UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

(Mark One)

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

For the fiscal year ended September 30, 2022

OR

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

For the transition period from                      to                     

Commission file number 1-10042

Atmos Energy Corporation

(Exact name of registrant as specified in its charter)

    Texas and Virginia    75-1743247

    (State or other jurisdiction of    (IRS employer

    incorporation or organization)    identification no.)

    1800 Three Lincoln Centre

    5430 LBJ Freeway

    Dallas, Texas    75240

    (Address of principal executive offices)    (Zip code)

Registrant’s telephone number, including area code:

(972) 934-9227

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

Table of each class		Trading Symbol	Name of each exchange on which registered
Common stock	No Par Value	ATO	New York Stock Exchange

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

None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.    Yes  þ        No  ¨

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.    Yes  ¨        No  þ

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, a smaller reporting company or an emerging growth company. See 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 ☑ 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 has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☑

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

The aggregate market value of the common voting stock held by non-affiliates of the registrant as of the last business day of the registrant’s most recently completed second fiscal quarter, March 31, 2022, was $16,491,263,629.

As of November 7, 2022, the registrant had 140,900,576 shares of common stock outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant’s Definitive Proxy Statement to be filed for the Annual Meeting of Shareholders on February 8, 2023 are incorporated by reference into Part III of this report.

TABLE OF CONTENTS

		Page
Glossary of Key Terms		3
	Part I
Item 1.	Business	4
Item 1A.	Risk Factors	14
Item 1B.	Unresolved Staff Comments	19
Item 2.	Properties	19
Item 3.	Legal Proceedings	20
Item 4.	Mine Safety Disclosures	20
	Part II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	20
Item 6.	Selected Financial Data	22
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	22
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	34
Item 8.	Financial Statements and Supplementary Data	35
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	85
Item 9A.	Controls and Procedures	85
Item 9B.	Other Information	87
	Part III
Item 10.	Directors, Executive Officers and Corporate Governance	87
Item 11.	Executive Compensation	88
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	88
Item 13.	Certain Relationships and Related Transactions, and Director Independence	88
Item 14.	Principal Accountant Fees and Services	88
	Part IV
Item 15.	Exhibits and Financial Statement Schedules	88
Item 16.	Form 10-K Summary	93

GLOSSARY OF KEY TERMS

Adjusted diluted net income per share	Non-GAAP measure defined as diluted net income per share before the one-time, non-cash income tax benefit
Adjusted net income	Non-GAAP measure defined as net income before the one-time, non-cash income tax benefit
AFUDC	Allowance for funds used during construction
AOCI	Accumulated Other Comprehensive Income
ARM	Annual Rate Mechanism
ATO	Trading symbol for Atmos Energy Corporation common stock on the NYSE
Bcf	Billion cubic feet
COSO	Committee of Sponsoring Organizations of the Treadway Commission
DARR	Dallas Annual Rate Review
ERISA	Employee Retirement Income Security Act of 1974
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
GAAP	Generally Accepted Accounting Principles
GRIP	Gas Reliability Infrastructure Program
GSRS	Gas System Reliability Surcharge
LIBOR	London Interbank Offered Rate
LTIP	1998 Long-Term Incentive Plan
Mcf	Thousand cubic feet
MDWQ	Maximum daily withdrawal quantity
Mid-Tex ATM Cities	Represents a coalition of 47 incorporated cities or approximately 10 percent of the Mid-Tex Division's customers.
Mid-Tex Cities	Represents all incorporated cities other than Dallas and Mid-Tex ATM Cities, or approximately 72 percent of the Mid-Tex Division’s customers.
MMcf	Million cubic feet
Moody’s	Moody’s Investor Service, Inc.
NGPA	Natural Gas Policy Act of 1978
NTSB	National Transportation Safety Board
NYSE	New York Stock Exchange
PHMSA	Pipeline and Hazardous Materials Safety Administration
PPA	Pension Protection Act of 2006
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
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

3

PART I

The terms “we,” “our,” “us,” “Atmos Energy” and the “Company” refer to Atmos Energy Corporation and its subsidiaries, unless the context suggests otherwise.

ITEM 1. Business.

Overview and Strategy

Atmos Energy Corporation, headquartered in Dallas, Texas, and incorporated in Texas and Virginia, is the country’s largest natural-gas-only distributor based on number of customers. We safely deliver reliable, affordable, efficient and abundant natural gas through regulated sales and transportation arrangements to approximately 3.3 million residential, commercial, public authority and industrial customers in eight states located primarily in the South. We also operate one of the largest intrastate pipelines in Texas based on miles of pipe.

Atmos Energy's vision is to be the safest provider of natural gas services. We will be recognized for exceptional customer service, for being a great employer and for achieving superior financial results.

Since 2011, our operating strategy has focused on modernizing our business and infrastructure while reducing regulatory lag. This operating strategy supports continued investment in safety, innovation, environmental sustainability and our communities.

Operating Segments

As of September 30, 2022, we manage and review our consolidated operations through the following reportable segments:

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

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

Distribution Segment Overview

The following table summarizes key information about our six regulated natural gas distribution divisions, presented in order of total rate base.

Division	Service Areas	Communities Served	Customer Meters
Mid-Tex	Texas, including the Dallas/Fort Worth Metroplex	550	1,822,036
Kentucky/Mid-States	Kentucky	230	184,547
	Tennessee		162,392
	Virginia		24,898
Louisiana	Louisiana	270	376,515
West Texas	Amarillo, Lubbock, Midland	80	329,378
Mississippi	Mississippi	110	273,934
Colorado-Kansas	Colorado	170	127,565
	Kansas		140,959

We operate in our service areas under terms of non-exclusive franchise agreements granted by the various cities and towns that we serve. At September 30, 2022, we held 1,028 franchises having terms generally ranging from five to 35 years. A significant number of our franchises expire each year, which require renewal prior to the end of their terms. Historically, we have successfully renewed these franchises and believe that we will continue to be able to renew our franchises as they expire.

Revenues in this operating segment are established by regulatory authorities in the states in which we operate. These rates are intended to be sufficient to cover the costs of conducting business, including a reasonable return on invested capital. In addition, we transport natural gas for others through our distribution systems.

4

Rates established by regulatory authorities often include cost adjustment mechanisms for costs that (i) are subject to significant price fluctuations compared to our other costs, (ii) represent a large component of our cost of service and (iii) are generally outside our control.

Purchased gas cost adjustment mechanisms represent a traditional and common form of cost adjustment mechanism. Purchased gas cost adjustment mechanisms provide a method of recovering purchased gas costs on an ongoing basis without filing a rate case because they provide a dollar-for-dollar offset to increases or decreases in the cost of natural gas. Therefore, although substantially all of our distribution operating revenues fluctuate with the cost of gas that we purchase, distribution operating income is generally not affected by fluctuations in the cost of gas.

Additionally, some jurisdictions have performance-based ratemaking adjustments to provide incentives to minimize purchased gas costs through improved storage management and use of financial instruments to reduce volatility in gas costs. Under the performance-based ratemaking adjustments, purchased gas costs savings are shared between the Company and its customers.

Our supply of natural gas is provided by a variety of suppliers, including independent producers and marketers. The gas is delivered into our systems by various pipeline companies, withdrawals of gas from proprietary and contracted storage assets and base load and peaking arrangements, as needed.

Supply arrangements consist of both base load and peaking quantities and are contracted from our suppliers on a firm basis with various terms at market prices. Base load quantities are those that flow at a constant level throughout the month and peaking quantities provide the flexibility to change daily quantities to match increases or decreases in requirements related to weather conditions.

Except for local production purchases, we select our natural gas suppliers through a competitive bidding process by periodically requesting proposals from suppliers. We select these suppliers based on their ability to reliably deliver gas supply to our designated firm pipeline receipt points at the lowest reasonable cost. Major suppliers during fiscal 2022 were ConocoPhillips Company, EnLink Gas Marketing LP, Enterprise Navitas Midstream Midland Basin LLC, EOG Resources, Inc., Hartree Partners, L.P., Sequent Energy Management LLC, Symmetry Energy Solutions, LLC, Targa Gas Marketing LLC, Texla Energy Management, Inc. and Twin Eagle Resource Management, LLC.

The combination of base load and peaking agreements, coupled with the withdrawal of gas held in storage, allows us the flexibility to adjust to changes in weather, which minimizes our need to enter into long-term firm commitments. We estimate our peak-day availability of natural gas supply to be approximately 4.4 Bcf. The peak-day demand for our distribution operations in fiscal 2022 was on February 3, 2022, when sales to customers reached approximately 3.6 Bcf.

Currently, our distribution divisions utilize 38 pipeline transportation companies, both interstate and intrastate, to transport our natural gas. The pipeline transportation agreements are firm and many of them have “pipeline no-notice” storage service, which provides for daily balancing between system requirements and nominated flowing supplies. These agreements have been negotiated with the shortest term necessary while still maintaining our right of first refusal. The natural gas supply for our Mid-Tex Division is delivered primarily by our APT Division.

To maintain our deliveries to high priority customers, we have the ability, and have exercised our right, to interrupt or curtail service to certain customers pursuant to contracts and applicable state regulations or statutes. Our customers’ demand on our system is not necessarily indicative of our ability to meet current or anticipated market demands or immediate delivery requirements because of factors such as the physical limitations of gathering, storage and transmission systems, the duration and severity of cold weather, the availability of gas reserves from our suppliers, the ability to purchase additional supplies on a short-term basis and actions by federal and state regulatory authorities. Interruption and curtailment rights provide us the flexibility to meet the human-needs requirements of our customers on a reliable basis. Priority allocations imposed by federal and state regulatory agencies, as well as other factors beyond our control, may affect our ability to meet the demands of some of our customers.

Pipeline and Storage Segment Overview

Our pipeline and storage segment consists of the pipeline and storage operations of APT and our natural gas transmission operations in Louisiana. APT is one of the largest intrastate pipeline operations in Texas with a heavy concentration in the established natural gas-producing areas of central, northern and eastern Texas, extending into or near the major producing areas of the Barnett Shale, the Texas Gulf Coast and the Permian Basin of West Texas. Through its system, APT provides transportation and storage services to our Mid-Tex Division, other third party local distribution companies, industrial and electric generation customers, marketers and producers. As part of its pipeline operations, APT owns and operates five underground storage reservoirs in Texas.

Revenues earned from transportation and storage services for APT are subject to traditional ratemaking governed by the RRC. Rates are updated through periodic filings made under Texas’ GRIP. GRIP allows us to include in our rate base annually approved capital costs incurred in the prior calendar year provided that we file a complete rate case at least once every five

5

years; the most recent of which was completed in August 2017. APT’s existing regulatory mechanisms allow certain transportation and storage services to be provided under market-based rates.

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 that serve distribution affiliates of the Company, 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.

Ratemaking Activity

Overview

The method of determining regulated rates varies among the states in which our regulated businesses operate. The regulatory authorities have the responsibility of ensuring that utilities in their jurisdictions operate in the best interests of customers while providing utility companies the opportunity to earn a reasonable return on their investment. Generally, each regulatory authority reviews rate requests and establishes a rate structure intended to generate revenue sufficient to cover the costs of conducting business, including a reasonable return on invested capital.

Our rate strategy focuses on reducing or eliminating regulatory lag, obtaining adequate returns and providing stable, predictable margins, which benefit both our customers and the Company. As a result of our ratemaking efforts in recent years, Atmos Energy has:

•Formula rate mechanisms in place in four states that provide for an annual rate review and adjustment to rates.

•Infrastructure programs in place in all of our states that provide for an annual adjustment to rates for qualifying capital expenditures. Through our annual formula rate mechanisms and infrastructure programs, we have the ability to recover approximately 90 percent of our capital expenditures within six months and substantially all of our capital expenditures within twelve months.

•Authorization in tariffs, statute or commission rules that allows us to defer certain elements of our cost of service such as depreciation, ad valorem taxes and pension costs, until they are included in rates.

•WNA mechanisms in seven states that serve to minimize the effects of weather on approximately 96 percent of our distribution residential and commercial revenues.

•The ability to recover the gas cost portion of bad debts in five states which represents approximately 81 percent of our distribution residential and commercial revenues.

6

The following table provides a jurisdictional rate summary for our regulated operations as of September 30, 2022. This information is for regulatory purposes only and may not be representative of our actual financial position.

Division	Jurisdiction	Effective Date of Last Rate/GRIP Action	Rate Base (thousands)(1)	Authorized Rate of Return(1)	Authorized Debt/ Equity Ratio(1)	Authorized Return on Equity(1)
Atmos Pipeline — Texas	Texas	05/18/2022	$3,432,180	8.87%	47/53	11.50%
Colorado-Kansas	Colorado	05/03/2018	134,726	7.55%	44/56	9.45%
	Colorado SSIR	01/01/2022	98,695	7.55%	44/56	9.45%
	Kansas	04/01/2020	242,314	7.03%	44/56	9.10%
	Kansas GSRS	02/01/2022	35,612	7.03%	44/56	9.10%
	Kansas SIP	04/01/2022	5,881	7.03%	44/56	9.10%
Kentucky/Mid-States	Kentucky	05/20/2022	568,506	6.82%	45/55	9.23%
	Kentucky-PRP	10/01/2020	39,368	7.49%	42/58	9.65%
	Tennessee	07/01/2022	447,448	7.53%	39/61	9.80%
	Virginia	04/01/2019	47,827	7.43%	42/58	9.20%
	Virginia-SAVE	10/01/2021	7,466	7.43%	42/58	9.20%
Louisiana	Louisiana	07/01/2022	942,422	7.30%	(4)	(4)
Mid-Tex	Mid-Tex Cities(6)	12/01/2021	4,394,489(5)	7.36%	42/58	9.80%
	Mid-Tex ATM Cities	06/10/2022	5,121,370(5)	7.97%	40/60	9.80%
	Mid-Tex Environs	06/10/2022	5,121,376(5)	7.97%	40/60	9.80%
	Mid-Tex — Dallas	05/25/2022	5,051,984(5)	7.41%	41/59	9.80%
Mississippi	Mississippi(7)	11/01/2021	473,932	7.81%	(4)	(4)
	Mississippi - SIR(7)	11/01/2021	323,695	7.81%	(4)	(4)
West Texas	West Texas Cities(8) (10)	12/01/2021	758,951(9)	7.36%	42/58	9.80%
	West Texas - ALDC	06/11/2022	857,631(9)	7.35%	41/59	(4)
	West Texas - Environs	06/11/2022	855,152(9)	7.97%	40/60	9.80%

Division	Jurisdiction	Bad  Debt Rider(2)	Formula Rate	Infrastructure Mechanism	Performance Based Rate Program(3)	WNA Period
Atmos Pipeline —  Texas	Texas	No	Yes	Yes	N/A	N/A
Colorado-Kansas	Colorado	No	No	Yes	No	N/A
	Kansas	Yes	No	Yes	Yes	October-May
Kentucky/Mid-States	Kentucky	Yes	No	Yes	Yes	November-April
	Tennessee	Yes	Yes	Yes	Yes	October-April
	Virginia	Yes	No	Yes	No	January-December
Louisiana	Louisiana	No	Yes	Yes	No	December-March
Mid-Tex Cities	Texas	Yes	Yes	Yes	No	November-April
Mid-Tex — Dallas	Texas	Yes	Yes	Yes	No	November-April
Mississippi	Mississippi	No	Yes	Yes	No	November-April
West Texas	Texas	Yes	Yes	Yes	No	October-May

7

(1)The rate base, authorized rate of return, authorized debt/equity ratio and authorized return on equity presented in this table are those from the most recent regulatory filing for each jurisdiction. These rate bases, rates of return, debt/equity ratios and returns on equity are not necessarily indicative of current or future rate bases, rates of return or returns on equity.

(2)The bad debt rider allows us to recover from customers the gas cost portion of customer accounts that have been written off.

(3)The performance-based rate program provides incentives to distribution companies to minimize purchased gas costs by allowing the companies and their customers to share the purchased gas costs savings.

(4)A rate base, rate of return, return on equity or debt/equity ratio was not included in the respective state commission’s final decision.

(5)The Mid-Tex rate base represents a “system-wide,” or 100 percent, of the Mid-Tex Division’s rate base.

(6)The Mid-Tex Cities approved the Formula Rate Mechanism filing with rates effective October 1, 2022, which included a rate base of $5,235.0 million, an authorized return of 7.28%, a debt/equity ratio of 42/58 and an authorized ROE of 9.80%.

(7)The Mississippi Public Service Commission approved a settlement at its meeting on October 4, 2022, which included a rate base of $915.6 million and an authorized return of 7.53%. New rates were implemented November 1, 2022.

(8)The West Texas Cities includes all West Texas Division cities except Amarillo, Lubbock, Dalhart and Channing (ALDC).

(9)The West Texas rate base represents a "system-wide," or 100 percent, of the West Texas Division's rate base.

(10)The West Texas Cities approved the Formula Rate Mechanism filing with rates effective October 1, 2022, which included a rate base of $855.3 million, an authorized return of 7.28%, a debt/equity ratio of 42/58 and an authorized ROE of 9.80%.

Although substantial progress has been made in recent years to improve rate design and recovery of investment across our service areas, we are continuing to seek improvements in rate design to address cost variations and pursue tariffs that reduce regulatory lag associated with investments. Further, potential changes in federal energy policy, federal safety regulations and changing economic conditions will necessitate continued vigilance by the Company and our regulators in meeting the challenges presented by these external factors.

Recent Ratemaking Activity

The amounts described in the following sections represent the annual 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 the commission's or other governmental authority's final ruling. 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. The following tables summarize the annualized ratemaking outcomes we implemented in each of the last three fiscal years.

Rate Action	Annual Increase (Decrease) in Operating Income		EDIT Impact		Annual Increase (Decrease) in Operating Income Excluding EDIT
	(In thousands)
2022 Filings:
Annual formula rate mechanisms	$	169,354	$	33,249	$	202,603
Rate case filings	5,938		7,379		13,317
Other ratemaking activity	(370)		—		(370)
Total 2022 Filings	$	174,922	$	40,628	$	215,550
2021 Filings:
Annual formula rate mechanisms	$	181,459	$	39,306	$	220,765
Rate case filings	5,119		1,168		6,287
Other ratemaking activity	(877)		—		(877)
Total 2021 Filings	$	185,701	$	40,474	$	226,175
2020 Filings:
Annual formula rate mechanisms	$	160,857	$	—	$	160,857
Rate case filings	(1,057)		—		(1,057)
Other ratemaking activity	353		—		353
Total 2020 Filings	$	160,153	$	—	$	160,153

8

The following ratemaking efforts seeking $144.5 million in annual operating income were initiated during fiscal 2022 but had not been completed or implemented as of September 30, 2022:

Division	Rate Action	Jurisdiction	Operating Income Requested
			(In thousands)
Colorado-Kansas	Rate Case	Colorado	$	7,554
Colorado-Kansas	Rate Case	Kansas	7,989
Kentucky/Mid-States	Infrastructure Mechanism	Virginia (1)	477
Kentucky/Mid-States	Infrastructure Mechanism	Kentucky (2)	1,904
Mid-Tex	Formula Rate Mechanism	Mid-Tex Cities (3)	92,615
Mississippi	Infrastructure Mechanism	Mississippi (4)	10,006
Mississippi	Formula Rate Mechanism	Mississippi (4)	15,700
West Texas	Formula Rate Mechanism	West Texas Cities (5)	8,208
			$	144,453

(1)     On August 12, 2022, the State Corporation Commission of Virginia approved a rate increase of $0.5 million effective October 1, 2022.

(2)    On August 12, 2022, the Kentucky Public Service Commission approved a rate increase of $1.9 million effective October 2, 2022, subject to refund.

(3)    The Mid-Tex Cities approved a rate increase of $81.4 million, which includes $(0.4) million related to the return of excess deferred income taxes that will be offset by lower income tax expense. New rates were implemented on October 1, 2022.

(4) The Mississippi Public Service Commission (MPSC) approved an increase in operating income of $8.6 million for the SIR filing. The MPSC also approved an increase in operating income of $12.2 million for the SRF filing, which includes $0.8 million related to the refund of excess deferred income taxes that will be offset by lower income tax expense. New rates for both filings were implemented November 1, 2022.

(5)    The West Texas Cities approved a rate increase of $7.3 million. New rates were implemented on October 1, 2022.

Our recent ratemaking activity is discussed in greater detail below.

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 specific infrastructure programs in 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.

9

The following table summarizes our annual formula rate mechanisms with effective dates during the fiscal years ended September 30, 2022, 2021 and 2020:

Division	Jurisdiction	Test Year Ended	Increase (Decrease) in Annual Operating Income		EDIT Impact		Increase (Decrease) in Annual Operating Income Excluding EDIT		Effective Date
					(In thousands)
2022 Filings:
Kentucky/Mid-States	Tennessee ARM	09/2021	$	2,466	$	—	$	2,466	07/01/2022
Louisiana	Louisiana (1)	12/2021	17,650		(10,389)		7,261		07/01/2022
West Texas	Amarillo, Lubbock, Dalhart and Channing	12/2021	6,122		—		6,122		06/11/2022
West Texas	Triangle	12/2021	1,549		—		1,549		06/11/2022
West Texas	Environs	12/2021	1,221		—		1,221		06/11/2022
Mid-Tex	ATM Cities	12/2021	12,815		—		12,815		06/10/2022
Mid-Tex	Environs	12/2021	5,646		—		5,646		06/10/2022
Mid-Tex	DARR (2)	09/2021	13,201		—		13,201		05/25/2022
Atmos Pipeline - Texas	Texas	12/2021	78,750		—		78,750		05/18/2022
Colorado-Kansas	Kansas SIP	12/2021	623		—		623		04/01/2022
Colorado-Kansas	Kansas GSRS	09/2021	1,820		—		1,820		02/01/2022
Colorado-Kansas	Colorado SSIR	12/2022	2,610		—		2,610		01/01/2022
Mid-Tex	Mid-Tex Cities RRM	12/2020	21,673		33,851		55,524		12/01/2021
West Texas	West Texas Cities RRM	12/2020	151		3,347		3,498		12/01/2021
Mississippi	Mississippi - SIR	10/2022	8,354		2,123		10,477		11/01/2021
Mississippi	Mississippi - SRF	10/2022	(5,624)		4,317		(1,307)		11/01/2021
Kentucky/Mid-States	Virginia - SAVE	09/2022	327		—		327		10/01/2021
Total 2022 Filings			$	169,354	$	33,249	$	202,603
2021 Filings:
Mid-Tex	Environs	12/2020	$	4,632	$	—	$	4,632	09/01/2021
Louisiana	Louisiana	12/2020	(2,407)		24,192		21,785		07/01/2021
Mid-Tex	ATM Cities (3)	12/2020	11,085		—		11,085		06/11/2021
West Texas	Triangle (3)	12/2020	416		—		416		06/11/2021
West Texas	Environs (3)	12/2020	1,267		—		1,267		06/11/2021
Mid-Tex	DARR (3)	09/2020	1,708		15,114		16,822		06/09/2021
Kentucky/Mid-States	Tennessee ARM	09/2020	10,260		—		10,260		06/01/2021
Atmos Pipeline - Texas	Texas	12/2020	43,868		—		43,868		05/11/2021
Colorado-Kansas	Kansas GSRS	09/2020	1,695		—		1,695		02/01/2021
Colorado-Kansas	Colorado SSIR	12/2021	2,366		—		2,366		01/01/2021
Mid-Tex	Mid-Tex Cities RRM	12/2019	82,645		—		82,645		12/01/2020
West Texas	West Texas Cities RRM	12/2019	5,645		—		5,645		12/01/2020
Mississippi	Mississippi - SIR	10/2021	10,556		—		10,556		11/01/2020
Mississippi	Mississippi - SRF	10/2021	5,856		—		5,856		11/01/2020
Kentucky/Mid-States	Virginia - SAVE	09/2021	305		—		305		10/01/2020
Kentucky/Mid-States	Kentucky PRP	09/2021	1,562		—		1,562		10/01/2020
Total 2021 Filings			$	181,459	$	39,306	$	220,765

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2020 Filings:
Mid-Tex	DARR	09/2019	$	14,746	$	—	$	14,746	09/01/2020
Louisiana	Louisiana	12/2019	14,781		—		14,781		07/01/2020
West Texas	Environs (4)	12/2019	1,031		—		1,031		06/16/2020
Kentucky/Mid-States	Tennessee ARM	05/2019	714		—		714		06/15/2020
Mid-Tex	ATM Cities (4)	12/2019	11,148		—		11,148		06/12/2020
Mid-Tex	Environs (4)	12/2019	4,440		—		4,440		05/20/2020
Atmos Pipeline - Texas	Texas	12/2019	49,251		—		49,251		05/20/2020
West Texas	Amarillo, Lubbock, Dalhart and Channing (4)	12/2019	5,937		—		5,937		04/28/2020
Colorado-Kansas	Colorado SSIR	12/2020	2,082		—		2,082		01/01/2020
Mississippi	Mississippi - SIR	10/2020	7,586		—		7,586		11/01/2019
Mississippi	Mississippi - SRF	10/2020	6,886		—		6,886		11/01/2019
Kentucky/Mid-States	Virginia - SAVE	09/2020	84		—		84		10/01/2019
Kentucky/Mid-States	Kentucky PRP	09/2020	2,912		—		2,912		10/01/2019
Mid-Tex	Mid-Tex RRM Cities	12/2018	34,380		—		34,380		10/01/2019
West Texas	West Texas Cities RRM	12/2018	4,879		—		4,879		10/01/2019
Total 2020 Filings			$	160,857	$	—	$	160,857

(1)    Rates were implemented on July 1, 2022, subject to refund.

(2)    The rate increase for this filing was approved based on the effective date herein; however, the new rates were implemented beginning September 1, 2022.

(3)    The rate increases for these filings were approved based on the effective dates herein; however, the new rates were implemented beginning September 1, 2021.

(4)    The rate increases for our Texas GRIP filings were approved based on the effective date herein; however, the new rates were implemented beginning September 1, 2020.

Rate Case Filings

A rate case is a formal request from Atmos Energy to a regulatory authority to increase rates that are charged to 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 reasonable rate of return to our shareholders and ensure that we continue to safely deliver reliable, reasonably priced natural gas service to our customers.

The following table summarizes our recent rate case activity during the fiscal years ended September 30, 2022, 2021 and 2020:

Division	State	Increase (Decrease) in Annual Operating Income		EDIT Impact		Increase (Decrease) in Annual Operating Income Excluding EDIT		Effective Date
				(In thousands)
2022 Rate Case Filings:
Kentucky/Mid-States	Kentucky (1)	$	5,938	$	7,379	$	13,317	05/20/2022
Total 2022 Rate Case Filings		$	5,938	$	7,379	$	13,317
2021 Rate Case Filings:
West Texas (ALDC)	Texas	$	5,119	$	1,168	$	6,287	06/01/2021
Total 2021 Rate Case Filings		$	5,119	$	1,168	$	6,287
2020 Rate Case Filings:
West Texas (Triangle)	Texas	$	(808)	$	—	$	(808)	04/21/2020
Colorado-Kansas	Kansas	(249)		—		(249)		04/01/2020
Total 2020 Rate Case Filings		$	(1,057)	$	—	$	(1,057)

(1)    The rate case outcome for Kentucky is inclusive of the fiscal 2022 pipeline replacement program.

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Other Ratemaking Activity

The following table summarizes other ratemaking activity during the fiscal years ended September 30, 2022, 2021 and 2020:

Division	Jurisdiction	Rate Activity	Increase (Decrease) in Annual Operating Income		Effective Date
			(In thousands)
2022 Other Rate Activity:
Colorado-Kansas	Kansas	Ad Valorem (1)	$	(370)	02/01/2022
Total 2022 Other Rate Activity			$	(370)
2021 Other Rate Activity:
Colorado-Kansas	Kansas	Ad Valorem (1)	$	(877)	02/01/2021
Total 2021 Other Rate Activity			$	(877)
2020 Other Rate Activity:
Colorado-Kansas	Kansas	Ad-Valorem (1)	$	353	02/01/2020
Total 2020 Other Rate Activity			$	353

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

Other Regulation

We are regulated by various state or local public utility authorities. We are also subject to regulation by the United States Department of Transportation with respect to safety requirements in the operation and maintenance of our transmission and distribution facilities. In addition, our operations are also subject to various state and federal laws regulating environmental matters. From time to time, we receive inquiries regarding various environmental matters. We believe that our properties and operations comply with, and are operated in conformity with, applicable safety and environmental statutes and regulations. There are no administrative or judicial proceedings arising under environmental quality statutes pending or known to be contemplated by governmental agencies which would have a material adverse effect on us or our operations. The Pipeline and Hazardous Materials Safety Administration (PHMSA), within the U.S. Department of Transportation, develops and enforces regulations for the safe, reliable and environmentally sound operation of the pipeline transportation system. The PHMSA pipeline safety statutes provide for states to assume safety authority over intrastate natural transmission and distribution gas pipelines. State pipeline safety programs are responsible for adopting and enforcing the federal and state pipeline safety regulations for intrastate natural gas transmission and distribution pipelines.

The Federal Energy Regulatory Commission (FERC) allows, pursuant to Section 311 of the Natural Gas Policy Act (NGPA), gas transportation services through our APT assets “on behalf of” interstate pipelines or local distribution companies served by interstate pipelines, without subjecting these assets to the jurisdiction of the FERC under the NGPA. Additionally, the FERC has regulatory authority over the use and release of interstate pipeline and storage capacity. The FERC also has authority to detect and prevent market manipulation and to enforce compliance with FERC’s other rules, policies and orders by companies engaged in the sale, purchase, transportation or storage of natural gas in interstate commerce. We have taken what we believe are the necessary and appropriate steps to comply with these regulations.

The SEC and the Commodities Futures Trading Commission, pursuant to the Dodd–Frank Act, established numerous regulations relating to U.S. financial markets. We enacted procedures and modified existing business practices and contractual arrangements to comply with such regulations. There are, however, some rulemaking proceedings that have not yet been finalized, including those relating to capital and margin rules for (non–cleared) swaps. We do not expect these rules to directly impact our business practices or collateral requirements. However, depending on the substance of these final rules, in addition to certain international regulatory requirements still under development that are similar to Dodd–Frank, our swap counterparties could be subject to additional and potentially significant capitalization requirements. These regulations could motivate counterparties to increase our collateral requirements or cash postings.

Competition

Although our regulated distribution operations are not currently in significant direct competition with any other distributors of natural gas to residential and commercial customers within our service areas, we do compete with other natural gas suppliers and suppliers of alternative fuels for sales to industrial customers. We compete in all aspects of our business with alternative energy sources, including, in particular, electricity. Electric utilities offer electricity as a rival energy source and compete for the space heating, water heating and cooking markets. Promotional incentives, improved equipment efficiencies

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and promotional rates all contribute to the acceptability of electrical equipment. The principal means to compete against alternative fuels is lower prices, and natural gas historically has maintained its price advantage in the residential, commercial and industrial markets.

Our pipeline and storage operations have historically faced competition from other existing intrastate pipelines seeking to provide or arrange transportation, storage and other services for customers. In the last few years, several new pipelines have been completed, which has increased the level of competition in this segment of our business.

Employees

The Corporate Responsibility, Sustainability, and Safety Committee of the Board of Directors oversees matters relating to equal employment opportunities, diversity, and inclusion; human workplace rights; employee health and safety; and the Company’s vision, values, and culture. It oversees the Company's policies, practices and procedures relating to sustainability to support the alignment of the Company's sustainability strategy with the Company's corporate strategy.

Part of our vision is to create a culture that respects and appreciates diversity. For this reason, we strive to have a workforce that reflects the communities we serve. At September 30, 2022, we had 4,791 employees, substantially unchanged from last year. We monitor our workforce data on a calendar year basis. As of December 31, 2021, 61 percent of our employees worked in field roles and 39 percent worked in support/shared services roles. No employees are subject to a collective bargaining agreement.

To recruit and hire individuals with a variety of skills, talents, backgrounds and experiences, we value and cultivate our strong relationships with hundreds of community and diversity outreach sources. We also target jobs fairs including those focused on minority, veteran and women candidates and partner with local colleges and universities to identify and recruit qualified applicants in each of the cities and towns we serve. Over the last five calendar years, we hired over 2,000 employees. Our culture is also reflected in our employee benefits. The physical, mental and financial health of our employees and their families is a top priority for the Company, which is why we have a strong, competitive benefits program to help employees and their families manage and protect their health, wealth and time.

We perform succession planning annually to ensure that we develop and sustain a strong bench of talent capable of performing at the highest levels. Not only is talent identified, but potential paths of development are discussed to ensure that employees have an opportunity to build their skills and are well-prepared for future roles. The strength of our succession planning process is evident through our long history of promoting our leaders from within the organization.

Available Information

Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and other reports, and amendments to those reports, and other forms that we file with or furnish to the Securities and Exchange Commission (SEC) at their website, www.sec.gov, are also available free of charge at our website, www.atmosenergy.com/company/publications-and-sec-filings, as soon as reasonably practicable, after we electronically file these reports with, or furnish these

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reports to, the SEC. We will also provide copies of these reports free of charge upon request to Shareholder Relations at the address and telephone number appearing below:

Shareholder Relations

Atmos Energy Corporation

P.O. Box 650205

Dallas, Texas 75265-0205

972-855-3729

Corporate Governance

In accordance with and pursuant to relevant related rules and regulations of the SEC as well as corporate governance-related listing standards of the New York Stock Exchange (NYSE), the Board of Directors of the Company has established and periodically updated our Corporate Governance Guidelines and Code of Conduct, which is applicable to all directors, officers and employees of the Company. In addition, in accordance with and pursuant to such NYSE listing standards, our Chief Executive Officer during fiscal 2022, John K. Akers, certified to the New York Stock Exchange that he was not aware of any violations by the Company of NYSE corporate governance listing standards. The Board of Directors also annually reviews and updates, if necessary, the charters for each of its Audit, Human Resources, Nominating and Corporate Governance and Corporate Responsibility, Sustainability and Safety Committees. All of the foregoing documents are posted on our website at www.atmosenergy.com/company/corporate-responsiblity-reports. We will also provide copies of all corporate governance documents free of charge upon request to Shareholder Relations at the address listed above.

ITEM 1A. Risk Factors.

Our financial and operating results are subject to a number of risk factors, many of which are not within our control. Investors should carefully consider the following discussion of risk factors as well as other information appearing in this report. These factors include the following, which are organized by category:

Regulatory and Legislative Risks

We are subject to federal, state and local regulations that affect our operations and financial results.

We are subject to regulatory oversight from various federal, state and local regulatory authorities in the eight states that we serve. Therefore, our returns are continuously monitored and are subject to challenge for their reasonableness by the appropriate regulatory authorities or other third-party intervenors. In the normal course of business, as a regulated entity, we often need to place assets in service and establish historical test periods before rate cases that seek to adjust our allowed returns to recover that investment can be filed. Further, the regulatory review process can be lengthy in the context of traditional ratemaking. Because of this process, we suffer the negative financial effects of having placed assets in service without the benefit of rate relief, which is commonly referred to as “regulatory lag.”

Regulatory authorities in the states we serve have approved various infrastructure and annual rate adjustment mechanisms to effectively reduce the regulatory lag inherent in the ratemaking process. Regulatory lag could significantly increase if the regulatory authorities modify or terminate these rate mechanisms. The regulatory process also involves the risk that regulatory authorities may (i) review our purchases of natural gas and adjust the amount of our gas costs that we pass through to our customers or (ii) limit or disallow the costs we may have incurred from our cost of service that can be recovered from customers.

We are also subject to laws, regulations and other legal requirements enacted or adopted by federal, state and local governmental authorities relating to protection of the environment and health and safety matters, including those that govern discharges of substances into the air and water, the management and disposal of hazardous substances and waste, the clean-up of contaminated sites, groundwater quality and availability, plant and wildlife protection, as well as work practices related to employee health and safety. Environmental legislation also requires that our facilities, sites and other properties associated with our operations be operated, maintained, abandoned and reclaimed to the satisfaction of applicable regulatory authorities. Failure to comply with these laws, regulations, permits and licenses may expose us to fines, penalties or interruptions in our operations that could be significant to our financial results. In addition, existing environmental regulations may be revised or our operations may become subject to new regulations.

Some of our operations are subject to increased federal regulatory oversight that could affect our operations and financial results.

FERC has regulatory authority over some of our operations, including the use and release of interstate pipeline and storage capacity. FERC has adopted rules designed to prevent market power abuse and market manipulation and to promote compliance with FERC’s other rules, policies and orders by companies engaged in the sale, purchase, transportation or storage of natural

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gas in interstate commerce. These rules carry increased penalties for violations. Although we have taken steps to structure current and future transactions to comply with applicable current FERC regulations, changes in FERC regulations or their interpretation by FERC or additional regulations issued by FERC in the future could also adversely affect our business, financial condition or financial results.

We may experience increased federal, state and local regulation of the safety of our operations.

The safety and protection of the public, our customers and our employees is our top priority. We constantly monitor and maintain our pipeline and distribution systems to ensure that natural gas is delivered safely, reliably and efficiently through our network of more than 75,000 miles of distribution and transmission lines. As in recent years, natural gas distribution and pipeline companies are continuing to encounter increasing federal, state and local oversight of the safety of their operations. Although we believe these are costs ultimately recoverable through our rates, the costs of complying with new laws and regulations may have at least a short-term adverse impact on our operating costs and financial results.

Operational Risks

We may incur significant costs and liabilities resulting from pipeline integrity and other similar programs and related repairs.

PHMSA requires pipeline operators to develop integrity management programs to comprehensively evaluate certain areas along their pipelines and to take additional measures to protect pipeline segments located in “high consequence areas” where a leak or rupture could potentially do the most harm. As a pipeline operator, the Company is required to:

•perform ongoing assessments of pipeline integrity;

•identify and characterize applicable threats to pipeline segments that could impact a “high consequence area”;

•improve data collection, integration and analysis;

•repair and remediate the pipeline as necessary; and

•implement preventative and mitigating actions.

The Company incurs significant costs associated with its compliance with existing PHMSA and comparable state regulations. Although we believe these are costs ultimately recoverable through our rates, the costs of complying with new laws and regulations may have at least a short-term adverse impact on our operating costs and financial results. For example, the adoption of new regulations requiring more comprehensive or stringent safety standards could require installation of new or modified safety controls, new capital projects, or accelerated maintenance programs, all of which could require a potentially significant increase in operating costs.

Distributing, transporting and storing natural gas involve risks that may result in accidents and additional operating costs.

Our operations involve a number of hazards and operating risks inherent in storing and transporting natural gas that could affect the public safety and reliability of our distribution system. While Atmos Energy, with the support from each of its regulatory commissions, is accelerating the replacement of pipeline infrastructure, operating issues such as leaks, accidents, equipment problems and incidents, including explosions and fire, could result in legal liability, repair and remediation costs, increased operating costs, significant increased capital expenditures, regulatory fines and penalties and other costs and a loss of customer confidence. We maintain liability and property insurance coverage in place for many of these hazards and risks. However, because some of our transmission pipeline and storage facilities are near or are in populated areas, any loss of human life or adverse financial results resulting from such events could be large. If these events were not fully covered by our general liability and property insurance, which policies are subject to certain limits and deductibles, our operations or financial results could be adversely affected.

If contracted gas supplies, interstate pipeline and/or storage services are not available or delivered in a timely manner, our ability to meet our customers’ natural gas requirements may be impaired and our financial condition may be adversely affected.

In order to meet our customers’ annual and seasonal natural gas demands, we must obtain a sufficient supply of natural gas, interstate pipeline capacity and storage capacity. If we are unable to obtain these, either from our suppliers’ inability to deliver the contracted commodity or the inability to secure replacement quantities, our financial condition and results of operations may be adversely affected. If a substantial disruption to or reduction in interstate natural gas pipelines’ transmission and storage capacity occurred due to operational failures or disruptions, legislative or regulatory actions, hurricanes, tornadoes, floods, extreme cold weather, terrorist or cyber-attacks or acts of war, our operations or financial results could be adversely affected.

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Our operations are subject to increased competition.

In residential and commercial customer markets, our distribution operations compete with other energy products, such as electricity and propane. Our primary product competition is with electricity for heating, water heating and cooking. Increases in the price of natural gas could negatively impact our competitive position by decreasing the price benefits of natural gas to the consumer. This could adversely impact our business if our customer growth slows or if our customers further conserve their use of gas, resulting in reduced gas purchases and customer billings.

In the case of industrial customers, such as manufacturing plants, adverse economic conditions, including higher gas costs, could cause these customers to use alternative sources of energy, such as electricity, or bypass our systems in favor of special competitive contracts with lower per-unit costs. Our pipeline and storage operations historically have faced limited competition from other existing intrastate pipelines and gas marketers seeking to provide or arrange transportation, storage and other services for customers. However, in the last few years, several new pipelines have been completed, which has increased the level of competition in this segment of our business.

Failure to attract and retain a qualified workforce could adversely affect our results of operations.

The competition for talent has become increasingly intense and we may experience increased employee turnover due to a tightening labor market. If we are unable to recruit and retain an appropriately qualified workforce, the Company could encounter operating challenges primarily due to a loss of institutional knowledge and expertise, errors due to inexperience, or the lengthy time period typically required to adequately train replacement personnel. In addition, higher costs could result from loss of productivity, increased safety compliance issues, or cost of contract labor.

Additionally, our ability to operate is contingent on maintaining a healthy workforce and a safe working environment. As a provider of essential services, we have an obligation to provide natural gas services to customers. Incidents of COVID-19 or any other future pandemic in our workforce could challenge the availability of our workforce which could threaten the continuity of our business operations.

Natural disasters, terrorist activities or other significant events could adversely affect our operations or financial results.

Natural disasters are always a threat to our assets and operations. In addition, the threat of terrorist activities could lead to increased economic instability and volatility in the price of natural gas that could affect our operations. Also, companies in our industry may face a heightened risk of exposure to actual acts of terrorism, which could subject our operations to increased risks. As a result, the availability of insurance covering such risks may become more limited, which could increase the risk that an event could adversely affect our operations or financial results.

Technology and Cybersecurity Risks

Increased dependence on technology may hinder the Company’s business operations and adversely affect its financial condition and results of operations if such technologies fail.

Over the last several years, the Company has implemented or acquired a variety of technological tools including both Company-owned information technology and technological services provided by outside parties. These tools and systems support critical functions including scheduling and dispatching of service technicians, automated meter reading systems, customer care and billing, operational plant logistics, management reporting and external financial reporting. The failure of these or other similarly important technologies, or the Company’s inability to have these technologies supported, updated, expanded, or integrated into other technologies, could hinder its business operations and adversely impact its financial condition and results of operations.

Although the Company has, when possible, developed alternative sources of technology and built redundancy into its computer networks and tools, there can be no assurance that these efforts would protect against all potential issues related to the loss of any such technologies.

Cyber-attacks or acts of cyber-terrorism 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.

Our business operations and information technology systems may be vulnerable to an attack by individuals or organizations intending to disrupt our business operations and information technology systems, even though the Company has implemented policies, procedures and controls to prevent and detect these activities. We use our information technology systems to manage our distribution and intrastate pipeline and storage operations and other business processes. Disruption of those systems could adversely impact our ability to safely deliver natural gas to our customers, operate our pipeline and storage systems or serve our customers timely. Accordingly, if such an attack or act of terrorism were to occur, our operations and financial results could be adversely affected.

In addition, we use our information technology systems to protect confidential or sensitive customer, employee and Company information developed and maintained in the normal course of our business. Any attack on such systems that would

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result in the unauthorized release of customer, employee or other confidential or sensitive data could have a material adverse effect on our business reputation, increase our costs and expose us to additional material legal claims and liability. Even though we have insurance coverage in place for many of these cyber-related risks, if such an attack or act of terrorism were to occur, our operations and financial results could be adversely affected to the extent not fully covered by such insurance coverage.

Compliance with and changes in cybersecurity requirements have a cost and operational impact on our business, and failure to comply with such laws and regulations could adversely impact our reputation, results of operations, financial condition and/or cash flows.

As cyber-attacks are becoming more sophisticated, U.S. government warnings have indicated that critical infrastructure assets, including pipeline infrastructure, may be specifically targeted by certain groups. In 2021, the Transportation Security Administration (TSA) announced two new security directives in response to a ransomware attack on the Colonial Pipeline that occurred earlier in the year. These directives require critical pipeline owners to comply with mandatory reporting measures, designate a cybersecurity coordinator, provide vulnerability assessments, and ensure compliance with certain cybersecurity requirements. Such directives or other requirements may require expenditure of significant additional resources to respond to cyber-attacks, to continue to modify or enhance protective measures, or to assess, investigate and remediate any critical infrastructure security vulnerabilities. Any failure to comply with such government regulations or failure in our cybersecurity protective measures may result in enforcement actions that may have a material adverse effect on our business, results of operations and financial condition. In addition, there is no certainty that costs incurred related to securing against threats will be recovered through rates.

Climate Risks

Adverse weather conditions could affect our operations or financial results.

We have weather-normalized rates for approximately 96 percent of our residential and commercial revenues in our distribution operations, which substantially mitigates the adverse effects of warmer-than-normal weather for meters in those service areas. However, there is no assurance that we will continue to receive such regulatory protection from adverse weather in our rates in the future. The loss of such weather-normalized rates could have an adverse effect on our operations and financial results. In addition, our operating results may continue to vary somewhat with the actual temperatures during the winter heating season. Additionally, sustained cold weather could challenge our ability to adequately meet customer demand in our operations.

Greenhouse gas emissions or other legislation or regulations intended to address climate change could increase our operating costs, adversely affecting our financial results, growth, cash flows and results of operations.

Six of the eight states in which we operate have passed legislation to block attempts by local governments to limit the types of energy available to customers. However, federal, regional and/or state legislative and/or regulatory initiatives may attempt to control or limit the causes of climate change, including greenhouse gas emissions, such as carbon dioxide and methane. Such laws or regulations could impose costs tied to greenhouse gas emissions, operational requirements or restrictions, or additional charges to fund energy efficiency activities. They could also provide a cost advantage to alternative energy sources, impose costs or restrictions on end users of natural gas, or result in other costs or requirements, such as costs associated with the adoption of new infrastructure and technology to respond to new mandates. The focus on climate change could adversely impact the reputation of fossil fuel products or services. The occurrence of the foregoing events could put upward pressure on the cost of natural gas relative to other energy sources, increase our costs and the prices we charge to customers, reduce the demand for natural gas or cause fuel switching to other energy sources, and impact the competitive position of natural gas and the ability to serve new or existing customers, adversely affecting our business, results of operations and cash flows.

The operations and financial results of the Company could be adversely impacted as a result of climate change.

As climate change occurs, our businesses could be adversely impacted. To the extent climate change results in temperatures that differ materially from temperatures we are currently experiencing, financial results could be adversely affected through lower gas volumes and revenues. Climate change could also cause shifts in population, including customers moving away from our service territories.

It could also result in more frequent and more severe weather events, such as hurricanes and tornadoes, which could increase our costs to repair damaged facilities and restore service to our customers or impact the cost of gas. If we were unable to deliver natural gas to our customers, our financial results would be impacted by lost revenues, and we generally would have to seek approval from regulators to recover restoration costs. To the extent we would be unable to recover those costs, or if higher rates resulting from our recovery of such costs would result in reduced demand for our services, our future business, financial condition or financial results could be adversely impacted.

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Financial, Economic and Market Risks

Our growth in the future may be limited by the nature of our business, which requires extensive capital spending.

Our operations are capital-intensive. We must make significant capital expenditures on a long-term basis to modernize our distribution and transmission system and to comply with the safety rules and regulations issued by the regulatory authorities responsible for the service areas we operate. In addition, we must continually build new capacity to serve the growing needs of the communities we serve. The magnitude of these expenditures may be affected by a number of factors, including new regulations, the general state of the economy and weather.

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. The cost and availability of borrowing funds from third party lenders or issuing equity is dependent on the liquidity of the credit markets, interest rates and other market conditions. This in turn may limit the amount of funds we can invest in our infrastructure.

The Company is dependent on continued access to the credit and capital markets to execute our business strategy.

Our long-term debt is currently rated as “investment grade” by Standard & Poor’s Corporation and Moody’s Investors Service, Inc. Similar to most companies, we rely upon access to both short-term and long-term credit and capital markets to satisfy our liquidity requirements. If adverse credit conditions were to cause a significant limitation on our access to the private credit and public capital markets, we could see a reduction in our liquidity. A significant reduction in our liquidity could in turn trigger a negative change in our ratings outlook or even a reduction in our credit ratings by one or more of the credit rating agencies. Such a downgrade could further limit our access to private credit and/or public capital markets and increase our costs of borrowing.

While we believe we can meet our capital requirements from our operations and the sources of financing available to us, we can provide no assurance that we will continue to be able to do so in the future, especially if the market price of natural gas increases significantly. The future effects on our business, liquidity and financial results of a deterioration of current conditions in the credit and capital markets could be material and adverse to us, both in the ways described above or in other ways that we do not currently anticipate.

We are exposed to market risks that are beyond our control, which could adversely affect our financial results.

We are subject to market risks beyond our control, including (i) commodity price volatility caused by market supply and demand dynamics, counterparty performance or counterparty creditworthiness and (ii) interest rate risk. We are generally insulated from commodity price risk through our purchased gas cost mechanisms. With respect to interest rate risk, increases in interest rates could adversely affect our future financial results to the extent that we do not recover our actual interest expense in our rates.

The concentration of our operations in the State of Texas exposes our operations and financial results to economic conditions, weather patterns and regulatory decisions in Texas.

Approximately 70 percent of our consolidated operations are located in the State of Texas. This concentration of our business in Texas means that our operations and financial results may be significantly affected by changes in the Texas economy in general, weather patterns and regulatory decisions by state and local regulatory authorities in Texas.

A deterioration in economic conditions could adversely affect our customers and negatively impact our financial results.

Any adverse changes in economic conditions in the states in which we operate could adversely affect the financial resources of many domestic households. As a result, our customers could seek to use less gas and it may be more difficult for them to pay their gas bills. This would likely lead to slower collections and higher than normal levels of accounts receivable. This, in turn, could increase our financing requirements. Additionally, should economic conditions deteriorate, our industrial customers could seek alternative energy sources, which could result in lower transportation volumes.

Increased gas costs could adversely impact our customer base and customer collections and increase our level of indebtedness.

Rapid increases in the costs of purchased gas would cause us to experience a significant increase in short-term or long-term debt. We must pay suppliers for gas when it is purchased, which can be significantly in advance of when these costs may be recovered through the collection of monthly customer bills for gas delivered. Increases in purchased gas costs also slow our natural gas distribution collections as customers are more likely to delay the payment of their gas bills, leading to higher than normal accounts receivable. This could result in higher short-term debt levels, greater collection efforts and increased bad debt expense.

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The costs of providing health care benefits, pension and postretirement health care benefits and related funding requirements may increase substantially.

We provide health care benefits, a cash-balance pension plan and postretirement health care benefits to eligible full-time employees. The costs of providing health care benefits to our employees could significantly increase over time due to rapidly increasing health care inflation, and any future legislative changes related to the provision of health care benefits. The impact of additional costs which are likely to be passed on to the Company is difficult to measure at this time.

The costs of providing a cash-balance pension plan to eligible full-time employees prior to 2011 and postretirement health care benefits to eligible full-time employees and related funding requirements could be influenced by changes in the market value of the assets funding our pension and postretirement health care plans. Any significant declines in the value of these investments due to sustained declines in equity markets or a reduction in bond yields could increase the costs of our pension and postretirement health care plans and related funding requirements in the future. Further, our costs of providing such benefits and related funding requirements are also subject to a number of factors, including (i) changing demographics, including longer life expectancy of beneficiaries and an expected increase in the number of eligible former employees over the next five to ten years; (ii) various actuarial calculations and assumptions which may differ materially from actual results due primarily to changing market and economic conditions, including changes in interest rates, and higher or lower withdrawal rates; and (iii) future government regulation.

The costs to the Company of providing these benefits and related funding requirements could also increase materially in the future, should there be a material reduction in the amount of the recovery of these costs through our rates or should significant delays develop in the timing of the recovery of such costs, which could adversely affect our financial results.

ITEM 1B. Unresolved Staff Comments.

Not applicable.

ITEM 2. Properties.

Distribution, transmission and related assets

At September 30, 2022, in our distribution segment, we owned an aggregate of 73,243 miles of underground distribution and transmission mains throughout our distribution systems. These mains are located on easements or rights-of-way. We maintain our mains through a program of continuous inspection and repair and believe that our system of mains is in good condition. Through our pipeline and storage segment we also owned 5,652 miles of gas transmission lines.

Storage Assets

We own underground gas storage facilities in several states to supplement the supply of natural gas in periods of peak demand. The following table summarizes certain information regarding our underground gas storage facilities at September 30, 2022:

State	Usable Capacity (Mcf)	Cushion Gas (Mcf)(1)	Total Capacity (Mcf)	Maximum Daily Delivery Capability (Mcf)
Distribution Segment
Kentucky	7,956,991	9,562,283	17,519,274	146,660
Kansas	3,239,000	2,300,000	5,539,000	32,000
Mississippi	1,907,571	2,442,917	4,350,488	29,136
Total	13,103,562	14,305,200	27,408,762	207,796
Pipeline and Storage Segment
Texas	46,083,549	15,878,025	61,961,574	1,710,000
Louisiana	411,040	256,900	667,940	56,000
Total	46,494,589	16,134,925	62,629,514	1,766,000
Total	59,598,151	30,440,125	90,038,276	1,973,796

(1)Cushion gas represents the volume of gas that must be retained in a facility to maintain reservoir pressure.

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Additionally, we contract for storage service in underground storage facilities on many of the interstate and intrastate pipelines serving us to supplement our proprietary storage capacity. The following table summarizes our contracted storage capacity at September 30, 2022:

Segment	Division/Company	Maximum Storage Quantity (MMBtu)	Maximum Daily Withdrawal Quantity (MDWQ)(1)
Distribution Segment
	Colorado-Kansas Division	6,343,728	147,965
	Kentucky/Mid-States Division	8,175,103	226,320
	Louisiana Division	2,594,875	177,765
	Mid-Tex Division	6,000,000	230,000
	Mississippi Division	5,299,536	202,764
	West Texas Division	5,000,000	161,000
Total		33,413,242	1,145,814
Pipeline and Storage Segment
	Trans Louisiana Gas Pipeline, Inc.	1,000,000	47,500
Total Contracted Storage Capacity		34,413,242	1,193,314

(1)Maximum daily withdrawal quantity (MDWQ) amounts will fluctuate depending upon the season and the month. Unless otherwise noted, MDWQ amounts represent the MDWQ amounts as of November 1, which is the beginning of the winter heating season.

ITEM 3. Legal Proceedings.

See Note 13 to the consolidated financial statements, which is incorporated in this Item 3 by reference.

ITEM 4. Mine Safety Disclosures.

Not applicable.

PART II

ITEM 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

Our stock trades on the New York Stock Exchange under the trading symbol “ATO.” The dividends paid per share of our common stock for fiscal 2022 and 2021 are listed below.

	Fiscal 2022		Fiscal 2021
Quarter ended:
December 31	$	0.680	$	0.625
March 31	0.680		0.625
June 30	0.680		0.625
September 30	0.680		0.625
	$	2.72	$	2.50

Dividends are payable at the discretion of our Board of Directors out of legally available funds. The Board of Directors typically declares dividends in the same fiscal quarter in which they are paid. As of October 31, 2022, there were 10,052 holders of record of our common stock. Future payments of dividends, and the amounts of these dividends, will depend on our financial condition, results of operations, capital requirements and other factors. We sold no securities during fiscal 2022 that were not registered under the Securities Act of 1933, as amended.

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Performance Graph

The performance graph and table below compares the yearly percentage change in our total return to shareholders for the last five fiscal years with the total return of the S&P 500 Stock Index (S&P 500) and the total return of the S&P 500 Utilities Industry Index. The graph and table below assume that $100.00 was invested on September 30, 2017 in our common stock, the S&P 500 and the S&P 500 Utilities Industry Index ax, as well as a reinvestment of dividends paid on such investments throughout the period.

Comparison of Five-Year Cumulative Total Return

among Atmos Energy Corporation, S&P 500 Index and

S&P 500 Utilities Industry Index

	Cumulative Total Return
	9/30/2017	9/30/2018	9/30/2019	9/30/2020	9/30/2021	9/30/2022
Atmos Energy Corporation	100.00	114.53	141.78	121.61	115.14	136.38
S&P 500 Stock Index	100.00	117.91	122.93	141.55	184.02	155.55
S&P 500 Utilities Stock Index	100.00	102.93	130.82	124.32	138.01	145.71

The following table sets forth the number of securities authorized for issuance under our equity compensation plans at September 30, 2022.

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	Number of securities to be issued upon exercise of outstanding options, warrants and rights		Weighted-average exercise price of outstanding options, warrants and rights		Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a))
	(a)		(b)		(c)
Equity compensation plans approved by security holders:
1998 Long-Term Incentive Plan	696,744	(1)	$	—	874,481
Total equity compensation plans approved by security holders	696,744		—		874,481
Equity compensation plans not approved by security holders	—		—		—
Total	696,744		$	—	874,481

(1)Comprised of a total of 301,403 time-lapse restricted stock units, 195,184 director share units and 200,157 performance-based restricted stock units at the target level of performance granted under our 1998 Long-Term Incentive Plan.

ITEM 6. Selected Financial Data.

No disclosure required by Regulation S-K.

ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

INTRODUCTION

This section provides management’s discussion of the financial condition, changes in financial condition and results of operations of Atmos Energy Corporation and its consolidated subsidiaries with specific information on results of operations and liquidity and capital resources. It includes management’s interpretation of our financial results, the factors affecting these results, the major factors expected to affect future operating results and future investment and financing plans. This discussion should be read in conjunction with our consolidated financial statements and notes thereto.

Several factors exist that could influence our future financial performance, some of which are described in Item 1A above, “Risk Factors”. They should be considered in connection with evaluating forward-looking statements contained in this report or otherwise made by or on behalf of us since these factors could cause actual results and conditions to differ materially from those set out in such forward-looking statements.

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

The statements contained in this Annual Report on Form 10-K may contain “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than statements of historical fact included in this Report are forward-looking statements made in good faith by us and are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. When used in this Report, or any other of our documents or oral presentations, the words “anticipate”, “believe”, “estimate”, “expect”, “forecast”, “goal”, “intend”, “objective”, “plan”, “projection”, “seek”, “strategy” or similar words are intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed or implied in the statements relating to our strategy, operations, markets, services, rates, recovery of costs, availability of gas supply and other factors. These risks and uncertainties include the following: federal, state and local regulatory and political trends and decisions, including the impact of rate proceedings before various state regulatory commissions; increased federal regulatory oversight and potential penalties; possible increased federal, state and local regulation of the safety of our operations; possible significant costs and liabilities resulting from pipeline integrity and other similar programs and related repairs; the inherent hazards and risks involved in distributing, transporting and storing natural gas; the availability and accessibility of contracted gas supplies, interstate pipeline and/or storage services; increased competition from energy suppliers and alternative forms of energy; failure to attract and retain a qualified workforce; natural disasters, terrorist activities or other events and other risks and uncertainties discussed herein, all of which are difficult to predict and many of which are beyond our control; increased dependence on technology that may hinder the Company's business if such technologies fail; the threat of cyber-attacks or acts of cyber-terrorism that could disrupt our business operations and information technology systems or result in the loss or exposure of confidential or sensitive customer, employee or Company information; the impact of new cybersecurity compliance requirements; adverse weather conditions; the impact of

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greenhouse gas emissions or other legislation or regulations intended to address climate change; the impact of climate change; the capital-intensive nature of our business; our ability to continue to access the credit and capital markets to execute our business strategy; market risks beyond our control affecting our risk management activities, including commodity price volatility, counterparty performance or creditworthiness and interest rate risk; the concentration of our operations in Texas; the impact of adverse economic conditions on our customers; changes in the availability and price of natural gas; and increased costs of providing health care benefits, along with pension and postretirement health care benefits and increased funding requirements. Accordingly, while we believe these forward-looking statements to be reasonable, there can be no assurance that they will approximate actual experience or that the expectations derived from them will be realized. Further, we undertake no obligation to update or revise any of our forward-looking statements whether as a result of new information, future events or otherwise.

CRITICAL ACCOUNTING POLICIES

Our 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 base our estimates on historical experience and various other assumptions that we believe to be reasonable under the circumstances. Actual results may differ from estimates.

Our significant accounting policies are discussed in Note 2 to our consolidated financial statements. The accounting policies discussed below are both important to the presentation of our financial condition and results of operations and require management to make difficult, subjective or complex accounting estimates. Accordingly, these critical accounting policies are reviewed periodically by the Audit Committee of the Board of Directors.

Critical Accounting Policy	Summary of Policy	Factors Influencing Application of the Policy
Regulation	Our distribution and pipeline operations meet the criteria of a cost-based, rate-regulated entity under accounting principles generally accepted in the United States. Accordingly, the financial results for these operations reflect the effects of the ratemaking and accounting practices and policies of the various regulatory commissions to which we are subject. As a result, certain costs that would normally be expensed under accounting principles generally accepted in the United States are permitted to be capitalized or deferred on the balance sheet because it is probable they can be recovered through rates. Further, regulation may impact the period in which revenues or expenses are recognized. The amounts expected to be recovered or recognized are based upon historical experience and our understanding of the regulations. Discontinuing the application of this method of accounting for regulatory assets and liabilities or changes in the accounting for our various regulatory mechanisms could significantly increase our operating expenses as fewer costs would likely be capitalized or deferred on the balance sheet, which could reduce our net income.	Decisions of regulatory authorities Issuance of new regulations or regulatory mechanisms Assessing the probability of the recoverability of deferred costs Continuing to meet the criteria of a cost-based, rate regulated entity for accounting purposes
Unbilled Revenue	We follow the revenue accrual method of accounting for distribution segment revenues whereby revenues attributable to gas delivered to customers, but not yet billed under the cycle billing method, are estimated and accrued and the related costs are charged to expense. When permitted, we implement rates that have not been formally approved by our regulatory authorities, subject to refund.We recognize this revenue and establish a reserve for amounts that could be refunded based on our experience for the jurisdiction in which the rates were implemented.	Estimates of delivered sales volumes based on actual tariff information and weather information and estimates of customer consumption and/or behavior Estimates of purchased gas costs related to estimated deliveries Estimates of amounts billed subject to refund

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Critical Accounting Policy	Summary of Policy	Factors Influencing Application of the Policy
Pension and other postretirement plans	Pension and other postretirement plan costs and liabilities are determined on an actuarial basis using a September 30 measurement date and are affected by numerous assumptions and estimates including the market value of plan assets, estimates of the expected return on plan assets, assumed discount rates and current demographic and actuarial mortality data. The assumed discount rate and the expected return are the assumptions that generally have the most significant impact on our pension costs and liabilities. The assumed discount rate, the assumed health care cost trend rate and assumed rates of retirement generally have the most significant impact on our postretirement plan costs and liabilities. The discount rate is utilized principally in calculating the actuarial present value of our pension and postretirement obligations and net periodic pension and postretirement benefit plan costs. When establishing our discount rate, we consider high quality corporate bond rates based on bonds available in the marketplace that are suitable for settling the obligations, changes in those rates from the prior year and the implied discount rate that is derived from matching our projected benefit disbursements with currently available high quality corporate bonds. The expected long-term rate of return on assets is utilized in calculating the expected return on plan assets component of our annual pension and postretirement plan costs. We estimate the expected return on plan assets by evaluating expected bond returns, equity risk premiums, asset allocations, the effects of active plan management, the impact of periodic plan asset rebalancing and historical performance. We also consider the guidance from our investment advisors in making a final determination of our expected rate of return on assets. To the extent the actual rate of return on assets realized over the course of a year is greater than or less than the assumed rate, that year’s annual pension or postretirement plan costs are not affected. Rather, this gain or loss reduces or increases future pension or postretirement plan costs over a period of approximately ten to twelve years. The market-related value of our plan assets represents the fair market value of the plan assets, adjusted to smooth out short-term market fluctuations over a five-year period. The use of this methodology will delay the impact of current market fluctuations on the pension expense for the period. We estimate the assumed health care cost trend rate used in determining our postretirement net expense based upon our actual health care cost experience, the effects of recently enacted legislation and general economic conditions. Our assumed rate of retirement is estimated based upon our annual review of our participant census information as of the measurement date.	General economic and market conditions Assumed investment returns by asset class Assumed future salary increases Assumed discount rate Projected timing of future cash disbursements Health care cost experience trends Participant demographic information Actuarial mortality assumptions Impact of legislation Impact of regulation
Impairment assessments	We review the carrying value of our long-lived assets, including goodwill and identifiable intangibles, whenever events or changes in circumstance indicate that such carrying values may not be recoverable, and at least annually for goodwill, as required by U.S. accounting standards. The evaluation of our goodwill balances and other long-lived assets or identifiable assets for which uncertainty exists regarding the recoverability of the carrying value of such assets involves the assessment of future cash flows and external market conditions and other subjective factors that could impact the estimation of future cash flows including, but not limited to the commodity prices, the amount and timing of future cash flows, future growth rates and the discount rate. Unforeseen events and changes in circumstances or market conditions could adversely affect these estimates, which could result in an impairment charge.	General economic and market conditions Projected timing and amount of future discounted cash flows Judgment in the evaluation of relevant data

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Non-GAAP Financial Measures

As described further in Note 14 to the consolidated financial statements, due to the passage of Kansas House Bill 2585, we remeasured our deferred tax liability and updated our state deferred tax rate. As a result, we recorded a non-cash income tax benefit of $21.0 million for the fiscal year ended September 30, 2020. Due to the non-recurring nature of this benefit, we believe that net income and diluted net income per share before the non-cash income tax benefit provide a more relevant measure to analyze our financial performance than net income and diluted net income per share in order to allow investors to better analyze our core results and allow the information to be presented on a comparative basis. Accordingly, the following discussion and analysis of our financial performance will reference adjusted net income and adjusted diluted earnings per share, non-GAAP measures, which are calculated as follows:

	For the Fiscal Year Ended September 30
	2022		2021		2020		2022 vs. 2021		2021 vs. 2020
	(In thousands, except per share data)
Net income	$	774,398	$	665,563	$	601,443	$	108,835	$	64,120
Non-cash income tax benefits	—		—		(20,962)		—		20,962
Adjusted net income	$	774,398	$	665,563	$	580,481	$	108,835	$	85,082
Diluted net income per share	$	5.60	$	5.12	$	4.89	$	0.48	$	0.23
Diluted EPS from non-cash income tax benefits	—		—		(0.17)		—		0.17
Adjusted diluted net income per share	$	5.60	$	5.12	$	4.72	$	0.48	$	0.40

RESULTS OF OPERATIONS

Overview

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

The following table details our consolidated net income by segment during the last three fiscal years:

	For the Fiscal Year Ended September 30
	2022		2021		2020
	(In thousands)
Distribution segment	$	521,977	$	445,862	$	395,664
Pipeline and storage segment	252,421		219,701		205,779
Net income	$	774,398	$	665,563	$	601,443

During fiscal 2022, we recorded net income of $774.4 million, or $5.60 per diluted share, compared to net income of $665.6 million, or $5.12 per diluted share in the prior year. The year-over-year increase in net income of $108.8 million largely reflects positive rate outcomes driven by safety and reliability spending and distribution customer growth, partially offset by an increase in employee related costs, increased spending on system maintenance activities and an increase in depreciation expense and property taxes associated with increased capital investments.

During the year ended September 30, 2022, we implemented ratemaking regulatory actions which resulted in an increase in annual operating income of $174.9 million. Excluding the impact of the refund of excess deferred income taxes resulting from previously enacted tax reform legislation, our total fiscal 2022 rate outcomes were $215.6 million. Additionally, we had ratemaking efforts in progress at September 30, 2022, seeking a total increase in annual operating income of $144.5 million.

During fiscal year 2022, we refunded $167.8 million in excess deferred tax liabilities to customers. The refunds reduced operating income and reduced our annual effective income tax rate to 9.1% in fiscal 2022 compared with 18.8% in fiscal 2021.

Capital expenditures for fiscal 2022 were $2.4 billion. Over 85 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 regulatory lag to six months or less.

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During fiscal 2022, we completed approximately $1.6 billion of long-term debt and equity financing. As of September 30, 2022, our equity capitalization was 53.6 percent. Excluding the $2.2 billion of incremental financing issued in conjunction with Winter Storm Uri, our equity capitalization was 61.3 percent. As of September 30, 2022, we had approximately $3.1 billion in total liquidity, consisting of $51.6 million in cash and cash equivalents, $776.6 million in funds available through equity forward sales agreements and $2,309.4 million in undrawn capacity under our credit facilities.

As a result of the continued stability of our earnings, cash flows and capital structure, our Board of Directors increased the quarterly dividend by 8.8% percent for fiscal 2023.

Distribution Segment

The distribution segment is primarily comprised of our regulated natural gas distribution and related sales operations in eight states. The primary factors that impact the results of our distribution operations 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 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. The “Ratemaking Activity” section of this Form 10-K describes our current rate strategy, progress towards implementing that strategy and recent ratemaking initiatives in more detail. During fiscal 2022, we completed regulatory proceedings in our distribution segment resulting in a $96.2 million increase in annual operating income. Excluding the impact of the refund of excess deferred income taxes resulting from previously enacted tax reform legislation, our total fiscal 2022 annualized rate outcomes in our distribution segment were $136.8 million.

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 81 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.

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Review of Financial and Operating Results

Financial and operational highlights for our distribution segment for the fiscal years ended September 30, 2022, 2021 and 2020 are presented below.

	For the Fiscal Year Ended September 30
	2022		2021		2020		2022 vs. 2021		2021 vs. 2020
	(In thousands, unless otherwise noted)
Operating revenues	$	4,035,194	$	3,241,973	$	2,626,993	$	793,221	$	614,980
Purchased gas cost	2,210,302		1,501,695		1,071,227		708,607		430,468
Operating expenses	1,220,347		1,121,764		1,027,523		98,583		94,241
Operating income	604,545		618,514		528,243		(13,969)		90,271
Other non-operating income (expense)	6,946		(20,694)		(1,265)		27,640		(19,429)
Interest charges	49,921		36,629		39,634		13,292		(3,005)
Income before income taxes	561,570		561,191		487,344		379		73,847
Income tax expense	39,593		115,329		105,147		(75,736)		10,182
Non-cash income tax benefit (1)	—		—		(13,467)		—		13,467
Net income	$	521,977	$	445,862	$	395,664	$	76,115	$	50,198
Consolidated distribution sales volumes — MMcf	292,266		308,833		291,650		(16,567)		17,183
Consolidated distribution transportation volumes — MMcf	152,709		152,513		147,387		196		5,126
Total consolidated distribution throughput — MMcf	444,975		461,346		439,037		(16,371)		22,309
Consolidated distribution average cost of gas per Mcf sold	$	7.56	$	4.86	$	3.67	$	2.70	$	1.19

(1)See Note 14 to the consolidated financial statements for further information.

Fiscal year ended September 30, 2022 compared with fiscal year ended September 30, 2021

Operating income for our distribution segment decreased two percent. Increased refunds of excess deferred taxes to customers decreased year-over-year operating income $98.5 million and reduced the effective income tax rate for this segment to 7.1% compared to 20.6% in the prior year. Additional key drivers for the change in operating income include:

•a $149.9 million increase in rate adjustments, primarily in our Mid-Tex, West Texas and Louisiana Divisions.

•a $15.2 million increase due to an increase in the number of customers served, primarily in our Mid-Tex Division.

•a $24.9 million decrease in bad debt expense, primarily due to the resumption of collection activities in late fiscal 2021 following the expiration of pandemic-related collection moratoriums.

Partially offset by:

•a $50.4 million increase in depreciation expense and property taxes associated with increased capital investments.

•a $17.3 million decrease in consumption, net of WNA, primarily due to the decline in residential consumption during the second fiscal quarter.

•an $8.8 million increase in system maintenance and related activities.

•a $25.5 million increase in employee related costs driven by increased headcount, increased number of service orders performed and higher benefits costs.

•an $8.9 million increase in insurance premiums.

The year-over-year change in other non-operating income (expense) of $27.6 million primarily reflects lower non-service costs related to our postretirement medical plan, partially offset by an increase in unrealized losses on equity investments. Interest charges increased $13.3 million due to the issuance of long-term debt during fiscal 2022 and interest expense recognized in fiscal 2022 related to debt incurred as a result of Winter Storm Uri. As described in Note 9 to the consolidated financial statements, interest related to the incremental financing incurred as a result of Winter Storm Uri was deferred through December 31, 2021 pursuant to a regulatory order issued by the State of Texas.

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The fiscal year ended September 30, 2021 compared with fiscal year ended September 30, 2020 for our distribution segment is described in Item 7 "Management's Discussion and Analysis of Financial Condition and Results of Operations" of our Annual Report on Form 10-K for the fiscal year ended September 30, 2021.

The following table shows our operating income by distribution division, in order of total rate base, for the fiscal years ended September 30, 2022, 2021 and 2020. The presentation of our distribution operating income is included for financial reporting purposes and may not be appropriate for ratemaking purposes.

	For the Fiscal Year Ended September 30
	2022		2021		2020		2022 vs. 2021		2021 vs. 2020
	(In thousands)
Mid-Tex	$	315,644	$	310,293	$	236,066	$	5,351	$	74,227
Kentucky/Mid-States	84,098		73,259		76,745		10,839		(3,486)
Louisiana	73,486		72,388		71,892		1,098		496
West Texas	53,604		51,104		52,493		2,500		(1,389)
Mississippi	65,947		65,337		55,938		610		9,399
Colorado-Kansas	26,000		32,778		34,039		(6,778)		(1,261)
Other	(14,234)		13,355		1,070		(27,589)		12,285
Total	$	604,545	$	618,514	$	528,243	$	(13,969)	$	90,271

Pipeline and Storage Segment

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

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

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

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

APT annually uses GRIP to recover capital costs incurred in the prior calendar year. On February 11, 2022, APT made a GRIP filing that covered changes in net property, plant and equipment investment from January 1, 2021 through December 31, 2021 with a requested increase in operating income of $78.8 million. On May 18, 2022, the Texas Railroad Commission approved the Company's GRIP filing.

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.

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Review of Financial and Operating Results

Financial and operational highlights for our pipeline and storage segment for the fiscal years ended September 30, 2022, 2021 and 2020 are presented below.

	For the Fiscal Year Ended September 30
	2022		2021		2020		2022 vs. 2021		2021 vs. 2020
	(In thousands, unless otherwise noted)
Mid-Tex / Affiliate transportation revenue	$	546,038	$	497,730	$	474,077	$	48,308	$	23,653
Third-party transportation revenue	136,907		127,874		127,444		9,033		430
Other revenue	10,715		11,743		7,818		(1,028)		3,925
Total operating revenues	693,660		637,347		609,339		56,313		28,008
Total purchased gas cost	(1,583)		1,582		1,548		(3,165)		34
Operating expenses	378,806		349,281		311,935		29,525		37,346
Operating income	316,437		286,484		295,856		29,953		(9,372)
Other non-operating income	26,791		18,549		8,436		8,242		10,113
Interest charges	52,890		46,925		44,840		5,965		2,085
Income before income taxes	290,338		258,108		259,452		32,230		(1,344)
Income tax expense	37,917		38,407		61,168		(490)		(22,761)
Non-cash income tax benefit (1)	—		—		(7,495)		—		7,495
Net income	$	252,421	$	219,701	$	205,779	$	32,720	$	13,922
Gross pipeline transportation volumes — MMcf	776,608		799,724		822,499		(23,116)		(22,775)
Consolidated pipeline transportation volumes — MMcf	580,488		585,857		621,371		(5,369)		(35,514)

(1)See Note 14 to the consolidated financial statements for further information.

Fiscal year ended September 30, 2022 compared with fiscal year ended September 30, 2021

Operating income for our pipeline and storage segment increased 10 percent. Increased refunds of excess deferred taxes to customers decreased year-over-year operating income by $13.3 million and reduced the effective income tax rate for this segment to 13.1% compared to 14.9% in the prior year. Additional drivers for the change in operating income include:

•a $70.4 million increase due to rate adjustments from GRIP filings approved in May 2021 and 2022. The increase in rates was driven by increased safety and reliability spending.

Partially offset by:

•an $8.4 million increase in system maintenance expense primarily due to spending on hydrostatic testing.

•a $15.4 million increase in depreciation expense and property taxes associated with increased capital investments.

The year-over-year change in other non-operating income and interest charges of $2.3 million reflects increased allowance for funds used during construction (AFUDC) primarily due to increased capital spending, partially offset by an increase in interest expense due to the issuance of long-term debt during fiscal 2022.

The fiscal year ended September 30, 2021 compared with fiscal year ended September 30, 2020 for our pipeline and storage segment is described in Item 7 "Management's Discussion and Analysis of Financial Condition and Results of Operations" of our Annual Report on Form 10-K for the fiscal year ended September 30, 2021.

INFLATION REDUCTION ACT OF 2022

In August 2022, the U.S. government enacted the Inflation Reduction Act of 2022 (the Inflation Reduction Act) into law. The Inflation Reduction Act includes a new corporate alternative minimum tax (the Corporate AMT) of 15% on the adjusted financial statement income (AFSI) of corporations with average AFSI exceeding $1.0 billion over a three-year period. We currently anticipate this tax will apply to us within the next four to five years. The impact on our financial position, results of operations and cash flows is dependent on future guidance from the U.S. government. Also, the Inflation Reduction Act imposes a methane emissions charge for methane emissions in excess of 25,000 metric tons carbon dioxide equivalent per year. Based on our preliminary evaluation of the regulations, we currently do not anticipate this provision of the Inflation Reduction Act will have a material impact on our financial position, results of operations or cash flows. Additionally, the Inflation

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Reduction Act imposes an excise tax of 1% tax on the fair market value of net stock repurchases made after December 31, 2022. The impact of this provision will be dependent on the extent of share repurchases made in future periods.

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 $2.5 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 with an equity-to-total-capitalization ratio between 50% and 60%, inclusive of long-term and short-term debt. Additionally, we have various uncommitted trade credit lines with our gas suppliers that we utilize to purchase natural gas on a monthly basis.

We have a shelf registration statement on file with the Securities and Exchange Commission (SEC) that allows us to issue up to $5.0 billion in common stock and/or debt securities. As of the date of this report, approximately $1.4 billion of securities remained available for issuance under the shelf registration statement, which expires June 29, 2024.

We also have an at-the-market (ATM) equity sales program that allows us to issue and sell shares of our common stock up to an aggregate offering price of $1.0 billion (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 June 29, 2024. At September 30, 2022, approximately $481.7 million of equity is available for issuance under this ATM equity sales program. Additionally, as of September 30, 2022, we had $776.6 million in available proceeds from outstanding forward sale agreements.

On September 27, 2022, we settled $500 million of forward starting interest rate swaps associated with a planned debt issuance that was completed on October 3, 2022. The following table summarizes our existing forward starting interest rate swaps as of September 30, 2022.

Planned Debt Issuance Date	Amount Hedged		Effective Interest Rate
	(In thousands)
Fiscal 2024	$	450,000	1.80	%
Fiscal 2025	600,000		1.75	%
Fiscal 2026	300,000		2.16	%
	$	1,350,000

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

The following table presents our capitalization as of September 30, 2022 and 2021:

	September 30
	2022				2021
	(In thousands, except percentages)
Short-term debt	$	184,967	1.1	%	$	—	—	%
Long-term debt (1)	7,962,104		45.3	%	7,330,657		48.1	%
Shareholders’ equity (2)	9,419,091		53.6	%	7,906,889		51.9	%
Total capitalization, including short-term debt	$	17,566,162	100.0	%	$	15,237,546	100.0	%

(1)Inclusive of our finance leases.

(2)Excluding the $2.2 billion of incremental financing issued to pay for the purchased gas costs incurred during Winter Storm Uri, our equity capitalization ratio would have been 61.3% and 60.6% at September 30, 2022 and 2021.

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, the demand for such products and services, margin requirements resulting from significant changes in commodity prices, operational risks and other factors.

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Cash flows from operating, investing and financing activities for the years ended September 30, 2022, 2021 and 2020 are presented below.

	For the Fiscal Year Ended September 30
	2022		2021		2020		2022 vs. 2021		2021 vs. 2020
	(In thousands)
Total cash provided by (used in)
Operating activities	$	977,584	$	(1,084,251)	$	1,037,999	$	2,061,835	$	(2,122,250)
Investing activities	(2,429,958)		(1,963,655)		(1,925,518)		(466,303)		(38,137)
Financing activities	1,387,205		3,143,821		883,777		(1,756,616)		2,260,044
Change in cash and cash equivalents	(65,169)		95,915		(3,742)		(161,084)		99,657
Cash and cash equivalents at beginning of period	116,723		20,808		24,550		95,915		(3,742)
Cash and cash equivalents at end of period	$	51,554	$	116,723	$	20,808	$	(65,169)	$	95,915

Cash flows for the fiscal year ended September 30, 2021 compared with fiscal year ended September 30, 2020 is described in Item 7 "Management's Discussion and Analysis of Financial Condition and Results of Operations" of our Annual Report on Form 10-K for the fiscal year ended September 30, 2021.

Cash flows from operating activities

For the fiscal year ended September 30, 2022, cash flow provided by operating activities was $977.6 million compared with cash flow used in operating activities of $1.1 billion in the prior year. Fiscal 2021 operating cash flow included $2.1 billion of cash paid for gas costs incurred during Winter Storm Uri. Excluding this cash outflow, operating cash flow in fiscal 2021 was $996.1 million. The year-over-year decrease in operating cash flow reflects the refund of excess deferred tax liabilities, increased purchases of gas stored underground and the timing of gas cost recoveries, partially offset by increased customer collections and the positive effects of successful rate case outcomes achieved in fiscal 2021 and 2022.

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 88 percent of our capital spending has been committed to improving the safety and reliability of our system.

For the fiscal year ended September 30, 2022, we had $2.4 billion in capital expenditures compared with $2.0 billion for the fiscal year ended September 30, 2021. Capital spending increased by $474.9 million, or 24 percent, as a result of planned increases to modernize our system.

Cash flows from financing activities

Our financing activities provided $1.4 billion and $3.1 billion in cash for fiscal years 2022 and 2021.

During the fiscal year ended September 30, 2022, we received $1.6 billion in net proceeds from the issuance of long-term debt and equity. We completed a public offering of $600 million of 2.85% senior notes due 2052. We also completed a public offering of $200 million of 2.625% senior notes due 2029 that were used to repay our $200 million floating-rate term loan. Additionally, during the year ended September 30, 2022, we settled 7,907,833 shares that had been sold on a forward basis for net proceeds of $776.8 million. The net proceeds were used primarily to support capital spending and for other general corporate purposes. We also received $197.1 million from the settlement of forward starting interest rate swaps related to a debt issuance completed in October 2022. Additionally, cash dividends increased due to an 8.8 percent increase in our dividend rate and an increase in shares outstanding.

During the fiscal year ended September 30, 2021, we received $3.4 billion in net proceeds from the issuance of long-term debt and equity. We completed a public offering of $600 million of 1.50% senior notes due 2031, $1.1 billion of 0.625% senior notes due 2023 and $1.1 billion floating rate senior notes due 2023. Net proceeds from the latter two notes were used to pay for gas costs incurred during Winter Storm Uri. Additionally, during the year ended September 30, 2021, we settled 6,130,875 shares that had been sold on a forward basis for net proceeds of $606.7 million. The net proceeds were used primarily to support capital spending and for other general corporate purposes, including the payment of natural gas purchases. Additionally, cash dividends increased due to an 8.7 percent increase in our dividend rate and an increase in shares outstanding.

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The following table shows the number of shares issued for the fiscal years ended September 30, 2022, 2021 and 2020:

	For the Fiscal Year Ended September 30
	2022	2021	2020
Shares issued:
Direct Stock Purchase Plan	68,693	79,921	107,989
Retirement Savings Plan and Trust	72,339	84,265	78,941
1998 Long-Term Incentive Plan (LTIP)	427,929	242,216	254,706
Equity Issuance (1)	7,907,883	6,130,875	6,101,916
Total shares issued	8,476,844	6,537,277	6,543,552

(1)Share amounts do not include shares issued under forward sale agreements until the shares have been settled.

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 operating cash flow less dividends to debt. In addition, the rating agencies consider qualitative factors such as consistency of our earnings over time, the risks associated with our business 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). As a result of the impacts of Winter Storm Uri, during the second quarter of fiscal 2021, S&P lowered our long-term and short-term credit ratings by one notch and placed our ratings under negative outlook. Additionally, Moody's placed our ratings under negative outlook. In February 2022, Moody’s reaffirmed its long-term and short-term credit ratings and revised our outlook from negative to stable.

As of September 30, 2022, our outlook and current 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	Negative	Stable

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 September 30, 2022. Our debt covenants are described in Note 7 to the consolidated financial statements.

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Contractual Obligations and Commercial Commitments

The following table provides information about contractual obligations and commercial commitments at September 30, 2022.

	Payments Due by Period
	Total		Less than 1 year		1-3 years		3-5 years		More than 5 years
					(In thousands)
Contractual Obligations
Long-term debt (1)	$	7,960,000	$	2,200,000	$	—	$	510,000	$	5,250,000
Short-term debt (1)	184,967		184,967		—		—		—
Interest charges (2)	4,098,799		232,370		423,684		422,487		3,020,258
Finance leases (3)	73,193		3,313		6,813		7,070		55,997
Operating leases (4)	259,835		43,104		63,631		38,393		114,707
Financial instrument obligations (5)	4,129		3,000		1,129		—		—
Pension and postretirement benefit plan contributions (6)	359,479		35,636		91,664		63,831		168,348
Uncertain tax positions (7)	52,683		—		52,683		—		—
Total contractual obligations	$	12,993,085	$	2,702,390	$	639,604	$	1,041,781	$	8,609,310

(1)Long-term and short-term debt excludes our finance lease obligations, which are separately reported within this table. See Note 7 to the consolidated financial statements for further details.

(2)Interest charges were calculated using the effective rate for each debt issuance through the contractual maturity date.

(3)Finance lease payments shown above include interest totaling $21.3 million. See Note 6 to the consolidated financial statements.

(4)Operating lease payments shown above include interest totaling $36.9 million. See Note 6 to the consolidated financial statements.

(5)Represents liabilities for natural gas commodity financial instruments that were valued as of September 30, 2022. The ultimate settlement amounts of these remaining liabilities are unknown because they are subject to continuing market risk until the financial instruments are settled.

(6)Represents expected contributions to our defined benefit and postretirement benefit plans, which are discussed in Note 10 to the consolidated financial statements.

(7)Represents liabilities associated with uncertain tax positions claimed or expected to be claimed on tax returns. The amount does not include interest and penalties that may be applied to these positions. See Note 14 to the consolidated financial statements for further details.

We 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 individual contracts. 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 market and fixed prices. At September 30, 2022, we were committed to purchase 55.6 Bcf within one year and 89.1 Bcf within two to three years under indexed contracts. At September 30, 2022, we were committed to purchase 13.2 Bcf within one year under fixed price contracts with a weighted average price of $5.39 per Mcf.

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 entering into financial instruments to effectively fix the Treasury yield component of the interest cost associated with anticipated financings.

We record our financial instruments as a component of risk management assets and liabilities, which are classified as current or noncurrent based upon the anticipated settlement date of the underlying financial instrument. Substantially all of our financial instruments are valued using external market quotes and indices.

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The following table shows the components of the change in fair value of our financial instruments for the fiscal year ended September 30, 2022 (in thousands):

Fair value of contracts at September 30, 2021	$	225,417
Contracts realized/settled	(167,683)
Fair value of new contracts	2,998
Other changes in value	317,130
Fair value of contracts at September 30, 2022	377,862
Netting of cash collateral	—
Cash collateral and fair value of contracts at September 30, 2022	$	377,862

The fair value of our financial instruments at September 30, 2022, is presented below by time period and fair value source:

	Fair Value of Contracts at September 30, 2022
	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	$	23,207	$	290,267	$	64,388	$	—	$	377,862
Prices based on models and other valuation methods	—		—		—		—		—
Total Fair Value	$	23,207	$	290,267	$	64,388	$	—	$	377,862

RECENT ACCOUNTING DEVELOPMENTS

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

ITEM 7A. Quantitative and Qualitative Disclosures About Market Risk.

We are exposed to risks associated with commodity prices and interest rates. Commodity price risk is the potential loss that we may incur as a result of changes in the fair value of a particular instrument or commodity. Interest-rate risk is the potential increased cost we could incur when we issue debt instruments or to provide financing and liquidity for our business activities. Additionally, interest-rate risk could affect our ability to issue cost effective equity instruments.

We conduct risk management activities in our distribution and pipeline and storage segments. In our distribution segment, we use 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. Our risk management activities and related accounting treatment are described in further detail in Note 15 to the consolidated financial statements. Additionally, our earnings are affected by changes in short-term interest rates as a result of our issuance of short-term commercial paper and our other short-term borrowings.

Commodity Price Risk

We purchase natural gas for our distribution operations. Substantially all of the costs of gas purchased for distribution operations are recovered from our customers through purchased gas cost adjustment mechanisms. Therefore, our distribution operations have limited commodity price risk exposure.

Interest Rate Risk

Our earnings are exposed to changes in short-term interest rates associated with our short-term commercial paper program and other short-term borrowings. We use a sensitivity analysis to estimate our short-term interest rate risk. For purposes of this analysis, we estimate our short-term interest rate risk as the difference between our actual interest expense for the period and estimated interest expense for the period assuming a hypothetical average one percent increase in the interest rates associated with our short-term borrowings. Had interest rates associated with our short-term borrowings increased by an average of one percent, our interest expense would not have materially increased during 2022.

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ITEM 8. Financial Statements and Supplementary Data.

Index to financial statements and financial statement schedules:

	Page
Report of independent registered public accounting firm (PCAOB ID: 42)	36
Financial statements and supplementary data:
Consolidated balance sheets at September 30, 2022 and 2021	38
Consolidated statements of comprehensive income for the years ended September 30, 2022, 2021 and 2020	39
Consolidated statements of shareholders' equity for the years ended September 30, 2022, 2021 and 2020	40
Consolidated statements of cash flow for the years ended September 30, 2022, 2021 and 2020	41
Notes to consolidated financial statements	42

All financial statement schedules are omitted because the required information is not present, or not present in amounts sufficient to require submission of the schedule or because the information required is included in the financial statements and accompanying notes thereto.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholders and the Board of Directors of Atmos Energy Corporation

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of Atmos Energy Corporation (the Company) as of September 30, 2022 and 2021, the related consolidated statements of comprehensive income, shareholders’ equity and cash flows for each of the three years in the period ended September 30, 2022, and the related notes (collectively referred to as the "consolidated financial statements"). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company at September 30, 2022 and 2021, and the results of its operations and its cash flows for each of the three years in the period ended September 30, 2022, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of September 30, 2022, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) and our report dated November 14, 2022 expressed an unqualified opinion thereon.

Basis for Opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. 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 Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matter

The critical audit matter communicated below is a matter arising from the current period audit of the financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of the critical audit matter does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

Determination of Capital Costs

Description of the Matter

As more fully described in Note 2 to the financial statements, the Company capitalizes the direct and indirect costs of construction. Once a project is completed, it is placed into service and included in the Company’s rate base. Costs of maintenance and repairs that are not included in the Company’s rate base are charged to expense. For the year ended September 30, 2022, the Company capitalized approximately $2.4 billion of construction-related costs for regulated property, plant and equipment. Auditing management’s identification of capital additions and maintenance and repairs expense involved significant effort and auditor judgment. These amounts have both a higher magnitude and a higher likelihood of potential misstatement. As a cost-based, rate-regulated entity, the rates charged to customers are designed to recover the entity’s costs and provide a rate of return on rate base. Net property, plant and equipment is the most significant component of the Company’s rate base. As a result, inappropriate capitalization of costs could affect the amount, timing and classification of revenues and expenses in the financial statements.

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How We Addressed the Matter in Our Audit We obtained an understanding, evaluated the design and tested the operating effectiveness of the Company’s controls over the initial determination and approval of expenditures for either capital additions or maintenance and repair. For example, we selected a sample of projects initiated during the year to evaluate the effectiveness of management’s review controls to determine the proper categorization of project expenditures as either capitalizable costs or current-period expense. Our audit procedures included, among others, testing a sample of projects initiated during the year, including the evaluation of the nature of the project, with Company personnel outside of accounting and financial reporting. For example, we evaluated project setup through inspection of each project’s description for compliance with the Company’s capitalization policy as described in Note 2 and a series of inquiries of the project approver to understand how they assessed whether projects should be treated as capital or expense. Other audit procedures included evaluating whether the descriptions and amounts included on third-party invoices either support or contradict the project classification as capital, evaluating the appropriateness of individuals capitalizing direct labor charges to projects by assessing the relevance of their job function to the capital project, and recalculating other overhead costs capitalized to projects.

/s/ Ernst & Young LLP

We have served as the Company’s auditor since 1983.

Dallas, Texas

November 14, 2022

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ATMOS ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

	September 30
	2022		2021
	(In thousands, except share data)
ASSETS
Property, plant and equipment	$	19,402,271	$	17,258,547
Construction in progress	835,868		626,551
	20,238,139		17,885,098
Less accumulated depreciation and amortization	2,997,900		2,821,128
Net property, plant and equipment	17,240,239		15,063,970
Current assets
Cash and cash equivalents	51,554		116,723
Accounts receivable, less allowance for uncollectible accounts of $49,993 in 2022 and $64,471 in 2021	363,708		342,967
Gas stored underground	357,941		178,116
Other current assets (See Note 9)	2,274,490		2,200,909
Total current assets	3,047,693		2,838,715
Goodwill	731,257		731,257
Deferred charges and other assets (See Note 9)	1,173,800		974,720
	$	22,192,989	$	19,608,662
CAPITALIZATION AND LIABILITIES
Shareholders’ equity
Common stock, no par value (stated at $0.005 per share); 200,000,000 shares authorized; issued and outstanding: 2022 — 140,896,598 shares; 2021 — 132,419,754 shares	$	704	$	662
Additional paid-in capital	5,838,118		5,023,751
Accumulated other comprehensive income	369,112		69,803
Retained earnings	3,211,157		2,812,673
Shareholders’ equity	9,419,091		7,906,889
Long-term debt	5,760,647		4,930,205
Total capitalization	15,179,738		12,837,094
Commitments and contingencies (See Note 13)
Current liabilities
Accounts payable and accrued liabilities	496,019		423,222
Other current liabilities	720,157		686,681
Short-term debt	184,967		—
Current maturities of long-term debt	2,201,457		2,400,452
Total current liabilities	3,602,600		3,510,355
Deferred income taxes	1,999,505		1,705,809
Regulatory excess deferred taxes (See Note 14)	385,213		549,227
Regulatory cost of removal obligation	487,631		468,688
Deferred credits and other liabilities	538,302		537,489
	$	22,192,989	$	19,608,662

See accompanying notes to consolidated financial statements.

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ATMOS ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Year Ended September 30
	2022		2021		2020
	(In thousands, except per share data)
Operating revenues
Distribution segment	$	4,035,194	$	3,241,973	$	2,626,993
Pipeline and storage segment	693,660		637,347		609,339
Intersegment eliminations	(527,192)		(471,830)		(415,195)
Total operating revenues	4,201,662		3,407,490		2,821,137
Purchased gas cost
Distribution segment	2,210,302		1,501,695		1,071,227
Pipeline and storage segment	(1,583)		1,582		1,548
Intersegment eliminations	(526,063)		(470,560)		(413,921)
Total purchased gas cost	1,682,656		1,032,717		658,854
Operation and maintenance expense	710,161		679,019		629,601
Depreciation and amortization expense	535,655		477,977		429,828
Taxes, other than income	352,208		312,779		278,755
Operating income	920,982		904,998		824,099
Other non-operating income (expense)	33,737		(2,145)		7,171
Interest charges	102,811		83,554		84,474
Income before income taxes	851,908		819,299		746,796
Income tax expense	77,510		153,736		145,353
Net income	$	774,398	$	665,563	$	601,443
Basic net income per share	$	5.61	$	5.12	$	4.89
Diluted net income per share	$	5.60	$	5.12	$	4.89
Weighted average shares outstanding:
Basic	137,830		129,779		122,788
Diluted	138,096		129,834		122,872
Net income	$	774,398	$	665,563	$	601,443
Other comprehensive income (loss), net of tax
Net unrealized holding gains (losses) on available-for-sale securities, net of tax of $(157), $(55) and $32	(542)		(191)		106
Cash flow hedges:
Amortization and unrealized gains on interest rate agreements, net of tax of $86,664, $36,875 and $17,198	299,851		127,583		56,888
Total other comprehensive income	299,309		127,392		56,994
Total comprehensive income	$	1,073,707	$	792,955	$	658,437

See accompanying notes to consolidated financial statements.

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ATMOS ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY

	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, 2019	119,338,925	$	597	$	3,712,194	$	(114,583)	$	2,152,015	$	5,750,223
Net income	—	—		—		—		601,443		601,443
Other comprehensive income	—	—		—		56,994		—		56,994
Cash dividends ($2.30 per share)	—	—		—		—		(282,444)		(282,444)
Common stock issued:
Public offering	6,101,916	30		624,272		—		—		624,302
Direct stock purchase plan	107,989	1		11,325		—		—		11,326
Retirement savings plan	78,941	—		8,222		—		—		8,222
1998 Long-term incentive plan	254,706	1		2,748		—		—		2,749
Employee stock-based compensation	—	—		18,388		—		—		18,388
Balance, September 30, 2020	125,882,477	629		4,377,149		(57,589)		2,471,014		6,791,203
Net income	—	—		—		—		665,563		665,563
Other comprehensive income	—	—		—		127,392		—		127,392
Cash dividends ($2.50 per share)	—	—		—		—		(323,904)		(323,904)
Common stock issued:
Public offering	6,130,875	31		606,636		—		—		606,667
Direct stock purchase plan	79,921	—		7,715		—		—		7,715
Retirement savings plan	84,265	1		8,125		—		—		8,126
1998 Long-term incentive plan	242,216	1		3,091		—		—		3,092
Employee stock-based compensation	—	—		21,035		—		—		21,035
Balance, September 30, 2021	132,419,754	662		5,023,751		69,803		2,812,673		7,906,889
Net income	—	—		—		—		774,398		774,398
Other comprehensive income	—	—		—		299,309		—		299,309
Cash dividends ($2.72 per share)	—	—		—		—		(375,914)		(375,914)
Common stock issued:
Public offering	7,907,883	40		776,765		—		—		776,805
Direct stock purchase plan	68,693	—		7,495		—		—		7,495
Retirement savings plan	72,339	—		7,908		—		—		7,908
1998 Long-term incentive plan	427,929	2		2,396		—		—		2,398
Employee stock-based compensation	—	—		19,803		—		—		19,803
Balance, September 30, 2022	140,896,598	$	704	$	5,838,118	$	369,112	$	3,211,157	$	9,419,091

See accompanying notes to consolidated financial statements.

40

ATMOS ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Year Ended September 30
	2022		2021		2020
	(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	774,398	$	665,563	$	601,443
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	535,655		477,977		429,828
Deferred income taxes	53,651		155,355		155,322
One-time income tax benefit	—		—		(20,962)
Stock-based compensation	10,743		11,255		9,583
Amortization of debt issuance costs	9,141		14,030		11,543
Equity component of AFUDC	(45,505)		(32,749)		(23,493)
Other	3,265		3,731		8,411
Changes in assets and liabilities:
(Increase) decrease in accounts receivable	(34,325)		(113,665)		7,167
(Increase) decrease in gas stored underground	(179,825)		(66,166)		18,188
Increase in Winter Storm Uri current regulatory asset (see Note 9)	—		(2,003,659)		—
Increase in other current assets	(65,979)		(84,705)		(35,878)
Increase in Winter Storm Uri long-term regulatory asset (see Note 9)	—		(76,652)		—
(Increase) decrease in deferred charges and other assets	13,287		136,809		(31,935)
Increase in accounts payable and accrued liabilities	40,394		104,242		7,359
Decrease in other current liabilities	(152,274)		(166,268)		(129,543)
Increase (decrease) in deferred credits and other liabilities	14,958		(109,349)		30,966
Net cash provided by (used in) operating activities	977,584		(1,084,251)		1,037,999
CASH FLOWS USED IN INVESTING ACTIVITIES
Capital expenditures	(2,444,420)		(1,969,540)		(1,935,676)
Purchases of debt and equity securities	(28,285)		(49,879)		(50,517)
Proceeds from sale of debt and equity securities	4,872		14,957		32,339
Maturities of debt securities	27,586		28,850		18,669
Other, net	10,289		11,957		9,667
Net cash used in investing activities	(2,429,958)		(1,963,655)		(1,925,518)
CASH FLOWS FROM FINANCING ACTIVITIES
Net increase (decrease) in short-term debt	184,967		—		(464,915)
Proceeds from issuance of long-term debt, net of premium/discount	798,802		2,797,346		999,450
Net proceeds from equity offering	776,805		606,667		624,302
Issuance of common stock through stock purchase and employee retirement plans	15,403		15,841		19,548
Settlement of interest rate swaps	197,073		62,159		(4,426)
Repayment of long-term debt	(200,000)		—		—
Cash dividends paid	(375,914)		(323,904)		(282,444)
Debt issuance costs	(8,196)		(14,288)		(7,738)
Other	(1,735)		—		—
Net cash provided by financing activities	1,387,205		3,143,821		883,777
Net increase (decrease) in cash and cash equivalents	(65,169)		95,915		(3,742)
Cash and cash equivalents at beginning of year	116,723		20,808		24,550
Cash and cash equivalents at end of year	$	51,554	$	116,723	$	20,808

See accompanying notes to consolidated financial statements.

41

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

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. Through our distribution business, we deliver natural gas through sales and transportation arrangements to approximately 3.3 million residential, commercial, public-authority and industrial customers through our six regulated distribution divisions in the service areas described below:

Division	Service Area
Atmos Energy Colorado-Kansas Division	Colorado, Kansas
Atmos Energy Kentucky/Mid-States Division	Kentucky, Tennessee, Virginia (1)
Atmos Energy Louisiana Division	Louisiana
Atmos Energy Mid-Tex Division	Texas, including the Dallas/Fort Worth metropolitan area
Atmos Energy Mississippi Division	Mississippi
Atmos Energy West Texas Division	West Texas

 

(1)Denotes location where we have more limited service areas.

In addition, we transport natural gas for others through our distribution system. Our distribution business is subject to federal and state regulation and/or regulation by local authorities in each of the states in which our distribution divisions operate. Our corporate headquarters and shared-services function are located in Dallas, Texas, and our customer support centers are located in Amarillo and Waco, Texas.

Our pipeline and storage business, which is also subject to federal and state regulation, consists of the pipeline and storage operations of our Atmos Pipeline–Texas (APT) Division and our natural gas transmission business in Louisiana. The APT division 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. As part of its pipeline operations, APT manages five underground storage facilities in Texas. We also provide ancillary services customary to the pipeline industry including parking arrangements, lending and sales of inventory on hand. 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.

2.    Summary of Significant Accounting Policies

Principles of consolidation — The accompanying consolidated financial statements include the accounts of Atmos Energy Corporation and its wholly-owned subsidiaries. All material intercompany transactions have been eliminated; however, we have not eliminated intercompany profits when such amounts are probable of recovery under the affiliates’ rate regulation process.

Use of estimates — The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses. The most significant estimates include the allowance for doubtful accounts, unbilled revenues, contingency accruals, pension and postretirement obligations, deferred income taxes, impairment of long-lived assets, risk management and trading activities, fair value measurements and the valuation of goodwill and other long-lived assets. Actual results could differ from those estimates.

Regulation — Our distribution and pipeline and storage operations are subject to regulation with respect to rates, service, maintenance of accounting records and various other matters by the respective regulatory authorities in the states in which we operate. Our accounting policies recognize the financial effects of the ratemaking and accounting practices and policies of the various regulatory commissions. 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. The amounts to be recovered or recognized are based upon historical experience and our understanding of the regulations. Further, regulation may impact the period in which revenues or expenses are recognized.

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

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

liabilities. Deferred gas costs are recorded either in other current assets or liabilities and the long-term portion of regulatory excess deferred taxes and regulatory cost of removal obligation are reported separately. Significant regulatory assets and liabilities as of September 30, 2022 and 2021 included the following:

	September 30
	2022		2021
	(In thousands)
Regulatory assets:
Pension and postretirement benefit costs	$	31,122	$	45,922
Infrastructure mechanisms (1)	235,972		222,795
Winter Storm Uri incremental costs (2)	2,109,454		2,100,728
Deferred gas costs	119,742		66,395
Regulatory excess deferred taxes (3)	47,311		45,370
Recoverable loss on reacquired debt	3,406		3,789
Deferred pipeline record collection costs	36,898		32,099
Other	21,467		4,343
	$	2,605,372	$	2,521,441
Regulatory liabilities:
Regulatory excess deferred taxes (3)	$	545,021	$	705,084
Regulatory cost of removal obligation	568,307		541,511
Deferred gas costs	28,834		52,553
Asset retirement obligation	5,737		18,373
APT annual adjustment mechanism	31,138		31,110
Pension and postretirement benefit costs	156,857		56,201
Other	23,013		19,363
	$	1,358,907	$	1,424,195

(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 the deferred expenses until the next rate proceeding (rate case or annual rate filing), at which time investment and costs would be recovered through base rates.

(2)Includes extraordinary gas costs incurred during Winter Storm Uri and related carrying costs. See Note 9 to the consolidated financial statements for further information. This amount is recorded within other current assets and deferred charges and other assets on the consolidated balance sheet as of September 30, 2022 and 2021.

(3)Regulatory excess deferred taxes represent changes in our net deferred tax liability related to our cost of service ratemaking due to the enactment of the Tax Cuts and Jobs Act of 2017 (the "TCJA") and a Kansas legislative change enacted in fiscal 2020. See Notes 12 and 14 to the consolidated financial statements for further information.

Revenue recognition

Distribution Revenues

Distribution revenues represent the delivery of natural gas to residential, commercial, industrial and public authority customers at prices based on tariff rates established by regulatory authorities in the states in which we operate. Revenue is recognized and our performance obligation is satisfied over time when natural gas is delivered and simultaneously consumed by our customers. We have elected to use the invoice practical expedient and recognize revenue for volumes delivered that we have the right to invoice our customers. We bill our customers on a monthly cycle basis. Accordingly, we estimate volumes from the last meter read to the balance sheet date and accrue revenue for gas delivered but not yet billed.

In our Texas and Mississippi jurisdictions, we pay franchise fees and gross receipt taxes to operate in these service areas. These franchise fees and gross receipts taxes are required to be paid regardless of our ability to collect from our customers. Accordingly, we account for these amounts on a gross basis in revenue and we record the associated tax expense as a component of taxes, other than income.

Pipeline and Storage Revenues

Pipeline and storage revenues primarily represent the transportation and storage of natural gas on our APT system and the transmission of natural gas through our 21-mile pipeline in Louisiana. APT provides transportation and storage services to our

43

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Mid-Tex Division, other third party local distribution companies and certain industrial customers under tariff rates approved by the RRC. APT also provides certain transportation and storage services to industrial and electric generation customers, as well as marketers and producers, under negotiated rates. Our pipeline in Louisiana is primarily used to aggregate gas supply for our Louisiana Division under a long-term contract and on a more limited basis to third parties. The demand fee charged to our Louisiana Division is subject to regulatory approval by the Louisiana Public Service Commission. We also manage two asset management plans with distribution affiliates of the Company at terms that have been approved by the applicable state regulatory commissions. The performance obligations for these transportation customers are satisfied by means of transporting customer-supplied gas to the designated location. Revenue is recognized and our performance obligation is satisfied over time when natural gas is delivered to the customer. Management determined that these arrangements qualify for the invoice practical expedient for recognizing revenue. For demand fee arrangements, revenue is recognized and our performance obligation is satisfied by standing ready to transport natural gas over the period of each individual month.

Alternative Revenue Program Revenues

In our distribution segment, we have weather-normalization adjustment mechanisms that serve to minimize the effects of weather on our residential and commercial revenues. Additionally, 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 of $69.4 million that was established in its most recent rate case. Differences between actual revenues and revenues calculated under these mechanisms adjust the amount billed to customers. These mechanisms are considered to be alternative revenue programs under accounting standards generally accepted in the United States as they are deemed to be contracts between us and our regulator. Accordingly, revenue under these mechanisms are excluded from revenue from contracts with customers.

Purchased gas costs — Rates established by regulatory authorities are adjusted for increases and decreases in our purchased gas costs through purchased gas cost adjustment mechanisms. There is no margin generated through purchased gas cost adjustments, but they provide a dollar-for-dollar offset to increases or decreases in our distribution segment’s gas costs. The effects of these purchased gas cost adjustment mechanisms are recorded as deferred gas costs on our consolidated balance sheets.

Cash and cash equivalents — We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.

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. The receivable balances are short term and generally do not extend beyond one month.

On October 1, 2020, we adopted new accounting guidance which requires credit losses on our accounts receivable to be measured using an expected credit loss model over the entire contractual term from the date of initial recognition. To minimize credit risk, we assess the credit worthiness of new customers, require deposits where necessary, assess late fees, pursue collection activities and disconnect service for nonpayment. After disconnection, accounts are written off when deemed uncollectible. At each reporting period, we assess the allowance for uncollectible accounts based on historical experience, current conditions and consideration of expected future conditions. Circumstances which could affect our estimates include, but are not limited to, customer credit issues, the level of natural gas prices, customer deposits and general economic conditions.

Gas stored underground — Our gas stored underground is comprised of natural gas injected into storage to support the winter season withdrawals for our distribution operations. The average cost method is used for all of our distribution operations. Gas in storage that is retained as cushion gas to maintain reservoir pressure is classified as property, plant and equipment and is valued at cost.

Property, plant and equipment — Regulated property, plant and equipment is stated at original cost, net of contributions in aid of construction. The cost of additions includes direct construction costs, payroll related costs (taxes, the service cost portion of pension expense and other benefits), administrative and general costs and an allowance for funds used during construction (AFUDC). AFUDC represents the capitalizable total cost of funds used to finance the construction of major projects.

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The following table details amounts capitalized for the fiscal year ended September 30.

		2022		2021		2020
Component of AFUDC	Statement of Comprehensive Income Location	(In thousands)
Debt	Interest charges	$	12,153	$	11,414	$	8,436
Equity	Other non-operating income (expense)	45,505		32,749		23,493
		$	57,658	$	44,163	$	31,929

Major renewals, including replacement pipe, and betterments that are recoverable through our regulatory rate base are capitalized while the costs of maintenance and repairs that are not capitalizable are charged to expense as incurred. The costs of large projects are accumulated in construction in progress until the project is completed. When the project is completed, tested and placed in service, the balance is transferred to the regulated plant in service account included in the rate base and depreciation begins.

Regulated property, plant and equipment is depreciated at various rates on a straight-line basis. These rates are approved by our regulatory commissions and are comprised of two components: one based on average service life and one based on cost of removal. Accordingly, we recognize our cost of removal expense as a component of depreciation expense. The related cost of removal accrual is reflected as a regulatory liability on the consolidated balance sheet. At the time property, plant and equipment is retired, removal expenses less salvage, are charged to the regulatory cost of removal accrual. The composite depreciation rate was 3.0 percent for the fiscal years ended September 30, 2022, 2021 and 2020.

Other property, plant and equipment is stated at cost. Depreciation is generally computed on the straight-line method for financial reporting purposes based upon estimated useful lives.

Asset retirement obligations — We record a liability at fair value for an asset retirement obligation when the legal obligation to retire the asset has been incurred with an offsetting increase to the carrying value of the related asset.

We believe we have a legal obligation to retire our natural gas storage facilities. However, we have not recognized an asset retirement obligation associated with our storage facilities because we are not able to determine the settlement date of this obligation as we do not anticipate taking our storage facilities out of service permanently. Therefore, we cannot reasonably estimate the fair value of this obligation.

Impairment of long-lived assets — We evaluate whether events or circumstances have occurred that indicate that other long-lived assets may not be recoverable or that the remaining useful life may warrant revision. When such events or circumstances are present, we assess the recoverability of long-lived assets by determining whether the carrying value will be recovered through the expected future cash flows. In the event the sum of the expected future cash flows resulting from the use of the asset is less than the carrying value of the asset, an impairment loss equal to the excess of the asset’s carrying value over its fair value is recorded.

Goodwill — We annually evaluate our goodwill balances for impairment during our second fiscal quarter or more frequently as impairment indicators arise. During the second quarter of fiscal 2022, we completed our annual goodwill impairment assessment. We test goodwill for impairment at the reporting unit level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of the reporting unit. Based on the assessment performed, we determined that our goodwill was not impaired. Although not applicable for the fiscal 2022 analysis, if a qualitative goodwill assessment resulted in impairment indicators, we would then use a present value technique based on discounted cash flows to estimate the fair value of our reporting units. These calculations are dependent on several subjective factors including the timing of future cash flows, future growth rates and the discount rate. An impairment charge is recognized if the carrying value of a reporting unit’s goodwill exceeds its fair value.

Lease accounting — We adopted the provisions of the new lease accounting standard beginning on October 1, 2019. Results for reporting periods beginning on October 1, 2019 are presented under the new lease accounting standard and prior periods are presented under the former lease accounting standard. Upon adoption, we recorded right of use (ROU) assets and lease liabilities within the consolidated balance sheet.

We determine if an arrangement is a lease at the inception of the agreement based on the terms and conditions in the contract. A contract contains a lease if there is an identified asset and we have the right to control the asset. We are the lessee for substantially all of our leasing activities, which primarily includes operating leases for office and warehouse space, tower space, vehicles and heavy equipment used in our operations. We are also a lessee in finance leases for certain service centers.

We record a lease liability and a corresponding ROU asset for all of our leases with a term greater than 12 months. For lease contracts containing renewal and termination options, we include the option period in the lease term when it is reasonably

45

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

certain the option will be exercised. We most frequently assume renewal options at the inception of the arrangement for our tower and fleet leases, based on our anticipated use of the assets. Real estate leases that contain a renewal option are evaluated on a lease-by-lease basis to determine if the option period should be included in the lease term. Currently, we have not included material renewal options for real estate leases in our ROU asset or lease liability.

The lease liability represents the present value of all lease payments over the lease term. We do not include short-term leases in the calculation of our lease liabilities. The discount rate used to determine the present value of the lease liability is the rate implicit in the lease unless that rate cannot be readily determined. We use the implicit rate stated in the agreement to determine the lease liability for our fleet leases. We use our corporate collateralized incremental borrowing rate as the discount rate for all other lease agreements. This rate is appropriate because we believe it represents the rate we would have incurred to borrow funds to acquire the leased asset over a similar term. We calculated this rate using a combination of inputs, including our current credit rating, quoted market prices of interest rates for our publicly traded unsecured debt, observable market yield curve data for peer companies with a credit rating one notch higher than our current credit rating and the lease term.

The ROU asset represents the right to use the underlying asset for the lease term, and is equal to the lease liability, adjusted for prepaid or accrued lease payments and any lease incentives that have been paid to us or when we are reasonably certain to incur costs equal to or greater than the allowance defined in the contract. We bundle our lease and non-lease components as a single component for all asset classes.

Variable payments included in our leasing arrangements are expensed in the period in which the obligation for these payments is incurred. Variable payments are dependent on usage, output or may vary for other reasons. Most of our variable lease expense is related to tower leases that have escalating payments based on changes to a stated CPI index, and usage of certain office equipment.

We have not provided material residual value guarantees for our leases, nor do our leases contain material restrictions or covenants.

Marketable securities — As of September 30, 2022, we hold marketable securities classified as either equity or debt securities. Changes in fair value of our equity securities are recorded in net income, while debt securities, which are considered available-for-sale securities, are reported at market value with unrealized gains and losses shown as a component of accumulated other comprehensive income (loss).

On October 1, 2020, we adopted new accounting guidance that introduced an impairment recognition model for available-for-sale debt securities that requires credit losses to be recorded through an allowance account. We regularly evaluate the performance of our available-for-sale debt securities on an investment by investment basis for impairment, taking into consideration the securities’ purpose, volatility and current returns. If a determination is made that a security will likely be sold before the recovery of its cost, the related investment is written down to its estimated fair value.

Financial instruments and hedging activities — We use financial instruments to mitigate commodity price risk in our distribution and pipeline and storage segments and to mitigate interest rate risk. The objectives and strategies for using financial instruments have been tailored to our business and are discussed in Note 15 to the consolidated financial statements.

We record all of our financial instruments on the balance sheet at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery, with changes in fair value ultimately recorded in the statement of comprehensive income. These financial instruments are reported as risk management assets and liabilities and are classified as current or noncurrent other assets or liabilities based upon the anticipated settlement date of the underlying financial instrument. We record the cash flow impact of our financial instruments in operating cash flows based upon their balance sheet classification.

The timing of when changes in fair value of our financial instruments are recorded in the statement of comprehensive income depends on whether the financial instrument has been designated and qualifies as a part of a hedging relationship or if regulatory rulings require a different accounting treatment. Changes in fair value for financial instruments that do not meet one of these criteria are recognized in the statement of comprehensive income as they occur.

Financial Instruments Associated with Commodity Price Risk

In our distribution segment, the costs associated with and the realized gains and losses arising from the use of financial instruments to mitigate commodity price risk are included in our purchased gas cost adjustment mechanisms in accordance with regulatory requirements. Therefore, changes in the fair value of these financial instruments are initially recorded as a component of deferred gas costs and recognized in the consolidated statements of comprehensive income as a component of purchased gas cost when the related costs are recovered through our rates and recognized in revenue in accordance with accounting principles generally accepted in the United States. Accordingly, there is no earnings impact on our distribution segment as a result of the use of these financial instruments.

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Financial Instruments Associated with Interest Rate Risk

In connection with the planned issuance of long-term debt, we may use financial instruments to manage interest rate risk. We currently manage this risk through the use of forward starting interest rate swaps to fix the Treasury yield component of the interest cost associated with anticipated financings. We designate these financial instruments as cash flow hedges at the time the agreements are executed. Unrealized gains and losses associated with the instruments are recorded as a component of accumulated other comprehensive income (loss). When the instruments settle, the realized gain or loss is recorded as a component of accumulated other comprehensive income (loss) and recognized as a component of interest charges over the life of the related financing arrangement. As of September 30, 2022 and 2021, no cash was required to be held in margin accounts.

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 primarily use quoted market prices and other observable market pricing information in valuing our financial assets and liabilities and minimize the use of unobservable pricing inputs in our measurements.

Fair-value estimates also consider our own creditworthiness and the creditworthiness of the counterparties involved. Our counterparties consist primarily of financial institutions and major energy companies. This concentration of counterparties may materially impact our exposure to credit risk resulting from market, economic or regulatory conditions. We seek to minimize counterparty credit risk through an evaluation of their financial condition and credit ratings and the use of collateral requirements under certain circumstances.

Amounts reported at fair value are subject to potentially significant volatility based upon changes in market prices, including, but not limited to, the valuation of the portfolio of our contracts, maturity and settlement of these contracts and newly originated transactions and interest rates, each of which directly affect the estimated fair value of our financial instruments. We believe the market prices and models used to value these financial instruments represent the best information available with respect to closing exchange and over-the-counter quotations, time value and volatility factors underlying the contracts. Values are adjusted to reflect the potential impact of an orderly liquidation of our positions over a reasonable period of time under then current market conditions.

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) and the lowest priority given to unobservable inputs (Level 3). The levels of the hierarchy are described below:

Level 1 — Represents unadjusted quoted prices in active markets for identical assets or liabilities. An active market for the asset or liability is defined as a market in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis. Prices actively quoted on national exchanges are used to determine the fair value of most of our assets and liabilities recorded on our balance sheet at fair value.

Our Level 1 measurements consist primarily of our debt and equity securities. The Level 1 measurements for investments in the Atmos Energy Corporation Master Retirement Trust (the Master Trust), Supplemental Executive Benefit Plan and postretirement benefit plan consist primarily of exchange-traded financial instruments.

Level 2 — Represents pricing inputs other than quoted prices included in Level 1 that are either directly or indirectly observable for the asset or liability as of the reporting date. These inputs are derived principally from, or corroborated by, observable market data. Our Level 2 measurements primarily consist of non-exchange-traded financial instruments, such as over-the-counter options and swaps and municipal and corporate bonds where market data for pricing is observable. The Level 2 measurements for investments in our Master Trust, Supplemental Executive Benefit Plan and postretirement benefit plan consist primarily of non-exchange traded financial instruments such as corporate bonds and government securities.

Level 3 — Represents generally unobservable pricing inputs which are developed based on the best information available, including our own internal data, in situations where there is little if any market activity for the asset or liability at the measurement date. The pricing inputs utilized reflect what a market participant would use to determine fair value. We currently do not have any Level 3 investments.

Pension and other postretirement plans — Pension and other postretirement plan costs and liabilities are determined on an actuarial basis and are affected by numerous assumptions and estimates including the market value of plan assets, estimates of the expected return on plan assets, assumed discount rates and current demographic and actuarial mortality data. Our measurement date is September 30. The assumed discount rate and the expected return are the assumptions that generally have the most significant impact on our pension costs and liabilities. The assumed discount rate, the assumed health care cost trend rate and assumed rates of retirement generally have the most significant impact on our postretirement plan costs and liabilities.

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ATMOS ENERGY CORPORATION

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The discount rate is utilized principally in calculating the actuarial present value of our pension and postretirement obligation and net pension and postretirement cost. When establishing our discount rate, we consider high quality corporate bond rates based on bonds available in the marketplace that are suitable for settling the obligations, changes in those rates from the prior year and the implied discount rate that is derived from matching our projected benefit disbursements with currently available high quality corporate bonds.

The expected long-term rate of return on assets is utilized in calculating the expected return on plan assets component of the annual pension and postretirement plan cost. We estimate the expected return on plan assets by evaluating expected bond returns, equity risk premiums, asset allocations, the effects of active plan management, the impact of periodic plan asset rebalancing and historical performance. We also consider the guidance from our investment advisors when making a final determination of our expected rate of return on assets. To the extent the actual rate of return on assets realized over the course of a year is greater than or less than the assumed rate, that year’s annual pension or postretirement plan cost is not affected. Rather, this gain or loss is amortized over the expected future working lifetime of the plan participants.

The expected return on plan assets is then calculated by applying the expected long-term rate of return on plan assets to the market-related value of the plan assets. The market-related value of our plan assets represents the fair market value of the plan assets, adjusted to smooth out short-term market fluctuations over a five-year period. The use of this calculation will delay the impact of current market fluctuations on the pension expense for the period.

We use a corridor approach to amortize actuarial gains and losses. Under this approach, net gains or losses in excess of ten percent of the larger of the pension benefit obligation or the market-related value of the assets are amortized on a straight-line basis. The period of amortization is the average remaining service of active participants who are expected to receive benefits under the plan.

We estimate the assumed health care cost trend rate used in determining our annual postretirement net cost based upon our actual health care cost experience, the effects of recently enacted legislation and general economic conditions. Our assumed rate of retirement is estimated based upon the annual review of our participant census information as of the measurement date.

We present only the current service cost component of the net benefit cost within operations and maintenance expense in the consolidated statements of comprehensive income. The remaining components of net benefit cost are recorded in other non-operating income (expense) in our consolidated statements of comprehensive income. Only the service cost component of net benefit cost is eligible for capitalization and we continue to capitalize these costs into property, plant and equipment. Additionally, we defer into a regulatory asset the portion of non-service components of net periodic benefit cost that are capitalizable for regulatory purposes.

Income taxes — Income taxes are determined based on the liability method, which results in income tax assets and liabilities arising from temporary differences. Temporary differences are differences between the tax bases of assets and liabilities and their reported amounts in the financial statements that will result in taxable or deductible amounts in future years. The liability method requires the effect of tax rate changes on accumulated deferred income taxes to be reflected in the period in which the rate change was enacted. The liability method also requires that deferred tax assets be reduced by a valuation allowance unless it is more likely than not that the assets will be realized.

The Company may recognize the tax benefit from uncertain tax positions only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the financial statements from such a position should be measured based on the largest benefit that has a greater than fifty percent likelihood of being realized upon settlement with the taxing authorities. We recognize accrued interest related to unrecognized tax benefits as a component of interest charges. We recognize penalties related to unrecognized tax benefits as a component of miscellaneous income (expense) in accordance with regulatory requirements.

Tax collections — We are allowed to recover from customers revenue-related taxes that are imposed upon us. We record such taxes as operating expenses and record the corresponding customer charges as operating revenues. However, we do collect and remit various other taxes on behalf of various governmental authorities, and we record these amounts in our consolidated balance sheets on a net basis. We do not collect income taxes from our customers on behalf of governmental authorities.

Contingencies — In the normal course of business, we are confronted with issues or events that may result in a contingent liability. These generally relate to lawsuits, claims made by third parties or the action of various regulatory agencies. For such matters, we record liabilities when they are considered probable and estimable, based on currently available facts and our estimates of the ultimate outcome or resolution of the liability in the future. We maintain liability insurance for various risks associated with the operation of our natural gas pipelines and facilities, including for property damage and bodily injury. These liability insurance policies generally require us to be responsible for the first $1.0 million (self-insured retention) of each incident. To the extent a loss contingency exceeds the self-insurance retention, we record an insurance receivable when

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

recovery is considered probable. Upon reaching a settlement, the loss contingency is deemed resolved and recorded in accounts payable and accrued liabilities until paid. Loss contingencies and any related insurance recovery receivables reflect our best estimate of these amounts as of the date of this report. Actual results may differ from estimates, depending on actual outcomes or changes in the facts or expectations surrounding each potential exposure.

Subsequent events — Except as noted in Note 7 to the consolidated financial statements regarding the public offering of senior notes and Note 9 to the consolidated financial statements regarding the most recent update to our securitization filing in the State of Kansas, no events occurred subsequent to the balance sheet date that would require recognition or disclosure in the consolidated financial statements.

Recent accounting pronouncements

Accounting pronouncements adopted in fiscal 2022

In November 2021, the Financial Accounting Standards Board (FASB) issued guidance which will require disclosure about government assistance in the notes to the financial statements. The amendment requires annual disclosures about transactions with a government that are accounted for by applying a grant or contribution accounting model by analogy, including information about the nature of the transactions and the related accounting policy used to account for the transactions, the line items on the balance sheet and income statement that are affected by the transactions and the significant terms and conditions of the transactions, including commitments and contingencies. The amendment was effective for us beginning October 1, 2022; however, we elected to adopt this amendment during the first quarter of fiscal 2022 as permitted by the guidance. As the guidance is related only to disclosures in the notes to the financial statements, there was no impact on our financial position, results of operations or cash flows.

In March 2020, the FASB issued optional guidance which will ease the potential burden in accounting for recognizing the effects of reference rate reform on financial reporting. The amendments provide optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships and other transactions affected by the cessation of the London Interbank Offered Rate (LIBOR). As discussed in Note 7, on March 31, 2022, we amended and restated our $1.5 billion credit facility and our $900 million unsecured revolving credit agreement which, among other things, included amending the interest rate provisions applicable to borrowings under this agreement to utilize the secured overnight financing rate as the reference rate, rather than LIBOR. In addition, we have evaluated the temporary expedients and options available under this guidance and identified the financial instruments to which the expedients could be applied, if deemed necessary. As of September 30, 2022, we have not applied any expedients or options available under these Accounting Standards Updates.

3.    Segment Information

    As of September 30, 2022, we manage and review our consolidated operations through the following two reportable segments:

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

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

Our determination of reportable segments considers the strategic operating units under which we manage sales of various products and services to customers. Although our distribution segment operations are geographically dispersed, they are aggregated and reported as a single segment as each natural gas distribution division has similar economic characteristics. In addition, because the pipeline and storage operations of our Atmos Pipeline-Texas division and our natural gas transmission operations in Louisiana have similar economic characteristics, they have been aggregated and reported as a single segment.

The accounting policies of the segments are the same as those described in the summary of significant accounting policies. We evaluate performance based on net income or loss of the respective operating units. We allocate interest and pension expense to the pipeline and storage segment; however, there is no debt or pension liability recorded on the pipeline and storage segment balance sheet. All material intercompany transactions have been eliminated; however, we have not eliminated intercompany profits when such amounts are probable of recovery under the affiliates’ rate regulation process. Income taxes are allocated to each segment as if each segment’s income taxes were calculated on a separate return basis.

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Income statements and capital expenditures by segment are shown in the following tables.

	Year Ended September 30, 2022
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Operating revenues from external parties	$	4,031,936	$	169,726	$	—	$	4,201,662
Intersegment revenues	3,258		523,934		(527,192)		—
Total operating revenues	4,035,194		693,660		(527,192)		4,201,662
Purchased gas cost	2,210,302		(1,583)		(526,063)		1,682,656
Operation and maintenance expense	518,443		192,847		(1,129)		710,161
Depreciation and amortization expense	387,858		147,797		—		535,655
Taxes, other than income	314,046		38,162		—		352,208
Operating income	604,545		316,437		—		920,982
Other non-operating income	6,946		26,791		—		33,737
Interest charges	49,921		52,890		—		102,811
Income before income taxes	561,570		290,338		—		851,908
Income tax expense	39,593		37,917		—		77,510
Net income	$	521,977	$	252,421	$	—	$	774,398
Capital expenditures	$	1,675,798	$	768,622	$	—	$	2,444,420

	Year Ended September 30, 2021
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Operating revenues from external parties	$	3,238,753	$	168,737	$	—	$	3,407,490
Intersegment revenues	3,220		468,610		(471,830)		—
Total operating revenues	3,241,973		637,347		(471,830)		3,407,490
Purchased gas cost	1,501,695		1,582		(470,560)		1,032,717
Operation and maintenance expense	501,209		179,080		(1,270)		679,019
Depreciation and amortization expense	345,481		132,496		—		477,977
Taxes, other than income	275,074		37,705		—		312,779
Operating income	618,514		286,484		—		904,998
Other non-operating income (expense)	(20,694)		18,549		—		(2,145)
Interest charges	36,629		46,925		—		83,554
Income before income taxes	561,191		258,108		—		819,299
Income tax expense	115,329		38,407		—		153,736
Net income	$	445,862	$	219,701	$	—	$	665,563
Capital expenditures	$	1,454,195	$	515,345	$	—	$	1,969,540

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	Year Ended September 30, 2020
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Operating revenues from external parties	$	2,624,251	$	196,886	$	—	$	2,821,137
Intersegment revenues	2,742		412,453		(415,195)		—
Total operating revenues	2,626,993		609,339		(415,195)		2,821,137
Purchased gas cost	1,071,227		1,548		(413,921)		658,854
Operation and maintenance expense	472,760		158,115		(1,274)		629,601
Depreciation and amortization expense	309,582		120,246		—		429,828
Taxes, other than income	245,181		33,574		—		278,755
Operating income	528,243		295,856		—		824,099
Other non-operating income (expense)	(1,265)		8,436		—		7,171
Interest charges	39,634		44,840		—		84,474
Income before income taxes	487,344		259,452		—		746,796
Income tax expense	91,680		53,673		—		145,353
Net income	$	395,664	$	205,779	$	—	$	601,443
Capital expenditures	$	1,466,631	$	469,045	$	—	$	1,935,676

The following table summarizes our revenues from external parties, excluding intersegment revenues, by products and services for the fiscal years ended September 30.

	2022		2021		2020
	(In thousands)
Distribution revenues:
Gas sales revenues:
Residential	$	2,492,116	$	2,117,272	$	1,717,070
Commercial	1,126,189		838,382		654,963
Industrial	224,632		113,171		89,641
Public authority and other	66,956		50,369		42,007
Total gas sales revenues	3,909,893		3,119,194		2,503,681
Transportation revenues	110,905		105,554		97,441
Other gas revenues	11,138		14,005		23,129
Total distribution revenues	4,031,936		3,238,753		2,624,251
Pipeline and storage revenues	169,726		168,737		196,886
Total operating revenues	$	4,201,662	$	3,407,490	$	2,821,137

Balance sheet information at September 30, 2022 and 2021 by segment is presented in the following tables.

	September 30, 2022
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Property, plant and equipment, net	$	12,723,532	$	4,516,707	$	—	$	17,240,239
Total assets	$	21,424,586	$	4,797,206	$	(4,028,803)	$	22,192,989

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	September 30, 2021
	Distribution		Pipeline and Storage		Eliminations		Consolidated
	(In thousands)
Property, plant and equipment, net	$	11,232,649	$	3,831,321	$	—	$	15,063,970
Total assets	$	18,847,266	$	4,076,844	$	(3,315,448)	$	19,608,662

4.    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 consolidated financial statements, when the impact is dilutive.

Basic and diluted earnings per share for the fiscal years ended September 30 are calculated as follows:

	2022		2021		2020
	(In thousands, except per share data)
Basic Earnings Per Share
Net income	$	774,398	$	665,563	$	601,443
Less: Income allocated to participating securities	508		465		444
Net income available to common shareholders	$	773,890	$	665,098	$	600,999
Basic weighted average shares outstanding	137,830		129,779		122,788
Net income per share — Basic	$	5.61	$	5.12	$	4.89
Diluted Earnings Per Share
Net income available to common shareholders	$	773,890	$	665,098	$	600,999
Effect of dilutive shares	—		—		—
Net income available to common shareholders	$	773,890	$	665,098	$	600,999
Basic weighted average shares outstanding	137,830		129,779		122,788
Dilutive shares	266		55		84
Diluted weighted average shares outstanding	138,096		129,834		122,872
Net income per share — Diluted	$	5.60	$	5.12	$	4.89

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

5.    Revenue and Accounts Receivable

The following tables disaggregates our revenue from contracts with customers by customer type and segment and provides a reconciliation to total operating revenues, including intersegment revenues, for the periods presented.

	Year Ended September 30, 2022
	Distribution		Pipeline and Storage
	(In thousands)
Gas sales revenues:
Residential	$	2,472,461	$	—
Commercial	1,120,322		—
Industrial	224,427		—
Public authority and other	66,691		—
Total gas sales revenues	3,883,901		—
Transportation revenues	113,043		707,205
Miscellaneous revenues	10,282		13,679
Revenues from contracts with customers	4,007,226		720,884
Alternative revenue program revenues (1)	26,041		(27,224)
Other revenues	1,927		—
Total operating revenues	$	4,035,194	$	693,660

	Year Ended September 30, 2021
	Distribution		Pipeline and Storage
Gas sales revenues:
Residential	$	2,129,704	$	—
Commercial	841,145		—
Industrial	113,091		—
Public authority and other	50,565		—
Total gas sales revenues	3,134,505		—
Transportation revenues	107,822		646,416
Miscellaneous revenues	10,971		14,141
Revenues from contracts with customers	3,253,298		660,557
Alternative revenue program revenues (1)	(13,303)		(23,210)
Other revenues	1,978		—
Total operating revenues	$	3,241,973	$	637,347

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	Year Ended September 30, 2020
	Distribution		Pipeline and Storage
Gas sales revenues:
Residential	$	1,704,444	$	—
Commercial	650,396		—
Industrial	89,467		—
Public authority and other	41,339		—
Total gas sales revenues	2,485,646		—
Transportation revenues	99,435		636,819
Miscellaneous revenues	19,085		9,754
Revenues from contracts with customers	2,604,166		646,573
Alternative revenue program revenues (1)	20,856		(37,234)
Other revenues	1,971		—
Total operating revenues	$	2,626,993	$	609,339

(1)In our distribution segment, we have weather-normalization adjustment mechanisms that serve to mitigate the effects of weather on our revenue. Additionally, 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.

Accounts receivable and allowance for uncollectible accounts

Rollforwards of our allowance for uncollectible accounts for the years ended September 30, 2022, 2021 and 2020 are presented in the table below.

In response to the COVID-19 pandemic, beginning in March 2020, regulators issued collection moratoriums, which required us to temporarily suspend our customer collection activities and charging late fees. After regulators lifted these moratoriums, we resumed customer collection activities during the third quarter of fiscal 2021. These regulatory orders influenced our bad debt expense and writeoffs from fiscal 2020 through 2022.

We actively work with our customers experiencing financial hardship to offer flexible payment options and to direct them to aid agencies for financial assistance. Our allowance for uncollectible accounts reflects the expected impact on our customers’ ability to pay. Our allowance for uncollectible accounts also reflects the fact that we have the ability to recovery the gas cost portion of uncollectible accounts through our gas cost recovery mechanisms in five states, which covers approximately 81 percent of our residential and commercial customers.

	Allowance for uncollectible accounts
	(In thousands)
Balance, September 30, 2019	$	15,899
Current period provisions	24,796
Write-offs charged against allowance	(12,698)
Recoveries of amounts previously written off	1,952
Balance, September 30, 2020	29,949
Current period provisions	43,807
Write-offs charged against allowance	(11,019)
Recoveries of amounts previously written off	1,734
Balance, September 30, 2021	64,471
Current period provisions	16,576
Write-offs charged against allowance	(32,885)
Recoveries of amounts previously written off	1,831
Balance, September 30, 2022	$	49,993

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

6.    Leases

We are the lessee for substantially all of our leasing activity, which primarily includes operating leases for office and warehouse space, tower space, vehicles and heavy equipment used in our operations. We are also a lessee in finance leases for service centers.

The following table presents our weighted average remaining lease term for our leases.

	September 30, 2022	September 30, 2021
Weighted average remaining lease term (years)
Finance leases	18.7	19.0
Operating leases	9.7	10.2

The following table represents our weighted average discount rate:

	September 30, 2022		September 30, 2021
Weighted average discount rate
Finance leases	4.0	%	5.7	%
Operating leases	2.9	%	2.8	%

Lease costs for the years ended September 30, 2022, 2021 and 2020 are presented in the table below. These costs include both amounts recognized in expense and amounts capitalized. For the years ended September 30, 2022, 2021 and 2020 we did not have material short-term lease costs or variable lease costs.

	Year Ended September 30
	2022		2021		2020
	(In thousands)
Finance lease cost	$	4,314	$	1,334	$	622
Operating lease cost	43,394		42,349		40,887
Total lease cost	$	47,708	$	43,683	$	41,509

Our ROU assets and lease liabilities are presented as follows on the consolidated balance sheets:

	Balance Sheet Classification	September 30, 2022		September 30, 2021
		(In thousands)
Assets
Finance leases	Net Property, Plant and Equipment	$	50,118	$	18,252
Operating leases	Deferred charges and other assets	214,663		222,446
Total right-of-use assets		$	264,781	$	240,698
Liabilities
Current
Finance leases	Current maturities of long-term debt	$	1,457	$	452
Operating leases	Other current liabilities	38,644		37,688
Noncurrent
Finance leases	Long-term debt	50,393		18,287
Operating leases	Deferred credits and other liabilities	184,301		194,745
Total lease liabilities		$	274,795	$	251,172

Two service center leases are expected to commence in the fourth quarter of fiscal 2023 that impact our future lease payments. The total future lease payments for these leases are $48.1 million.

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Other pertinent information related to leases was as follows. During the years ended September 30, 2022, 2021 and 2020 amounts paid in cash for our finance leases were not material.

	Year Ended September 30
	2022		2021		2020
	(In thousands)
Cash paid amounts included in the measurement of lease liabilities
Operating cash flows used for operating leases	$	45,080	$	42,013	$	37,758
Right-of-use assets obtained in exchange for lease obligations
Finance leases	$	33,833	$	10,333	$	6,083
Operating leases	$	28,310	$	25,690	$	34,169

Maturities of our lease liabilities as of September 30, 2022 were as follows by fiscal years:

	Total		Finance Leases		Operating Leases
	(In thousands)
2023	$	46,417	$	3,313	$	43,104
2024	39,832		3,375		36,457
2025	30,612		3,438		27,174
2026	24,141		3,502		20,639
2027	21,322		3,568		17,754
Thereafter	170,704		55,997		114,707
Total lease payments	333,028		73,193		259,835
Less: Imputed interest	58,233		21,343		36,890
Total	$	274,795	$	51,850	$	222,945
Reported as of September 30, 2022
Short-term lease liabilities	$	40,101	$	1,457	$	38,644
Long-term lease liabilities	234,694		50,393		184,301
Total lease liabilities	$	274,795	$	51,850	$	222,945

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7.    Debt

Long-term debt

Long-term debt at September 30, 2022 and 2021 consisted of the following:

	2022		2021
	(In thousands)
Unsecured 0.625% Senior Notes, due March 2023	$	1,100,000	$	1,100,000
Unsecured 3.00% Senior Notes, due June 2027	500,000		500,000
Unsecured 2.625% Senior Notes, due September 2029	500,000		300,000
Unsecured 1.50% Senior Notes, due January 2031	600,000		600,000
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		—
Floating-rate term loan, due April 2022	—		200,000
Floating-rate Senior Notes, due March 2023	1,100,000		1,100,000
Medium term Series A notes, 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 (see Note 6)	51,850		18,739
Total long-term debt	8,011,850		7,378,739
Less:
Net original issue discount on unsecured senior notes and debentures	3,704		2,811
Debt issuance cost	46,042		45,271
Current maturities	2,201,457		2,400,452
	$	5,760,647	$	4,930,205

Maturities of long-term debt, excluding our finance lease obligations, at September 30, 2022 were as follows by fiscal years (in thousands):

2023	$	2,200,000
2024	—
2025	—
2026	10,000
2027	500,000
Thereafter	5,250,000
	$	7,960,000

On October 3, 2022, we completed a public offering of $500 million of 5.750% senior notes due fiscal 2053, with an effective interest rate of 4.504%, after giving effect to the estimated offering costs and settlement of our interest rate swaps, and $300 million of 5.450% senior notes due fiscal 2033, with an effective interest rate of 5.570%, after giving effect to the estimated offering costs. The net proceeds from the offering, after the underwriting discount and estimated offering expenses, of $789.4 million were used for general corporate purposes. In September 2022, we settled the interest rate swaps associated with the $500 million offering and received $197.1 million.

On January 14, 2022, we completed a public offering of $200 million of 2.625% senior notes due fiscal 2029, with an effective interest rate of 2.54%, after giving effect to the offering costs. The net proceeds from the offering, after the

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

underwriting discount and offering expenses, of $200.8 million were used to repay our $200 million floating-rate term loan on January 18, 2022.

On October 1, 2021, we completed a public offering of $600 million of 2.85% senior notes due fiscal 2052, with an effective interest rate of 2.58%, 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 $589.8 million, will be used for general corporate purposes. In September 2021, we settled the interest rate swaps associated with this offering and received $62.2 million.

On March 9, 2021, we completed a public offering of $1.1 billion of 0.625% senior notes due fiscal 2023, with an effective interest rate of 0.834%, after giving effect to the offering costs, and $1.1 billion floating rate senior notes due fiscal 2023 that bear interest at a rate equal to the Three-Month LIBOR rate plus 0.38%. The net proceeds from the offering, after the underwriting discount and offering expenses, of $2.2 billion were used for the payment of unplanned natural gas costs incurred during Winter Storm Uri. The notes are subject to optional redemption at any time on or after September 9, 2021 at a price equal to 100% of the principal amount of the notes being redeemed, plus any accrued and unpaid interest thereon, if any, to, but excluding, the redemption date. As discussed in Note 9 to the consolidated financial statements, we intend to repay these notes in fiscal 2023 after the expected receipt of securitization funds.

On October 1, 2020, we completed a public offering of $600 million of 1.50% senior notes due 2031, with an effective interest rate of 1.71%, 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 $592.3 million, were used for general corporate purposes, including the repayment of working capital borrowings pursuant to our commercial paper program and the related settlement of our interest rate swaps.

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 with an equity-to-total-capitalization ratio between 50% and 60%, inclusive of long-term and short-term debt. 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 $2.5 billion of total working capital funding.

The primary source of our funding is our commercial paper program, which is supported by a five-year unsecured $1.5 billion credit facility. On March 31, 2022, we amended this agreement to (i) extend the maturity date from March 31, 2026 to March 31, 2027 and (ii) replace the London interbank offered rate (the LIBOR Rate) with the forward-looking term rate based on the secured overnight financing rate (the SOFR Rate) as the interest rate benchmark. The facility now bears interest at a base rate or at a 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 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 September 30, 2022, there was $185.0 million outstanding under our commercial paper program with a weighted average interest rate of 3.06% and weighted average maturities of less than one month. At September 30, 2021, there were no amounts outstanding under our commercial paper program

We also have a $900 million three-year unsecured revolving credit facility which is used to provide additional working capital funding. On March 31, 2022, we amended this agreement to (i) extend the maturity date from March 31, 2024 to March 31, 2025 and (ii) replace the LIBOR Rate with the SOFR Rate as the interest benchmark. This facility now bears interest at a base rate or at a 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 SOFR-based advances, based on the Company's credit ratings. Additionally, the facility contains a $100 million accordion feature, which provides the opportunity to increase the total committed loan to $1.0 billion. At September 30, 2022 and 2021, there were no borrowings outstanding under this facility.

Additionally, we have a $50 million 364-day unsecured facility, which was renewed April 1, 2022 and is used to provide working capital funding. There were no borrowings outstanding under this facility as of September 30, 2022 and 2021.

Finally, we have a $50 million 364-day unsecured revolving credit facility, which was renewed March 31, 2022 and is used to issue letters of credit and to provide working capital funding. At September 30, 2022, there were no borrowings outstanding under the new facility; however, outstanding letters of credit reduced the total amount available to us to $44.4 million.

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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 September 30, 2022, our total-debt-to-total-capitalization ratio, as defined, was 47 percent. In addition, both the interest margin and the fee that we pay on unused amounts under each 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 is not paid at maturity. We were in compliance with all of our debt covenants as of September 30, 2022. 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

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

On June 29, 2021, we filed a shelf registration statement with the Securities and Exchange Commission (SEC) that allows us to issue up to $5.0 billion in common stock and/or debt securities, which expires June 29, 2024. At September 30, 2022, approximately $2.2 billion of securities remained available for issuance under the shelf registration statement. Following the completion of the $800 million senior unsecured notes offering on October 3, 2022 (see Note 7 to the consolidated financial statements), approximately $1.4 billion of securities remained available for issuance under the shelf registration statement.

On March 23, 2022, we filed a prospectus supplement under the shelf registration statement relating to an at-the-market (ATM) equity sales program under which we may issue and sell shares of our common stock up to an aggregate offering price of $1.0 billion through June 29, 2024 (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 June 29, 2021, which was exhausted during our second fiscal quarter.

During the year ended September 30, 2022, we executed forward sales under our ATM equity sales programs with various forward sellers who borrowed and sold 11,862,319 shares of our common stock at an aggregate price of $1.3 billion. During the year ended September 30, 2022, we also settled forward sale agreements with respect to 7,907,883 shares that had been borrowed and sold by various forward sellers under the ATM program for net proceeds of $776.8 million. As of September 30, 2022, $481.7 million of equity was available for issuance under our existing ATM program. Additionally, we had $776.6 million in available proceeds from outstanding forward sale agreements, as detailed below.

Maturity	Shares Available	Net Proceeds Available (In Thousands)		Forward Price
September 29, 2023	4,552,157	$	492,015	$	108.08
December 29, 2023	919,898	105,451		$	114.63
March 28, 2024	1,554,105	179,177		$	115.29
Total	7,026,160	$	776,643	$	110.54

Accumulated Other Comprehensive Income (Loss)

We record deferred gains (losses) in accumulated other comprehensive income (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 as a component of interest charges, as they are amortized. 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, 2021	$	47	$	69,756	$	69,803
Other comprehensive income (loss) before reclassifications	(542)		296,875		296,333
Amounts reclassified from accumulated other comprehensive income	—		2,976		2,976
Net current-period other comprehensive income (loss)	(542)		299,851		299,309
September 30, 2022	$	(495)	$	369,607	$	369,112

	Available- for-Sale Securities		Interest Rate Agreement Cash Flow Hedges		Total
	(In thousands)
September 30, 2020	$	238	$	(57,827)	$	(57,589)
Other comprehensive income (loss) before reclassifications	(191)		123,017		122,826
Amounts reclassified from accumulated other comprehensive income	—		4,566		4,566
Net current-period other comprehensive income (loss)	(191)		127,583		127,392
September 30, 2021	$	47	$	69,756	$	69,803

9.    Winter Storm Uri

Overview

A historic winter storm impacted supply, market pricing and demand for natural gas in our service territories in mid-February 2021. During this time, the governors of Kansas and Texas each declared a state of emergency, and certain regulatory agencies issued emergency orders that impacted the utility and natural gas industries, including statewide utilities curtailment programs and orders encouraging or requiring jurisdictional natural gas utilities to work to ensure customers were provided with safe and reliable natural gas service.

Due to the historic nature of this winter storm, we experienced unforeseeable and unprecedented market pricing for gas costs, which resulted in aggregated natural gas purchases during the month of February of approximately $2.3 billion. These gas costs were paid by the end of March 2021.

Incremental Financing

As discussed in Note 7 to the consolidated financial statements, on March 9, 2021, we completed a public offering of $2.2 billion in debt securities and the net proceeds from the offering, after the underwriting discount and offering expenses, were used to substantially fund these purchased gas costs. As a result of this unplanned debt issuance, S&P lowered its long-term/short-term credit ratings from A/A-1 to A-/A-2 and placed our ratings under negative outlook. Moody’s reaffirmed its long-term and short-term credit ratings and placed our ratings under negative outlook, which was upgraded to stable in February 2022. These credit rating adjustments and the issuance of unplanned debt did not impact our ability to satisfy our debt covenants.

Regulatory Asset Accounting

Our purchased gas costs are recoverable through purchased gas cost adjustment mechanisms in each state where we operate. Due to the unprecedented level of purchased gas costs incurred during Winter Storm Uri, the Kansas Corporation Commission (KCC) and the Railroad Commission of Texas (RRC) issued orders authorizing natural gas utilities to record a regulatory asset to account for the extraordinary costs associated with the winter storm. Pursuant to these orders, as of September 30, 2022, we have recorded a $2.1 billion regulatory asset for incremental costs, including carrying costs, incurred in Kansas ($88.5 million) and Texas ($2,021.0 million).

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Securitization Proceedings

To minimize the impact on the customer bill by extending the recovery periods for these unprecedented purchased gas costs, the Kansas and Texas State Legislatures each approved securitization legislation during fiscal 2021. The following summarizes the status of the securitization of each state as of the date of this filing.

Kansas

The Kansas securitization legislation, which became effective April 9, 2021, permits a natural gas public utility, in its sole discretion, to apply to the KCC for a financing order for the recovery of qualified extraordinary costs through the issuance of bonds. On September 14, 2021, we filed with the KCC an application to securitize $94.1 million of extraordinary gas costs incurred during Winter Storm Uri, which included an estimate of penalties, carrying costs and administrative costs that we expect to incur in connection with the resolution of this filing. On March 24, 2022, the KCC issued an Order Approving Unanimous Settlement Agreement which stipulated that all of our gas and storage costs were prudently incurred.

The KCC issued a financing order on October 25, 2022, which authorizes us to securitize, through the issuance of bonds, $118.5 million, which includes the carrying costs and estimated interest related to the securitization over a time period not to exceed 12 years. We expect the issuance of bonds to take place in the second quarter of fiscal 2023. Because we intend to securitize these costs and recover over several years, we have recorded the regulatory asset for Kansas as a long-term asset in deferred charges and other assets as of September 30, 2022.

Texas

On June 16, 2021, House Bill 1520 became effective. House Bill 1520 authorizes the RRC to issue a statewide securitization financing order directing the Texas Public Finance authority to issue bonds (customer rate relief bonds) for gas utilities that choose to participate to recover extraordinary costs incurred to secure gas supply and to provide service during Winter Storm Uri, and to restore gas utility systems after that event, thereby providing rate relief to customers by extending the period during which these extraordinary costs would otherwise be recovered and supporting the financial strength and stability of gas utility companies.

The legislation required natural gas utilities seeking to participate in the securitization program to file an application with the RRC and submit extraordinary gas costs incurred during Winter Storm Uri for a prudency review by July 30, 2021. We filed our application with the RRC on July 30, 2021 to securitize $2.0 billion of extraordinary gas costs incurred during Winter Storm Uri.

On November 10, 2021, the RRC issued a Final Determination of the Regulatory Asset (the Final Determination). The Final Determination stipulates that all of our gas and storage costs were prudently incurred. Additionally, the Final Determination permits us to defer, through December 31, 2021 our actual carrying costs associated with the $2.2 billion of incremental financing issued in March 2021 and to recover approximately $0.6 million of our administrative costs.

On February 8, 2022, the RRC issued a financing order that authorizes the Texas Public Financing Authority to issue customer rate relief bonds to securitize the costs that were approved in the Final Determination over a period not to exceed 30 years. Upon receipt of the securitization funds we will repay the $2.2 billion in public notes issued to finance the incremental gas costs incurred during Winter Storm Uri.

10.    Retirement and Postretirement Employee Benefit Plans

We have both funded and unfunded noncontributory defined benefit plans that together cover most of our employees. We also maintain a postretirement plan that provides health care benefits to retired employees. Finally, we sponsor a defined contribution plan that covers substantially all employees. These plans are discussed in further detail below.

As a rate regulated entity, most of our net periodic pension and other postretirement benefits costs are recoverable through our rates over a period of up to 15 years. 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. Additionally, the amounts that have not yet been recognized in net periodic pension cost that have been recorded as regulatory assets or liabilities are as follows:

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	Employee Pension Plan		Supplemental Executive Retirement Plans		Postretirement Plan		Total
	(In thousands)
September 30, 2022
Unrecognized prior service credit	$	(121)	$	—	$	(51,079)	$	(51,200)
Unrecognized actuarial (gain) loss	(32,159)		14,029		(87,527)		(105,657)
	$	(32,280)	$	14,029	$	(138,606)	$	(156,857)
September 30, 2021
Unrecognized prior service credit	$	(353)	$	—	$	(64,313)	$	(64,666)
Unrecognized actuarial (gain) loss	(3,060)		39,666		(28,141)		8,465
	$	(3,413)	$	39,666	$	(92,454)	$	(56,201)

Defined Benefit Plans

Employee Pension Plan

As of September 30, 2022, we maintained one cash balance defined benefit plan, the Atmos Energy Corporation Pension Account Plan (the Pension Plan). The Pension Plan was established effective January 1999 and covers most of the employees of Atmos Energy that were hired on or before September 30, 2010. Effective October 1, 2010, the Pension Plan was closed to new participants. The assets of the Pension Plan are held within the Atmos Energy Corporation Master Retirement Trust (the Master Trust).

Opening account balances were established for participants as of January 1999 equal to the present value of their respective accrued benefits under the pension plans which were previously in effect as of December 31, 1998. The Pension Plan credits an allocation to each participant’s account at the end of each year according to a formula based on the participant’s age, service and total pay (excluding incentive pay). In addition, at the end of each year, a participant’s account is credited with interest on the employee’s prior year account balance. Participants are fully vested in their account balances after three years of service and may choose to receive their account balances as a lump sum or an annuity.

Generally, our funding policy is to contribute annually an amount in accordance with the requirements of the Employee Retirement Income Security Act of 1974 (ERISA), including the funding requirements under the Pension Protection Act of 2006 (PPA). However, additional voluntary contributions are made from time to time as considered necessary. Contributions are intended to provide not only for benefits attributed to service to date but also for those expected to be earned in the future.

During fiscal 2022 and 2021, we contributed $8.5 million and $10.0 million in cash to the Pension Plan to achieve a desired level of funding while maximizing the tax deductibility of this payment. Based upon market conditions at September 30, 2022, the current funded position of the Pension Plan and the funding requirements under the PPA, we do not anticipate a minimum required contribution for fiscal 2023. However, we may consider whether a voluntary contribution is prudent to maintain certain funding levels.

We make investment decisions and evaluate performance of the assets in the Master Trust on a medium-term horizon of at least three to five years. We also consider our current financial status when making recommendations and decisions regarding the Master Trust’s assets. Finally, we strive to ensure the Master Trust’s assets are appropriately invested to maintain an acceptable level of risk and meet the Master Trust’s long-term asset investment policy adopted by the Board of Directors.

To achieve these objectives, we invest the Master Trust’s assets in equity securities, fixed income securities, interests in commingled pension trust funds, other investment assets and cash and cash equivalents. Investments in equity securities are diversified among the market’s various subsectors in an effort to diversify risk and maximize returns. Fixed income securities are invested in investment grade securities. Cash equivalents are invested in securities that either are short term (less than 180 days) or readily convertible to cash with modest risk.

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The following table presents asset allocation information for the Master Trust as of September 30, 2022 and 2021.

	Targeted Allocation  Range	Actual Allocation September 30
Security Class		2022	2021
Domestic equities	35%-55%	39.7%	44.5%
International equities	10%-20%	14.6%	16.9%
Fixed income	5%-30%	16.0%	16.0%
Company stock	0%-15%	15.3%	10.6%
Other assets	0%-20%	14.4%	12.0%

At September 30, 2022 and 2021, the Pension Plan held 716,700 shares of our common stock which represented 15.3 percent and 10.6 percent of total Pension Plan assets. These shares generated dividend income for the Pension Plan of approximately $1.9 million and $1.8 million during fiscal 2022 and 2021.

Our Pension Plan expenses and liabilities are determined on an actuarial basis and are affected by numerous assumptions and estimates including the market value of plan assets, estimates of the expected return on plan assets and assumed discount rates and demographic data. We review the estimates and assumptions underlying our Pension Plan annually based upon a September 30 measurement date. The development of our assumptions is fully described in our significant accounting policies in Note 2 to the consolidated financial statements. The actuarial assumptions used to determine the pension liability for the Pension Plan was determined as of September 30, 2022 and 2021 and the actuarial assumptions used to determine the net periodic pension cost for the Pension Plan was determined as of September 30, 2021, 2020 and 2019.

Additional assumptions are presented in the following table:

	Pension Liability				Pension Cost
	2022		2021		2022		2021		2020
Discount rate	5.66	%	2.97	%	2.97	%	2.80	%	3.29	%
Rate of compensation increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%
Expected return on plan assets	6.25	%	6.25	%	6.25	%	6.25	%	6.50	%
Interest crediting rate	4.69	%	4.69	%	4.69	%	4.69	%	4.69	%

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The following table presents the Pension Plan’s accumulated benefit obligation, projected benefit obligation and funded status as of September 30, 2022 and 2021:

	2022		2021
	(In thousands)
Accumulated benefit obligation	$	428,629	$	558,639
Change in projected benefit obligation:
Benefit obligation at beginning of year	$	596,029	$	604,221
Service cost	16,165		17,369
Interest cost	17,606		16,883
Actuarial gain	(141,567)		(7,561)
Benefits paid	(38,706)		(34,883)
Benefit obligation at end of year	449,527		596,029
Change in plan assets:
Fair value of plan assets at beginning of year	596,806		528,881
Actual return on plan assets	(87,575)		92,808
Employer contributions	8,500		10,000
Benefits paid	(38,706)		(34,883)
Fair value of plan assets at end of year	479,025		596,806
Reconciliation:
Funded status	29,498		777
Unrecognized prior service cost	—		—
Unrecognized net loss	—		—
Net amount recognized	$	29,498	$	777

Net periodic pension cost for the Pension Plan for fiscal 2022, 2021 and 2020 is presented in the following table.

	Fiscal Year Ended September 30
	2022		2021		2020
	(In thousands)
Components of net periodic pension cost:
Service cost	$	16,165	$	17,369	$	17,551
Interest cost (1)	17,606		16,883		19,028
Expected return on assets (1)	(29,531)		(27,913)		(28,316)
Amortization of prior service credit (1)	(231)		(231)		(231)
Recognized actuarial loss (1)	4,638		8,686		9,025
Net periodic pension cost	$	8,647	$	14,794	$	17,057

(1)    The components of net periodic cost other than the service cost component are included in the line item other non-operating income (expense) in the consolidated statements of comprehensive income or are capitalized on the consolidated balance sheets as a regulatory asset or liability, as described in Note 2 to the consolidated financial statements.

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The following tables set forth by level, within the fair value hierarchy, the Pension Plan's assets at fair value as of September 30, 2022 and 2021. As required by authoritative accounting literature, assets are categorized in their entirety based on the lowest level of input that is significant to the fair value measurement. The methods used to determine fair value for the assets held by the Pension Plan are fully described in Note 2 to the consolidated financial statements. Investments in our common/collective trusts and limited partnerships that are measured at net asset value per share equivalent are not classified in the fair value hierarchy. The net asset value amounts presented are intended to reconcile the fair value hierarchy to the total investments. In addition to the assets shown below, the Pension Plan had net accounts receivable of $2.4 million and $2.1 million at September 30, 2022 and 2021, which materially approximates fair value due to the short-term nature of these assets.

	Assets at Fair Value as of September 30, 2022
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Common stocks	$	210,325	$	—	$	—	$	210,325
Money market funds	—		14,490		—		14,490
Registered investment companies	53,401		—		—		53,401
Government securities:
Mortgage-backed securities	—		14,175		—		14,175
U.S. treasuries	3,681		28		—		3,709
Corporate bonds	—		22,320		—		22,320
Total investments measured at fair value	$	267,407	$	51,013	$	—	318,420
Investments measured at net asset value:
Common/collective trusts (1)							86,891
Limited partnerships (1)							71,331
Total investments							$	476,642

	Assets at Fair Value as of September 30, 2021
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Common stocks	$	239,166	$	—	$	—	$	239,166
Money market funds	—		7,060		—		7,060
Registered investment companies	74,236		—		—		74,236
Government securities:
Mortgage-backed securities	—		14,048		—		14,048
U.S. treasuries	7,483		34		—		7,517
Corporate bonds	—		30,834		—		30,834
Total investments measured at fair value	$	320,885	$	51,976	$	—	372,861
Investments measured at net asset value:
Common/collective trusts (1)							121,570
Limited partnerships (1)							100,299
Total investments							$	594,730

(1)    The fair value of our common/collective trusts and limited partnerships are measured using the net asset value per share practical expedient. There are no redemption restrictions, redemption notice periods or unfunded commitments for these investments. The redemption frequency is daily.

Supplemental Executive Retirement Plans

We have three nonqualified supplemental plans (the Supplemental Plans) which provide additional pension, disability and death benefits to our officers and certain other employees of the Company.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The Supplemental Executive Benefits Plan (SEBP) covers our corporate officers and certain other employees of the Company who were employed on or before August 12, 1998. The SEBP is a defined benefit arrangement which provides a benefit equal to 75 percent of covered compensation under which benefits paid from the underlying qualified defined benefit plan are an offset to the benefits under the SEBP.

In August 1998, we adopted the Supplemental Executive Retirement Plan (SERP) (formerly known as the Performance-Based Supplemental Executive Benefits Plan), which covers all corporate officers selected to participate in the plan between August 12, 1998 and August 5, 2009. The SERP is a defined benefit arrangement which provides a benefit equal to 60 percent of covered compensation under which benefits paid from the underlying qualified defined benefit plan are an offset to the benefits under the SERP.

Effective August 5, 2009, we adopted a new defined benefit Supplemental Executive Retirement Plan (the 2009 SERP), for corporate officers or any other employees selected at the discretion of the Board. Under the 2009 SERP, a nominal account has been established for each participant, to which the Company contributes at the end of each calendar year an amount equal to ten percent (25 percent for members of the Management Committee appointed on or after January 1, 2016) of the total of each participant’s base salary and cash incentive compensation earned during each prior calendar year, beginning December 31, 2009. The benefits vest after three years of service and attainment of age 55 and earn interest credits at the same annual rate as the Company’s Pension Plan.

During fiscal 2021, we recognized a settlement charge of $9.2 million and paid a $25.7 million lump sum in relation to the retirements of certain executives.

We review the estimates and assumptions underlying our Supplemental Plans annually based upon a September 30 measurement date using the same techniques as our Pension Plan. The actuarial assumptions used to determine the pension liability for the Supplemental Plans were determined as of September 30, 2022 and 2021 and the actuarial assumptions used to determine the net periodic pension cost for the Supplemental Plans were determined as of September 30, 2021, 2020 and 2019. These assumptions are presented in the following table:

	Pension Liability				Pension Cost
	2022		2021		2022		2021		2020
Discount rate (1)	5.71	%	2.57	%	2.57	%	2.90	%	3.19	%
Rate of compensation increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%
Interest crediting rate	4.69	%	4.69	%	4.69	%	4.69	%	4.69	%

 (1)     Reflects a weighted average discount rate for pension cost for fiscal 2021 and 2020 due to the settlements during the year.

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The following table presents the Supplemental Plans’ accumulated benefit obligation, projected benefit obligation and funded status as of September 30, 2022 and 2021:

	2022		2021
	(In thousands)
Accumulated benefit obligation	$	79,233	$	100,981
Change in projected benefit obligation:
Benefit obligation at beginning of year	$	104,301	$	129,140
Service cost	1,129		1,067
Interest cost	2,647		3,180
Actuarial (gain) loss	(22,471)		1,332
Benefits paid	(4,831)		(4,720)
Settlements	—		(25,698)
Benefit obligation at end of year	80,775		104,301
Change in plan assets:
Fair value of plan assets at beginning of year	—		—
Employer contribution	4,831		30,418
Benefits paid	(4,831)		(4,720)
Settlements	—		(25,698)
Fair value of plan assets at end of year	—		—
Reconciliation:
Funded status	(80,775)		(104,301)
Unrecognized prior service cost	—		—
Unrecognized net loss	—		—
Accrued pension cost	$	(80,775)	$	(104,301)

Assets for the Supplemental Plans are held in separate rabbi trusts. At September 30, 2022 and 2021, assets held in the rabbi trusts consisted of equity securities of $30.2 million and $38.1 million, which are included in our fair value disclosures in Note 16 to the consolidated financial statements.

Net periodic pension cost for the Supplemental Plans for fiscal 2022, 2021 and 2020 is presented in the following table.

	Fiscal Year Ended September 30
	2022		2021		2020
	(In thousands)
Components of net periodic pension cost:
Service cost	$	1,129	$	1,067	$	1,074
Interest cost (1)	2,647		3,180		4,188
Recognized actuarial loss (1)	3,166		3,560		3,945
Settlements (1)	—		9,151		9,180
Net periodic pension cost	$	6,942	$	16,958	$	18,387

(1)    The components of net periodic cost other than the service cost component are included in the line item other non-operating income (expense) in the consolidated statements of comprehensive income or are capitalized on the consolidated balance sheets as a regulatory asset or liability, as described in Note 2 to the consolidated financial statements.

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Estimated Future Benefit Payments

The following benefit payments for our defined benefit plans, which reflect expected future service, as appropriate, are expected to be paid in the following fiscal years:

	Pension Plan		Supplemental Plans
	(In thousands)
2023	$	40,569	$	9,995
2024	40,126		9,538
2025	40,396		30,135
2026	41,611		6,594
2027	41,358		3,946
2028-2032	198,156		27,420

Postretirement Benefits Plan

We sponsor the Retiree Medical Plan for Retirees and Disabled Employees of Atmos Energy Corporation (the Retiree Medical Plan). This plan provides medical and prescription drug protection to all qualified participants based on their date of retirement. The Retiree Medical Plan provides different levels of benefits depending on the level of coverage chosen by the participants and the terms of predecessor plans; however, we generally pay 80 percent of the projected net claims and administrative costs and participants pay the remaining 20 percent. Effective January 1, 2015, for employees who had not met the participation requirements by September 30, 2009, the contribution rates for the Company were limited to a three percent cost increase in claims and administrative costs each year, with the participant responsible for the additional costs. Effective January 1, 2022, the Retiree Medical Plan was amended to remove the three percent cost increase limitation and change the post-65 retiree coverage to Via Benefits with an Atmos Energy funded Health Reimbursement Account. Eligible post-65 retirees and post-65 spouses will be eligible to enroll in benefits provided by Via Benefits, including those that previously deferred or declined retiree coverage.

Generally, our funding policy is to contribute annually an amount in accordance with the requirements of ERISA. However, additional voluntary contributions are made annually as considered necessary. Contributions are intended to provide not only for benefits attributed to service to date but also for those expected to be earned in the future. We expect to contribute between $15 million and $25 million to our Retiree Medical Plan during fiscal 2023.

We maintain a formal investment policy with respect to the assets in our Retiree Medical Plan to ensure the assets funding the Retiree Medical Plan are appropriately invested to maintain an acceptable level of risk. We also consider our current financial status when making recommendations and decisions regarding the Retiree Medical Plan.

We currently invest the assets funding our Retiree Medical Plan in diversified investment funds which consist of common stocks, preferred stocks and fixed income securities. The diversified investment funds may invest up to 75 percent of assets in common stocks and convertible securities. The following table presents asset allocation information for the Retiree Medical Plan assets as of September 30, 2022 and 2021.

	Actual Allocation September 30
Security Class	2022	2021
Diversified investment funds	97.7%	97.9%
Cash and cash equivalents	2.3%	2.1%

We review the estimates and assumptions underlying our Retiree Medical Plan annually based upon a September 30 measurement date using the same techniques as our Pension Plan and Supplemental Plans. The actuarial assumptions used to determine the pension liability for our Retiree Medical Plan were determined as of September 30, 2022 and 2021 and the actuarial assumptions used to determine the net periodic pension cost for the Retiree Medical Plan were determined as of September 30, 2021, 2020 and 2019.

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The assumptions are presented in the following table:

	Postretirement Liability				Postretirement Cost
	2022		2021		2022		2021		2020
Discount rate	5.61	%	3.01	%	3.01	%	2.80	%	3.29	%
Expected return on plan assets	4.94	%	4.94	%	4.94	%	4.94	%	5.14	%
Initial trend rate	6.25	%	6.25	%	6.25	%	6.25	%	6.25	%
Ultimate trend rate	4.75	%	5.00	%	5.00	%	5.00	%	5.00	%
Ultimate trend reached in	2029		2027		2027		2026		2025

The following table presents the Retiree Medical Plan’s benefit obligation and funded status as of September 30, 2022 and 2021:

	2022		2021
	(In thousands)
Change in benefit obligation:
Benefit obligation at beginning of year	$	355,156	$	370,678
Service cost	10,235		11,000
Interest cost	10,734		15,372
Plan participants’ contributions	3,210		5,648
Actuarial (gain) loss	(112,748)		6,800
Benefits paid	(16,359)		(19,610)
Plan amendments	—		(34,732)
Benefit obligation at end of year	250,228		355,156
Change in plan assets:
Fair value of plan assets at beginning of year	268,199		208,245
Actual return on plan assets	(40,113)		53,335
Employer contributions	14,749		20,581
Plan participants’ contributions	3,210		5,648
Benefits paid	(16,359)		(19,610)
Fair value of plan assets at end of year	229,686		268,199
Reconciliation:
Funded status	(20,542)		(86,957)
Unrecognized transition obligation	—		—
Unrecognized prior service cost	—		—
Unrecognized net loss	—		—
Accrued postretirement cost	$	(20,542)	$	(86,957)

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Net periodic postretirement cost for the Retiree Medical Plan for fiscal 2022, 2021 and 2020 is presented in the following table.

	Fiscal Year Ended September 30
	2022		2021		2020
	(In thousands)
Components of net periodic postretirement cost:
Service cost	$	10,235	$	11,000	$	13,466
Interest cost (1)	10,734		15,372		10,612
Expected return on assets (1)	(13,249)		(10,455)		(10,499)
Amortization of prior service (credit) cost (1)	(13,234)		30,533		173
Recognized actuarial (gain) loss (1)	—		1,172		(1,337)
Net periodic postretirement cost	$	(5,514)	$	47,622	$	12,415

(1)    The components of net periodic cost other than the service cost component are included in the line item other non-operating income (expense) in the consolidated statements of comprehensive income or are capitalized on the consolidated balance sheets as a regulatory asset or liability, as described in Note 2 to the consolidated financial statements.

We are currently recovering other postretirement benefits costs through our regulated rates in substantially all of our service areas under accrual accounting as prescribed by accounting principles generally accepted in the United States. Other postretirement benefits costs have been specifically addressed in rate orders in each jurisdiction served by our Kentucky/Mid-States, West Texas, Mid-Tex and Mississippi Divisions as well as our Kansas jurisdiction and APT or have been included in a rate case and not disallowed. Management believes that this accounting method is appropriate and will continue to seek rate recovery of accrual-based expenses in its ratemaking jurisdictions that have not yet approved the recovery of these expenses.

The following tables set forth by level, within the fair value hierarchy, the Retiree Medical Plan’s assets at fair value as of September 30, 2022 and 2021. The methods used to determine fair value for the assets held by the Retiree Medical Plan are fully described in Note 2 to the consolidated financial statements.

	Assets at Fair Value as of September 30, 2022
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Money market funds	$	—	$	5,214	$	—	$	5,214
Registered investment companies	224,472		—		—		224,472
Total investments measured at fair value	$	224,472	$	5,214	$	—	$	229,686

	Assets at Fair Value as of September 30, 2021
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Money market funds	$	—	$	5,527	$	—	$	5,527
Registered investment companies	262,672		—		—		262,672
Total investments measured at fair value	$	262,672	$	5,527	$	—	$	268,199

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Estimated Future Benefit Payments

The following benefit payments paid by the Company, retirees and prescription drug subsidies for our Retiree Medical Plan, which reflect expected future service, as appropriate, are expected to be paid in the following fiscal years.

	Company Payments		Retiree Payments		Subsidy Payments		Total Postretirement Benefits
	(In thousands)
2023	$	17,141	$	2,445	$	—	$	19,586
2024	17,409		2,410		—		19,819
2025	17,582		2,314		—		19,896
2026	18,022		2,282		—		20,304
2027	18,269		2,193		—		20,462
2028-2032	94,528		9,638		—		104,166

Defined Contribution Plan

The Atmos Energy Corporation Retirement Savings Plan and Trust (the Retirement Savings Plan) covers substantially all employees and is subject to the provisions of Section 401(k) of the Internal Revenue Code. Effective January 1, 2007, employees automatically become participants of the Retirement Savings Plan on the date of employment. Participants may elect a salary reduction up to a maximum of 65 percent of eligible compensation, as defined by the Retirement Savings Plan, not to exceed the maximum allowed by the Internal Revenue Service. New participants are automatically enrolled in the Retirement Savings Plan at a contribution rate of four percent of eligible compensation, from which they may opt out. We match 100 percent of a participant’s contributions, limited to four percent of the participant’s salary. Prior to January 1, 2021, participants were eligible to receive matching contributions after completing one year of service, in which they are immediately vested.

Effective January 1, 2021, participants are eligible to receive matching contributions immediately upon enrollment in the Retirement Savings Plan. This matching contribution vests after completing one year of service. Participants are also permitted to take out a loan against their accounts subject to certain restrictions. Employees hired on or after October 1, 2010 participate in the enhanced plan in which participants receive a fixed annual contribution of four percent of eligible earnings to their Retirement Savings Plan account. Participants will continue to be eligible for company matching contributions of up to four percent of their eligible earnings and will be fully vested in the fixed annual contribution after three years of service.

Effective October 1, 2022, the Retirement Savings Plan was amended to add a Roth elective deferral feature and to implement an automatic increase feature whereby a participant who contributes less than 10 percent will have their contribution percent increased by one percent annually unless the participant opts out.

Matching and fixed annual contributions to the Retirement Savings Plan are expensed as incurred and amounted to $21.9 million, $20.6 million and $17.9 million for fiscal years 2022, 2021 and 2020. At September 30, 2022 and 2021, the Retirement Savings Plan held 1.6 percent and 1.9 percent of our outstanding common stock.

11.    Stock and Other Compensation Plans

Stock-Based Compensation Plans

Total stock-based compensation cost was $22.2 million, $24.1 million and $21.1 million for the fiscal years ended September 30, 2022, 2021 and 2020. Of this amount, $11.5 million, $12.9 million and $11.6 million was capitalized.

1998 Long-Term Incentive Plan

We have the 1998 Long-Term Incentive Plan (LTIP), which provides a comprehensive, long-term incentive compensation plan providing for discretionary awards of incentive stock options, non-qualified stock options, stock appreciation rights, bonus stock, time-lapse restricted stock, time-lapse restricted stock units, performance-based restricted stock units and stock units to certain employees and non-employee directors of the Company and our subsidiaries. The objectives of this plan include attracting and retaining the best available personnel, providing for additional performance incentives and promoting our success by providing employees with the opportunity to acquire common stock.

We are authorized to grant awards up to a maximum cumulative amount of 11.2 million shares of common stock under this plan subject to certain adjustment provisions. As of September 30, 2022, non-qualified stock options, bonus stock, time-

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lapse restricted stock, time-lapse restricted stock units, performance-based restricted stock units and stock units had been issued under this plan, and 0.9 million shares are available for future issuance.

Restricted Stock Units Award Grants

As noted above, the LTIP provides for discretionary awards of restricted stock units to help attract, retain and reward employees of Atmos Energy and its subsidiaries. Certain of these awards vest based upon the passage of time and other awards vest based upon the passage of time and the achievement of specified performance targets. The fair value of the awards granted is based on the market price of our stock at the date of grant. We estimate forfeitures using our historical forfeiture rate. The associated expense is recognized ratably over the vesting period. We use authorized and unissued shares to meet share requirements for the vesting of restricted stock units.

Employees who are granted time-lapse restricted stock units under our LTIP have a nonforfeitable right to dividend equivalents that are paid at the same rate and at the same time at which they are paid on shares of stock without restrictions. Time-lapse restricted stock units contain only a service condition that the employee recipients render continuous services to the Company for a period of three years from the date of grant, except for accelerated vesting in the event of death, disability, change of control of the Company or termination without cause (with certain exceptions). There are no performance conditions required to be met for employees to be vested in time-lapse restricted stock units.

Employees who are granted performance-based restricted stock units under our LTIP have a forfeitable right to dividend equivalents that accrue at the same rate at which they are paid on shares of stock without restrictions. Dividend equivalents on the performance-based restricted stock units are paid either in cash or in the form of shares upon the vesting of the award. Performance-based restricted stock units contain a service condition that the employee recipients render continuous services to the Company for a period of three years from the beginning of the applicable three-year performance period, except for accelerated vesting in the event of death, disability, change of control of the Company or termination without cause (with certain exceptions) and a performance condition based on a cumulative earnings per share target amount.

The following summarizes information regarding the restricted stock units granted under the plan during the fiscal years ended September 30, 2022, 2021 and 2020:

	2022			2021			2020
	Number of Restricted Units	Weighted Average Grant-Date Fair Value		Number of Restricted Units	Weighted Average Grant-Date Fair Value		Number of Restricted Units	Weighted Average Grant-Date Fair Value
Nonvested at beginning of year	378,127	$	102.45	443,279	$	99.28	503,072	$	91.66
Granted	179,738	108.07		223,954	102.68		199,985	102.34
Vested	(159,019)	100.99		(271,435)	97.44		(242,975)	85.66
Forfeited	(17,551)	103.37		(17,671)	101.48		(16,803)	96.87
Nonvested at end of year	381,295	$	105.69	378,127	$	102.45	443,279	$	99.28

As of September 30, 2022, there was $14.1 million of total unrecognized compensation cost related to nonvested restricted stock units granted under the LTIP. That cost is expected to be recognized over a weighted average period of 1.4 years. The fair value of restricted stock vested during the fiscal years ended September 30, 2022, 2021 and 2020 was $16.0 million, $26.3 million and $20.7 million.

Other Plans

Direct Stock Purchase Plan

We maintain a Direct Stock Purchase Plan, open to all investors, which allows participants to have all or part of their cash dividends paid quarterly in additional shares of our common stock. The minimum initial investment required to join the plan is $1,250. Direct Stock Purchase Plan participants may purchase additional shares of our common stock as often as weekly with voluntary cash payments of at least $25, up to an annual maximum of $100,000.

Equity Incentive and Deferred Compensation Plan for Non-Employee Directors

We have an Equity Incentive and Deferred Compensation Plan for Non–Employee Directors, which provides non-employee directors of Atmos Energy with the opportunity to defer receipt, until retirement, of compensation for services rendered to the Company and invest deferred compensation into either a cash account or a stock account.

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Other Discretionary Compensation Plans

We have an annual incentive program covering substantially all employees to give each employee an opportunity to share in our financial success based on the achievement of key performance measures considered critical to achieving business objectives for a given year with minimum and maximum thresholds. The Company must meet the minimum threshold for the plan to be funded and distributed to employees. These performance measures may include earnings growth objectives, improved cash flow objectives or crucial customer satisfaction and safety results. We monitor progress towards the achievement of the performance measures throughout the year and record accruals based upon the expected payout using the best estimates available at the time the accrual is recorded. During the last several fiscal years, we have used earnings per share as our sole performance measure.

12.    Details of Selected Financial Statement Captions

The following tables provide additional information regarding the composition of certain financial statement captions.

Balance Sheet

Accounts receivable

Accounts receivable was comprised of the following at September 30, 2022 and 2021:

	September 30
	2022		2021
	(In thousands)
Billed accounts receivable	$	258,333	$	218,219
Unbilled revenue	121,518		97,417
Contributions in aid of construction receivable	5,390		18,984
Insurance receivable	13,160		53,779
Other accounts receivable	15,300		19,039
Total accounts receivable	413,701		407,438
Less: allowance for uncollectible accounts	(49,993)		(64,471)
Net accounts receivable	$	363,708	$	342,967

Other current assets

Other current assets as of September 30, 2022 and 2021 were comprised of the following accounts.

	September 30
	2022		2021
	(In thousands)
Deferred gas costs	$	119,742	$	66,395
Winter Storm Uri incremental costs	2,020,954		2,011,719
Prepaid expenses	58,551		48,766
Taxes receivable	11,911		—
Materials and supplies	25,880		15,581
Assets from risk management activities	26,207		55,073
Other	11,245		3,375
Total	$	2,274,490	$	2,200,909

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Property, plant and equipment

Property, plant and equipment was comprised of the following as of September 30, 2022 and 2021:

	September 30
	2022		2021
	(In thousands)
Storage plant	$	589,210	$	539,972
Transmission plant	4,325,540		3,725,347
Distribution plant	13,511,409		12,085,654
General plant	937,500		868,962
Intangible plant	38,612		38,612
	19,402,271		17,258,547
Construction in progress	835,868		626,551
	20,238,139		17,885,098
Less: accumulated depreciation and amortization	(2,997,900)		(2,821,128)
Net property, plant and equipment (1)	$	17,240,239	$	15,063,970

(1)     Net property, plant and equipment includes plant acquisition adjustments of $(26.6) million and $(28.5) million at September 30, 2022 and 2021.

Deferred charges and other assets

Deferred charges and other assets as of September 30, 2022 and 2021 were comprised of the following accounts.

	September 30
	2022		2021
	(In thousands)
Marketable securities	$	96,012	$	108,071
Regulatory assets (See Note 2)	368,375		351,843
Operating lease right of use assets (See Note 6)	214,663		222,446
Winter Storm Uri incremental costs	88,500		89,009
Assets from risk management activities	355,784		175,613
Pension assets	29,498		—
Other	20,968		27,738
Total	$	1,173,800	$	974,720

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Accounts payable and accrued liabilities

Accounts payable and accrued liabilities as of September 30, 2022 and 2021 were comprised of the following accounts.

	September 30
	2022		2021
	(In thousands)
Trade accounts payable	$	258,506	$	224,873
Accrued gas payable	157,942		100,699
Accrued liabilities	79,571		97,650
Total	$	496,019	$	423,222

Other current liabilities

Other current liabilities as of September 30, 2022 and 2021 were comprised of the following accounts.

	September 30
	2022		2021
	(In thousands)
Customer credit balances and deposits	$	56,016	$	49,722
Accrued employee costs	47,661		50,517
Deferred gas costs	28,834		52,553
Operating lease liabilities (See Note 6)	38,644		37,688
Accrued interest	59,542		55,164
Liabilities from risk management activities	3,000		5,269
Taxes payable	189,239		160,986
Pension and postretirement liabilities	9,721		4,863
Regulatory cost of removal obligation	80,676		72,823
APT annual adjustment mechanism	18,034		22,694
Regulatory excess deferred taxes (See Note 14)	159,808		155,857
Other	28,982		18,545
Total	$	720,157	$	686,681

Deferred credits and other liabilities

Deferred credits and other liabilities as of September 30, 2022 and 2021 were comprised of the following accounts.

	September 30
	2022		2021
	(In thousands)
Pension and postretirement liabilities	$	91,596	$	185,617
Operating lease liabilities (See Note 6)	184,301		194,745
Customer advances for construction	8,628		9,879
Other regulatory liabilities (See Note 2)	178,990		75,506
Asset retirement obligation	5,737		18,373
Liabilities from risk management activities	1,129		—
APT annual adjustment mechanism	13,104		8,416
Unrecognized tax benefits (See Note 14)	39,908		32,792
Other	14,909		12,161
Total	$	538,302	$	537,489

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Statement of Comprehensive Income

Other non-operating income (expense)

Other non-operating income (expense) for the fiscal years ended September 30, 2022, 2021 and 2020 were comprised of the following accounts.

	Year Ended September 30
	2022		2021		2020
	(In thousands)
Equity component of AFUDC	$	45,505	$	32,749	$	23,493
Performance-based rate program	8,327		6,362		6,771
Pension and other postretirement non-service credit (cost)	8,337		(19,238)		(3,189)
Interest income	2,781		2,144		2,932
Community support spending	(16,357)		(14,460)		(11,728)
Unrealized losses on equity securities	(7,737)		(860)		(4,176)
Miscellaneous	(7,119)		(8,842)		(6,932)
Total	$	33,737	$	(2,145)	$	7,171

Statement of Cash Flows

Supplemental disclosures of cash flow information for the fiscal years ended September 30, 2022, 2021 and 2020 were as follows:

	Year Ended September 30
	2022		2021		2020
	(In thousands)
Cash Paid (Received) During The Period For:
Interest (1)	$	234,297	$	207,555	$	194,993
Income taxes	$	15,760	$	8,199	$	(3,071)
Non-Cash Transactions:
Capital expenditures included in current liabilities	$	217,868	$	184,786	$	113,365

(1)    Cash paid during the period for interest, net of amounts capitalized was $98.4 million, $81.9 million and $82.3 million for the fiscal years ended September 30, 2022, 2021 and 2020.

13.    Commitments and Contingencies

Litigation and Environmental Matters

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

The National Transportation Safety Board (NTSB) held a public meeting on January 12, 2021 to determine the probable cause of the incident that occurred at a Dallas, Texas residence on February 23, 2018 that resulted in one fatality and injuries to four other residents. At the meeting, the Board deliberated and voted on proposed findings of fact, a probable cause statement, and safety recommendations. On February 8, 2021, the NTSB issued its final report that included an Executive Summary, Findings, Probable Cause and Recommendations. Also on February 8, 2021, safety recommendations letters were distributed to recommendation recipients, including Atmos Energy. Atmos Energy provided a written response on May 7, 2021. Following the release of the NTSB’s final report, the Railroad Commission of Texas (RRC) completed its safety evaluation related to the

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same incident finding four alleged violations and initiated an enforcement proceeding to pursue administrative penalties totaling $1.6 million. Atmos Energy is working with the RRC to resolve the alleged violations and satisfy the administrative penalties.

On October 26, 2022, the NTSB issued its final report that included Factual Information, Analysis and Probable Cause of a worksite accident that occurred in Farmersville, Texas on June 28, 2021 that resulted in two fatalities and injuries to two others. Three civil actions have been filed in Dallas, Texas against Atmos Energy and one of its contractors in response to the accident.

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 trading hubs or fixed price contracts. At September 30, 2022, we were committed to purchase 55.6 Bcf within one year and 89.1 Bcf within two to three years under indexed contracts. At September 30, 2022, we were committed to purchase 13.2 Bcf within one year under fixed price contracts with a weighted average price of $5.39 per Mcf. Purchases under these contracts totaled $352.6 million, $149.4 million and $58.5 million for 2022, 2021 and 2020.

Rate Regulatory Proceedings

As of September 30, 2022, routine rate regulatory proceedings were in progress in some of our service areas, which are discussed in further detail above in the Business — Ratemaking Activity section.

14.    Income Taxes

Income Tax Expense

The components of income tax expense from continuing operations for 2022, 2021 and 2020 were as follows:

	2022		2021		2020
	(In thousands)
Current
Federal	$	2,849	$	—	$	—
State	28,125		252		14,193
Deferred
Federal	43,435		128,867		143,039
State (1)	3,101		24,617		(11,879)
Income tax expense	$	77,510	$	153,736	$	145,353

(1)    Includes a non-cash income tax benefit of $21.0 million in fiscal 2020 resulting from the remeasurement of the rate at which state deferred taxes will reverse in the future as discussed below.

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Reconciliations of the provision for income taxes computed at the statutory rate of 21 percent to the reported provisions for income taxes from continuing operations for 2022, 2021 and 2020 are set forth below:

	2022		2021		2020
	(In thousands)
Tax at statutory rate	$	178,901	$	172,053	$	156,827
Common stock dividends deductible for tax reporting	(1,355)		(1,372)		(1,419)
State taxes (net of federal benefit)	24,669		19,647		22,791
Amortization of excess deferred taxes	(127,193)		(45,382)		(16,125)
Remeasurement due to state deferred tax rate change	—		—		(20,962)
Other, net	2,488		8,790		4,241
Income tax expense	$	77,510	$	153,736	$	145,353

Deferred income taxes reflect the tax effect of differences between the basis of assets and liabilities for book and tax purposes. The tax effect of temporary differences that gave rise to significant components of the deferred tax liabilities and deferred tax assets at September 30, 2022 and 2021 are presented below:

	2022		2021
	(In thousands)
Deferred tax assets:
Employee benefit plans	$	57,094	$	64,316
Net operating loss carryforwards	485,061		911,424
Charitable and other credit carryforwards	1,903		7,712
Regulatory excess deferred tax	110,548		148,200
Lease asset	50,007		52,138
Other	44,035		33,591
Total deferred tax assets	748,648		1,217,381
Valuation allowance	(523)		(663)
Net deferred tax assets	748,125		1,216,718
Deferred tax liabilities:
Difference in net book value and net tax value of assets	(2,431,757)		(2,258,264)
Gas cost adjustments	(43,964)		(26,413)
Winter Storm Uri regulatory asset	(20,710)		(471,025)
Lease liability	(50,007)		(52,138)
Rate deferral adjustment	(49,309)		(47,445)
Interest rate agreements	(106,820)		(20,156)
Other	(45,063)		(47,086)
Total deferred tax liabilities	(2,747,630)		(2,922,527)
Net deferred tax liabilities	$	(1,999,505)	$	(1,705,809)

We deduct our purchased gas costs for federal income tax purposes in the period they are paid. As a result of impacts from Winter Storm Uri, we recorded a $471.0 million (tax effected) increase in our deferred tax liability and an increase in our net operating loss carryforward as of September 30, 2021. As a result of the financing order issued by the Texas RRC on February 8, 2022, we reduced the deferred tax liability associated with the Winter Storm Uri regulatory asset and the corresponding deferred tax asset associated with net operating loss carry forwards by $450.3 million during fiscal 2022.

At September 30, 2022, we had $441.3 million (tax effected) of federal net operating loss carryforwards. The federal net operating loss carryforwards are available to offset future taxable income and have no expiration date. The Company has no charitable contribution carryforwards to offset future taxable income as of September 30, 2022.

78

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The Company also has $43.8 million (tax effected) of state net operating loss carryforwards (net of $11.4 million of federal effects) and $1.9 million of state tax credits carryforwards (net of $0.5 million of federal effects). Depending on the jurisdiction in which the state net operating loss was generated, the carryforwards expiration period begins in fiscal 2026.

At September 30, 2022, we had recorded liabilities associated with unrecognized tax benefits totaling $52.7 million, which includes $12.8 million in deferred tax liabilities. The following table reconciles the beginning and ending balance of our unrecognized tax benefits:

	2022		2021		2020
	(In thousands)
Unrecognized tax benefits - beginning balance	$	32,792	$	30,921	$	27,716
Increase (decrease) resulting from prior period tax positions	(721)		671		(26)
Increase resulting from current period tax positions	20,612		1,200		3,231
Unrecognized tax benefits - ending balance	52,683		32,792		30,921
Less: deferred federal and state income tax benefits	(11,063)		(6,886)		(6,493)
Total unrecognized tax benefits that, if recognized, would impact the effective income tax rate as of the end of the year	$	41,620	$	25,906	$	24,428

The Company recognizes interest accrued related to unrecognized tax benefits in interest expense and penalties included within interest charges in our consolidated statements of comprehensive income. During the years ended September 30, 2022, 2021 and 2020, the Company recognized approximately $1.3 million, $1.4 million and $0.7 million in interest and penalties. The Company had approximately $11.7 million, $10.4 million and $8.2 million for the payment of interest and penalties accrued at September 30, 2022, 2021 and 2020.

We file income tax returns in the U.S. federal jurisdiction as well as in various states where we have operations. We have concluded substantially all U.S. federal income tax matters through fiscal year 2009 and concluded substantially all Texas income tax matters through fiscal year 2010.

Regulatory Excess Deferred Taxes

Regulatory excess net deferred taxes represent changes in our net deferred tax liability related to our cost of service ratemaking due to the enactment of the Tax Cuts and Jobs Act of 2017 (the TCJA) and a Kansas legislative change enacted in fiscal 2020. As of September 30, 2022 and 2021, $159.8 million and $155.9 million is recorded in other current liabilities.

Currently, the regulatory excess net deferred tax liability is being returned over various periods. Of this amount, $404.2 million, is being returned to customers over 35 - 60 months. An additional $78.4 million is being returned to customers on a provisional basis over 15 - 69 years until our regulators establish the final refund periods. The refund of the remaining $15.1 million will be addressed in future rate proceedings.

15.    Financial Instruments

We currently use financial instruments to mitigate commodity price risk and interest rate risk. Our financial instruments do not contain any credit-risk-related or other contingent features that could cause accelerated payments when our financial instruments are in net liability positions.

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.

In jurisdictions where we are permitted to mitigate commodity price risk through financial instruments, the relevant regulatory authorities may establish the level of heating season gas purchases that can be hedged. Our distribution gas supply department is responsible for executing this segment’s commodity risk management activities in conformity with regulatory requirements. Historically, if the regulatory authority does not establish this level, we seek to hedge between 25 and 50 percent of anticipated heating season gas purchases using financial instruments. For the 2021-2022 heating season (generally October through March), in the jurisdictions where we are permitted to utilize financial instruments, we hedged approximately 42 percent, or approximately 23.9 Bcf of the winter flowing gas requirements at a weighted average cost of approximately $3.67 per Mcf. We have not designated these financial instruments as hedges for accounting purposes.

79

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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 September 30, 2022. These swaps were designated as cash flow hedges at the time the agreements were executed.

Planned Debt Issuance Date	Amount Hedged
	(In thousands)
Fiscal 2024	$	450,000
Fiscal 2025	600,000
Fiscal 2026	300,000
	$	1,350,000

Quantitative Disclosures Related to Financial Instruments

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

As of September 30, 2022, 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 September 30, 2022, we had 14,335 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 September 30, 2022 and 2021. As discussed in Note 2 to the consolidated financial statements, we report our financial instruments as risk management assets and liabilities, each of which is classified as current or noncurrent based upon the anticipated settlement date of the underlying financial instrument. The gross amounts of recognized assets and liabilities are netted within our consolidated balance sheets to the extent that we have netting arrangements with the counterparties. However, as of September 30, 2022 and 2021, no gross amounts and no cash collateral were netted within our consolidated balance sheet.

	Balance Sheet Location	Assets		Liabilities
		(In thousands)
September 30, 2022
Designated As Hedges:
Interest rate contracts	Deferred charges and other assets / Deferred credits and other liabilities	$	355,075	$	—
Total		355,075		—
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	26,207		(3,000)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	709		(1,129)
Total		26,916		(4,129)
Gross / Net Financial Instruments		$	381,991	$	(4,129)

80

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	Balance Sheet Location	Assets		Liabilities
		(In thousands)
September 30, 2021
Designated As Hedges:
Interest rate contracts	Deferred charges and other assets / Deferred credits and other liabilities	$	169,469	$	—
Total		169,469		—
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	55,073		(5,269)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	6,144		—
Total		61,217		(5,269)
Gross / Net Financial Instruments		$	230,686	$	(5,269)

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 designate as cash flow hedges at the time the agreements were executed. The net loss on settled interest rate agreements reclassified from AOCI into interest charges on our consolidated statements of comprehensive income for the years ended September 30, 2022, 2021 and 2020 was $3.8 million, $5.9 million and $5.5 million.

The following table summarizes the gains and losses arising from hedging transactions that were recognized as a component of other comprehensive income, net of taxes, for the years ended September 30, 2022 and 2021.

	Fiscal Year Ended September 30
	2022		2021
	(In thousands)
Increase in fair value:
Interest rate agreements	$	296,875	$	123,017
Recognition of losses in earnings due to settlements:
Interest rate agreements	2,976		4,566
Total other comprehensive income from hedging, net of tax	$	299,851	$	127,583

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 September 30, 2022, we had $94.1 million of net realized gains in AOCI associated with our interest rate agreements. The following amounts, net of deferred taxes, represent the expected recognition in earnings of the deferred net gains recorded in AOCI associated with our interest rate agreements, based upon the fair values of these agreements at the date of settlement. The remaining amortization periods for these settled amounts extend through fiscal 2053. However, the table below does not include the expected recognition in earnings of our outstanding interest rate agreements as those financial instruments have not yet settled.

81

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	Interest Rate Agreements
	(In thousands)
2023	$	2,120
2024	2,120
2025	2,120
2026	2,120
2027	2,120
Thereafter	83,547
Total	$	94,147

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 statements 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.

16.    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, accounts receivable and accounts payable 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.

Fair value measurements also apply to the valuation of our pension and postretirement plan assets. The fair value of these assets is presented in Note 10 to the consolidated financial statements.

Quantitative Disclosures

Financial Instruments

The classification of our fair value measurements requires judgment regarding the degree to which market data are observable or corroborated by observable market data. 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 September 30, 2022 and 2021. As required under authoritative accounting literature, 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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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	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, 2022
	(In thousands)
Assets:
Financial instruments	$	—	$	381,991	$	—	$	—	$	381,991
Debt and equity securities
Registered investment companies	26,367		—		—		—		26,367
Bond mutual funds	32,367		—		—		—		32,367
Bonds (2)	—		33,433		—		—		33,433
Money market funds	—		3,845		—		—		3,845
Total debt and equity securities	58,734		37,278		—		—		96,012
Total assets	$	58,734	$	419,269	$	—	$	—	$	478,003
Liabilities:
Financial instruments	$	—	$	4,129	$	—	$	—	$	4,129

	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, 2021
	(In thousands)
Assets:
Financial instruments	$	—	$	230,686	$	—	$	—	$	230,686
Debt and equity securities
Registered investment companies	35,175		—		—		—		35,175
Bond mutual funds	34,298		—		—		—		34,298
Bonds (2)	—		35,655		—		—		35,655
Money market funds	—		2,943		—		—		2,943
Total debt and equity securities	69,473		38,598		—		—		108,071
Total assets	$	69,473	$	269,284	$	—	$	—	$	338,757
Liabilities:
Financial instruments	$	—	$	5,269	$	—	$	—	$	5,269

(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 which 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. 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 September 30, 2022, no allowance for credit losses was recorded for our available-for-sale debt securities. At September 30, 2022 and 2021, the amortized cost of our available-for-sale debt securities was $34.1 million and $35.6 million. At September 30, 2022 we maintained investments in bonds that have contractual maturity dates ranging from October 2022 through September 2026.

Other Fair Value Measures

In addition to the financial instruments above, we have several financial and nonfinancial assets and liabilities subject to fair value measures. These financial assets and liabilities include cash and cash equivalents, accounts receivable, accounts payable, finance leases and debt, which are recorded at carrying value. The nonfinancial assets and liabilities include asset retirement obligations and pension and postretirement plan assets. For cash and cash equivalents, accounts receivable, accounts payable and finance leases we consider carrying value to materially approximate fair value due to the short-term nature of these assets and liabilities.

83

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Our long-term debt is recorded at carrying value. The fair value of our long-term debt, excluding finance leases, is determined using third party market value quotations, which are considered Level 1 fair value measurements for debt instruments with a recent, observable trade or Level 2 fair value measurements for debt instruments where fair value is determined using the most recent available quoted market price. The following table presents the carrying value and fair value of our long-term debt, excluding finances leases, debt issuance costs and original issue premium or discount, as of September 30, 2022:

	September 30, 2022
	(In thousands)
Carrying Amount	$	7,960,000
Fair Value	$	6,918,843

17.    Concentration of Credit Risk

Credit risk is the risk of financial loss to us if a customer fails to perform its contractual obligations. We engage in transactions for the purchase and sale of products and services with major companies in the energy industry and with industrial, commercial, residential and municipal energy consumers. These transactions principally occur in the southern and midwestern regions of the United States. We believe that this geographic concentration does not contribute significantly to our overall exposure to credit risk. Credit risk associated with trade accounts receivable for the distribution segment is mitigated by the large number of individual customers and the diversity in our customer base. The credit risk for our pipeline and storage segment is not significant.

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ITEM 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure.

None. 

ITEM 9A. 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 Rule 13a-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 September 30, 2022 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.

Management’s Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f), in providing reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we evaluated the effectiveness of our internal control over financial reporting based on the framework in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (COSO). Based on our evaluation under the framework in Internal Control-Integrated Framework issued by COSO and applicable Securities and Exchange Commission rules, our management concluded that our internal control over financial reporting was effective as of September 30, 2022, in providing reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.

Ernst & Young LLP has issued its report on the effectiveness of the Company’s internal control over financial reporting. That report appears below.

/s/    JOHN K. AKERS	/s/    CHRISTOPHER T. FORSYTHE
John K. Akers	Christopher T. Forsythe
President, Chief Executive Officer and Director	Senior Vice President and Chief Financial Officer
November 14, 2022

85

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholders and the Board of Directors of Atmos Energy Corporation

Opinion on Internal Control Over Financial Reporting

We have audited Atmos Energy Corporation’s internal control over financial reporting as of September 30, 2022, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO criteria). In our opinion, Atmos Energy Corporation (the Company) maintained, in all material respects, effective internal control over financial reporting as of September 30, 2022, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the 2022 consolidated financial statements of the Company and our report dated November 14, 2022 expressed an unqualified opinion thereon.

Basis for Opinion

The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. 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 Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.

Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

Definition and Limitations of Internal Control Over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ Ernst & Young LLP

Dallas, Texas

November 14, 2022

86

Changes in Internal Control over Financial Reporting

We did not make any changes in our internal control over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the Act) during the fourth quarter of the fiscal year ended September 30, 2022 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

ITEM 9B. Other Information.

Not applicable.

PART III

ITEM 10. Directors, Executive Officers and Corporate Governance.

Information regarding directors is incorporated herein by reference to the Company’s Definitive Proxy Statement for the Annual Meeting of Shareholders on February 8, 2023. Information regarding executive officers is reported below:

INFORMATION ABOUT OUR EXECUTIVE OFFICERS

The following table sets forth certain information as of September 30, 2022, regarding the executive officers of the Company. It is followed by a brief description of the business experience of each executive officer.

Name	Age	Years of Service	Office Currently Held
John K. Akers	59	31	President, Chief Executive Officer and Director
Christopher T. Forsythe	51	19	Senior Vice President and Chief Financial Officer
John S. McDill	58	35	Senior Vice President, Utility Operations
Karen E. Hartsfield	52	7	Senior Vice President, General Counsel and Corporate Secretary
John M. Robbins	52	9	Senior Vice President, Human Resources

John K. (Kevin) Akers was named President and Chief Executive Officer and was appointed to the Board of Directors effective October 1, 2019. Mr. Akers joined the company in 1991. Mr. Akers assumed increased responsibilities over time and was named President of the Mississippi Division in 2002. He was later named President of the Kentucky/Mid-States Division in May 2007, a position he held until December 2016. Effective January 1, 2017, Mr. Akers was named Senior Vice President, Safety and Enterprise Services and was responsible for customer service, facilities management, safety and supply chain management. In November 2018, Mr. Akers was named Executive Vice President and assumed oversight responsibility for APT.

Christopher T. Forsythe was named Senior Vice President and Chief Financial Officer effective February 1, 2017. Mr. Forsythe joined the Company in June 2003 and prior to this promotion, served as the Company's Vice President and Controller from May 2009 through January 2017. Prior to joining Atmos Energy, Mr. Forsythe worked in public accounting for 10 years.

John S. McDill was named Senior Vice President, Utility Operations, effective October 1, 2021. In this role, Mr. McDill is responsible for the operations of Atmos Energy's six utility divisions as well as gas supply. Prior to this promotion, Mr. McDill served as Vice President, Pipeline Safety from May 2012 to September 2021. Mr. McDill also served as Vice President of Operations in our Mississippi Division. Mr. McDill's years of service include that with Mississippi Valley Gas, a company acquired by Atmos Energy in 2002.

Karen E. Hartsfield was named Senior Vice President, General Counsel and Corporate Secretary of Atmos Energy, effective August 7, 2017. Ms. Hartsfield joined the Company in June 2015, after having served in private practice for 19 years, most recently as Managing Partner of Jackson Lewis LLP in its Dallas office from July 2013 to June 2015. Prior to joining Jackson Lewis as a partner in January 2009, Ms. Hartsfield was a partner with Baker Botts LLP in Dallas.

John M. (Matt) Robbins was named Senior Vice President, Human Resources, effective January 1, 2017. Mr. Robbins joined the Company in May 2013 and prior to this promotion served as Vice President, Human Resources from February 2015 to December 2016. Before joining Atmos Energy, Mr. Robbins had over 20 years of experience in human resources.

Identification of the members of the Audit Committee of the Board of Directors as well as the Board of Directors’ determination as to whether one or more audit committee financial experts are serving on the Audit Committee of the Board of

87

Directors is incorporated herein by reference to the Company’s Definitive Proxy Statement for the Annual Meeting of Shareholders on February 8, 2023.

The Company has adopted a code of ethics for its principal executive officer, principal financial officer and principal accounting officer. Such code of ethics is represented by the Company’s Code of Conduct, which is applicable to all directors, officers and employees of the Company, including the Company’s principal executive officer, principal financial officer and principal accounting officer. A copy of the Company's Code of Conduct, as well as any amendment to or waiver granted from a provision of the Company's Code of Conduct is posted on the Company's website at www.atmosenergy.com/company/corporate-responsibility-reports.

ITEM 11. Executive Compensation.

Information on executive compensation is incorporated herein by reference to the Company’s Definitive Proxy Statement for the Annual Meeting of Shareholders on February 8, 2023, under the captions "Director Compensation," "Compensation Discussion and Analysis," "Other Executive Compensation Matters" and "Named Executive Officer Compensation."

ITEM 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.

Security ownership of certain beneficial owners and of management is incorporated herein by reference to the Company’s Definitive Proxy Statement for the Annual Meeting of Shareholders on February 8, 2023, under the heading "Beneficial Ownership of Common Stock." Information concerning our equity compensation plans is provided in Part II, Item 5, “Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities”, of this Annual Report on Form 10-K.

ITEM 13. Certain Relationships and Related Transactions, and Director Independence.

Information on certain relationships and related transactions as well as director independence is incorporated herein by reference to the Company’s Definitive Proxy Statement for the Annual Meeting of Shareholders on February 8, 2023, under the heading "Corporate Governance and Other Board Matters," and "Proposal One – Election of Directors."

ITEM 14. Principal Accountant Fees and Services.

Information on our principal accountant’s fees and services is incorporated herein by reference to the Company’s Definitive Proxy Statement for the Annual Meeting of Shareholders on February 8, 2023, under the heading "Proposal Two – Ratification of Appointment of Independent Registered Public Accounting Firm."

PART IV

ITEM 15. Exhibits and Financial Statement Schedules.

(a)  1. and 2. Financial statements and financial statement schedules.

The financial statements listed in the Index to Financial Statements in Part II, Item 8 are filed as part of this Form 10-K. All financial statement schedules are omitted because the required information is not present, or not present in amounts sufficient to require submission of the schedule or because the information required is included in the financial statements and accompanying notes thereto.

3.     Exhibits

Exhibit Number	Description	Page Number or Incorporation by Reference to
	Articles of Incorporation and Bylaws
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)

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3.3	Amended and Restated Bylaws of Atmos Energy Corporation (as of February 5, 2019)	Exhibit 3.1 to Form 8-K dated February 5, 2019 (File No. 1-10042)
	Instruments Defining Rights of Security Holders, Including Indentures
4.1(a)	Specimen Common Stock Certificate (Atmos Energy Corporation)	Exhibit 4.1 to Form 10-K for fiscal year ended September 30, 2012 (File No. 1-10042)
4.1(b)	Description of Registrant's Securities	Exhibit 4.1(b) to Form 10-K for fiscal year ended September 30, 2021 (File No. 1-10042)
4.2	Indenture dated as of November 15, 1995 between United Cities Gas Company and Bank of America Illinois, Trustee	Exhibit 4.11(a) to Form S-3 dated August 31, 2004 (File No. 333-118706)
4.3	Indenture dated as of July 15, 1998 between Atmos Energy Corporation and U.S. Bank Trust National Association, Trustee	Exhibit 4.8 to Form S-3 dated August 31, 2004 (File No. 333-118706)
4.4	Indenture dated as of May 22, 2001 between Atmos Energy Corporation and SunTrust Bank, Trustee	Exhibit 99.3 to Form 8-K dated May 22, 2001 (File No. 1-10042)
4.5	Indenture dated as of March 26, 2009 between Atmos Energy Corporation and U.S. Bank National Corporation, Trustee	Exhibit 4.1 to Form 8-K dated March 26, 2009 (File No. 1-10042)
4.6(a)	Debenture Certificate for the 6 3/4% Debentures due 2028	Exhibit 99.2 to Form 8-K dated July 29, 1998 (File No. 1-10042)
4.6(b)	Global Security for the 5.95% Senior Notes due 2034	Exhibit 10(2)(g) to Form 10-K for fiscal year ended September 30, 2004 (File No. 1-10042)
4.6(c)	Officers' Certificate dated June 10, 2011	Exhibit 4.1 to Form 8-K dated June 13, 2011 (File No. 1-10042)
4.6(d)	Global Security for the 5.5% Senior Notes due 2041	Exhibit 4.2 to Form 8-K dated June 13, 2011 (File No. 1-10042)
4.6(e)	Officers' Certificate dated January 11, 2013	Exhibit 4.1 to Form 8-K dated January 15, 2013 (File No. 1-10042)
4.6(f)	Global Security for the 4.15% Senior Notes due 2043	Exhibit 4.2 to Form 8-K dated January 15, 2013 (File No. 1-10042)
4.6(g)	Officers' Certificate dated October 15, 2014	Exhibit 4.1 to Form 8-K dated October 17, 2014 (File No. 1-10042)
4.6(h)	Global Security for the 4.125% Senior Notes due 2044	Exhibit 4.2 to Form 8-K dated October 17, 2014 (File No. 1-10042)
4.6(i)	Officers' Certificate dated June 8, 2017	Exhibit 4.1 to Form 8-K dated June 8, 2017 (File No. 1-10042)
4.6(j)	Officers' Certificate dated October 4, 2018	Exhibit 4.1 to Form 8-K dated October 4, 2018 (File No. 1-10042)
4.6(k)	Global Security for the 4.300% Senior Notes due 2048	Exhibit 4.2 to Form 8-K dated October 4, 2018 (File No. 1-10042)
4.6(l)	Global Security for the 4.300% Senior Notes due 2048	Exhibit 4.3 to Form 8-K dated October 4, 2018 (File No. 1-10042)
4.6(m)	Officers' Certificate dated March 4, 2019	Exhibit 4.1 to Form 8-K dated March 4, 2019 (File No. 1-10042)
4.6(n)	Global Security for the 4.125% Senior Notes due 2049	Exhibit 4.2 to Form 8-K dated March 4, 2019 (File No. 1-10042)
4.6(o)	Officers' Certificate dated October 2, 2019	Exhibit 4.1 to Form 8-K dated October 2, 2019 (File No. 1-10042)

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4.6(p)	Global Security for the 2.625% Senior Notes due 2029	Exhibit 4.2 to Form 8-K dated October 2, 2019 (File No. 1-10042)
4.6(q)	Global Security for the 3.375% Senior Notes due 2049	Exhibit 4.3 to Form 8-K dated October 2, 2019 (File No. 1-10042)
4.6(r)	Officers' Certificate dated October 1, 2020	Exhibit 4.1 to Form 8-K dated October 1, 2020 (File No. 1-10042)
4.6(s)	Global Security for the 1.500% Senior Notes due 2031	Exhibit 4.2 to Form 8-K dated October 1, 2020 (File No. 1-10042)
4.6(t)	Global Security for the 1.500% Senior Notes due 2031	Exhibit 4.3 to Form 8-K dated October 1, 2020 (File No. 1-10042)
4.6(u)	Fixed Rate Notes Officers' Certificate dated March 9, 2021	Exhibit 4.1 to Form 8-K dated March 9, 2021 (File No. 1-10042)
4.6(v)	Floating Rate Notes Officers' Certificate dated March 9, 2021	Exhibit 4.2 to Form 8-K dated March 9, 2021 (File No. 1-10042)
4.6(w)	Global Security for the 0.625% Senior Notes due 2023	Exhibit 4.3 to Form 8-K dated March 9, 2021 (File No. 1-10042)
4.6(x)	Global Security for the 0.625% Senior Notes due 2023	Exhibit 4.4 to Form 8-K dated March 9, 2021 (File No. 1-10042)
4.6(y)	Global Security for the 0.625% Senior Notes due 2023	Exhibit 4.5 to Form 8-K dated March 9, 2021 (File No. 1-10042)
4.6(z)	Global Security for the Floating Rate Senior Notes due 2023	Exhibit 4.6 to Form 8-K dated March 9, 2021 (File No. 1-10042)
4.6(aa)	Global Security for the Floating Rate Senior Notes due 2023	Exhibit 4.7 to Form 8-K dated March 9, 2021 (File No. 1-10042)
4.6(bb)	Global Security for the Floating Rate Senior Notes due 2023	Exhibit 4.8 to Form 8-K dated March 9, 2021 (File No. 1-10042)
4.6(cc)	Officers' Certificate dated October 1, 2021	Exhibit 4.1 to Form 8-K dated October 1, 2021 (File No. 1-10042)
4.6(dd)	Global Security for the 2.850% Senior Notes due 2052	Exhibit 4.2 to Form 8-K dated October 1, 2021 (File No. 1-10042)
4.6(ee)	Global Security for the 2.850% Senior Notes due 2052	Exhibit 4.3 to Form 8-K dated October 1, 2021 (File No. 1-10042)
4.6(ff)	Officers' Certificate dated January 14, 2022	Exhibit 4.1 to Form 8-K dated January 14, 2022 (File No. 1-10042)
4.6(gg)	Global Security for the 2.625% Senior Notes due 2029	Exhibit 4.2 to Form 8-K dated January 14, 2022 (File No. 1-10042)
4.6(hh)	Officers' Certificate dated October 3, 2022	Exhibit 4.1 to Form 8-K dated October 3, 2022 (File No. 1-10042)
4.6(ii)	Global Security for the 5.450% Senior Notes due 2032	Exhibit 4.2 to Form 8-K dated October 3, 2022 (File No. 1-10042)
4.6(jj)	Global Security for the 5.750% Senior Notes due 2052	Exhibit 4.3 to Form 8-K dated October 3, 2022 (File No. 1-10042)
	Material Contracts
10.1(a)	Revolving Credit Agreement, dated as of March 31, 2021, among Atmos Energy Corporation, Crédit Agricole Corporate and Investment Bank, as the Administrative Agent, the agents, arrangers and bookrunners named therein, and the lenders named therein	Exhibit 10.1 to Form 8-K dated March 31, 2021 (File No. 1-10042)

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10.1(b)	First Amendment to Revolving Credit Agreement, dated as of March 31, 2022, among Atmos Energy Corporation, Credit Agricole Corporate and Investment Bank, as the Administrative Agent, the agents, arrangers and bookrunners named therein, and the lenders named therein	Exhibit 10.2 to Form 8-K dated April 1, 2022 (File No. 1-10042)
10.2(a)	Revolving Credit Agreement, dated as of March 31, 2021, among Atmos Energy Corporation, Crédit Agricole Corporate and Investment Bank, as the Administrative Agent, the agents, arrangers and bookrunners named therein, and the lenders named therein	Exhibit 10.2 to Form 8-K dated March 31, 2021 (File No. 1-10042)
10.2(b)	First Amendment to Revolving Credit Agreement, dated as of March 31, 2022, among Atmos Energy Corporation, Credit Agricole Corporate and Investment Bank, as the Administrative Agent, the agents, arrangers and bookrunners named therein, and the lenders named therein	Exhibit 10.1 to Form 8-K dated April 1, 2022 (File No. 1-10042)
10.3(a)	Equity Distribution Agreement, dated as of February 12, 2020, among Atmos Energy Corporation and the Managers and Forward Purchasers named in Schedule A thereto	Exhibit 1.1 to Form 8-K dated February 12, 2020 (File No. 1-10042)
10.3(b)	Form of Master Forward Sale Confirmation	Exhibit 1.2 to Form 8-K dated February 12, 2020 (File No. 1-10042)
10.4(a)	Equity Distribution Agreement, dated as of June 29, 2021, among Atmos Energy Corporation and the Managers and Forward Purchasers named in Schedule A thereto	Exhibit 1.1 to Form 8-K dated June 29, 2021 (File No. 1-10042)
10.4(b)	Form of Master Forward Sale Confirmation	Exhibit 1.2 to Form 8-K dated June 29, 2021 (File No. 1-10042)
10.5(a)	Equity Distribution Agreement, dated as of March 23, 2022, among Atmos Energy Corporation and the Managers and Forward Purchases named in Schedule A thereto	Exhibit 1.1 to Form 8-K dated March 23, 2022 (File No. 1-10042)
10.5(b)	Form of Master Forward Sale Confirmation	Exhibit 1.2 to Form 8-K dated March 23, 2022 (File No. 1-10042)
	Executive Compensation Plans and Arrangements
10.6(a)*	Form of Atmos Energy Corporation Change in Control Severance Agreement - Tier I	Exhibit 10.7(a) to Form 10-K for fiscal year ended September 30, 2010 (File No. 1-10042)
10.6(b)*	Form of Atmos Energy Corporation Change in Control Severance Agreement - Tier II	Exhibit 10.7(b) to Form 10-K for fiscal year ended September 30, 2010 (File No. 1-10042)
10.7(a)*	Atmos Energy Corporation Executive Retiree Life Plan	Exhibit 10.31 to Form 10-K for fiscal year ended September 30, 1997 (File No. 1-10042)
10.7(b)*	Amendment No. 1 to the Atmos Energy Corporation Executive Retiree Life Plan	Exhibit 10.31(a) to Form 10-K for fiscal year ended September 30, 1997 (File No. 1-10042)
10.8*	Atmos Energy Corporation Annual Incentive Plan for Management (as amended and restated August 3, 2021)	Exhibit 10.1 to Form 8-K dated August 3, 2021 (File No. 1-10042)
10.9(a)*	Atmos Energy Corporation Supplemental Executive Benefits Plan, Amended and Restated in its Entirety August 7, 2007	Exhibit 10.8(a) to Form 10-K for fiscal year ended September 30, 2008 (File No. 1-10042)

91

10.9(b)*	Form of Individual Trust Agreement for the Supplemental Executive Benefits Plan	Exhibit 10.3 to Form 10-Q for quarter ended December 31, 2000 (File No. 1-10042)
10.10(a)*	Atmos Energy Corporation Supplemental Executive Retirement Plan (As Amended and Restated, Effective as of January 1, 2016)	Exhibit 10.7(a) to Form 10-K for fiscal year ended September 30, 2016 (File No. 1-10042)
10.10(b)*	Atmos Energy Corporation Performance-Based Supplemental Executive Benefits Plan Trust Agreement, Effective Date December 1, 2000	Exhibit 10.1 to Form 10-Q for quarter ended December 31, 2000 (File No. 1-10042)
10.11*	Atmos Energy Corporation Account Balance Supplemental Executive Retirement Plan (As Amended and Restated, Effective as of January 1, 2022)	Exhibit 10.1 to Form 10-Q dated December 31, 2021 (File No. 1-10042)
10.12(a)*	Mini-Med/Dental Benefit Extension Agreement dated October 1, 1994	Exhibit 10.28(f) to Form 10-K for fiscal year ended September 30, 2001 (File No. 1-10042)
10.12(b)*	Amendment No. 1 to Mini-Med/Dental Benefit Extension Agreement dated August 14, 2001	Exhibit 10.28(g) to Form 10-K for fiscal year ended September 30, 2001 (File No. 1-10042)
10.12(c)*	Amendment No. 2 to Mini-Med/Dental Benefit Extension Agreement dated December 31, 2002	Exhibit 10.1 to Form 10-Q for quarter ended December 31, 2002 (File No. 1-10042)
10.13*	Atmos Energy Corporation Equity Incentive and Deferred Compensation Plan for Non-Employee Directors, Amended and Restated as of January 1, 2012	Exhibit 10.1 to Form 10-Q for quarter ended December 31, 2011 (File No. 1-10042)
10.14(a)*	Atmos Energy Corporation 1998 Long-Term Incentive Plan (as amended and restated February 3, 2021)
10.14(b)*	Form of Award Agreement of Time-Lapse Restricted Stock Units under the Atmos Energy Corporation 1998 Long-Term Incentive Plan	Exhibit 10.13(b) to Form 10-K for fiscal year ended September 20, 2020 (File No. 1-10042)
10.14(c)*	Form of Award Agreement of Performance-Based Restricted Stock Units under the Atmos Energy Corporation 1998 Long-Term Incentive Plan	Exhibit 10.13(c) to Form 10-K for fiscal year ended September 20, 2020 (File No. 1-10042)
10.14(d)*	Form of Non-Employee Director Award Agreement of Time-Lapse Restricted Stock Units Under the Atmos Energy Corporation 1998 Long-Term Incentive Plan	Exhibit 10.11(d) to Form 10-K for fiscal year ended September 30, 2019 (File No. 1-10042)
10.14(e)*	Form of Non-Employee Director Award Agreement of Stock Unit Awards Under The Atmos Energy Corporation 1998 Long-Term Incentive Plan	Exhibit 10.11(e) to Form 10-K for fiscal year ended September 30, 2019 (File No. 1-10042)
	Other Exhibits, as indicated
21	Subsidiaries of the registrant
23.1	Consent of independent registered public accounting firm, Ernst & Young LLP
24	Power of Attorney	Signature page of Form 10-K for fiscal year ended September 30, 2022
31	Rule 13a-14(a)/15d-14(a) Certifications
32	Section 1350 Certifications**
	Interactive Data File
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

92

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

*

This exhibit constitutes a "management contract or compensatory plan, contract, or arrangement."

**

These certifications 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 Annual Report on Form 10-K, will not be deemed to be filed with the Securities and Exchange 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.

ITEM 16. Form 10-K Summary.

Not applicable.

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SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	ATMOS ENERGY CORPORATION
	(Registrant)
By:	/s/    CHRISTOPHER T. FORSYTHE
	Christopher T. Forsythe Senior Vice President and Chief Financial Officer

Date: November 14, 2022

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POWER OF ATTORNEY

KNOW ALL MEN BY THESE PRESENTS, that each person whose signature appears below hereby constitutes and appoints John K. Akers and Christopher T. Forsythe, or either of them acting alone or together, as his true and lawful attorney-in-fact and agent with full power to act alone, for him and in his name, place and stead, in any and all capacities, to sign any and all amendments to this Annual Report on Form 10-K, and to file the same, with all exhibits thereto, and all other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorney-in-fact and agent full power and authority to do and perform each and every act and thing requisite and necessary to be done in and about the premises, as fully to all intents and purposes as he might or could do in person, hereby ratifying and confirming all that said attorney-in-fact and agent, may lawfully do or cause to be done by virtue hereof.

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated:

/s/    KIM R. COCKLIN	Chairman of the Board	November 14, 2022
Kim R. Cocklin
/s/    JOHN K. AKERS	President, Chief Executive Officer and Director	November 14, 2022
John K. Akers
/s/    CHRISTOPHER T. FORSYTHE	Senior Vice President and Chief Financial Officer	November 14, 2022
Christopher T. Forsythe
/s/    RICHARD M. THOMAS	Vice President and Controller (Principal Accounting Officer)	November 14, 2022
Richard M. Thomas
/s/    JOHN C. ALE	Director	November 14, 2022
John C. Ale
/s/    KELLY H. COMPTON	Director	November 14, 2022
Kelly H. Compton
/s/ SEAN DONOHUE	Director	November 14, 2022
Sean Donohue
/s/    RAFAEL G. GARZA	Director	November 14, 2022
Rafael G. Garza
/s/    RICHARD K. GORDON	Director	November 14, 2022
Richard K. Gordon
/s/    NANCY K. QUINN	Director	November 14, 2022
Nancy K. Quinn
/s/    RICHARD A. SAMPSON	Director	November 14, 2022
Richard A. Sampson
/s/ DIANA J. WALTERS	Director	November 14, 2022
Diana J. Walters
/s/    FRANK YOHO	Director	November 14, 2022
Frank Yoho

95