosure [Abstract]
Reduction in income tax expense for the amortization of the regulatory liability associated with excess ADIT that was returned to customers	$ 3.1	$ 3.0	$ 13.0	$ 10.9

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OTHER INCOME AND OTHER EXPENSE (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Other Nonoperating Income (Expense)	$ 2,174	$ (3,983)	$ 4,755	$ (8,128)
Net periodic cost other than service cost [Member]
Other Nonoperating Income (Expense)	963	1,366	1,871	778
Earnings (losses) on investments associated with nonqualified employee benefit plans [Member]
Other Nonoperating Income (Expense)	1,274	(4,619)	2,887	(7,452)
Other, net [Member]
Other Nonoperating Income (Expense)	$ (63)	$ (730)	$ (3)	$ (1,454)

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COMMITMENTS AND CONTINGENCIES (Details) $ in Millions	Jun. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)
Commitments and Contingencies [Line Items]
Number Of Former Manufactured Gas Sites Where We Own Or Retain Legal Responsibility For Environmental Conditions	12
Number of sites where regulatory closure has been achieved	5
Deferred MGP Costs, Maximum	$ 15.0
Regulatory Asset for Costs Associated with Manufactured Gas Sites	$ 32.0	$ 32.0
Number of sites with ongoing groundwater monitoring	7
Accrual for Environmental Loss Contingencies	$ 14.8	$ 12.7

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DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS (Details) Table - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Other Current Assets
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	$ 14,016	$ 14,405
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	(616)
Other Current Assets | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	4,020	4,695
Other Current Assets | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	10,612	9,710
Other Current Assets | Swap
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	(616)
Other Current Assets | Swap | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0
Other Current Assets | Swap | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	616
Other Current Assets | Commodity Option
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	452
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	0
Other Current Assets | Commodity Option | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0
Other Current Assets | Commodity Option | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	452
Other Assets | US Treasury Securities
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	4,020	4,695
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	0
Other Assets | US Treasury Securities | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	4,020	4,695
Other Assets | US Treasury Securities | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Other Assets | Corporate Bond Securities
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	9,544	9,710
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	0
Other Assets | Corporate Bond Securities | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	0	0
Other Assets | Corporate Bond Securities | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset Including Not Subject to Master Netting Arrangement	9,544	$ 9,710
Other Current Liabilities | Swap
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Financial Instruments, Owned, at Fair Value	3,131
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	(616)
Other Current Liabilities | Swap | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Financial Instruments, Owned, at Fair Value	0
Other Current Liabilities | Swap | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Financial Instruments, Owned, at Fair Value	$ 3,747

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DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS (Details) Note $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($) Bcf	Dec. 31, 2022 USD ($) Bcf
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Premiums recorded in other current assets on natural gas contracts held	$ 0.8	$ 14.1
Fair Value Assets, Transfers between Levels	$ 0.0
Swap
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative, Nonmonetary Notional Amount | Bcf	7.7
Commodity Option
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative, Nonmonetary Notional Amount | Bcf	0.7	19.4
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Long-term Debt, Fair Value	$ 2,500.0

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VARIABLE INTEREST ENTITES (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022	Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2021
Variable Interest Entity [Line Items]
Restricted Cash and Cash Equivalents	$ 32,006	$ 32,006		$ 8,446
Accounts receivable, net	234,409	234,409		553,834
Current maturities of securitized utility tariff bonds	34,201	34,201		20,716
Accounts payable	154,121	154,121		360,493
Stockholders' Equity Attributable to Parent	2,654,826	2,654,826	$ 2,651,480	2,584,426	$ 2,453,596	$ 2,449,390	$ 2,349,532
Kansas Gas Service Securitization I LLC
Variable Interest Entity [Line Items]
Restricted Cash and Cash Equivalents	32,006	32,006		8,446
Accounts receivable, net	3,157	3,157		4,862
Finite-Lived Intangible Assets, Net	309,569	309,569		323,838
Current maturities of securitized utility tariff bonds	34,201	34,201		20,716
Accounts payable	1,483	1,483		3,204
Interest Payable	11,418	11,418		2,202
Securitized utility tariff bonds	295,949	295,949		309,343
Stockholders' Equity Attributable to Parent	1,681	1,681		$ 1,681
Forward Contract Indexed to Equity, Settlement, Cash, Amount	11,807	23,740
Utilities Operating Expense	(109)	(219)
Depreciation and amortization	(7,180)	(14,269)
Interest Income, Other	226	301
Interest Expense	(4,744)	(9,553)
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	$ 0	$ 0