ATO 10-Q Quarterly Report Dec. 31, 2024 | Alphaminr
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ATO 10-Q Quarter ended Dec. 31, 2024

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ATMOS ENERGY CORP
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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 December 31, 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 Corp oration
(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 January 31, 2025.
Class Shares Outstanding
Common stock No Par Value 158,728,197


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
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

2

PART I. FINANCIAL INFORMATION
Item 1. Financial Statements

ATMOS ENERGY CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS
December 31,
2024 		September 30,
2024
(Unaudited)
(In thousands, except
share data)
ASSETS
Property, plant and equipment $ 26,675,943 $ 25,848,083
Less accumulated depreciation and amortization 3,713,900 3,643,716
Net property, plant and equipment 22,962,043 22,204,367
Current assets
Cash and cash equivalents 584,536 307,340
Restricted cash and cash equivalents 4,870 1,516
Cash and cash equivalents and restricted cash and cash equivalents 589,406 308,856
Accounts receivable, net
628,871 365,882
Gas stored underground 153,034 169,508
Other current assets
456,816 288,068
Total current assets 1,828,127 1,132,314
Securitized intangible asset, net (See Note 9)
80,580 82,844
Goodwill 731,257 731,257
Deferred charges and other assets
895,086 1,043,683
$ 26,497,093 $ 25,194,465
CAPITALIZATION AND LIABILITIES
Shareholders’ equity
Common stock, no par value (stated at $ 0.005 per share); 200,000,000 shares authorized; issued and outstanding: December 31, 2024 — 158,726,065 shares; September 30, 2024 — 155,258,845 shares
$ 794 $ 776
Additional paid-in capital 7,864,525 7,474,559
Accumulated other comprehensive income 482,138 465,715
Retained earnings 4,433,024 4,216,619
Shareholders’ equity 12,780,481 12,157,669
Long-term debt, net 8,413,374 7,783,646
Securitized long-term debt (See Note 9)
76,871 76,871
Total capitalization 21,270,726 20,018,186
Current liabilities
Accounts payable and accrued liabilities 453,045 445,397
Other current liabilities 701,915 750,620
Current maturities of long-term debt 11,681 1,651
Current maturities of securitized long-term debt (See Note 9)
8,207 8,207
Total current liabilities 1,174,848 1,205,875
Deferred income taxes 2,674,678 2,593,342
Regulatory excess deferred taxes 173,001 177,315
Regulatory cost of removal obligation 520,190 507,815
Deferred credits and other liabilities 683,650 691,932
$ 26,497,093 $ 25,194,465
See accompanying notes to condensed consolidated financial statements.
3

ATMOS ENERGY CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Three Months Ended December 31
2024 2023
(Unaudited)
(In thousands, except per
share data)
Operating revenues
Distribution segment $ 1,109,335 $ 1,105,338
Pipeline and storage segment 255,390 211,169
Intersegment eliminations ( 188,726 ) ( 158,040 )
Total operating revenues 1,175,999 1,158,467
Purchased gas cost
Distribution segment 422,570 496,662
Pipeline and storage segment ( 58 ) 4
Intersegment eliminations ( 188,464 ) ( 157,797 )
Total purchased gas cost 234,048 338,869
Operation and maintenance expense 207,044 166,345
Depreciation and amortization expense 180,533 164,608
Taxes, other than income 94,894 89,540
Operating income 459,480 399,105
Other non-operating income 24,634 17,886
Interest charges 52,925 51,875
Income before income taxes 431,189 365,116
Income tax expense 79,331 53,824
Net income
$ 351,858 $ 311,292
Basic net income per share $ 2.25 $ 2.08
Diluted net income per share $ 2.23 $ 2.08
Cash dividends per share $ 0.870 $ 0.805
Basic weighted average shares outstanding 156,301 149,796
Diluted weighted average shares outstanding 157,824 149,796
Net income $ 351,858 $ 311,292
Other comprehensive income (loss), net of tax
Net unrealized holding gains (losses) on available-for-sale securities, net of tax of $( 42 ) and $ 86
( 138 ) 296
Cash flow hedges:
Amortization and unrealized gains (losses) on interest rate agreements, net of tax of $ 3,492 and $( 14,519 )
16,561 ( 50,232 )
Total other comprehensive income (loss) 16,423 ( 49,936 )
Total comprehensive income $ 368,281 $ 261,356
See accompanying notes to condensed consolidated financial statements.



4

ATMOS ENERGY CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Three Months Ended December 31
2024 2023
(Unaudited)
(In thousands)
Cash Flows From Operating Activities
Net income $ 351,858 $ 311,292
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense 180,533 164,608
Deferred income taxes 71,107 44,108
Other ( 19,279 ) ( 16,839 )
Net assets / liabilities from risk management activities 1,891 5,589
Net change in other operating assets and liabilities ( 304,088 ) ( 263,478 )
Net cash provided by operating activities
282,022 245,280
Cash Flows From Investing Activities
Capital expenditures ( 891,191 ) ( 769,650 )
Debt and equity securities activities, net ( 490 ) ( 78 )
Other, net 2,740 5,353
Net cash used in investing activities
( 888,941 ) ( 764,375 )
Cash Flows From Financing Activities
Net decrease in short-term debt — ( 241,933 )
Net proceeds from equity issuances 379,490 254,022
Issuance of common stock through stock purchase and employee retirement plans 4,047 3,746
Proceeds from issuance of long-term debt 645,372 898,275
Cash dividends paid ( 135,453 ) ( 119,898 )
Debt issuance costs ( 5,987 ) ( 8,920 )
Net cash provided by financing activities
887,469 785,292
Net increase in cash and cash equivalents and restricted cash and cash equivalents
280,550 266,197
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period 308,856 19,248
Cash and cash equivalents and restricted cash and cash equivalents at end of period $ 589,406 $ 285,445
See accompanying notes to condensed consolidated financial statements.
5

ATMOS ENERGY CORPORATION
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
December 31, 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 December 31, 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, 2024. 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, 2024. Because of seasonal and other factors, the results of operations for the three-month period ended December 31, 2024 are not indicative of our results of operations for the full 2025 fiscal year, which ends September 30, 2025.
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, 2024.
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.
In November 2024, the FASB issued guidance that will require more detailed information about the types of expenses in commonly presented expense captions. The amendment is effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027. Early adoption is permitted. This amendment will be effective for our Form 10-K for fiscal 2028 and our Form 10-Q for the first quarter of fiscal 2029. We are currently evaluating the impact this may have on our financial statement disclosures.
6


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 December 31, 2024 and September 30, 2024 included the following:
December 31,
2024 		September 30,
2024
(In thousands)
Regulatory assets:
Pension and postretirement benefit costs $ 7,885 $ 11,243
Infrastructure mechanisms (1)
189,939 246,734
Winter Storm Uri incremental costs 8,834 10,373
Deferred gas costs 169,203 159,762
Regulatory excess deferred taxes (2)
50,941 51,380
Recoverable loss on reacquired debt 3,028 3,070
Deferred pipeline record collection costs 41,245 41,742
APT annual System Safety and Integrity Rider (3)
35,290 38,632
Other 16,151 16,454
$ 522,516 $ 579,390
Regulatory liabilities:
Regulatory excess deferred taxes (2)
$ 249,790 $ 257,001
Regulatory cost of removal obligation 615,371 607,032
Deferred gas costs 3,731 9,142
APT annual adjustment mechanism 76,418 73,119
Pension and postretirement benefit costs 241,816 247,250
Other 36,282 34,338
$ 1,223,408 $ 1,227,882
(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"), a Kansas legislative change enacted in fiscal 2020, and a Louisiana legislative change enacted in fiscal 2025. See Note 12 to the condensed consolidated financial statements for further information.
(3) In APT's general rate case settlement in December 2023, the RRC approved a new annual compliance filing that allows APT to recover certain system safety and integrity costs incurred each year. Costs above a specified benchmark are deferred onto the balance sheet as incurred. Once the filing is approved by the RRC, the revenue and expense are recognized over 12 months resulting in no impact to operating income.
We deferred $ 32.4 million in carrying costs incurred after September 1, 2022 associated with interim financing for gas costs incurred in February 2021 during Winter Storm Uri. During fiscal 2024, we recovered $ 22.0 million of this amount. During the first quarter of fiscal 2025, we have recovered $ 1.6 million of this amount. Of the remaining $ 8.8 million, $ 2.4 million has been recorded as a current asset in other current assets as of December 31, 2024 and $ 6.4 million has been recorded as a long-term asset in deferred charges and other assets as of December 31, 2024 as we anticipate recovering this amount in future regulatory proceedings.
7


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, 2024.
Income statements and capital expenditures for the three months ended December 31, 2024 and 2023 by segment are presented in the following tables:
Three Months Ended December 31, 2024
Distribution Pipeline and Storage Eliminations Consolidated
(In thousands)
Operating revenues from external parties $ 1,108,569 $ 67,430 $ — $ 1,175,999
Intersegment revenues 766 187,960 ( 188,726 ) —
Total operating revenues 1,109,335 255,390 ( 188,726 ) 1,175,999
Purchased gas cost
422,570 ( 58 ) ( 188,464 ) 234,048
Operation and maintenance expense 154,514 52,792 ( 262 ) 207,044
Depreciation and amortization expense 133,627 46,906 — 180,533
Taxes, other than income 82,576 12,318 — 94,894
Operating income 316,048 143,432 — 459,480
Other non-operating income 10,084 14,550 — 24,634
Interest charges 34,249 18,676 — 52,925
Income before income taxes
291,883 139,306 — 431,189
Income tax expense 51,670 27,661 — 79,331
Net income $ 240,213 $ 111,645 $ — $ 351,858
Capital expenditures $ 625,649 $ 265,542 $ — $ 891,191

8

Three Months Ended December 31, 2023
Distribution Pipeline and Storage Eliminations Consolidated
(In thousands)
Operating revenues from external parties $ 1,104,619 $ 53,848 $ — $ 1,158,467
Intersegment revenues 719 157,321 ( 158,040 ) —
Total operating revenues 1,105,338 211,169 ( 158,040 ) 1,158,467
Purchased gas cost
496,662 4 ( 157,797 ) 338,869
Operation and maintenance expense 127,615 38,973 ( 243 ) 166,345
Depreciation and amortization expense 119,685 44,923 — 164,608
Taxes, other than income 80,895 8,645 — 89,540
Operating income 280,481 118,624 — 399,105
Other non-operating income 5,839 12,047 — 17,886
Interest charges 34,581 17,294 — 51,875
Income before income taxes
251,739 113,377 — 365,116
Income tax expense 30,302 23,522 — 53,824
Net income $ 221,437 $ 89,855 $ — $ 311,292
Capital expenditures $ 539,158 $ 230,492 $ — $ 769,650

Balance sheet information at December 31, 2024 and September 30, 2024 by segment is presented in the following tables:
December 31, 2024
Distribution Pipeline and Storage Eliminations Consolidated
(In thousands)
Net property, plant and equipment $ 16,942,174 $ 6,019,869 $ — $ 22,962,043
Total assets $ 25,623,410 $ 6,341,439 $ ( 5,467,756 ) $ 26,497,093
September 30, 2024
Distribution Pipeline and Storage Eliminations Consolidated
(In thousands)
Net property, plant and equipment $ 16,372,659 $ 5,831,708 $ — $ 22,204,367
Total assets $ 24,328,877 $ 6,181,558 $ ( 5,315,970 ) $ 25,194,465

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 months ended December 31, 2024 and 2023 are calculated as follows:
Three Months Ended December 31
2024 2023
(In thousands, except per share amounts)
Basic Earnings Per Share
Net income $ 351,858 $ 311,292
Less: Income allocated to participating securities
159 186
Income available to common shareholders
$ 351,699 $ 311,106
Basic weighted average shares outstanding
156,301 149,796
Net income per share — Basic
$ 2.25 $ 2.08
Diluted Earnings Per Share
Income available to common shareholders $ 351,699 $ 311,106
Effect of dilutive shares
— —
Income available to common shareholders
$ 351,699 $ 311,106
Basic weighted average shares outstanding
156,301 149,796
Dilutive shares 1,523 —
Diluted weighted average shares outstanding
157,824 149,796
Net income per share — Diluted $ 2.23 $ 2.08

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, 2024. 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 months ended December 31, 2024 and 2023.
Three Months Ended December 31, 2024 Three Months Ended December 31, 2023
Distribution Pipeline and Storage Distribution Pipeline and Storage
(In thousands)
Gas sales revenues:
Residential $ 693,050 $ — $ 727,682 $ —
Commercial 266,054 — 277,253 —
Industrial 26,321 — 28,231 —
Public authority and other 12,881 — 14,584 —
Total gas sales revenues 998,306 — 1,047,750 —
Transportation revenues 36,727 266,029 33,767 215,305
Miscellaneous revenues 3,022 2,664 2,643 3,042
Revenues from contracts with customers 1,038,055 268,693 1,084,160 218,347
Alternative revenue program revenues 67,336 ( 13,303 ) 17,401 ( 7,178 )
Other revenues 3,944 — 3,777 —
Total operating revenues $ 1,109,335 $ 255,390 $ 1,105,338 $ 211,169
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. Other revenues includes AEK revenues (see Note 9 to the condensed consolidated financial statements) and other miscellaneous revenues.
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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, 2024. During the three months ended December 31, 2024, there were no material changes to this policy. Rollforwards of our allowance for uncollectible accounts for the three months ended December 31, 2024 and 2023 are presented in the table below. The allowance excludes the gas cost portion of customers’ bills for approximately 89 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 December 31, 2024
(In thousands)
Beginning balance, September 30, 2024 $ 37,056
Current period provisions 8,623
Write-offs charged against allowance ( 7,447 )
Recoveries of amounts previously written off 934
Ending balance, December 31, 2024
$ 39,166
Three Months Ended December 31, 2023
(In thousands)
Beginning balance, September 30, 2023 $ 40,840
Current period provisions 6,750
Write-offs charged against allowance ( 8,757 )
Recoveries of amounts previously written off 765
Mississippi recovery of uncollectible accounts ( 4,192 )
Ending balance, December 31, 2023
$ 35,406


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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, 2024. Other than as described below, there were no material changes in the terms of our debt instruments during the three months ended December 31, 2024.
Long-term debt at December 31, 2024 and September 30, 2024 consisted of the following:
December 31, 2024 September 30, 2024
(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 November 2033

725,000 725,000
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 November 2053
500,000 500,000
Unsecured 5.00 % Senior Notes, due December 2054
650,000 —
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 48,486 48,890
Total long-term debt 8,483,486 7,833,890
Less:
Original issue premium on unsecured senior notes and debentures ( 4,135 ) ( 9,071 )
Debt issuance cost 62,566 57,664
Current maturities of long-term debt 11,681 1,651
Total long-term debt, net $ 8,413,374 $ 7,783,646
On October 1, 2024, we completed a public offering of $ 650 million of 5.00 % senior notes due December 2054, with an effective interest rate of 3.90 %, 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 $ 639.4 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 expires on March 28, 2029. This 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 December 31, 2024 and September 30, 2024, there were no amounts outstanding under our commercial paper program.
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We also have a $ 1.5 billion three-year unsecured revolving credit facility, which expires March 28, 2027 and is used to provide additional working capital funding. This 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 December 31, 2024 and September 30, 2024, there were no borrowings outstanding under this facility.
Additionally, we have a $ 50 million 364 -day unsecured facility, which will expire March 31, 2025 and is used to provide working capital funding. There were no borrowings outstanding under this facility as of December 31, 2024 and September 30, 2024.
Finally, we have a $ 50 million 364 -day unsecured revolving credit facility, which will expire March 31, 2025 and is used to issue letters of credit and to provide working capital funding. At December 31, 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 December 31, 2024, our total-debt-to-total-capitalization ratio, as defined in the agreements, was 41 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 December 31, 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 months ended December 31, 2024 and 2023.
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, 2024
155,258,845 $ 776 $ 7,474,559 $ 465,715 $ 4,216,619 $ 12,157,669
Net income — — — — 351,858 351,858
Other comprehensive income — — — 16,423 — 16,423
Cash dividends ($ 0.87 per share)
— — — — ( 135,453 ) ( 135,453 )
Common stock issued:
Public and other stock offerings 3,329,358 17 383,520 — — 383,537
Stock-based compensation plans 137,862 1 6,446 — — 6,447
Balance, December 31, 2024 158,726,065 $ 794 $ 7,864,525 $ 482,138 $ 4,433,024 $ 12,780,481
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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
Shelf Registration, At-the-Market Equity Sales Program and Equity Issuances
On December 3, 2024, we filed a shelf registration statement with the Securities and Exchange Commission (SEC) that allows us to issue up to $ 8.0 billion in common stock and/or debt securities, which expires December 3, 2027. At December 31, 2024, $ 6.3 billion of securities were available for issuance under this shelf registration statement.
On December 3, 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 $ 1.7 billion through December 3, 2027 (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 May 8, 2024.
During the three months ended December 31, 2024, we executed forward sales under our ATM equity sales program with various forward sellers who borrowed and sold 3,397,596 shares of our common stock at an aggregate price of $ 476.0 million. During the three months ended December 31, 2024, we also settled forward sale agreements with respect to 3,300,904 shares that had been borrowed and sold by various forward sellers under the ATM program for net proceeds of $ 379.5 million. As of December 31, 2024, $ 1.2 billion of equity was available for issuance under our existing ATM program. Additionally, we had $ 1.5 billion in available proceeds from outstanding forward sale agreements, as detailed below.
Maturity Shares Available Net Proceeds Available
(In thousands) 		Forward Price
June 30, 2025 630,514 $ 73,312 $ 116.27
September 30, 2025 815,655 96,179 $ 117.92
December 31, 2025 2,344,567 297,079 $ 126.71
March 31, 2026 3,627,033 462,383 $ 127.48
June 30, 2026 669,043 88,951 $ 132.95
December 31, 2026 3,300,000 457,866 $ 138.75
Total 11,386,812 $ 1,475,770 $ 129.60
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).
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Available-
for-Sale
Securities 		Interest Rate
Agreement
Cash Flow
Hedges 		Total
(In thousands)
September 30, 2024 $ 213 $ 465,502 $ 465,715
Other comprehensive income (loss) before reclassifications ( 138 ) 19,719 19,581
Amounts reclassified from accumulated other comprehensive income — ( 3,158 ) ( 3,158 )
Net current-period other comprehensive income (loss) ( 138 ) 16,561 16,423
December 31, 2024 $ 75 $ 482,063 $ 482,138
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 296 ( 47,741 ) ( 47,445 )
Amounts reclassified from accumulated other comprehensive income — ( 2,491 ) ( 2,491 )
Net current-period other comprehensive income (loss) 296 ( 50,232 ) ( 49,936 )
December 31, 2023 $ ( 73 ) $ 468,665 $ 468,592

9. Securitization
Kansas
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 February 2021. 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.
As described in Note 10 of our Annual Report on Form 10-K for the fiscal year ended September 30, 2024, 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:
December 31, 2024 September 30, 2024
(In thousands)
Restricted cash and cash equivalents $ 4,870 $ 1,516
Other current assets $ 12 $ 3
Securitized intangible asset, net $ 80,580 $ 82,844
Accrued interest $ 1,462 $ 365
Current maturities of securitized long-term debt $ 8,207 $ 8,207
Securitized long-term debt $ 76,871 $ 76,871
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 December 31, 2024 Three Months Ended December 31, 2023
Operating revenues $ 3,393 $ 3,333
Operation and maintenance expense ( 61 ) —
Amortization expense ( 2,264 ) ( 2,166 )
Interest expense, net ( 1,068 ) ( 1,167 )
Income before income taxes $ — $ —
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 December 31, 2024 is $ 85.1 million and $ 85.0 million.
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 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.

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 months ended December 31, 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.
Three Months Ended December 31
Pension Benefits Other Benefits
2024 2023 2024 2023
(In thousands)
Components of net periodic pension cost:
Service cost $ 2,837 $ 2,389 $ 2,033 $ 1,507
Interest cost (1)
6,663 7,497 3,365 3,509
Expected return on assets (1)
( 7,655 ) ( 7,202 ) ( 3,831 ) ( 3,128 )
Amortization of prior service cost (credit) (1)
— — ( 3,260 ) ( 3,260 )
Amortization of actuarial (gain) loss (1)
256 118 ( 2,429 ) ( 2,718 )
Settlements (1)
— 776 — —
Net periodic pension cost $ 2,101 $ 3,578 $ ( 4,122 ) $ ( 4,090 )
(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, 2024.

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.
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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.
The NTSB issued a Preliminary Report on December 30, 2024 relating to its investigation of an incident that occurred in Avondale, Louisiana on December 2, 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, 2024. At December 31, 2024, we were committed to purchase 55.5 Bcf within one year and 29.9 Bcf within two to three years under indexed contracts. At December 31, 2024, we were committed to purchase 3.9 Bcf within one year under fixed price contracts with a weighted average price of $ 3.26 per Mcf.
Rate Regulatory Proceedings
As of December 31, 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 three months ended December 31, 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, 2025 and 2024, adjusted for tax expense associated with certain discrete items. The effective tax rates for the three months ended December 31, 2024 and 2023 were 18.4 % and 14.7 %. 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), a Kansas legislative change enacted in fiscal 2020, and a Louisiana legislative change enacted in fiscal 2025. Currently, the regulatory excess net deferred tax liability of $ 198.8 million is being returned over various periods. Of this amount, $ 135.3 million is being returned to customers over 12 - 60 months. An additional $ 49.0 million is being returned to customers on a provisional basis over 15 - 68 years until our regulators establish the final refund periods. The refund of the remaining $ 14.5 million will be addressed in future rate proceedings.
As of December 31, 2024 and September 30, 2024, $ 76.8 million and $ 79.7 million is recorded in other current liabilities.

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, 2024. During the three months ended December 31, 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
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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 2024-2025 heating season (generally October through March), in the jurisdictions where we are permitted to utilize financial instruments, we anticipate hedging approximately 24.0 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 December 31, 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 2026 $ 300,000
$ 300,000
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 December 31, 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 December 31, 2024, we had 15,053 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 December 31, 2024 and September 30, 2024. 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 December 31, 2024 and September 30, 2024, no gross amounts and no cash collateral were netted within our consolidated balance sheet.
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December 31, 2024
Balance Sheet Location Assets Liabilities
(In thousands)
Designated As Hedges:
Interest rate contracts Other current assets /
Other current liabilities 		$ 117,154 $ —
Total 117,154 —
Not Designated As Hedges:
Commodity contracts Other current assets /
Other current liabilities 		2,459 ( 4,063 )
Commodity contracts Deferred charges and other assets /
Deferred credits and other liabilities 		1,338 —
Total 3,797 ( 4,063 )
Gross / Net Financial Instruments $ 120,951 $ ( 4,063 )
September 30, 2024
Balance Sheet Location Assets Liabilities
(In thousands)
Designated As Hedges:
Interest rate contracts Deferred charges and other assets /
Deferred credits and other liabilities 		$ 91,981 $ —
Total 91,981 —
Not Designated As Hedges:
Commodity contracts Other current assets /
Other current liabilities 		2,091 ( 7,324 )
Commodity contracts Deferred charges and other assets /
Deferred credits and other liabilities 		2,216 ( 313 )
Total 4,307 ( 7,637 )
Gross / Net Financial Instruments $ 96,288 $ ( 7,637 )
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 December 31, 2024 and 2023 was $( 5.1 ) million and $( 3.2 ) 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 months ended December 31, 2024 and 2023.
Three Months Ended December 31
2024 2023
(In thousands)
Increase (decrease) in fair value:
Interest rate agreements $ 19,719 $ ( 47,741 )
Recognition of (gains) losses in earnings due to settlements:
Interest rate agreements ( 3,158 ) ( 2,491 )
Total other comprehensive income (loss) from hedging, net of tax $ 16,561 $ ( 50,232 )
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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 December 31, 2024, we had $ 391.0 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 2055. 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 $ 15,925
Thereafter 375,062
Total $ 390,987

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, 2024. During the three months ended December 31, 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, 2024.
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 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 December 31, 2024 and September 30, 2024. Assets and liabilities are categorized in their entirety based on the lowest level of input that is significant to the fair value measurement.
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Quoted
Prices in
Active
Markets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2) (1)
Significant
Other
Unobservable
Inputs
(Level 3) 		Netting and
Cash
Collateral 		December 31, 2024
(In thousands)
Assets:
Financial instruments $ — $ 120,951 $ — $ — $ 120,951
Debt and equity securities
Registered investment companies 27,344 — — — 27,344
Bond mutual funds 40,332 — — — 40,332
Bonds (2)
— 39,381 — — 39,381
Money market funds — 2,507 — — 2,507
Total debt and equity securities 67,676 41,888 — — 109,564
Total assets $ 67,676 $ 162,839 $ — $ — $ 230,515
Liabilities:
Financial instruments $ — $ 4,063 $ — $ — $ 4,063

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, 2024
(In thousands)
Assets:
Financial instruments $ — $ 96,288 $ — $ — $ 96,288
Debt and equity securities
Registered investment companies 28,311 — — — 28,311
Bond mutual funds 40,341 — — — 40,341
Bonds (2)
— 39,142 — — 39,142
Money market funds — 2,800 — — 2,800
Total debt and equity securities 68,652 41,942 — — 110,594
Total assets $ 68,652 $ 138,230 $ — $ — $ 206,882
Liabilities:
Financial instruments $ — $ 7,637 $ — $ — $ 7,637
(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, 2024, 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 December 31, 2024, no allowance for credit losses was recorded for our available-for-sale debt securities. At December 31, 2024 and September 30, 2024, the amortized cost of our available-for-sale debt securities was $ 39.3 million and $ 38.9 million. At December 31, 2024, we maintained investments in bonds that have contractual maturity dates ranging from January 2025 through November 2027.
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
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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 December 31, 2024 and September 30, 2024:
December 31, 2024 September 30, 2024
(In thousands)
Carrying Amount $ 8,435,000 $ 7,785,000
Fair Value $ 7,484,877 $ 7,337,936

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, 2024. During the three months ended December 31, 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 December 31, 2024, the related condensed consolidated statements of comprehensive income and cash flows for the three months ended December 31, 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, 2024, 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 18, 2024, 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, 2024, 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
February 4, 2025
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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, 2024.
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, adverse weather, 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; failure of technology that affects the Company's business operations; 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 legislation to reduce or eliminate greenhouse gas emissions or fossil fuels; 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 December 31, 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, 2024 and include the following:
• Regulation
• Pension and other postretirement plans
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 three months ended December 31, 2024.
RESULTS OF OPERATIONS

Executive Summary
Atmos Energy's vision is to be the safest provider of natural gas services. Our commitment to this vision requires significant levels of capital spending to modernize our natural gas distribution system and operating costs to deliver natural gas safely and reliably and in full compliance with the various safety regulations impacting our business. We have the ability to begin recovering a significant portion of our expenditures 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 expenditures 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 three months ended December 31, 2024, we recorded net income of $351.9 million, or $2.23 per diluted share, compared to net income of $311.3 million, or $2.08 per diluted share for the three months ended December 31, 2023.
The 13 percent year-over-year increase in net income largely reflects positive rate outcomes driven by safety and reliability spending, partially offset by higher bad debt expense, depreciation and property tax expenses, and higher spending on certain operating expenses, as well as higher interest expense.
During the three months ended December 31, 2024, we implemented, or received approval to implement, ratemaking regulatory actions which resulted in an increase in annual operating income of $150.5 million. Additionally, as of December 31, 2024, we had ratemaking efforts in progress seeking a total increase in annual operating income of $95.4 million.
Capital expenditures for the three months ended December 31, 2024 were $891.2 million. Approximately 86 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 three months ended December 31, 2024, we completed approximately $1.0 billion of long-term debt and equity financing. As of December 31, 2024, our equity capitalization was 60.3 percent. As of December 31, 2024, we had approximately $5.2 billion in total liquidity, consisting of $584.5 million in cash and cash equivalents, $1,475.8 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 segment revenue, excluding gas costs, through the base customer charge, which partially separates the recovery of our approved rate from customer usage patterns.
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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 97 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 89 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 December 31, 2024 compared with Three Months Ended December 31, 2023
Financial and operational highlights for our distribution segment for the three months ended December 31, 2024 and 2023 are presented below.
Three Months Ended December 31
2024 2023 Change
(In thousands, unless otherwise noted)
Operating revenues $ 1,109,335 $ 1,105,338 $ 3,997
Purchased gas cost 422,570 496,662 (74,092)
Operating expenses 370,717 328,195 42,522
Operating income 316,048 280,481 35,567
Other non-operating income 10,084 5,839 4,245
Interest charges 34,249 34,581 (332)
Income before income taxes 291,883 251,739 40,144
Income tax expense 51,670 30,302 21,368
Net income $ 240,213 $ 221,437 $ 18,776
Consolidated distribution sales volumes — MMcf
71,924 82,716 (10,792)
Consolidated distribution transportation volumes — MMcf
37,662 40,500 (2,838)
Total consolidated distribution throughput — MMcf
109,586 123,216 (13,630)
Consolidated distribution average cost of gas per Mcf sold $ 5.88 $ 6.00 $ (0.12)
Operating income for our distribution segment increased 12.7 percent. Key drivers for the change in operating income include:
• a $50.7 million increase in rate adjustments, primarily in our Mid-Tex Division.
• a $6.0 million increase related to residential customer growth, primarily in our Mid-Tex Division, and increased industrial load.
• a $13.6 million decrease in refunds of excess deferred taxes to customers, which is substantially offset in income tax expense.
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Partially offset by:
• a $17.0 million increase in depreciation expense and property taxes associated with increased capital investments.
• an $11.0 million increase in employee-related costs primarily due to an increase in headcount to support company growth.
• a $15.0 million increase in bad debt expense due to a regulatory change in Mississippi in the first quarter of fiscal 2024, as discussed in Note 6 to the condensed consolidated financial statements.
The following table shows our operating income by distribution division, in order of total rate base, for the three months ended December 31, 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 December 31
2024 2023 Change
(In thousands)
Mid-Tex $ 168,608 $ 143,114 $ 25,494
Kentucky/Mid-States 37,430 27,059 10,371
Louisiana 29,303 26,439 2,864
West Texas 26,685 26,020 665
Mississippi 34,200 43,944 (9,744)
Colorado-Kansas 13,500 16,105 (2,605)
Other 6,322 (2,200) 8,522
Total $ 316,048 $ 280,481 $ 35,567
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 three months of fiscal 2025, we implemented, or received approval to implement, regulatory proceedings, resulting in a $150.5 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 three months ended December 31, 2024 were $151.3 million.
Rate Action Annual Increase in
Operating Income 		EDIT Impact Annual Increase in
Operating Income Excluding EDIT
(In thousands)
Annual formula rate mechanisms $ 150,540 $ 782 $ 151,322
Rate case filings — — —
Other rate activity — — —
$ 150,540 $ 782 $ 151,322
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The following ratemaking efforts seeking $95.4 million in increased annual operating income were in progress as of December 31, 2024:
Division Rate Action Jurisdiction Operating Income Requested
(In thousands)
Colorado-Kansas Infrastructure Mechanism
Colorado (1)
$ 1,907
Colorado-Kansas Ad Valorem
Kansas (2)
111
Kentucky/Mid-States Rate Case Kentucky 33,654
Mid-Tex Rate Case ATM Cities 12,531
Mid-Tex Rate Case Environs 7,994
West Texas Rate Case West Texas Systemwide 39,196
$ 95,393
(1)    The Colorado Public Utilities Commission approved the SSIR implementation at their December 18, 2024 meeting with rates effective January 1, 2025.
(2)    The Kansas Corporation Commission approved the Ad Valorem filing on January 8, 2025, with rates effective February 1, 2025.

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 three months ended December 31, 2024:
Division Jurisdiction Test Year
Ended 		Increase in
Annual
Operating
Income 		EDIT Impact Increase in
Annual
Operating
Income Excluding EDIT 		Effective
Date
(In thousands)
2025 Filings:
Colorado-Kansas Kansas GSRS 09/30/2024 $ 1,998 $ — $ 1,998 12/17/2024
Mississippi Mississippi - SIR 10/31/2025 23,995 — 23,995 11/04/2024
Mississippi Mississippi - SRF 10/31/2025 3,800 15 3,815 11/04/2024
Kentucky/Mid-States
Kentucky PRP (1)
09/30/2025 3,441 — 3,441 10/02/2024
Mid-Tex Mid-Tex Cities RRM 12/31/2023 112,144 645 112,789 10/01/2024
West Texas West Texas Cities RRM 12/31/2023 4,414 122 4,536 10/01/2024
Kentucky/Mid-States Virginia - SAVE 09/30/2025 748 — 748 10/01/2024
Total 2025 Filings $ 150,540 $ 782 $ 151,322
(1)    On September 27, 2024, the Kentucky Public Service Commission approved a rate increase of $3.4 million effective October 2, 2024, subject to refund.
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. There was no rate case activity completed in our distribution segment during the three months ended December 31, 2024.

Other Ratemaking Activity
The Company had no other ratemaking activity during the three months ended December 31, 2024.
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 an intrastate pipeline 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
29

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.
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 December 31, 2024 compared with Three Months Ended December 31, 2023
Financial and operational highlights for our pipeline and storage segment for the three months ended December 31, 2024 and 2023 are presented below.
Three Months Ended December 31
2024 2023 Change
(In thousands, unless otherwise noted)
Mid-Tex / Affiliate transportation revenue $ 195,922 $ 164,890 $ 31,032
Third-party transportation revenue 56,949 43,273 13,676
Other revenue 2,519 3,006 (487)
Total operating revenues 255,390 211,169 44,221
Total purchased gas cost (58) 4 (62)
Operating expenses 112,016 92,541 19,475
Operating income 143,432 118,624 24,808
Other non-operating income 14,550 12,047 2,503
Interest charges 18,676 17,294 1,382
Income before income taxes 139,306 113,377 25,929
Income tax expense 27,661 23,522 4,139
Net income $ 111,645 $ 89,855 $ 21,790
Gross pipeline transportation volumes — MMcf 217,458 209,272 8,186
Consolidated pipeline transportation volumes — MMcf 169,090 153,534 15,556
Operating income for our pipeline and storage segment increased 20.9 percent. Key drivers for the change in operating income include:
• a $22.8 million increase primarily due to rate adjustments from the GRIP filing approved in May 2024, the System Safety and Integrity Rider filing approved in November 2024, and the rate case approved in December 2023.
• a $7.9 million increase in APT's through-system activities primarily associated with increased spreads.
• a $9.2 million decrease in refunds of excess deferred taxes to customers, which is partially 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.
Partially offset by:
• a $5.4 million increase in depreciation expense and property taxes associated with increased capital investments.
• a $4.7 million increase in expenses recognized as a result of the System Safety and Integrity Rider filing approved in November 2024, which is offset in operating revenues.
• a $9.1 million increase in other operation and maintenance expense due to compliance-related activities and other administrative costs.
30

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.
On December 3, 2024, we filed a shelf registration statement with the Securities and Exchange Commission (SEC) that allows us to issue up to $8.0 billion in common stock and/or debt securities, which expires December 3, 2027. As of December 31, 2024, $6.3 billion of securities were available for issuance under this shelf registration statement.
On December 3, 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 $1.7 billion through December 3, 2027 (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 December 3, 2027. This ATM equity sales program replaced our previous ATM equity sales program, filed on May 8, 2024. As of December 31, 2024, $1.2 billion of equity was available for issuance under our existing ATM equity sales program. Additionally, as of December 31, 2024, we had $1.5 billion 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 2025. 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 December 31, 2024.
Planned Debt Issuance Date Amount Hedged Effective Interest Rate
(In thousands)
Fiscal 2026 $ 300,000 2.16 %
$ 300,000
The following table presents our capitalization inclusive of short-term debt and the current portion of long-term debt as of December 31, 2024, September 30, 2024 and December 31, 2023:
December 31, 2024 September 30, 2024 December 31, 2023
(In thousands, except percentages)
Short-term debt $ — — % $ — — % $ — — %
Long-term debt (1)
8,425,055 39.7 % 7,785,297 39.0 % 7,445,756 39.8 %
Shareholders’ equity 12,780,481 60.3 % 12,157,669 61.0 % 11,273,209 60.2 %
Total $ 21,205,536 100.0 % $ 19,942,966 100.0 % $ 18,718,965 100.0 %
(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 three months ended December 31, 2024 and 2023 are presented below.
31

Three Months Ended December 31
2024 2023 Change
(In thousands)
Total cash provided by (used in)
Operating activities $ 282,022 $ 245,280 $ 36,742
Investing activities (888,941) (764,375) (124,566)
Financing activities 887,469 785,292 102,177
Change in cash and cash equivalents and restricted cash and cash equivalents 280,550 266,197 14,353
Cash and cash equivalents and restricted cash and cash equivalents at beginning of period 308,856 19,248 289,608
Cash and cash equivalents and restricted cash and cash equivalents at end of period $ 589,406 $ 285,445 $ 303,961
Cash flows from operating activities
For the three months ended December 31, 2024, we generated cash flow from operating activities of $282.0 million compared with $245.3 million for the three months ended December 31, 2023. Operating cash flow increased $36.7 million primarily due to the positive effects of successful rate case outcomes achieved in fiscal 2024.
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. Over the last three fiscal years, approximately 86 percent of our capital spending has been committed to improving the safety and reliability of our system.
For the three months ended December 31, 2024, cash used for investing activities was $888.9 million compared to $764.4 million for the three months ended December 31, 2023. Capital spending in our distribution segment increased $86.5 million, primarily as a result of increased system modernization and customer growth spending. Capital spending in our pipeline and storage segment increased $35.0 million primarily due to increased spending for pipeline system safety and reliability in Texas.
Cash flows from financing activities
For the three months ended December 31, 2024, our financing activities provided $887.5 million of cash compared with $785.3 million of cash used by financing activities in the prior-year period.
In the three months ended December 31, 2024, we received approximately $1.0 billion in net proceeds from the issuance of long-term debt and equity. We completed a public offering of $650 million of 5.00% senior notes due December 2054, and received net proceeds from the offering, after the underwriting discount and offering expenses, of $639.4 million. Additionally, during the three months ended December 31, 2024, we settled 3,300,904 shares that had been sold on a forward basis for net proceeds of $379.5 million. The net proceeds were used primarily to support capital spending and for other general corporate purposes. Cash dividends increased due to an 8.1 percent increase in our dividend rate and an increase in shares outstanding.
In the three months ended December 31, 2023, we received approximately $1.1 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 November 2053 and $400 million of 5.90% senior notes due November 2033, and received net proceeds from the offering, after the underwriting discount and offering expenses, of $889.4 million. Additionally, during the three months ended December 31, 2023, we settled 2,144,558 shares that had been sold on a forward basis for net proceeds of $254.0 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.
32

The following table summarizes our share issuances for the three months ended December 31, 2024 and 2023:
Three Months Ended December 31
2024 2023
Shares issued:
Direct Stock Purchase Plan 12,344 16,192
1998 Long-Term Incentive Plan 137,862 163,750
Retirement Savings Plan and Trust 16,110 17,114
Equity Issuance 3,300,904 2,144,558
Total shares issued 3,467,220 2,341,614
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). Currently, our outlook and debt ratings, which are all considered investment grade, are as follows:
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 December 31, 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 three months ended December 31, 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 months ended December 31, 2024 and 2023:
33

Three Months Ended December 31
2024 2023
(In thousands)
Fair value of contracts at beginning of period $ 88,651 $ 370,256
Contracts realized/settled (8,336) (19,329)
Fair value of new contracts 518 232
Other changes in value 36,055 (51,888)
Fair value of contracts at end of period 116,888 299,271
Netting of cash collateral — —
Cash collateral and fair value of contracts at period end $ 116,888 $ 299,271
The fair value of our financial instruments at December 31, 2024 is presented below by time period and fair value source:
Fair Value of Contracts at December 31, 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 $ 115,550 $ 1,338 $ — $ — $ 116,888
Prices based on models and other valuation methods — — — — —
Total Fair Value $ 115,550 $ 1,338 $ — $ — $ 116,888
34

OPERATING STATISTICS AND OTHER INFORMATION
The following tables present certain operating statistics for our distribution and pipeline and storage segments for the three months ended December 31, 2024 and 2023.
Distribution Sales and Statistical Data
Three Months Ended December 31
2024 2023
METERS IN SERVICE, end of period
Residential 3,136,028 3,097,381
Commercial 258,052 257,793
Industrial 1,496 1,510
Public authority and other 7,983 8,064
Total meters 3,403,559 3,364,748
INVENTORY STORAGE BALANCE — Bcf 70.1 67.7
SALES VOLUMES — MMcf (1)
Gas sales volumes
Residential 39,363 47,312
Commercial 24,481 26,916
Industrial 6,518 6,693
Public authority and other 1,562 1,795
Total gas sales volumes 71,924 82,716
Transportation volumes 39,538 42,292
Total throughput 111,462 125,008
Pipeline and Storage Operations Sales and Statistical Data
Three Months Ended December 31
2024 2023
CUSTOMERS, end of period
Industrial 93 95
Other 203 192
Total 296 287
INVENTORY STORAGE BALANCE — Bcf 1.4 1.1
PIPELINE TRANSPORTATION VOLUMES — MMcf (1)
217,458 209,272
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.

35

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, 2024. During the three months ended December 31, 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 December 31, 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 first quarter of the fiscal year ended September 30, 2025 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

36

PART II. OTHER INFORMATION
Item 1 .
Legal Proceedings
During the three months ended December 31, 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, 2024. 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, 2024.
Item 5 .
Other Information
During the three months ended December 31, 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.


37

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)
3.2 Restated Articles of Incorporation of Atmos Energy Corporation - Virginia (As Amended Effective February 3, 2010)
3.3 Amended and Restated Bylaws of Atmos Energy Corporation (as of August 4, 2023)
4.1(a) Officers' Certificate dated October 1, 2024
4.1(b) Global Security for the 5.000% Senior Notes due 2054
4.1(c) Global Security for the 5.000% Senior Notes due 2054
10.1(a) Equity Distribution Agreement, dated as of December 3, 2024, among Atmos Energy Corporation and the Managers and Forward Purchasers named in Schedule A thereto
10.1(b) Form of Master Forward Sale Confirmation
15
31
32
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.

38

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.
A TMOS E NERGY C ORPORATION
(Registrant)
By: /s/    CHRISTOPHER T. FORSYTHE
Christopher T. Forsythe
Senior Vice President and Chief Financial Officer
(Duly authorized signatory)
Date: February 4, 2025
39
TABLE OF CONTENTS
Part I. Financial InformationItem 1. Financial StatementsItem 2. Management S Discussion and Analysis Of Financial Condition and Results Of OperationsItem 3. Quantitative and Qualitative Disclosures About Market RiskItem 4. Controls and ProceduresPart II. Other InformationItem 1. Legal ProceedingsItem 1A. Risk FactorsItem 5. Other InformationItem 6. Exhibits

Exhibits

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 October 1, 2024 Exhibit 4.2 to Form 8-K dated October 1, 2024 (File No. 1-10042) 4.1(b) Global Security for the 5.000% Senior Notes due 2054 Exhibit 4.3 to Form 8-K dated October 1, 2024 (File No. 1-10042) 4.1(c) Global Security for the 5.000% Senior Notes due 2054 Exhibit 4.4 to Form 8-K dated October 1, 2024 (File No. 1-10042) 10.1(a) Equity Distribution Agreement, dated as of December 3, 2024, among Atmos Energy Corporation and the Managers and Forward Purchasers named in Schedule A thereto Exhibit 1.1 to Form 8-K dated December 3, 2024 (File No. 1-10042) 10.1(b) Form of Master Forward Sale Confirmation Exhibit 1.2 to Form 8-K dated December 3, 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*