Atmos Energy (ATO) 10-Q 2024 Q3 Quarterly report

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2024

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 1-10042

Atmos Energy Corporation

(Exact name of registrant as specified in its charter)

Texas	and		Virginia	75-1743247
(State or other jurisdiction of incorporation or organization)				(IRS employer identification no.)
1800 Three Lincoln Centre
5430 LBJ Freeway
Dallas		Texas		75240
(Address of principal executive offices)				(Zip code)

(972) 934-9227

(Registrant’s telephone number, including area code)

Title of each class		Trading Symbol	Name of each exchange on which registered
Common stock	No Par Value	ATO	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  þ    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  þ    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. (Check one):

Large accelerated filer þ 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  þ

Number of shares outstanding of each of the issuer’s classes of common stock, as of August 2, 2024.

Class		Shares Outstanding
Common stock	No Par Value	155,232,827

GLOSSARY OF KEY TERMS

AEC	Atmos Energy Corporation
AEK	Atmos Energy Kansas Securitization I, LLC
AOCI	Accumulated other comprehensive income
ARM	Annual Rate Mechanism
ASC	Accounting Standards Codification
Bcf	Billion cubic feet
DARR	Dallas Annual Rate Review
FASB	Financial Accounting Standards Board
GAAP	Generally Accepted Accounting Principles
GRIP	Gas Reliability Infrastructure Program
GSRS	Gas System Reliability Surcharge
KCC	Kansas Corporation Commission
Mcf	Thousand cubic feet
MMcf	Million cubic feet
Moody’s	Moody’s Investors Services, Inc.
PRP	Pipeline Replacement Program
Rider SSI	APT System Safety and Integrity Rider
RRC	Railroad Commission of Texas
RRM	Rate Review Mechanism
RSC	Rate Stabilization Clause
S&P	Standard & Poor’s Corporation
SAVE	Steps to Advance Virginia Energy
SEC	United States Securities and Exchange Commission
Securitized Utility Tariff Bonds	Series 2023-A Senior Secured Securitized Utility Tariff Bonds
Securitized Utility Tariff Property	As defined in the financing order issued by the KCC in October 2022
SIP	System Integrity Program
SIR	System Integrity Rider
SOFR	Secured Overnight Financing Rate
SRF	Stable Rate Filing
SSIR	System Safety and Integrity Rider
TCJA	Tax Cuts and Jobs Act of 2017
WNA	Weather Normalization Adjustment

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PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

ATMOS ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS 

	June 30, 2024		September 30, 2023
	(Unaudited)
	(In thousands, except share data)
ASSETS
Property, plant and equipment	$	24,979,631	$	22,898,374
Less accumulated depreciation and amortization	3,557,513		3,291,791
Net property, plant and equipment	21,422,118		19,606,583
Current assets
Cash and cash equivalents	674,620		15,404
Restricted cash and cash equivalents	4,642		3,844
Cash and cash equivalents and restricted cash and cash equivalents	679,262		19,248
Accounts receivable, net	391,551		328,654
Gas stored underground	157,912		245,830
Other current assets	479,840		292,036
Total current assets	1,708,565		885,768
Securitized intangible asset, net (See Note 9)	84,998		92,202
Goodwill	731,257		731,257
Deferred charges and other assets	944,313		1,201,158
	$	24,891,251	$	22,516,968
CAPITALIZATION AND LIABILITIES
Shareholders’ equity
Common stock, no par value (stated at $0.005 per share); 200,000,000 shares authorized; issued and outstanding: June 30, 2024 — 155,229,024 shares; September 30, 2023 — 148,492,783 shares	$	776	$	742
Additional paid-in capital	7,463,334		6,684,120
Accumulated other comprehensive income	510,132		518,528
Retained earnings	4,208,834		3,666,674
Shareholders’ equity	12,183,076		10,870,064
Long-term debt, net	7,785,196		6,554,133
Securitized long-term debt (See Note 9)	81,261		85,078
Total capitalization	20,049,533		17,509,275
Current liabilities
Accounts payable and accrued liabilities	319,361		336,083
Other current liabilities	655,944		763,086
Short-term debt	—		241,933
Current maturities of long-term debt	1,620		1,568
Current maturities of securitized long-term debt (See Note 9)	8,001		9,922
Total current liabilities	984,926		1,352,592
Deferred income taxes	2,549,829		2,304,974
Regulatory excess deferred taxes	195,505		253,212
Regulatory cost of removal obligation	515,629		497,017
Deferred credits and other liabilities	595,829		599,898
	$	24,891,251	$	22,516,968

See accompanying notes to condensed consolidated financial statements.

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ATMOS ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Three Months Ended June 30
	2024		2023
	(Unaudited) (In thousands, except per share data)
Operating revenues
Distribution segment	$	633,211	$	616,067
Pipeline and storage segment	250,680		208,225
Intersegment eliminations	(182,342)		(161,559)
Total operating revenues	701,549		662,733
Purchased gas cost
Distribution segment	179,510		206,048
Pipeline and storage segment	(19)		(194)
Intersegment eliminations	(182,084)		(161,304)
Total purchased gas cost	(2,593)		44,550
Operation and maintenance expense	211,309		195,049
Depreciation and amortization expense	166,827		150,726
Taxes, other than income	105,739		103,155
Operating income	220,267		169,253
Other non-operating income	19,898		16,170
Interest charges	41,160		31,334
Income before income taxes	199,005		154,089
Income tax expense	33,441		16,282
Net income	$	165,564	$	137,807
Basic net income per share	$	1.08	$	0.94
Diluted net income per share	$	1.08	$	0.94
Cash dividends per share	$	0.805	$	0.740
Basic weighted average shares outstanding	153,309		146,051
Diluted weighted average shares outstanding	153,396		146,067
Net income	$	165,564	$	137,807
Other comprehensive income (loss), net of tax
Net unrealized holding losses on available-for-sale securities, net of tax of $(1) and $(35)	(4)		(121)
Cash flow hedges:
Amortization and unrealized gains on interest rate agreements, net of tax of $4,173 and $12,580	14,436		43,527
Total other comprehensive income	14,432		43,406
Total comprehensive income	$	179,996	$	181,213

See accompanying notes to condensed consolidated financial statements.

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ATMOS ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Nine Months Ended June 30
	2024		2023
	(Unaudited) (In thousands, except per share data)
Operating revenues
Distribution segment	$	3,327,730	$	3,556,703
Pipeline and storage segment	685,336		579,278
Intersegment eliminations	(505,823)		(448,266)
Total operating revenues	3,507,243		3,687,715
Purchased gas cost
Distribution segment	1,464,815		1,896,986
Pipeline and storage segment	825		(431)
Intersegment eliminations	(505,069)		(447,545)
Total purchased gas cost	960,571		1,449,010
Operation and maintenance expense	577,553		574,781
Depreciation and amortization expense	496,522		445,063
Taxes, other than income	302,235		305,784
Operating income	1,170,362		913,077
Other non-operating income	54,471		54,767
Interest charges	148,477		105,464
Income before income taxes	1,076,356		862,380
Income tax expense	167,477		95,042
Net income	$	908,879	$	767,338
Basic net income per share	$	6.00	$	5.33
Diluted net income per share	$	6.00	$	5.33
Cash dividends per share	$	2.415	$	2.220
Basic weighted average shares outstanding	151,459		143,938
Diluted weighted average shares outstanding	151,497		143,998
Net income	$	908,879	$	767,338
Other comprehensive income (loss), net of tax
Net unrealized holding gains on available-for-sale securities, net of tax of $70 and $29	242		100
Cash flow hedges:
Amortization and unrealized gains (losses) on interest rate agreements, net of tax of $(2,496) and $10,171	(8,638)		35,191
Total other comprehensive income (loss)	(8,396)		35,291
Total comprehensive income	$	900,483	$	802,629

See accompanying notes to condensed consolidated financial statements.

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ATMOS ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

	Nine Months Ended June 30
	2024		2023
	(Unaudited) (In thousands)
Cash Flows From Operating Activities
Net income	$	908,879	$	767,338
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	496,522		445,063
Deferred income taxes	138,658		75,407
Other	(39,418)		(38,360)
Net assets / liabilities from risk management activities	2,292		(1,545)
Net change in Winter Storm Uri current regulatory asset	—		2,021,889
Net change in other operating assets and liabilities	(103,869)		(48,284)
Net cash provided by operating activities	1,403,064		3,221,508
Cash Flows From Investing Activities
Capital expenditures	(2,129,137)		(2,083,486)
Debt and equity securities activities, net	(1,701)		(7,302)
Other, net	11,744		13,469
Net cash used in investing activities	(2,119,094)		(2,077,319)
Cash Flows From Financing Activities
Net decrease in short-term debt	(241,933)		(184,967)
Net proceeds from equity issuances	749,987		671,630
Issuance of common stock through stock purchase and employee retirement plans	11,390		11,660
Proceeds from issuance of long-term debt	1,240,204		797,258
Proceeds from issuance of securitized long-term debt by AEK	—		95,000
Proceeds from term loan	—		2,020,000
Repayment of term loan	—		(2,020,000)
Repayment of long-term debt	—		(2,200,000)
Repayment of securitized long-term debt by AEK	(5,738)		—
Cash dividends paid	(366,719)		(319,074)
Debt issuance costs	(11,147)		(7,864)
Securitized debt issuance costs	—		(1,273)
Net cash provided by (used in) financing activities	1,376,044		(1,137,630)
Net increase in cash and cash equivalents and restricted cash and cash equivalents	660,014		6,559
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period	19,248		51,554
Cash and cash equivalents and restricted cash and cash equivalents at end of period	$	679,262	$	58,113

See accompanying notes to condensed consolidated financial statements.

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ATMOS ENERGY CORPORATION

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

June 30, 2024

1.    Nature of Business

Atmos Energy Corporation (“Atmos Energy” or the “Company”) and its subsidiaries are engaged in the regulated natural gas distribution and pipeline and storage businesses. Our distribution business is subject to federal and state regulation and/or regulation by local authorities in each of the states in which our regulated divisions and subsidiaries operate.

Our distribution business delivers natural gas through sales and transportation arrangements to over 3.3 million residential, commercial, public authority and industrial customers through our six regulated distribution divisions, which at June 30, 2024, covered service areas located in eight states.

Our pipeline and storage business, which is also subject to federal and state regulations, includes the transportation of natural gas to our Texas and Louisiana distribution systems and the management of our underground storage facilities used to support our distribution business in various states.

2.    Summary of Significant Accounting Policies

Basis of Presentation

These consolidated interim-period financial statements have been prepared in accordance with accounting principles generally accepted in the United States on the same basis as those used for the Company’s audited consolidated financial statements included in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. In the opinion of management, all material adjustments (consisting of normal recurring accruals) necessary for a fair presentation have been made to the unaudited consolidated interim-period financial statements. These consolidated interim-period financial statements are condensed as permitted by the instructions to Form 10-Q and should be read in conjunction with the audited consolidated financial statements of Atmos Energy Corporation included in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. Because of seasonal and other factors, the results of operations for the nine-month period ended June 30, 2024 are not indicative of our results of operations for the full 2024 fiscal year, which ends September 30, 2024.

Significant accounting policies

Our accounting policies are described in Note 2 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023.

During the second quarter of fiscal 2024, we completed our annual goodwill impairment assessment using a qualitative assessment, as permitted under U.S. GAAP. We test for goodwill at the reporting unit level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of the reporting unit. Based on the assessment performed, we determined that our goodwill was not impaired.

No events have occurred subsequent to the balance sheet date that would require recognition or disclosure in the condensed consolidated financial statements.

Recently issued accounting pronouncements

In November 2023, the Financial Accounting Standards Board (FASB) issued guidance which provides updates to qualitative and quantitative reportable segment disclosure requirements, including enhanced disclosures about significant segment expenses and increased interim disclosure requirements, among others. The amendment is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted, and the amendments should be applied retrospectively. This amendment will be effective for our Form 10-K for fiscal 2025 and our Form 10-Q for the first quarter of fiscal 2026. We are currently evaluating the impact this may have on our financial statement disclosures.

In December 2023, the FASB issued guidance which provides qualitative and quantitative updates to the rate reconciliation and income taxes paid disclosures, among others, in order to enhance the transparency of income tax disclosures, including consistent categories and greater disaggregation of information in the rate reconciliation and disaggregation by jurisdiction of income taxes paid. The amendment is effective for fiscal years beginning after December 15, 2024, with early adoption permitted. The amendments should be applied prospectively; however, retrospective application is also permitted. This amendment will be effective for our Form 10-K for fiscal 2026. We are currently evaluating the impact this amendment may have on our financial statement disclosures.

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3.    Regulation

Accounting principles generally accepted in the United States require cost-based, rate-regulated entities that meet certain criteria to reflect the authorized recovery of costs due to regulatory decisions in their financial statements. As a result, certain costs are permitted to be capitalized rather than expensed because they can be recovered through rates. We record certain costs as regulatory assets when future recovery through customer rates is considered probable. Regulatory liabilities are recorded when it is probable that revenues will be reduced for amounts that will be credited to customers through the ratemaking process. Substantially all of our regulatory assets are recorded as a component of other current assets and deferred charges and other assets and our regulatory liabilities are recorded as a component of other current liabilities and deferred credits and other liabilities. Deferred gas costs are recorded either in other current assets or liabilities.

Regulatory assets and liabilities as of June 30, 2024 and September 30, 2023 included the following:

	June 30, 2024		September 30, 2023
	(In thousands)
Regulatory assets:
Pension and postretirement benefit costs	$	14,033	$	20,629
Infrastructure mechanisms (1)	209,609		229,996
Winter Storm Uri incremental costs	12,549		32,115
Deferred gas costs	68,296		148,297
Regulatory excess deferred taxes (2)	50,462		47,549
Recoverable loss on reacquired debt	3,112		3,238
Deferred pipeline record collection costs	42,454		54,008
APT annual System Safety and Integrity Rider	35,721		—
Other	15,288		19,096
	$	451,524	$	554,928
Regulatory liabilities:
Regulatory excess deferred taxes (2)	$	283,073	$	384,513
Regulatory cost of removal obligation	605,449		582,867
Deferred gas costs	20,188		23,093
APT annual adjustment mechanism	48,544		49,894
Pension and postretirement benefit costs	199,838		215,913
Other	30,280		28,054
	$	1,187,372	$	1,284,334

(1)Infrastructure mechanisms in Texas, Louisiana and Tennessee allow for the deferral of all eligible expenses associated with capital expenditures incurred pursuant to these rules, including the recording of interest on deferred expenses until the next rate proceeding (rate case or annual rate filing), at which time investment and costs would be recoverable through base rates.

(2)Regulatory excess deferred taxes represent changes in our net deferred tax liability related to our cost of service ratemaking due to the enactment of Tax Cuts and Jobs Act of 2017 (the "TCJA") and a Kansas legislative change enacted in fiscal 2020. See Note 12 to the condensed consolidated financial statements for further information.

Securitization

Kansas

See Note 9 to the condensed consolidated financial statements for securitization and other information related to Atmos Energy Kansas Securitization I, LLC (AEK).

Texas

In March 2023, the Texas Natural Gas Securitization Finance Corporation (the Finance Corporation), with the authority of the Texas Public Finance Authority (TPFA), issued $3.5 billion in customer rate relief bonds with varying scheduled final maturities from 12 to 18 years. The bonds are obligations of the Finance Corporation, payable from the customer rate relief charges and other bond collateral, and are not an obligation of Atmos Energy. We began collecting the customer rate relief

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charges on October 1, 2023, and any such property collected is solely owned by the Finance Corporation and not available to pay creditors of Atmos Energy.

Additionally, we deferred $32.4 million in carrying costs incurred after September 1, 2022. Effective October 1, 2023, we began recovering a portion of these carrying costs. We have recorded $6.1 million and $21.2 million as a current asset in other current assets as of June 30, 2024 and September 30, 2023. We anticipate recovering the remaining $6.4 million in future regulatory filings and have recorded this amount as a long-term asset in deferred charges and other assets as of June 30, 2024.

4.    Segment Information

We manage and review our consolidated operations through the following reportable segments:

•The distribution segment is comprised of our regulated natural gas distribution and related sales operations in eight states.

•The pipeline and storage segment is comprised primarily of the regulated pipeline and storage operations of our Atmos Pipeline-Texas division and our natural gas transmission operations in Louisiana.

The accounting policies of the segments are the same as those described in the summary of significant accounting policies found in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023.

Income statements and capital expenditures for the three and nine months ended June 30, 2024 and 2023 by segment are presented in the following tables:

	Three Months Ended June 30, 2024
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Operating revenues from external parties	$	632,446	$	69,103	$	—	$	701,549
Intersegment revenues	765		181,577		(182,342)		—
Total operating revenues	633,211		250,680		(182,342)		701,549
Purchased gas cost	179,510		(19)		(182,084)		(2,593)
Operation and maintenance expense	153,140		58,427		(258)		211,309
Depreciation and amortization expense	122,912		43,915		—		166,827
Taxes, other than income	94,527		11,212		—		105,739
Operating income	83,122		137,145		—		220,267
Other non-operating income	11,452		8,446		—		19,898
Interest charges	22,550		18,610		—		41,160
Income before income taxes	72,024		126,981		—		199,005
Income tax expense	6,175		27,266		—		33,441
Net income	$	65,849	$	99,715	$	—	$	165,564
Capital expenditures	$	587,062	$	126,549	$	—	$	713,611

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	Three Months Ended June 30, 2023
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Operating revenues from external parties	$	615,259	$	47,474	$	—	$	662,733
Intersegment revenues	808		160,751		(161,559)		—
Total operating revenues	616,067		208,225		(161,559)		662,733
Purchased gas cost	206,048		(194)		(161,304)		44,550
Operation and maintenance expense	138,351		56,953		(255)		195,049
Depreciation and amortization expense	107,809		42,917		—		150,726
Taxes, other than income	92,180		10,975		—		103,155
Operating income	71,679		97,574		—		169,253
Other non-operating income	6,695		9,475		—		16,170
Interest charges	16,146		15,188		—		31,334
Income before income taxes	62,228		91,861		—		154,089
Income tax expense	2,589		13,693		—		16,282
Net income	$	59,639	$	78,168	$	—	$	137,807
Capital expenditures	$	512,585	$	155,552	$	—	$	668,137

	Nine Months Ended June 30, 2024
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Operating revenues from external parties	$	3,325,459	$	181,784	$	—	$	3,507,243
Intersegment revenues	2,271		503,552		(505,823)		—
Total operating revenues	3,327,730		685,336		(505,823)		3,507,243
Purchased gas cost	1,464,815		825		(505,069)		960,571
Operation and maintenance expense	435,711		142,596		(754)		577,553
Depreciation and amortization expense	363,981		132,541		—		496,522
Taxes, other than income	273,430		28,805		—		302,235
Operating income	789,793		380,569		—		1,170,362
Other non-operating income	26,650		27,821		—		54,471
Interest charges	93,915		54,562		—		148,477
Income before income taxes	722,528		353,828		—		1,076,356
Income tax expense	92,550		74,927		—		167,477
Net income	$	629,978	$	278,901	$	—	$	908,879
Capital expenditures	$	1,659,217	$	469,920	$	—	$	2,129,137

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	Nine Months Ended June 30, 2023
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Operating revenues from external parties	$	3,554,389	$	133,326	$	—	$	3,687,715
Intersegment revenues	2,314		445,952		(448,266)		—
Total operating revenues	3,556,703		579,278		(448,266)		3,687,715
Purchased gas cost	1,896,986		(431)		(447,545)		1,449,010
Operation and maintenance expense	426,173		149,329		(721)		574,781
Depreciation and amortization expense	319,783		125,280		—		445,063
Taxes, other than income	275,002		30,782		—		305,784
Operating income	638,759		274,318		—		913,077
Other non-operating income	20,934		33,833		—		54,767
Interest charges	60,405		45,059		—		105,464
Income before income taxes	599,288		263,092		—		862,380
Income tax expense	56,707		38,335		—		95,042
Net income	$	542,581	$	224,757	$	—	$	767,338
Capital expenditures	$	1,381,118	$	702,368	$	—	$	2,083,486

Balance sheet information at June 30, 2024 and September 30, 2023 by segment is presented in the following tables:

	June 30, 2024
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Net property, plant and equipment	$	15,855,074	$	5,567,044	$	—	$	21,422,118
Total assets	$	24,067,602	$	5,901,759	$	(5,078,110)	$	24,891,251

	September 30, 2023
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Net property, plant and equipment	$	14,402,578	$	5,204,005	$	—	$	19,606,583
Total assets	$	21,716,467	$	5,504,972	$	(4,704,471)	$	22,516,968

5.    Earnings Per Share

We use the two-class method of computing earnings per share because we have participating securities in the form of non-vested restricted stock units with a nonforfeitable right to dividend equivalents, for which vesting is predicated solely on the passage of time. The calculation of earnings per share using the two-class method excludes income attributable to these participating securities from the numerator and excludes the dilutive impact of those shares from the denominator. Basic weighted average shares outstanding is calculated based upon the weighted average number of common shares outstanding during the periods presented. Also, this calculation includes fully vested stock awards that have not yet been issued as common stock. Additionally, the weighted average shares outstanding for diluted EPS includes the incremental effects of the forward sale agreements, discussed in Note 8 to the condensed consolidated financial statements, when the impact is dilutive.

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Basic and diluted earnings per share for the three and nine months ended June 30, 2024 and 2023 are calculated as follows:

	Three Months Ended June 30				Nine Months Ended June 30
	2024		2023		2024		2023
	(In thousands, except per share amounts)
Basic Earnings Per Share
Net income	$	165,564	$	137,807	$	908,879	$	767,338
Less: Income allocated to participating securities	87		83		490		482
Income available to common shareholders	$	165,477	$	137,724	$	908,389	$	766,856
Basic weighted average shares outstanding	153,309		146,051		151,459		143,938
Net income per share — Basic	$	1.08	$	0.94	$	6.00	$	5.33
Diluted Earnings Per Share
Income available to common shareholders	$	165,477	$	137,724	$	908,389	$	766,856
Effect of dilutive shares	—		—		—		—
Income available to common shareholders	$	165,477	$	137,724	$	908,389	$	766,856
Basic weighted average shares outstanding	153,309		146,051		151,459		143,938
Dilutive shares	87		16		38		60
Diluted weighted average shares outstanding	153,396		146,067		151,497		143,998
Net income per share — Diluted	$	1.08	$	0.94	$	6.00	$	5.33

6.    Revenue and Accounts Receivable

Revenue

Our revenue recognition policy is fully described in Note 2 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. The following tables disaggregate our revenue from contracts with customers by customer type and segment and provide a reconciliation to total operating revenues, including intersegment revenues, for the three and nine months ended June 30, 2024 and 2023.

	Three Months Ended June 30, 2024				Three Months Ended June 30, 2023
	Distribution		Pipeline and Storage		Distribution		Pipeline and Storage
	(In thousands)
Gas sales revenues:
Residential	$	384,957	$	—	$	380,099	$	—
Commercial	169,508		—		165,930		—
Industrial	21,160		—		23,533		—
Public authority and other	8,177		—		8,562		—
Total gas sales revenues	583,802		—		578,124		—
Transportation revenues	30,773		260,779		27,988		212,322
Miscellaneous revenues	2,681		7,592		2,706		4,397
Revenues from contracts with customers	617,256		268,371		608,818		216,719
Alternative revenue program revenues	11,997		(17,691)		6,772		(8,494)
Other revenues	3,958		—		477		—
Total operating revenues	$	633,211	$	250,680	$	616,067	$	208,225

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	Nine Months Ended June 30, 2024				Nine Months Ended June 30, 2023
	Distribution		Pipeline and Storage		Distribution		Pipeline and Storage
	(In thousands)
Gas sales revenues:
Residential	$	2,177,935	$	—	$	2,276,240	$	—
Commercial	851,462		—		953,409		—
Industrial	79,810		—		127,792		—
Public authority and other	43,881		—		54,074		—
Total gas sales revenues	3,153,088		—		3,411,515		—
Transportation revenues	102,147		699,243		93,661		597,822
Miscellaneous revenues	9,048		12,796		7,650		8,271
Revenues from contracts with customers	3,264,283		712,039		3,512,826		606,093
Alternative revenue program revenues	51,713		(26,703)		42,360		(26,815)
Other revenues	11,734		—		1,517		—
Total operating revenues	$	3,327,730	$	685,336	$	3,556,703	$	579,278

We have alternative revenue programs in each of our segments. In our distribution segment, we have weather-normalization adjustment mechanisms that serve to mitigate the effects of weather on our revenue. In our pipeline and storage segment, APT has a regulatory mechanism that requires that we share with its tariffed customers 75% of the difference between the total non-tariffed revenues earned during a test period and a revenue benchmark established by the RRC. With the completion of APT's most recent rate case in December 2023, the revenue benchmark was increased from $69.4 million to $106.9 million. Other revenues includes AEK revenues (see Note 9 to the condensed consolidated financial statements) and other miscellaneous revenues.

Accounts receivable and allowance for uncollectible accounts

Accounts receivable arise from natural gas sales to residential, commercial, industrial, public authority and other customers. Our accounts receivable balance includes unbilled amounts which represent a customer’s consumption of gas from the date of the last cycle billing through the last day of the month. Our policy related to the accounting for our accounts receivable and allowance for uncollectible accounts is fully described in Note 2 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. During the nine months ended June 30, 2024, there were no material changes to this policy. Rollforwards of our allowance for uncollectible accounts for the three and nine months ended June 30, 2024 and 2023 are presented in the table below. The allowance excludes the gas cost portion of customers’ bills for approximately 88 percent of our customers as we have the ability to collect these gas costs through our gas cost recovery mechanisms in most of our jurisdictions.

In December 2023, the Mississippi Public Service Commission approved the recovery of uncollectible accounts through our purchased gas cost mechanism over a two-year period rather than through our annual filing mechanism over a one-year period. As a result of this decision, we recorded a $13.9 million reduction to bad debt expense during the first quarter of fiscal 2024. Of this amount, $9.7 million represents future recovery of customer receivables previously written off since April 2022 but not yet recovered through our rates. This amount increased our deferred gas cost regulatory asset. The remaining $4.2 million reduction represents a reversal of our allowance for uncollectible accounts for customer balances that have not yet been written off.

	Three Months Ended June 30, 2024
	(In thousands)
Beginning balance, March 31, 2024	$	42,705
Current period provisions	3,575
Write-offs charged against allowance	(4,407)
Recoveries of amounts previously written off	286
Ending balance, June 30, 2024	$	42,159

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	Three Months Ended June 30, 2023
	(In thousands)
Beginning balance, March 31, 2023	$	52,751
Current period provisions	1,758
Write-offs charged against allowance	(5,902)
Recoveries of amounts previously written off	294
Ending balance, June 30, 2023	$	48,901

	Nine Months Ended June 30, 2024
	(In thousands)
Beginning balance, September 30, 2023	$	40,840
Current period provisions	23,122
Write-offs charged against allowance	(19,023)
Recoveries of amounts previously written off	1,412
Mississippi recovery of uncollectible accounts	(4,192)
Ending balance, June 30, 2024	$	42,159

	Nine Months Ended June 30, 2023
	(In thousands)
Beginning balance, September 30, 2022	$	49,993
Current period provisions	22,000
Write-offs charged against allowance	(24,656)
Recoveries of amounts previously written off	1,564
Ending balance, June 30, 2023	$	48,901

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7.    Debt

The nature and terms of our debt instruments and credit facilities are described in detail in Note 8 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. Other than as described below, there were no material changes in the terms of our debt instruments during the nine months ended June 30, 2024.

Long-term debt at June 30, 2024 and September 30, 2023 consisted of the following:

	June 30, 2024		September 30, 2023
	(In thousands)
Unsecured 3.00% Senior Notes, due June 2027	$	500,000	$	500,000
Unsecured 2.625% Senior Notes, due September 2029	500,000		500,000
Unsecured 1.50% Senior Notes, due January 2031	600,000		600,000
Unsecured 5.45% Senior Notes, due October 2032	300,000		300,000
Unsecured 5.90% Senior Notes, due October 2033	725,000		—
Unsecured 5.95% Senior Notes, due October 2034	200,000		200,000
Unsecured 5.50% Senior Notes, due June 2041	400,000		400,000
Unsecured 4.15% Senior Notes, due January 2043	500,000		500,000
Unsecured 4.125% Senior Notes, due October 2044	750,000		750,000
Unsecured 4.30% Senior Notes, due October 2048	600,000		600,000
Unsecured 4.125% Senior Notes, due March 2049	450,000		450,000
Unsecured 3.375% Senior Notes, due September 2049	500,000		500,000
Unsecured 2.85% Senior Notes, due February 2052	600,000		600,000
Unsecured 5.75% Senior Notes, due October 2052	500,000		500,000
Unsecured 6.20% Senior Notes, due October 2053	500,000		—
Medium-term note Series A, 1995-1, 6.67%, due December 2025	10,000		10,000
Unsecured 6.75% Debentures, due July 2028	150,000		150,000
Finance lease obligations	49,283		50,393
Total long-term debt	7,834,283		6,610,393
Less:
Original issue (premium) discount on unsecured senior notes and debentures	(9,418)		6,104
Debt issuance cost	56,885		48,588
Current maturities of long-term debt	1,620		1,568
Total long-term debt, net	$	7,785,196	$	6,554,133

On October 10, 2023, we completed a public offering of $500 million of 6.20% senior notes due October 2053, with an effective interest rate of 5.56%, after giving effect to the offering costs and settlement of our interest rate swaps, and $400 million of 5.90% senior notes due October 2033, with an effective interest rate of 4.35%, after giving effect to the offering costs and settlement of our interest rate swaps. The net proceeds from the offering, after the underwriting discount and offering expenses, of $889.4 million were used for general corporate purposes.

On June 21, 2024, we completed a public offering of $325 million of 5.90% senior notes due October 2033, with an effective interest rate of 5.17%, after giving effect to the estimated offering costs. The net proceeds from the offering, after the underwriting discount and offering expenses as of June 30, 2024, of $339.7 million were used for general corporate purposes.

Short-term debt

We utilize short-term debt to provide cost-effective, short-term financing until it can be replaced with a balance of long-term debt and equity financing that achieves the Company’s desired capital structure. Our short-term borrowing requirements are driven primarily by construction work in progress and the seasonal nature of the natural gas business.

Our short-term borrowing requirements are satisfied through a combination of a $1.5 billion commercial paper program and four committed revolving credit facilities with third-party lenders that provide $3.1 billion of total working capital funding.

Our commercial paper program is supported by a five-year unsecured $1.5 billion credit facility that was replaced on March 28, 2024, with a new five-year senior unsecured $1.5 billion credit facility that expires on March 28, 2029. This new facility bears interest at a base rate or at a Term SOFR-based rate for the applicable interest period, plus a margin ranging from

15

zero percent to 0.25 percent for base rate advances or a margin ranging from 0.75 percent to 1.25 percent for Term SOFR-based advances, based on the Company’s credit ratings. Additionally, the facility contains a $250 million accordion feature, which provides the opportunity to increase the total committed loan to $1.75 billion. At June 30, 2024, there were no amounts outstanding under our commercial paper program. At September 30, 2023, there was $241.9 million outstanding under our commercial paper program.

We also had a $900 million three-year unsecured revolving credit facility, which was replaced on March 28, 2024, with a new $1.5 billion three-year senior unsecured credit facility, which expires March 28, 2027 and is used to provide additional working capital funding. This new facility bears interest at a base rate or at a Term SOFR-based rate for the applicable interest period, plus a margin ranging from zero percent to 0.25 percent for base rate advances or a margin ranging from 0.75 percent to 1.25 percent for Term SOFR-based advances, based on the Company's credit ratings. Additionally, the facility contains a $250 million accordion feature, which provides the opportunity to increase the total committed loan to $1.75 billion. At June 30, 2024 and September 30, 2023, there were no borrowings outstanding under this facility.

Additionally, we have a $50 million 364-day unsecured facility, which was renewed April 1, 2024 and is used to provide working capital funding. There were no borrowings outstanding under this facility as of June 30, 2024 and September 30, 2023.

Finally, we have a $50 million 364-day unsecured revolving credit facility, which was renewed March 31, 2024 and is used to issue letters of credit and to provide working capital funding. At June 30, 2024, there were no borrowings outstanding under this facility; however, outstanding letters of credit reduced the total amount available to us to $44.4 million.

Debt covenants

The availability of funds under these credit facilities is subject to conditions specified in the respective credit agreements, all of which we currently satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and warranties contained in these agreements. We are required by the financial covenants in each of these facilities to maintain, at the end of each fiscal quarter, a ratio of total-debt-to-total-capitalization of no greater than 70 percent. At June 30, 2024, our total-debt-to-total-capitalization ratio, as defined in the agreements, was 40 percent. In addition, both the interest margin and the fee that we pay on unused amounts under certain of these facilities are subject to adjustment depending upon our credit ratings.

These credit facilities and our public indentures contain usual and customary covenants for our business, including covenants substantially limiting liens, substantial asset sales and mergers. Additionally, our public debt indentures relating to our senior notes and debentures, as well as certain of our revolving credit agreements, each contain a default provision that is triggered if outstanding indebtedness arising out of any other credit agreements in amounts ranging from in excess of $15 million to in excess of $100 million becomes due by acceleration or if not paid at maturity. We were in compliance with all of our debt covenants as of June 30, 2024. If we were unable to comply with our debt covenants, we would likely be required to repay our outstanding balances on demand, provide additional collateral or take other corrective actions.

8.    Shareholders' Equity

The following tables present a reconciliation of changes in stockholders' equity for the three and nine months ended June 30, 2024 and 2023.

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	Common stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)		Retained Earnings		Total
	Number of Shares	Stated Value
	(In thousands, except share and per share data)
Balance, September 30, 2023	148,492,783	$	742	$	6,684,120	$	518,528	$	3,666,674	$	10,870,064
Net income	—	—		—		—		311,292		311,292
Other comprehensive loss	—	—		—		(49,936)		—		(49,936)
Cash dividends ($0.805 per share)	—	—		—		—		(119,898)		(119,898)
Common stock issued:
Public and other stock offerings	2,177,864	11		257,757		—		—		257,768
Stock-based compensation plans	163,750	1		3,918		—		—		3,919
Balance, December 31, 2023	150,834,397	754		6,945,795		468,592		3,858,068		11,273,209
Net income	—	—		—		—		432,023		432,023
Other comprehensive income	—	—		—		27,108		—		27,108
Cash dividends ($0.805 per share)	—	—		—		—		(121,667)		(121,667)
Common stock issued:
Public and other stock offerings	34,687	—		4,025		—		—		4,025
Stock-based compensation plans	5,468	—		3,941		—		—		3,941
Balance, March 31, 2024	150,874,552	754		6,953,761		495,700		4,168,424		11,618,639
Net income	—	—		—		—		165,564		165,564
Other comprehensive income	—	—		—		14,432		—		14,432
Cash dividends ($0.805 per share)	—	—		—		—		(125,154)		(125,154)
Common stock issued:
Public and other stock offerings	4,288,217	22		499,562		—		—		499,584
Stock-based compensation plans	66,255	—		10,011		—		—		10,011
Balance, June 30, 2024	155,229,024	$	776	$	7,463,334	$	510,132	$	4,208,834	$	12,183,076

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	Common stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)		Retained Earnings		Total
	Number of Shares	Stated Value
	(In thousands, except share and per share data)
Balance, September 30, 2022	140,896,598	$	704	$	5,838,118	$	369,112	$	3,211,157	$	9,419,091
Net income	—	—		—		—		271,860		271,860
Other comprehensive income	—	—		—		22,218		—		22,218
Cash dividends ($0.74 per share)	—	—		—		—		(104,552)		(104,552)
Common stock issued:
Public and other stock offerings	2,147,210	11		223,768		—		—		223,779
Stock-based compensation plans	111,953	1		3,877		—		—		3,878
Balance, December 31, 2022	143,155,761	716		6,065,763		391,330		3,378,465		9,836,274
Net income	—	—		—		—		357,671		357,671
Other comprehensive loss	—	—		—		(30,333)		—		(30,333)
Cash dividends ($0.74 per share)	—	—		—		—		(106,173)		(106,173)
Common stock issued:
Public and other stock offerings	1,316,930	6		143,808		—		—		143,814
Stock-based compensation plans	11,959	—		3,952		—		—		3,952
Balance, March 31, 2023	144,484,650	722		6,213,523		360,997		3,629,963		10,205,205
Net income	—	—		—		—		137,807		137,807
Other comprehensive income	—	—		—		43,406		—		43,406
Cash dividends ($0.74 per share)	—	—		—		—		(108,349)		(108,349)
Common stock issued:
Public and other stock offerings	2,754,533	15		315,682		—		—		315,697
Stock-based compensation plans	65,355	—		8,615		—		—		8,615
Balance, June 30, 2023	147,304,538	$	737	$	6,537,820	$	404,403	$	3,659,421	$	10,602,381

Shelf Registration, At-the-Market Equity Sales Program and Equity Issuances

We have a shelf registration statement with the Securities and Exchange Commission (SEC) that allows us to issue up to $5.0 billion in common stock and/or debt securities, which expires March 31, 2026. At June 30, 2024, $1.8 billion of securities were available for issuance under this shelf registration statement.

On May 8, 2024, we filed a prospectus supplement under the shelf registration statement relating to an at-the-market (ATM) equity sales program under which we may issue and sell shares of our common stock up to an aggregate offering price of $1.0 billion through March 31, 2026 (including shares of common stock that may be sold pursuant to forward sale agreements entered into concurrently with the ATM equity sales program). This ATM equity sales program replaced our previous ATM equity sales program, filed on March 31, 2023.

During the nine months ended June 30, 2024, we executed forward sales under our ATM equity sales program with various forward sellers who borrowed and sold 7,224,450 shares of our common stock at an aggregate price of $833.2 million. During the nine months ended June 30, 2024, we also settled forward sale agreements with respect to 6,401,469 shares that had been borrowed and sold by various forward sellers under the ATM program for net proceeds of $750.0 million. As of June 30, 2024, $845.7 million of equity was available for issuance under our existing ATM program. Additionally, we had $550.7 million in available proceeds from outstanding forward sale agreements, as detailed below.

Maturity	Shares Available	Net Proceeds Available (In thousands)		Forward Price
June 30, 2025	3,931,418	$	450,884	$	114.69
September 30, 2025	815,655	95,523		$	117.11
December 31, 2025	36,933	4,328		$	117.18
Total	4,784,006	$	550,735	$	115.12

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Accumulated Other Comprehensive Income (Loss)

We record deferred gains (losses) in AOCI related to available-for-sale debt securities and interest rate agreement cash flow hedges. Deferred gains (losses) for our available-for-sale debt securities are recognized in earnings upon settlement, while deferred gains (losses) related to our interest rate agreement cash flow hedges are recognized in earnings on a straight-line basis over the life of the related financing. The following tables provide the components of our accumulated other comprehensive income (loss) balances, net of the related tax effects allocated to each component of other comprehensive income (loss).

	Available- for-Sale Securities		Interest Rate Agreement Cash Flow Hedges		Total
	(In thousands)
September 30, 2023	$	(369)	$	518,897	$	518,528
Other comprehensive income (loss) before reclassifications	242		(1,165)		(923)
Amounts reclassified from accumulated other comprehensive income	—		(7,473)		(7,473)
Net current-period other comprehensive income (loss)	242		(8,638)		(8,396)
June 30, 2024	$	(127)	$	510,259	$	510,132

	Available- for-Sale Securities		Interest Rate Agreement Cash Flow Hedges		Total
	(In thousands)
September 30, 2022	$	(495)	$	369,607	$	369,112
Other comprehensive income before reclassifications	100		36,781		36,881
Amounts reclassified from accumulated other comprehensive income	—		(1,590)		(1,590)
Net current-period other comprehensive income	100		35,191		35,291
June 30, 2023	$	(395)	$	404,798	$	404,403

9.    Variable Interest Entity

Atmos Energy Kansas Securitization I, LLC (AEK), a special-purpose entity wholly owned by Atmos Energy, was formed for the purpose of issuing securitized bonds to recover extraordinary costs incurred during Winter Storm Uri. In June 2023, AEK completed a public offering of $95 million of Securitized Utility Tariff Bonds. AEK's assets cannot be used to settle Atmos Energy's obligations, and the holders of the Securitized Utility Tariff Bonds have no recourse against Atmos Energy.

AEK is considered to be a variable interest entity. As a result, AEK is included in the condensed consolidated financial statements of Atmos Energy.

The following table summarizes the impact of AEK on our condensed consolidated balance sheets, for the periods indicated:

	June 30, 2024		September 30, 2023
	(In thousands)
Restricted cash and cash equivalents	$	4,642	$	3,844
Other current assets	$	14	$	11
Securitized intangible asset, net	$	84,998	$	92,202
Accrued interest	$	1,534	$	1,374
Current maturities of securitized long-term debt	$	8,001	$	9,922
Securitized long-term debt	$	81,261	$	85,078

The following table summarizes the impact of AEK on our condensed consolidated statement of comprehensive income, for the period indicated:

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	Three Months Ended June 30, 2024		Nine Months Ended June 30, 2024
Operating revenues	$	3,463	$	10,265
Operation and maintenance expense	(52)		(276)
Amortization expense	(2,292)		(6,561)
Interest expense, net	(1,119)		(3,428)
Income before income taxes	$	—	$	—

There were no material impacts to the condensed consolidated statements of comprehensive income for the three and nine months ended June 30, 2023.

The securitized long-term debt is recorded at carrying value. The fair value of the securitized long-term debt is determined using third party market value quotations, which are considered Level 2 fair value measurements for debt instruments where fair value is determined using the most recent available quoted market price. The carrying value and fair value of the securitized long-term debt as of June 30, 2024 is $89.3 million and $89.2 million.

10.     Interim Pension and Other Postretirement Benefit Plan Information

The components of our net periodic pension cost for our pension and other postretirement benefit plans for the three and nine months ended June 30, 2024 and 2023 are presented in the following tables. Most of these costs are recoverable through our tariff rates. A portion of these costs is capitalized into our rate base or deferred as a regulatory asset or liability. The remaining costs are recorded as a component of operation and maintenance expense or other non-operating expense.

In the first quarter of fiscal 2024, due to the retirement of an executive, we recognized a settlement charge of $0.8 million associated with our Supplemental Executive Retirement Plan and revalued the net periodic pension cost for the remainder of fiscal 2024. The revaluation of the net periodic pension cost for our Supplemental Executive Retirement Plan resulted in a decrease in the discount rate, effective November 30, 2023, to 5.82% from 6.17%, which will decrease our net periodic pension cost by approximately $0.4 million for the remainder of the fiscal year.

	Three Months Ended June 30
	Pension Benefits				Other Benefits
	2024		2023		2024		2023
	(In thousands)
Components of net periodic pension cost:
Service cost	$	2,405	$	2,915	$	1,507	$	1,546
Interest cost (1)	7,430		7,265		3,509		3,478
Expected return on assets (1)	(7,202)		(7,278)		(3,128)		(2,804)
Amortization of prior service cost (credit) (1)	—		(30)		(3,260)		(3,285)
Amortization of actuarial (gain) loss (1)	97		178		(2,718)		(1,863)
Settlements (1)	—		1,030		—		—
Net periodic pension cost	$	2,730	$	4,080	$	(4,090)	$	(2,928)

	Nine Months Ended June 30
	Pension Benefits				Other Benefits
	2024		2023		2024		2023
	(In thousands)
Components of net periodic pension cost:
Service cost	$	7,199	$	8,731	$	4,521	$	4,637
Interest cost (1)	22,356		21,915		10,526		10,433
Expected return on assets (1)	(21,606)		(21,835)		(9,383)		(8,411)
Amortization of prior service cost (credit) (1)	—		(91)		(9,780)		(9,856)
Amortization of actuarial (gain) loss (1)	313		506		(8,154)		(5,589)
Settlements (1)	776		1,030		—		—
Net periodic pension cost	$	9,038	$	10,256	$	(12,270)	$	(8,786)

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(1)    The components of net periodic cost other than the service cost component are included in the line item other non-operating expense in the condensed consolidated statements of comprehensive income or are capitalized on the condensed consolidated balance sheets as a regulatory asset or liability, as described in Note 2 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023.

11.    Commitments and Contingencies

Litigation and Environmental Matters

In the normal course of business, we are subject to various legal and regulatory proceedings. For such matters, we record liabilities when they are considered probable and estimable, based on currently available facts, our historical experience and our estimates of the ultimate outcome or resolution of the liability in the future. While the outcome of these proceedings is uncertain and a loss in excess of the amount we have accrued is possible though not reasonably estimable, it is the opinion of management that any amounts exceeding the accruals will not have a material adverse impact on our financial position, results of operations or cash flows.

The National Transportation Safety Board (NTSB) issued a Preliminary Report on February 14, 2024 relating to its investigation of two incidents that occurred in Jackson, Mississippi on January 24 and 27, 2024 that resulted in one fatality. Atmos Energy is working closely with the NTSB and other state and federal regulators to help determine causal factors.

We are a party to various other litigation and environmental-related matters or claims that have arisen in the ordinary course of our business. While the results of such litigation and response actions to such environmental-related matters or claims cannot be predicted with certainty, we continue to believe the final outcome of such litigation and matters or claims will not have a material adverse effect on our financial condition, results of operations or cash flows.

Purchase Commitments

Our distribution divisions maintain supply contracts with several vendors that generally cover a period of up to one year. Commitments for estimated base gas volumes are established under these contracts on a monthly basis at contractually negotiated prices. Commitments for incremental daily purchases are made as necessary during the month in accordance with the terms of the individual contract.

Our Mid-Tex Division also maintains a limited number of long-term supply contracts to ensure a reliable source of gas for our customers in its service area, which obligate it to purchase specified volumes at prices under contracts indexed to natural gas hubs or fixed price contracts. These purchase commitment contracts are detailed in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. At June 30, 2024, we were committed to purchase 67.8 Bcf within one year and 31.5 Bcf within two to three years under indexed contracts. At June 30, 2024, we were committed to purchase 12.8 Bcf within one year under fixed price contracts with a weighted average price of $3.06 per Mcf.

Rate Regulatory Proceedings

As of June 30, 2024, routine rate regulatory proceedings were in progress in several of our service areas, which are discussed in further detail below in Management’s Discussion and Analysis — Recent Ratemaking Developments. Except for these proceedings, there were no material changes to rate regulatory proceedings for the nine months ended June 30, 2024.

12.    Income Taxes

Income Tax Expense

Our interim effective tax rates reflect the estimated annual effective tax rates for the fiscal years ended September 30, 2024 and 2023, adjusted for tax expense associated with certain discrete items. The effective tax rates for the three months ended June 30, 2024 and 2023 were 16.8% and 10.6% and for the nine months ended June 30, 2024 and 2023 were 15.6% and 11.0%. These effective tax rates differ from the federal statutory tax rate of 21% primarily due to the amortization of excess deferred federal income tax liabilities, tax credits, state income taxes and other permanent book-to-tax differences. These adjustments have a relative impact on the effective tax rate proportionally to pretax income or loss.

Regulatory Excess Deferred Taxes

Regulatory excess net deferred taxes represent changes in our net deferred tax liability related to our cost of service ratemaking due to the enactment of the Tax Cuts and Jobs Act of 2017 (the TCJA) and a Kansas legislative change enacted in fiscal 2020. Currently, the regulatory excess net deferred tax liability of $232.6 million is being returned over various periods. Of this amount, $180.0 million is being returned to customers over 12 - 60 months. An additional $51.6 million is being returned to customers on a provisional basis over 15 - 69 years until our regulators establish the final refund periods. The refund of the remaining $1.0 million will be addressed in future rate proceedings.

As of June 30, 2024 and September 30, 2023, $87.6 million and $131.3 million is recorded in other current liabilities.

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13.    Financial Instruments

We currently use financial instruments to mitigate commodity price risk and interest rate risk. The objectives and strategies for using financial instruments and the related accounting for these financial instruments are fully described in Notes 2 and 16 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. During the nine months ended June 30, 2024, there were no material changes in our objectives, strategies and accounting for using financial instruments. Our financial instruments do not contain any credit-risk-related or other contingent features that could cause payments to be accelerated when our financial instruments are in net liability positions. The following summarizes those objectives and strategies.

Commodity Risk Management Activities

Our purchased gas cost adjustment mechanisms essentially insulate our distribution segment from commodity price risk; however, our customers are exposed to the effects of volatile natural gas prices. We manage this exposure through a combination of physical storage, fixed-price forward contracts and financial instruments, primarily over-the-counter swap and option contracts, in an effort to minimize the impact of natural gas price volatility on our customers during the winter heating season.

We typically seek to hedge between 25 and 50 percent of anticipated heating season gas purchases using financial instruments. For the 2023-2024 heating season (generally October through March), in the jurisdictions where we are permitted to utilize financial instruments, we hedged approximately 27.6 Bcf of the winter flowing gas requirements. We have not designated these financial instruments as hedges for accounting purposes.

Interest Rate Risk Management Activities

We manage interest rate risk by periodically entering into financial instruments to effectively fix the Treasury yield component of the interest cost associated with anticipated financings.

The following table summarizes our existing forward starting interest rate swaps as of June 30, 2024. These swaps were designated as cash flow hedges at the time the agreements were executed.

Planned Debt Issuance Date	Amount Hedged
	(In thousands)
Fiscal 2025	$	600,000
Fiscal 2026	300,000
	$	900,000

Quantitative Disclosures Related to Financial Instruments

The following tables present detailed information concerning the impact of financial instruments on our condensed consolidated balance sheet and statements of comprehensive income.

As of June 30, 2024, our financial instruments were comprised of both long and short commodity positions. A long position is a contract to purchase the commodity, while a short position is a contract to sell the commodity. As of June 30, 2024, we had 15,455 MMcf of net long commodity contracts outstanding. These contracts have not been designated as hedges.

Financial Instruments on the Balance Sheet

The following tables present the fair value and balance sheet classification of our financial instruments as of June 30, 2024 and September 30, 2023. The gross amounts of recognized assets and liabilities are netted within our condensed consolidated balance sheets to the extent that we have netting arrangements with our counterparties. However, as of June 30, 2024 and September 30, 2023, no gross amounts and no cash collateral were netted within our consolidated balance sheet.

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		June 30, 2024
	Balance Sheet Location	Assets		Liabilities
		(In thousands)
Designated As Hedges:
Interest rate contracts	Other current assets / Other current liabilities	$	273,551	$	—
Interest rate contracts	Deferred charges and other assets / Deferred credits and other liabilities	104,049		—
Total		377,600		—
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	2,349		(5,928)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	1,271		(49)
Total		3,620		(5,977)
Gross / Net Financial Instruments		$	381,220	$	(5,977)

		September 30, 2023
	Balance Sheet Location	Assets		Liabilities
		(In thousands)
Designated As Hedges:
Interest rate contracts	Deferred charges and other assets / Deferred credits and other liabilities	$	379,101	$	—
Total		379,101		—
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	4,071		(14,584)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	2,492		(824)
Total		6,563		(15,408)
Gross / Net Financial Instruments		$	385,664	$	(15,408)

Impact of Financial Instruments on the Statement of Comprehensive Income

Cash Flow Hedges

As discussed above, our distribution segment has interest rate agreements, which we designated as cash flow hedges at the time the agreements were executed. The net (gain) loss on settled interest rate agreements reclassified from AOCI into interest charges on our condensed consolidated statements of comprehensive income for the three months ended June 30, 2024 and 2023 was $(3.2) million and $(0.7) million and for the nine months ended June 30, 2024 and 2023 was $(9.6) million and $(2.1) million.

The following table summarizes the gains and losses arising from hedging transactions that were recognized as a component of other comprehensive income (loss), net of taxes, for the three and nine months ended June 30, 2024 and 2023.

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	Three Months Ended June 30				Nine Months Ended June 30
	2024		2023		2024		2023
	(In thousands)
Increase (decrease) in fair value:
Interest rate agreements	$	16,926	$	44,057	$	(1,165)	$	36,781
Recognition of (gains) losses in earnings due to settlements:
Interest rate agreements	(2,490)		(530)		(7,473)		(1,590)
Total other comprehensive income (loss) from hedging, net of tax	$	14,436	$	43,527	$	(8,638)	$	35,191

Deferred gains (losses) recorded in AOCI associated with our interest rate agreements are recognized in earnings as they are amortized over the terms of the underlying debt instruments. As of June 30, 2024, we had $217.3 million of net realized gains in AOCI associated with our interest rate agreements. The following amounts, net of deferred taxes, represent the expected recognition in earnings of the deferred net gains recorded in AOCI associated with our interest rate agreements, based upon the fair values of these agreements at the date of settlement. The remaining amortization periods for these settled amounts extend through fiscal 2053. However, the table below does not include the expected recognition in earnings of our outstanding interest rate swaps as those instruments have not yet settled.

	Interest Rate Agreements
	(In thousands)
Next twelve months	$	9,965
Thereafter	207,359
Total	$	217,324

Financial Instruments Not Designated as Hedges

As discussed above, commodity contracts which are used in our distribution segment are not designated as hedges. However, there is no earnings impact on our distribution segment as a result of the use of these financial instruments because the gains and losses arising from the use of these financial instruments are recognized in the consolidated statement of comprehensive income as a component of purchased gas cost when the related costs are recovered through our rates and recognized in revenue. Accordingly, the impact of these financial instruments is excluded from this presentation.

14.    Fair Value Measurements

We report certain assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We record cash and cash equivalents, restricted cash and cash equivalents, accounts receivable, accounts payable, and short-term debt at carrying value, which substantially approximates fair value due to the short-term nature of these assets and liabilities. For other financial assets and liabilities, we primarily use quoted market prices and other observable market pricing information to minimize the use of unobservable pricing inputs in our measurements when determining fair value. The methods used to determine fair value for our assets and liabilities are fully described in Note 2 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. During the nine months ended June 30, 2024, there were no changes in these methods.

Fair value measurements also apply to the valuation of our pension and postretirement plan assets. Current accounting guidance requires employers to annually disclose information about fair value measurements of the assets of a defined benefit pension or other postretirement plan. The fair value of these assets is presented in Note 11 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023.

Quantitative Disclosures

Financial Instruments

The classification of our fair value measurements requires judgment regarding the degree to which market data is observable or corroborated by observable market data. Authoritative accounting literature establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to unadjusted quoted prices in active markets for identical assets and

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liabilities (Level 1), with the lowest priority given to unobservable inputs (Level 3). The following tables summarize, by level within the fair value hierarchy, our assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, 2024 and September 30, 2023. Assets and liabilities are categorized in their entirety based on the lowest level of input that is significant to the fair value measurement.

	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)(1)		Significant Other Unobservable Inputs (Level 3)		Netting and Cash Collateral		June 30, 2024
	(In thousands)
Assets:
Financial instruments	$	—	$	381,220	$	—	$	—	$	381,220
Debt and equity securities
Registered investment companies	26,948		—		—		—		26,948
Bond mutual funds	39,253		—		—		—		39,253
Bonds (2)	—		38,369		—		—		38,369
Money market funds	—		3,791		—		—		3,791
Total debt and equity securities	66,201		42,160		—		—		108,361
Total assets	$	66,201	$	423,380	$	—	$	—	$	489,581
Liabilities:
Financial instruments	$	—	$	5,977	$	—	$	—	$	5,977

	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)(1)		Significant Other Unobservable Inputs (Level 3)		Netting and Cash Collateral		September 30, 2023
	(In thousands)
Assets:
Financial instruments	$	—	$	385,664	$	—	$	—	$	385,664
Debt and equity securities
Registered investment companies	26,685		—		—		—		26,685
Bond mutual funds	37,573		—		—		—		37,573
Bonds (2)	—		35,507		—		—		35,507
Money market funds	—		4,837		—		—		4,837
Total debt and equity securities	64,258		40,344		—		—		104,602
Total assets	$	64,258	$	426,008	$	—	$	—	$	490,266
Liabilities:
Financial instruments	$	—	$	15,408	$	—	$	—	$	15,408

(1)Our Level 2 measurements consist of over-the-counter options and swaps, which are valued using a market-based approach in which observable market prices are adjusted for criteria specific to each instrument, such as the strike price, notional amount or basis differences, municipal and corporate bonds, which are valued based on the most recent available quoted market prices and money market funds that are valued at cost.

(2)Our investments in bonds are considered available-for-sale debt securities in accordance with current accounting guidance.

Debt and equity securities are comprised of our available-for-sale debt securities and our equity securities. As described in Note 2 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023, we evaluate the performance of our available-for-sale debt securities on an investment by investment basis for impairment, taking into consideration the investment’s purpose, volatility, current returns and any intent to sell the security. As of June 30, 2024, no allowance for credit losses was recorded for our available-for-sale debt securities. At June 30, 2024 and September 30, 2023, the amortized cost of our available-for-sale debt securities was $38.5 million and $36.0 million. At June 30, 2024, we maintained investments in bonds that have contractual maturity dates ranging from July 2024 through September 2027.

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Other Fair Value Measures

Our long-term debt is recorded at carrying value. The fair value of our long-term debt, excluding finance leases, is determined using third party market value quotations, which are considered Level 1 fair value measurements for debt instruments with a recent, observable trade or Level 2 fair value measurements for debt instruments where fair value is determined using the most recent available quoted market price. The carrying value of our finance leases materially approximates fair value. The following table presents the carrying value and fair value of our long-term debt, excluding finance leases, debt issuance costs and original issue premium or discount, as of June 30, 2024 and September 30, 2023:

	June 30, 2024		September 30, 2023
	(In thousands)
Carrying Amount	$	7,785,000	$	6,560,000
Fair Value	$	6,892,431	$	5,402,591

15.    Concentration of Credit Risk

Information regarding our concentration of credit risk is disclosed in Note 18 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. During the nine months ended June 30, 2024, there were no material changes in our concentration of credit risk.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors and Shareholders of Atmos Energy Corporation

Results of Review of Interim Financial Statements

We have reviewed the accompanying condensed consolidated balance sheet of Atmos Energy Corporation (the Company) as of June 30, 2024, the related condensed consolidated statements of comprehensive income for the three and nine month periods ended June 30, 2024 and 2023, the condensed consolidated statements of cash flows for the nine month periods ended June 30, 2024 and 2023, and the related notes (collectively referred to as the "condensed consolidated interim financial statements"). Based on our reviews, we are not aware of any material modifications that should be made to the condensed consolidated interim financial statements for them to be in conformity with U.S. generally accepted accounting principles.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheet of the Company as of September 30, 2023, the related consolidated statements of comprehensive income, shareholders’ equity and cash flows for the year then ended, and the related notes (not presented herein); and in our report dated November 14, 2023, we expressed an unqualified audit opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of September 30, 2023, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

Basis for Review Results

These financial statements are the responsibility of the Company's management. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the SEC and the PCAOB. We conducted our review in accordance with the standards of the PCAOB. A review of interim financial statements consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

/s/    ERNST & YOUNG LLP

Dallas, Texas

August 7, 2024

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

INTRODUCTION

The following discussion should be read in conjunction with the condensed consolidated financial statements in this Quarterly Report on Form 10-Q and Management’s Discussion and Analysis in our Annual Report on Form 10-K for the year ended September 30, 2023.

Cautionary Statement for the Purposes of the Safe Harbor under the Private Securities Litigation Reform Act of 1995

The statements contained in this Quarterly Report on Form 10-Q may contain “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than statements of historical fact included in this Report are forward-looking statements made in good faith by us and are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. When used in this Report, or any other of our documents or oral presentations, the words “anticipate”, “believe”, “estimate”, “expect”, “forecast”, “goal”, “intend”, “objective”, “plan”, “projection”, “seek”, “strategy” or similar words are intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed or implied in the statements relating to our strategy, operations, markets, services, rates, recovery of costs, availability of gas supply and other factors. These risks and uncertainties include the following: federal, state and local regulatory and political trends and decisions, including the impact of rate proceedings before various state regulatory commissions; increased federal regulatory oversight and potential penalties; possible increased federal, state and local regulation of the safety of our operations; possible significant costs and liabilities resulting from pipeline integrity and other similar programs and related repairs; the inherent hazards and risks involved in distributing, transporting and storing natural gas; the availability and accessibility of contracted gas supplies, interstate pipeline and/or storage services; increased competition from energy suppliers and alternative forms of energy; failure to attract and retain a qualified workforce; natural disasters, terrorist activities or other events and other risks and uncertainties discussed herein, all of which are difficult to predict and many of which are beyond our control; increased dependence on technology that may hinder the Company's business if such technologies fail; the threat of cyber-attacks or acts of cyber-terrorism that could disrupt our business operations and information technology systems or result in the loss or exposure of confidential or sensitive customer, employee or Company information; the impact of new cybersecurity compliance requirements; adverse weather conditions; the impact of greenhouse gas emissions or other legislation or regulations intended to address climate change; the impact of climate change; the capital-intensive nature of our business; our ability to continue to access the credit and capital markets to execute our business strategy; market risks beyond our control affecting our risk management activities, including commodity price volatility, counterparty performance or creditworthiness and interest rate risk; the concentration of our operations in Texas; the impact of adverse economic conditions on our customers; changes in the availability and price of natural gas; and increased costs of providing health care benefits, along with pension and postretirement health care benefits and increased funding requirements. Accordingly, while we believe these forward-looking statements to be reasonable, there can be no assurance that they will approximate actual experience or that the expectations derived from them will be realized. Further, we undertake no obligation to update or revise any of our forward-looking statements whether as a result of new information, future events or otherwise.

OVERVIEW

Atmos Energy and our subsidiaries are engaged in the regulated natural gas distribution and pipeline and storage businesses. We distribute natural gas through sales and transportation arrangements to over 3.3 million residential, commercial, public authority and industrial customers throughout our six distribution divisions, which at June 30, 2024 covered service areas located in eight states. In addition, we transport natural gas for others through our distribution and pipeline systems.

We manage and review our consolidated operations through the following reportable segments:

•The distribution segment is comprised of our regulated natural gas distribution and related sales operations in eight states.

•The pipeline and storage segment is comprised primarily of the regulated pipeline and storage operations of our Atmos Pipeline-Texas division and our natural gas transmission operations in Louisiana.

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CRITICAL ACCOUNTING ESTIMATES AND POLICIES

Our condensed consolidated financial statements were prepared in accordance with accounting principles generally accepted in the United States. Preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures of contingent assets and liabilities. We based our estimates on historical experience and various other assumptions that we believe to be reasonable under the circumstances. On an ongoing basis, we evaluate our estimates, including those related to the allowance for doubtful accounts, legal and environmental accruals, insurance accruals, pension and postretirement obligations, deferred income taxes and the valuation of goodwill and other long-lived assets. Actual results may differ from such estimates.

Our critical accounting policies used in the preparation of our consolidated financial statements are described in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023 and include the following:

•Regulation

•Pension and other postretirement plans

•Impairment assessments

Our critical accounting policies are reviewed periodically by the Audit Committee of our Board of Directors. There were no significant changes to these critical accounting policies during the nine months ended June 30, 2024.

RESULTS OF OPERATIONS

Executive Summary

Atmos Energy strives to operate our businesses safely and reliably while delivering superior financial results. Our commitment to modernizing our natural gas distribution and transmission systems requires a significant level of capital spending. We have the ability to begin recovering a significant portion of these investments timely through rate designs and mechanisms that reduce or eliminate regulatory lag and separate the recovery of our approved rate from customer usage patterns. The execution of our capital spending program, the ability to recover these investments timely and our ability to access the capital markets to satisfy our financing needs are the primary drivers that affect our financial performance.

During the nine months ended June 30, 2024, we recorded net income of $908.9 million, or $6.00 per diluted share, compared to net income of $767.3 million, or $5.33 per diluted share for the nine months ended June 30, 2023.

The 18 percent year-over-year increase in net income largely reflects positive rate outcomes driven by safety and reliability spending and lower bad debt expense. Additionally, our fiscal 2024 year to date results were favorably impacted by $17.9 million as a result of legislation that became effective during the first quarter of fiscal 2024 to reduce property tax expenses in Texas. These increases were partially offset by increased depreciation expense and higher interest expense.

During the nine months ended June 30, 2024, we implemented, or received approval to implement, ratemaking regulatory actions which resulted in an increase in annual operating income of $340.6 million. Additionally, as of June 30, 2024, we had ratemaking efforts in progress seeking a total increase in annual operating income of $176.5 million.

Capital expenditures for the nine months ended June 30, 2024 were $2,129.1 million. Approximately 82 percent was invested to improve the safety and reliability of our distribution and transportation systems, with a significant portion of this investment incurred under regulatory mechanisms that reduce lag to six months or less.

During the nine months ended June 30, 2024, we completed approximately $2.0 billion of long-term debt and equity financing. As of June 30, 2024, our equity capitalization was 61.0 percent. As of June 30, 2024, we had approximately $4.3 billion in total liquidity, consisting of $674.6 million in cash and cash equivalents, $550.7 million in funds available through equity forward sales agreements and $3,094.4 million in undrawn capacity under our credit facilities.

The following discusses the results of operations for each of our operating segments.

Distribution Segment

The distribution segment is comprised of our regulated natural gas distribution and related sales operations in eight states. The primary factors that impact the results of this segment are our ability to earn our authorized rates of return, competitive factors in the energy industry and economic conditions in our service areas.

Our ability to earn our authorized rates of return is based primarily on our ability to improve the rate design in our various ratemaking jurisdictions to minimize regulatory lag and, ultimately, separate the recovery of our approved rates from customer usage patterns. Improving rate design is a long-term process and is further complicated by the fact that we operate in multiple rate jurisdictions. Under our current rate design, approximately 70 percent of our distribution segment revenues are earned through the first six months of the fiscal year. Additionally, we currently recover approximately 50 percent of our distribution

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segment revenue, excluding gas costs, through the base customer charge, which partially separates the recovery of our approved rate from customer usage patterns.

Seasonal weather patterns can also affect our distribution operations. However, the effect of weather that is above or below normal is substantially offset through weather normalization adjustments, known as WNA, which have been approved by state regulatory commissions for approximately 96 percent of our residential and commercial revenues in the following states for the following time periods:

Kansas, West Texas	October — May
Tennessee	October — April
Kentucky, Mississippi, Mid-Tex	November — April
Louisiana	December — March
Virginia	January — December

Our distribution operations are also affected by the cost of natural gas. We are generally able to pass the cost of gas through to our customers without markup under purchased gas cost adjustment mechanisms; therefore, increases in the cost of gas are offset by a corresponding increase in revenues. Revenues in our Texas and Mississippi service areas include franchise fees and gross receipts taxes, which are calculated as a percentage of revenue (inclusive of gas costs). Therefore, the amount of these taxes included in revenues is influenced by the cost of gas and the level of gas sales volumes. We record the associated tax expense as a component of taxes, other than income.

The cost of gas typically does not have a direct impact on our operating income because these costs are recovered through our purchased gas cost adjustment mechanisms. However, higher gas costs may adversely impact our accounts receivable collections, resulting in higher bad debt expense. This risk is currently mitigated by rate design that allows us to collect from our customers the gas cost portion of our bad debt expense on approximately 88 percent of our residential and commercial revenues. Additionally, higher gas costs may require us to increase borrowings under our credit facilities, resulting in higher interest expense. Finally, higher gas costs, as well as competitive factors in the industry and general economic conditions may cause customers to conserve or, in the case of industrial consumers, to use alternative energy sources.

Three Months Ended June 30, 2024 compared with Three Months Ended June 30, 2023

Financial and operational highlights for our distribution segment for the three months ended June 30, 2024 and 2023 are presented below.

	Three Months Ended June 30
	2024		2023		Change
	(In thousands, unless otherwise noted)
Operating revenues	$	633,211	$	616,067	$	17,144
Purchased gas cost	179,510		206,048		(26,538)
Operating expenses	370,579		338,340		32,239
Operating income	83,122		71,679		11,443
Other non-operating income	11,452		6,695		4,757
Interest charges	22,550		16,146		6,404
Income before income taxes	72,024		62,228		9,796
Income tax expense	6,175		2,589		3,586
Net income	$	65,849	$	59,639	$	6,210
Consolidated distribution sales volumes — MMcf	37,863		41,550		(3,687)
Consolidated distribution transportation volumes — MMcf	34,562		33,722		840
Total consolidated distribution throughput — MMcf	72,425		75,272		(2,847)
Consolidated distribution average cost of gas per Mcf sold	$	4.74	$	4.96	$	(0.22)

Operating income for our distribution segment increased 16.0 percent. Key drivers for the change in operating income include:

•a $30.6 million increase in rate adjustments, primarily in our Mid-Tex Division.

•a $5.3 million increase related to residential customer growth, primarily in our Mid-Tex Division, and increased industrial load.

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•a $6.8 million decrease in refunds of excess deferred taxes to customers, which is partially offset in income tax expense.

Partially offset by:

•a $15.1 million increase in depreciation expense associated with increased capital investments.

•a $14.8 million increase in operation and maintenance expense primarily due to higher employee-related and other administrative costs.

Interest charges increased $6.4 million primarily due to the issuance of long-term debt during fiscal 2024.

The following table shows our operating income by distribution division, in order of total rate base, for the three months ended June 30, 2024 and 2023. The presentation of our distribution operating income is included for financial reporting purposes and may not be appropriate for ratemaking purposes.

	Three Months Ended June 30
	2024		2023		Change
	(In thousands)
Mid-Tex	$	42,820	$	37,608	$	5,212
Kentucky/Mid-States	13,615		12,811		804
Louisiana	14,167		10,415		3,752
West Texas	4,186		2,811		1,375
Mississippi	6,309		7,131		(822)
Colorado-Kansas	2,925		3,014		(89)
Other	(900)		(2,111)		1,211
Total	$	83,122	$	71,679	$	11,443

Nine Months Ended June 30, 2024 compared with Nine Months Ended June 30, 2023

Financial and operational highlights for our distribution segment for the nine months ended June 30, 2024 and 2023 are presented below.

	Nine Months Ended June 30
	2024		2023		Change
	(In thousands, unless otherwise noted)
Operating revenues	$	3,327,730	$	3,556,703	$	(228,973)
Purchased gas cost	1,464,815		1,896,986		(432,171)
Operating expenses	1,073,122		1,020,958		52,164
Operating income	789,793		638,759		151,034
Other non-operating income	26,650		20,934		5,716
Interest charges	93,915		60,405		33,510
Income before income taxes	722,528		599,288		123,240
Income tax expense	92,550		56,707		35,843
Net income	$	629,978	$	542,581	$	87,397
Consolidated distribution sales volumes — MMcf	252,116		259,359		(7,243)
Consolidated distribution transportation volumes — MMcf	119,755		117,699		2,056
Total consolidated distribution throughput — MMcf	371,871		377,058		(5,187)
Consolidated distribution average cost of gas per Mcf sold	$	5.81	$	7.31	$	(1.50)

Operating income for our distribution segment increased 23.6 percent. Key drivers for the change in operating income include:

•a $185.8 million increase in rate adjustments, primarily in our Mid-Tex Division.

•a $17.8 million increase related to residential customer growth, primarily in our Mid-Tex Division, and increased industrial load.

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•an $11.6 million decrease in bad debt expense, as discussed in Note 6 to the condensed consolidated financial statements.

•an $8.5 million increase due to lower line locate spending and timing of other activities.

•a $0.9 million decrease in property taxes, which is inclusive of a $13.4 million decrease related to the Texas property tax legislation discussed above.

Partially offset by:

•a $44.2 million increase in depreciation expense associated with increased capital investments.

•a $10.7 million increase in refunds of excess deferred taxes to customers, which is partially offset in income tax expense.

•a $12.4 million increase in employee-related costs.

•a $17.2 million increase in other operation and maintenance expense, including higher insurance premiums and software maintenance costs.

Interest charges increased $33.5 million primarily due to the issuance of long-term debt during fiscal 2024. The increase in interest charges is also due to the amortization of the Texas regulatory asset that is discussed in Note 3 to the condensed consolidated financial statements. However, this increase is offset by a corresponding increase in revenue resulting in no impact to net income.

The following table shows our operating income by distribution division, in order of total rate base, for the nine months ended June 30, 2024 and 2023. The presentation of our distribution operating income is included for financial reporting purposes and may not be appropriate for ratemaking purposes.

	Nine Months Ended June 30
	2024		2023		Change
	(In thousands)
Mid-Tex	$	424,027	$	315,140	$	108,887
Kentucky/Mid-States	83,049		78,299		4,750
Louisiana	77,676		69,092		8,584
West Texas	70,096		59,560		10,536
Mississippi	97,610		76,736		20,874
Colorado-Kansas	44,389		41,833		2,556
Other	(7,054)		(1,901)		(5,153)
Total	$	789,793	$	638,759	$	151,034

Recent Ratemaking Developments

The amounts described in the following sections represent the operating income that was requested or received in each rate filing, which may not necessarily reflect the stated amount referenced in the final order, as certain operating costs may have changed as a result of a commission’s or other governmental authority’s final ruling. During the first nine months of fiscal 2024, we implemented, or received approval to implement, regulatory proceedings, resulting in a $231.1 million increase in annual operating income as summarized below. Our ratemaking outcomes include the refund (return) of excess deferred income taxes (EDIT) resulting from previously enacted tax reform legislation and do not reflect the true economic benefit of the outcomes because they do not include the corresponding income tax benefit. Excluding these amounts, our total rate outcomes for ratemaking activities for the nine months ended June 30, 2024 were $210.7 million.

Rate Action	Annual Increase (Decrease) in Operating Income		EDIT Impact		Annual Increase (Decrease) in Operating Income Excluding EDIT
	(In thousands)
Annual formula rate mechanisms	$	229,678	$	(19,529)	$	210,149
Rate case filings	2,434		(939)		1,495
Other rate activity	(971)		—		(971)
	$	231,141	$	(20,468)	$	210,673

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The following ratemaking efforts seeking $176.5 million in increased annual operating income were in progress as of June 30, 2024:

Division	Rate Action	Jurisdiction	Operating Income Requested
			(In thousands)
Kentucky/Mid-States	Infrastructure Mechanism	Virginia	$	748
Louisiana	Formula Rate Mechanism	Louisiana (1)	35,645
Mid-Tex	Formula Rate Mechanism	Mid-Tex Cities	133,414
West Texas	Formula Rate Mechanism	West Texas Cities	6,709
			$	176,516

(1)    The Company implemented the requested amount with rates effective July 1, 2024 and anticipates receiving final commission approval during the fourth quarter of fiscal 2024.

Annual Formula Rate Mechanisms

As an instrument to reduce regulatory lag, formula rate mechanisms allow us to refresh our rates on an annual basis without filing a formal rate case. However, these filings still involve discovery by the appropriate regulatory authorities prior to the final determination of rates under these mechanisms. We currently have formula rate mechanisms in our Louisiana, Mississippi and Tennessee operations and in substantially all the service areas in our Texas divisions. Additionally, we have specific infrastructure programs in substantially all of our distribution divisions with tariffs in place to permit the investment associated with these programs to have their surcharge rate adjusted annually to recover approved capital costs incurred in a prior test-year period. The following table summarizes our annual formula rate mechanisms by state:

	Annual Formula Rate Mechanisms
State	Infrastructure Programs	Formula Rate Mechanisms
Colorado	System Safety and Integrity Rider (SSIR)	—
Kansas	Gas System Reliability Surcharge (GSRS), System Integrity Program (SIP)	—
Kentucky	Pipeline Replacement Program (PRP)	—
Louisiana	(1)	Rate Stabilization Clause (RSC)
Mississippi	System Integrity Rider (SIR)	Stable Rate Filing (SRF)
Tennessee	(1)	Annual Rate Mechanism (ARM)
Texas	Gas Reliability Infrastructure Program (GRIP), (1)	Dallas Annual Rate Review (DARR), Rate Review Mechanism (RRM)
Virginia	Steps to Advance Virginia Energy (SAVE)	—

(1)    Infrastructure mechanisms in Texas, Louisiana and Tennessee allow for the deferral of all expenses associated with capital expenditures incurred pursuant to these rules, which primarily consists of interest, depreciation and other taxes (Texas only), until the next rate proceeding (rate case or annual rate filing), at which time investment and costs would be recoverable through base rates.

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The following annual formula rate mechanisms were approved during the nine months ended June 30, 2024:

Division	Jurisdiction	Test Year Ended	Increase in Annual Operating Income		EDIT Impact		Increase in Annual Operating Income Excluding EDIT		Effective Date
			(In thousands)
2024 Filings:
Mid-Tex	ATM Cities	12/31/2023	$	17,104	$	—	$	17,104	06/07/2024
West Texas	Amarillo, Lubbock, Dalhart and Channing	12/31/2023	7,344		—		7,344		06/07/2024
Kentucky/Mid-States	Tennessee ARM	09/30/2023	18,570		(4,348)		14,222		06/01/2024
Mid-Tex	DARR	09/30/2023	37,809		(14,782)		23,027		06/01/2024
West Texas	Triangle	12/31/2023	1,300		—		1,300		06/01/2024
West Texas	Environs	12/31/2023	1,379		—		1,379		06/01/2024
Mid-Tex	Environs	12/31/2023	8,529		—		8,529		06/01/2024
Colorado-Kansas	Kansas SIP	12/31/2023	708		—		708		04/01/2024
Colorado-Kansas	Colorado SSIR	12/31/2024	2,017		—		2,017		01/01/2024
Mississippi	Mississippi - SIR	10/31/2024	10,969		—		10,969		12/01/2023
Mississippi	Mississippi - SRF	10/31/2024	11,539		(472)		11,067		12/01/2023
Colorado-Kansas	Kansas GSRS	09/30/2023	1,752		—		1,752		11/02/2023
Kentucky/Mid-States	Kentucky PRP	09/30/2024	2,906		—		2,906		10/01/2023
Mid-Tex	Mid-Tex Cities RRM	12/31/2022	98,585		185		98,770		10/01/2023
West Texas	West Texas Cities RRM	12/31/2022	8,594		(112)		8,482		10/01/2023
Kentucky/Mid-States	Virginia - SAVE	09/30/2024	573		—		573		10/01/2023
Total 2024 Filings			$	229,678	$	(19,529)	$	210,149

Rate Case Filings

A rate case is a formal request from Atmos Energy to a regulatory authority to increase rates that are charged to our customers. Rate cases may also be initiated when the regulatory authorities request us to justify our rates. This process is referred to as a “show cause” action. Adequate rates are intended to provide for recovery of the Company’s costs as well as a fair rate of return and ensure that we continue to deliver reliable, reasonably priced natural gas service safely to our customers. The following table summarizes the rate cases completed in our distribution segment during the nine months ended June 30, 2024.

Division	State	Increase in Annual Operating Income		EDIT Impact		Increase in Annual Operating Income Excluding EDIT		Effective Date
		(In thousands)
2024 Rate Case Filings:
Kentucky/Mid-States	Virginia	$	2,434	$	(939)	$	1,495	12/01/2023
Total 2024 Rate Case Filings		$	2,434	$	(939)	$	1,495

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Other Ratemaking Activity

The following table summarizes other ratemaking activity during the nine months ended June 30, 2024.

Division	Jurisdiction	Rate Activity	Change in Annual Operating Income		Effective Date
			(In thousands)
2024 Other Rate Activity:
Colorado-Kansas	Kansas	Ad Valorem (1)	$	(971)	02/01/2024
Total 2024 Other Rate Activity			$	(971)

(1)    The Ad Valorem filing relates to property taxes that are either over or undercollected compared to the amount included in our Kansas service area's base rate.

Pipeline and Storage Segment

Our pipeline and storage segment consists of the regulated pipeline and storage operations of our Atmos Pipeline–Texas Division (APT) and our natural gas transmission operations in Louisiana. APT is one of the largest intrastate pipeline operations in Texas with a heavy concentration in the established natural gas producing areas of central, northern and eastern Texas, extending into or near the major producing areas of the Barnett Shale, the Texas Gulf Coast and the Permian Basin of West Texas. APT provides transportation and storage services to our Mid-Tex Division, other third-party local distribution companies, industrial and electric generation customers, as well as marketers and producers. Over 80 percent of this segment’s revenues are derived from these APT services. These revenues are subject to traditional ratemaking governed by the Texas Railroad Commission (RRC). As part of its pipeline operations, APT owns and operates five underground storage facilities in Texas.

Our natural gas transmission operations in Louisiana are comprised of a 21-mile pipeline located in the New Orleans, Louisiana area that is primarily used to aggregate gas supply for our distribution division in Louisiana under a long-term contract and, on a more limited basis, to third parties. The demand fee charged to our Louisiana distribution division for these services is subject to regulatory approval by the Louisiana Public Service Commission. We also manage two asset management plans, which have been approved by applicable state regulatory commissions. Generally, these asset management plans require us to share with our distribution customers a significant portion of the cost savings earned from these arrangements.

Our pipeline and storage segment is impacted by seasonal weather patterns, competitive factors in the energy industry and economic conditions in our Texas and Louisiana service areas. Natural gas prices do not directly impact the results of this segment as revenues are derived from the transportation and storage of natural gas. However, natural gas prices and demand for natural gas could influence the level of drilling activity in the supply areas that we serve, which may influence the level of throughput we may be able to transport on our pipelines. Further, natural gas price differences between the various hubs that we serve in Texas could influence the volumes of gas transported for shippers through our Texas pipeline system and rates for such transportation.

The results of APT are also significantly impacted by the natural gas requirements of its local distribution company customers. Additionally, its operations may be impacted by the timing of when costs and expenses are incurred and when these costs and expenses are recovered through its tariffs.

APT annually uses GRIP to recover capital costs incurred in the prior calendar year. On February 27, 2024, APT made a GRIP filing that covered changes in net property, plant and equipment investments from January 1, 2023 through December 31, 2023 with a requested increase in operating income of $82.4 million. On May 14, 2024, the RRC approved the Company's GRIP filing.

GRIP also requires a utility to file a statement of intent at least once every five years to review its costs and expenses, including capital costs filed for recovery under GRIP. On May 19, 2023, APT filed a statement of intent seeking $107.4 million in additional annual operating income. On December 13, 2023, the RRC approved the settlement agreement between APT and the intervening parties for an increase in annual operating income of $27.0 million, exclusive of the impact of the cessation of $36.9 million in excess deferred income tax refunds, which are substantially offset by a corresponding increase in income taxes. New rates were implemented effective December 13, 2023.

As part of our statement of intent settlement in December 2023, APT is now allowed to file an annual System Safety and Integrity Rider (Rider SSI) compliance filing that allows APT to recover certain system safety and integrity costs incurred each year. Costs above the benchmark are deferred onto the balance sheet as incurred. The revenue and expense are recognized after review and approval by the RRC which results in no impact to operating income. On June 14, 2024, APT made its first Rider

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SSI filing that covered certain costs from January 1, 2023 through March 31, 2024 with a requested increase in operating revenue of $18.7 million.

The demand fee our Louisiana natural gas transmission pipeline charges to our Louisiana distribution division increases five percent annually and has been approved by the Louisiana Public Service Commission until September 30, 2027.

Three Months Ended June 30, 2024 compared with Three Months Ended June 30, 2023

Financial and operational highlights for our pipeline and storage segment for the three months ended June 30, 2024 and 2023 are presented below.

	Three Months Ended June 30
	2024		2023		Change
	(In thousands, unless otherwise noted)
Mid-Tex / Affiliate transportation revenue	$	189,069	$	164,587	$	24,482
Third-party transportation revenue	55,420		39,800		15,620
Other revenue	6,191		3,838		2,353
Total operating revenues	250,680		208,225		42,455
Total purchased gas cost	(19)		(194)		175
Operating expenses	113,554		110,845		2,709
Operating income	137,145		97,574		39,571
Other non-operating income	8,446		9,475		(1,029)
Interest charges	18,610		15,188		3,422
Income before income taxes	126,981		91,861		35,120
Income tax expense	27,266		13,693		13,573
Net income	$	99,715	$	78,168	$	21,547
Gross pipeline transportation volumes — MMcf	193,766		205,046		(11,280)
Consolidated pipeline transportation volumes — MMcf	162,334		172,266		(9,932)

Operating income for our pipeline and storage segment increased 40.6 percent. Key drivers for the change in operating income include:

•a $16.0 million increase primarily due to rate adjustments from the GRIP filing approved in May 2024 and the rate case approved in December 2023.

•an $11.0 million increase in APT's through-system activities primarily associated with increased spreads.

•a $9.3 million decrease in refunds of excess deferred taxes to customers, which is substantially offset in income tax expense.

•a $4.1 million increase due to higher capacity contracted by tariff-based customers due to their increased peak day demand.

Nine Months Ended June 30, 2024 compared with Nine Months Ended June 30, 2023

Financial and operational highlights for our pipeline and storage segment for the nine months ended June 30, 2024 and 2023 are presented below.

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	Nine Months Ended June 30
	2024		2023		Change
	(In thousands, unless otherwise noted)
Mid-Tex / Affiliate transportation revenue	$	526,200	$	457,592	$	68,608
Third-party transportation revenue	147,926		114,747		33,179
Other revenue	11,210		6,939		4,271
Total operating revenues	685,336		579,278		106,058
Total purchased gas cost	825		(431)		1,256
Operating expenses	303,942		305,391		(1,449)
Operating income	380,569		274,318		106,251
Other non-operating income	27,821		33,833		(6,012)
Interest charges	54,562		45,059		9,503
Income before income taxes	353,828		263,092		90,736
Income tax expense	74,927		38,335		36,592
Net income	$	278,901	$	224,757	$	54,144
Gross pipeline transportation volumes — MMcf	622,747		613,957		8,790
Consolidated pipeline transportation volumes — MMcf	452,770		440,015		12,755

Operating income for our pipeline and storage segment increased 38.7 percent. Key drivers for the change in operating income include:

•a $52.4 million increase primarily due to rate adjustments from the GRIP filings approved in May 2023 and 2024, and the rate case approved in December 2023.

•a $15.3 million increase primarily due to timing of pipeline inspection spending.

•an $18.5 million net increase in APT's through-system activities primarily associated with increased spreads.

•an $18.6 million decrease in refunds of excess deferred taxes to customers, which is substantially offset in income tax expense.

•a $10.4 million increase due to higher capacity contracted by tariff-based customers due to their increased peak day demand.

•a $2.8 million decrease in property taxes, which is inclusive of a $4.5 million decrease related to the Texas property tax legislation discussed above.

Partially offset by:

•a $7.3 million increase in depreciation expense associated with increased capital investments.

Interest charges increased $9.5 million primarily due to the issuance of long-term debt during fiscal 2024.

Liquidity and Capital Resources

The liquidity required to fund our working capital, capital expenditures and other cash needs is provided from a combination of internally generated cash flows and external debt and equity financing. Additionally, we have a $1.5 billion commercial paper program and four committed revolving credit facilities with $3.1 billion in total availability from third-party lenders. The commercial paper program and credit facilities provide cost-effective, short-term financing until it can be replaced with a balance of long-term debt and equity financing that achieves the Company's desired capital structure. Additionally, we have various uncommitted trade credit lines with our gas suppliers that we utilize to purchase natural gas on a monthly basis.

We have a shelf registration statement on file with the Securities and Exchange Commission (SEC) that allows us to issue up to $5.0 billion in common stock and/or debt securities, which expires March 31, 2026. As of June 30, 2024, $1.8 billion of securities were available for issuance under this shelf registration statement.

On May 8, 2024, we filed a prospectus supplement under the shelf registration statement relating to an at-the-market (ATM) equity sales program under which we may issue and sell shares of our common stock up to an aggregate offering price of $1.0 billion through March 31, 2026 (including shares of common stock that may be sold pursuant to forward sale agreements entered into in connection with the ATM equity sales program), which expires March 31, 2026. This ATM equity sales program replaced our previous ATM equity sales program, filed on March 31, 2023. As of June 30, 2024, $845.7 million of equity was available for issuance under our existing ATM equity sales program. Additionally, as of June 30, 2024, we had

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$550.7 million in available proceeds from outstanding forward sale agreements. Additional details are summarized in Note 8 to the condensed consolidated financial statements.

The liquidity provided by these sources is expected to be sufficient to fund the Company's working capital needs and capital expenditure program for the remainder of fiscal year 2024. Additionally, we expect to continue to be able to obtain financing upon reasonable terms as necessary.

The following table summarizes our existing forward starting interest rate swaps as of June 30, 2024.

Planned Debt Issuance Date	Amount Hedged		Effective Interest Rate
	(In thousands)
Fiscal 2025	$	600,000	1.75	%
Fiscal 2026	300,000		2.16	%
	$	900,000

The following table presents our capitalization inclusive of short-term debt and the current portion of long-term debt as of June 30, 2024, September 30, 2023 and June 30, 2023:

	June 30, 2024				September 30, 2023				June 30, 2023
	(In thousands, except percentages)
Short-term debt	$	—	—	%	$	241,933	1.4	%	$	—	—	%
Long-term debt (1)	7,786,816		39.0	%	6,555,701		37.1	%	6,555,158		38.2	%
Shareholders’ equity	12,183,076		61.0	%	10,870,064		61.5	%	10,602,381		61.8	%
Total	$	19,969,892	100.0	%	$	17,667,698	100.0	%	$	17,157,539	100.0	%

(1)     Inclusive of our finance leases, but exclusive of AEK's securitized long-term debt.

Cash Flows

Our internally generated funds may change in the future due to a number of factors, some of which we cannot control. These factors include regulatory changes, the price for our services, demand for such products and services, margin requirements resulting from significant changes in commodity prices, operational risks and other factors.

Cash flows from operating, investing and financing activities for the nine months ended June 30, 2024 and 2023 are presented below.

	Nine Months Ended June 30
	2024		2023		Change
	(In thousands)
Total cash provided by (used in)
Operating activities	$	1,403,064	$	3,221,508	$	(1,818,444)
Investing activities	(2,119,094)		(2,077,319)		(41,775)
Financing activities	1,376,044		(1,137,630)		2,513,674
Change in cash and cash equivalents and restricted cash and cash equivalents	660,014		6,559		653,455
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period	19,248		51,554		(32,306)
Cash and cash equivalents and restricted cash and cash equivalents at end of period	$	679,262	$	58,113	$	621,149

Cash flows from operating activities

For the nine months ended June 30, 2024, we generated cash flow from operating activities of $1,403.1 million compared with $3,221.5 million for the nine months ended June 30, 2023. Operating cash flow decreased $1,818.4 million primarily due to the receipt of $2.02 billion in the second quarter of fiscal 2023 related to Texas securitization activities.

Cash flows from investing activities

Our capital expenditures are primarily used to improve the safety and reliability of our distribution and transmission system through pipeline replacement and system modernization and to enhance and expand our system to meet customer needs.

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Over the last three fiscal years, approximately 87 percent of our capital spending has been committed to improving the safety and reliability of our system.

For the nine months ended June 30, 2024, cash used for investing activities was $2,119.1 million compared to $2,077.3 million for the nine months ended June 30, 2023. Capital spending in our distribution segment increased $278.1 million, primarily as a result of increased system modernization and customer growth spending. Capital spending in our pipeline and storage segment decreased $232.5 million primarily due to timing of spending for pipeline system safety and reliability in Texas.

Cash flows from financing activities

For the nine months ended June 30, 2024, our financing activities provided $1,376.0 million of cash compared with $1,137.6 million of cash used by financing activities in the prior-year period.

In the nine months ended June 30, 2024, we received approximately $2.0 billion in net proceeds from the issuance of long-term debt and equity. We completed a public offering of $500 million of 6.20% senior notes due October 2053 and $400 million of 5.90% senior notes due October 2033, and received net proceeds from the offering, after the underwriting discount and offering expenses, of $889.4 million. We also completed a public offering of $325 million of 5.90% senior notes due October 2033, and received net proceeds from the offering, after the underwriting discount and offering expenses, of $339.7 million. Additionally, during the nine months ended June 30, 2024, we settled 6,401,469 shares that had been sold on a forward basis for net proceeds of $750.0 million. The net proceeds were used primarily to support capital spending and for other general corporate purposes. Cash dividends increased due to an 8.8 percent increase in our dividend rate and an increase in shares outstanding.

In the nine months ended June 30, 2023, we repaid $2.2 billion in long-term debt, and we received approximately $1.5 billion in net proceeds from the issuance of long-term debt and equity. We completed a public offering of $500 million of 5.75% senior notes due October 2052 and $300 million of 5.45% senior notes due October 2032, and received net proceeds from the offering, after the underwriting discount and offering expenses, of $789.4 million. Additionally, during the nine months ended June 30, 2023, we settled 6,116,848 shares that had been sold on a forward basis for net proceeds of $671.6 million. The net proceeds were used primarily to support capital spending and for other general corporate purposes. Cash dividends increased due to an 8.8 percent increase in our dividend rate and an increase in shares outstanding. Finally, AEK issued $95 million in securitized long-term debt.

The following table summarizes our share issuances for the nine months ended June 30, 2024 and 2023:

	Nine Months Ended June 30
	2024	2023
Shares issued:
Direct Stock Purchase Plan	46,927	49,160
1998 Long-Term Incentive Plan	235,473	189,267
Retirement Savings Plan and Trust	52,372	52,665
Equity Issuance	6,401,469	6,116,848
Total shares issued	6,736,241	6,407,940

Credit Ratings

Our credit ratings directly affect our ability to obtain short-term and long-term financing, in addition to the cost of such financing. In determining our credit ratings, the rating agencies consider a number of quantitative factors, including but not limited to, debt to total capitalization, operating cash flow relative to outstanding debt, operating cash flow coverage of interest and pension liabilities. In addition, the rating agencies consider qualitative factors such as consistency of our earnings over time, the quality of our management and business strategy, the risks associated with our businesses and the regulatory structures that govern our rates in the states where we operate.

Our debt is rated by two rating agencies: Standard & Poor’s Corporation (S&P) and Moody’s Investors Service (Moody’s). On April 1, 2024, Moody's reaffirmed its long-term and short-term credit ratings and placed our ratings under negative outlook. Currently, our outlook and debt ratings, which are all considered investment grade, are as follows:

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	S&P	Moody’s
Senior unsecured long-term debt	A-	A1
Short-term debt	A-2	P-1
Outlook	Stable	Negative

A significant degradation in our operating performance or a significant reduction in our liquidity caused by more limited access to the private and public credit markets as a result of deteriorating global or national financial and credit conditions could trigger a negative change in our ratings outlook or even a reduction in our credit ratings by the two credit rating agencies. This would mean more limited access to the private and public credit markets and an increase in the costs of such borrowings.

A credit rating is not a recommendation to buy, sell or hold securities. The highest investment grade credit rating is AAA for S&P and Aaa for Moody’s. The lowest investment grade credit rating is BBB- for S&P and Baa3 for Moody’s. Our credit ratings may be revised or withdrawn at any time by the rating agencies, and each rating should be evaluated independently of any other rating. There can be no assurance that a rating will remain in effect for any given period of time or that a rating will not be lowered, or withdrawn entirely, by a rating agency if, in its judgment, circumstances so warrant.

Debt Covenants

We were in compliance with all of our debt covenants as of June 30, 2024. Our debt covenants are described in greater detail in Note 7 to the condensed consolidated financial statements.

Contractual Obligations and Commercial Commitments

Except as noted in Note 11 to the condensed consolidated financial statements, there were no significant changes in our contractual obligations and commercial commitments during the nine months ended June 30, 2024.

Risk Management Activities

In our distribution and pipeline and storage segments, we use a combination of physical storage, fixed physical contracts and fixed financial contracts to reduce our exposure to unusually large winter-period gas price increases. Additionally, we manage interest rate risk by periodically entering into financial instruments to effectively fix the Treasury yield component of the interest cost associated with anticipated financings.

The following table shows the components of the change in fair value of our financial instruments for the three and nine months ended June 30, 2024 and 2023:

	Three Months Ended June 30				Nine Months Ended June 30
	2024		2023		2024		2023
	(In thousands)
Fair value of contracts at beginning of period	$	351,261	$	335,990	$	370,256	$	377,862
Contracts realized/settled	(131)		(294)		(34,234)		(3,161)
Fair value of new contracts	1,880		3,129		2,265		3,091
Other changes in value	22,233		56,896		36,956		17,929
Fair value of contracts at end of period	375,243		395,721		375,243		395,721
Netting of cash collateral	—		—		—		—
Cash collateral and fair value of contracts at period end	$	375,243	$	395,721	$	375,243	$	395,721

The fair value of our financial instruments at June 30, 2024 is presented below by time period and fair value source:

	Fair Value of Contracts at June 30, 2024
	Maturity in Years
Source of Fair Value	Less Than 1		1-3		4-5		Greater Than 5		Total Fair Value
	(In thousands)
Prices actively quoted	$	269,972	$	105,271	$	—	$	—	$	375,243
Prices based on models and other valuation methods	—		—		—		—		—
Total Fair Value	$	269,972	$	105,271	$	—	$	—	$	375,243

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OPERATING STATISTICS AND OTHER INFORMATION

The following tables present certain operating statistics for our distribution and pipeline and storage segments for the three and nine months ended June 30, 2024 and 2023.

Distribution Sales and Statistical Data

	Three Months Ended June 30		Nine Months Ended June 30
	2024	2023	2024	2023
METERS IN SERVICE, end of period
Residential	3,096,038	3,057,074	3,096,038	3,057,074
Commercial	252,494	253,497	252,494	253,497
Industrial	1,491	1,491	1,491	1,491
Public authority and other	7,960	8,090	7,960	8,090
Total meters	3,357,983	3,320,152	3,357,983	3,320,152
INVENTORY STORAGE BALANCE — Bcf	61.2	59.0	61.2	59.0
SALES VOLUMES — MMcf (1)
Gas sales volumes
Residential	14,940	17,495	140,953	144,316
Commercial	15,299	16,095	84,459	85,488
Industrial	6,585	6,869	21,124	23,859
Public authority and other	1,039	1,091	5,580	5,696
Total gas sales volumes	37,863	41,550	252,116	259,359
Transportation volumes	36,471	35,798	125,439	123,643
Total throughput	74,334	77,348	377,555	383,002

Pipeline and Storage Operations Sales and Statistical Data

	Three Months Ended June 30		Nine Months Ended June 30
	2024	2023	2024	2023
CUSTOMERS, end of period
Industrial	94	95	94	95
Other	194	197	194	197
Total	288	292	288	292
INVENTORY STORAGE BALANCE — Bcf	1.5	1.0	1.5	1.0
PIPELINE TRANSPORTATION VOLUMES — MMcf (1)	193,766	205,046	622,747	613,957

Note to preceding tables:

(1)Sales and transportation volumes reflect segment operations, including intercompany sales and transportation amounts.

RECENT ACCOUNTING DEVELOPMENTS

Recent accounting developments, if any, and their impact on our financial position, results of operations and cash flows are described in Note 2 to the condensed consolidated financial statements.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Information regarding our quantitative and qualitative disclosures about market risk are disclosed in Item 7A in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. During the nine months ended June 30, 2024, there were no material changes in our quantitative and qualitative disclosures about market risk.

Item 4. Controls and Procedures

Management’s Evaluation of Disclosure Controls and Procedures

We carried out an evaluation, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, of the effectiveness of the Company’s disclosure controls and procedures, as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (Exchange Act). Based on this evaluation, the Company’s principal executive officer and principal financial officer have concluded that the Company’s disclosure controls and procedures were effective as of June 30, 2024 to provide reasonable assurance that information required to be disclosed by us, including our consolidated entities, in the reports that we file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified by the SEC’s rules and forms, including a reasonable level of assurance that such information is accumulated and communicated to our management, including our principal executive and principal financial officers, as appropriate to allow timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting

    We did not make any changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the third quarter of the fiscal year ended September 30, 2024 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

During the nine months ended June 30, 2024, except as noted in Note 11 to the condensed consolidated financial statements, there were no material changes in the status of the litigation and other matters that were disclosed in Note 14 to the consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended September 30, 2023. We continue to believe that the final outcome of such litigation and other matters or claims will not have a material adverse effect on our financial condition, results of operations or cash flows.

Item 1A. Risk Factors

There were no material changes from the risk factors disclosed under the heading “Risk Factors” in Item 1A in the Annual Report on Form 10-K for the year ended September 30, 2023.

Item 5. Other Information

During the three months ended June 30, 2024, no director or officer of the Company adopted or terminated a "Rule 10b5-1 trading arrangement" or "non-Rule 10b5-1 trading arrangement," as each term is defined in Item 408(a) of Regulation S-K.

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Item 6. Exhibits

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

Exhibit Number	Description	Page Number or Incorporation by Reference to
3.1	Restated Articles of Incorporation of Atmos Energy Corporation - Texas (As Amended Effective February 3, 2010)	Exhibit 3.1 to Form 10-Q dated March 31, 2010 (File No. 1-10042)
3.2	Restated Articles of Incorporation of Atmos Energy Corporation - Virginia (As Amended Effective February 3, 2010)	Exhibit 3.2 to Form 10-Q dated March 31, 2010 (File No. 1-10042)
3.3	Amended and Restated Bylaws of Atmos Energy Corporation (as of August 4, 2023)	Exhibit 3.1 to Form 8-K dated August 1, 2023 (File No. 1-10042)
4.1(a)	Officers' Certificate dated June 21, 2024	Exhibit 4.2 to Form 8-K dated June 21, 2024 (File No. 1-10042)
4.1(b)	Global Security for the 5.900% Senior Notes due 2033	Exhibit 4.3 to Form 8-K dated June 21, 2024 (File No. 1-10042)
10.1(a)	Equity Distribution Agreement, dated as of May 8, 2024, among Atmos Energy Corporation and the Managers and Forward Purchasers named in Schedule A thereto	Exhibit 1.1 to Form 8-K dated May 8, 2024 (File No. 1-10042)
10.1(b)	Form of Master Forward Sale Confirmation	Exhibit 1.2 to Form 8-K dated May 8, 2024 (File No. 1-10042)
15	Letter regarding unaudited interim financial information
31	Rule 13a-14(a)/15d-14(a) Certifications
32	Section 1350 Certifications*
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	Inline XBRL Taxonomy Extension Schema
101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase
101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase
101.LAB	Inline XBRL Taxonomy Extension Labels Linkbase
101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File - the cover page interactive data file does not appear in the interactive data file because its XBRL tags are embedded within the Inline XBRL document

* These certifications, which were made pursuant to 18 U.S.C. Section 1350 by the Company’s Chief Executive Officer and Chief Financial Officer, furnished as Exhibit 32 to this Quarterly Report on Form 10-Q, will not be deemed to be filed with the Commission or incorporated by reference into any filing by the Company under the Securities Act of 1933 or the Securities Exchange Act of 1934, except to the extent that the Company specifically incorporates such certifications by reference.

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SIGNATURE

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

ATMOS ENERGY CORPORATION

               (Registrant)

By: /s/    CHRISTOPHER T. FORSYTHE

Christopher T. Forsythe

Senior Vice President and Chief Financial Officer

(Duly authorized signatory)

Date: August 7, 2024

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