ATMOS ENERGY CORPORATION 2021 Annual Report Atmos Energy at a Glance We safely deliver reliable, affordable, and resilient natural gas to more than 3 million homes and businesses. Colorado-Kansas Division Denver, CO West Texas Division Lubbock, TX Atmos Energy Corporation Headquarters, Dallas, TX Kentucky/Mid-States Division Franklin, TN Waha Hub Mid-Tex Division Atmos Pipeline-Texas Division Dallas, TX Carthage Hub Louisiana Division Baton Rouge, LA Mississippi Division Flowood, MS Katy Hub Natural gas distribution areas Division offices Proprietary storage Major gas delivery hubs Financial Highlights 3 million+ Regulated distribution assets in eight states serving more than 3 million customers. $13-$14 billion Projected annual capital expenditures of about $13-$14 billion through fiscal 2026; over 80% spent on safety and reliability. 90% | 99% 6% to 8% Earning on about 90% of annual capital expenditures within 6 months and on 99% within 12 months. 6% to 8% forecasted earnings and dividends per share growth through fiscal 2026. 37 years 19 consecutive years of annual EPS growth; 37 consecutive years of annual dividend growth. ON THE COVER: Phillip, who works out of our Dallas Service Center, enjoys volunteering and coaching baseball, basketball and football teams in his community. Earnings Growth Through System and Business Modernization Constructive Regulatory Mechanisms Support System and Business Modernization $13-$14 billion in capital investments through 2026; >80% allocated to safety + Constructive rate mechanisms reducing regulatory lag = 6% to 8% consolidated EPS growth R AT E B A S E ( I N B I L L I O N S ) E A R N I N G O N A N N U A L E A R N I N G S P E R S H A R E Pipeline and Storage Distribution $21.0-$23.0 I N V E S T M E N T S Within 0 – 6 Months Within 7–12 Months Greater than 12 Months $12.1 $10.7 ~90% $25.0 $20.0 $15.0 $10.0 $5.0 $0 $8.00 $7.00 $6.00 $5.00 $4.00 $3.00 $2.00 $1.00 $0 $7.00-$7.40 $5.40-$5.60 $5.12 2020 2021 2026E 2021 2022E 2026E Fiscal 2021 by the Numbers $665.6 million $5.12 EPS $2.0 billion $2.50 share Net income for the fiscal year of $665.6 million, compared with adjusted net income of $580.5 million* in fiscal 2020. Earnings per diluted share in fiscal 2021 increased 8.5 percent compared to fiscal 2020 adjusted diluted earnings per share of $4.72,* marking our 19th consecutive annual increase. In fiscal 2021 we spent $2.0 billion to modernize our natural gas distribution and transmissions systems. Dividends paid in fiscal 2021 were $2.50 per share. *Adjusted net income and adjusted earnings per diluted share are Non-GAAP measures. See reconciliation on Page 2. ATMOS ENERGY CORPORATION | 1 In fiscal 2021, Atmos Energy continued our journey to being the safest provider of natural gas services. We invested $2.0 billion with about 88 percent of the capital investment dedicated to safety and reliability projects. These investments not only improved the safety of our assets but also our environmental footprint. And, although our capital spending has increased, our average monthly bill remains one of the most affordable utility bills in the household. 1,100 miles 58,000 lines 19 percent 217,000 hours 48 percent We replaced approximately 1,100 miles of natural gas distribution and transmission pipelines to make our system even safer and more reliable. We replaced more than 58,000 service lines. We have achieved 19 percent reduction in methane emissions from 2017 reported EPA values for distribution mains and services. We conducted 217,000 hours of safety and technical and other training in order to continue to provide safe and reliable service. The percentage of electronic bills issued increased to 48 percent. 230,000 wireless meters We installed approximately 230,000 wireless meter reading devices and now have nearly 1.9 million, which represents approximately 55% of our total meters. Non-GAAP Reconciliation — Adjusted Net Income and Earnings Per Diluted Share (in thousands, except per share data) 2021 2020 Net income Non-cash income tax benefit Adjusted net income Diluted net income per share Diluted EPS from non-cash income tax benefits Adjusted diluted net income per share 2 | ATM OS ENER GY CORPORATIO N $ 665,563 $ 601,443 — 665,563 5.12 — $ $ 5.12 $ (20,962) 580,481 4.89 (0.17) 4.72 $ $ $ A M E S S A G E F R O M L E A D E R S H I P Letter To Our Stakeholders iscal 2021 was our tenth year executing our investment strategy of operating safely and F reliably while we modernize our natural gas distribution, transmission, and storage systems. Over that ten-year period, we invested nearly $13 billion dollars in modernizing and expanding our natural gas systems. Those investments provided our natural gas systems the reliability and resiliency necessary J. Kevin Akers President and Chief Executive Officer November 12, 2021 to meet the human needs of our customers during the American Red Cross to support our neighbors in Winter Storm Uri, which impacted our service Louisiana in the aftermath of Hurricane Ida. Finally, territories in February. We invested $2.0 billion in during our annual Week of Giving in September, our fiscal 2021 with approximately 88 percent of that employees generously pledged over $800,000 in capital investment dedicated to safety and reliability donations to benefit No Kid Hungry, United Way and projects. We also replaced 1,100 miles of distribution The Salvation Army. Atmos Energy will match our em- and transmission mains and over 58,000 service ployee pledges, which will support the important work lines. Finally, these capital investments enabled us to these agencies do every day. make progress towards reducing methane emissions 50% by 2035 from 2017 levels for EPA-reported Financial performance distribution mains and services. Through the end of Earnings per diluted share for fiscal 2021 was $5.12, fiscal 2021 we have achieved an approximate 19% which was an 8.5 percent increase compared to fiscal reduction. As a result, our system is safer and more 2020 adjusted earnings per share and our nineteenth environmentally responsible. consecutive annual increase. Net income was $666 million, of which our distribution operations contrib- Building resilient communities uted 67 percent. During fiscal 2021, rate outcomes The resources we invest in our Fueling Safe and Thriv- increased our operating income by $186 million and ing Communities campaign help build strong, resilient we benefited from net customer growth exceeding one communities. In fiscal 2021, we donated over $14 percent. We raised over $3.4 billion of debt and equity million to support our friends and neighbors in need financing in fiscal 2021 that we used to support our throughout our 1,400 communities. We provided capital spending program and strengthen our funding that supplied 30,000 backpacks, lunchboxes, financial profile, including $2.2 billion of interim and water bottles. Through our Share the Warmth financing issued to pay for the gas costs incurred program we provided energy assistance to over 9,000 during Winter Storm Uri. We finished the fiscal year customers in need and we donated $1 million to with a very strong financial position with total liquidity *Adjusted earnings per diluted share is a Non-GAAP measure. See reconciliation on Page 2. ATMOS ENERGY CORPORATION | 3 A M E S S A G E F R O M L E A D E R S H I P Investing in Safety Investments Drive Rate Base Growth which Drives Earnings per Share Growth 6% to 8% Annually $7 $6 $5 $4 $3 $2 $1 $0 $7.00-$7.40 $5.12 2021 2026E Key Assumptions • Capital expenditures of $13 - $14 billion through fiscal 2026, financed with a blend of long-term debt and equity • Maintain existing regulatory mechanisms for infrastructure investment • Normal weather • O&M expense inflation rate of 3.0% - 3.5% annually • Approximately $7 billion to $8 billion of incremental financing through fiscal 2026 of $2.9 billion and an equity capitalization of 60.6 the end of fiscal 2021 to between $21 billion and $23 percent, excluding the interim winter storm financing. billion by the end of fiscal 2026 at a rate of between Outlook 11 percent and 13 percent per year. Accordingly, we project earnings per diluted share and dividends System modernization is an ongoing effort that per share will increase at an annual growth rate of requires significant capital investments and between 6 percent and 8 percent through fiscal 2026. partnering closely with regulators and customers to Our guidance for earnings per diluted share in fiscal achieve balanced regulatory constructs. Our portfolio 2022 ranges between $5.40 and $5.60. of regulatory mechanisms provides for the accelerated recovery of investments in safety that support our Fiscal year 2021 marked another successful chapter ability to continue to increase our capital spending. in our journey to becoming the nation’s safest provider Our capital spending for fiscal 2022 is forecasted to of natural gas services. Our performance this fiscal be between $2.4 billion and $2.5 billion. We expect year leaves us well positioned for continued success our capital expenditures through fiscal 2026 will be as we enter the second decade of our organic growth about $13 billion to $14 billion. Our total rate base is strategy focused on system modernization. expected to grow from approximately $12.1 billion at 4 | ATM OS ENER GY CORPORATIO N 10K FINANCIALS 116 PAGES (Mark One) Í ‘ UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 Form 10-K ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the fiscal year ended September 30, 2021 TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from to OR Commission file number 1-10042 Atmos Energy Corporation (Exact name of registrant as specified in its charter) Texas and Virginia (State or other jurisdiction of incorporation or organization) 1800 Three Lincoln Centre 5430 LBJ Freeway Dallas, Texas (Address of principal executive offices) 75-1743247 (IRS employer identification no.) 75240 (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 Common stock No Par Value ATO Securities registered pursuant to Section 12(g) of the Act: None Name of each exchange on which registered New York Stock Exchange Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes Í 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 ‘ 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 sub- ject to such filing requirements for the past 90 days. Yes Í No ‘ No ‘ No Í 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 Í 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 Í 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. Í Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes ‘ 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 No Í most recently completed second fiscal quarter, March 31, 2021, was $12,737,499,573. As of November 5, 2021, the registrant had 132,425,817 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 9, 2022 are incorporated by reference into Part III of this report. TABLE OF CONTENTS Glossary of Key Terms . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Item 1. Item 1A. Item 1B. Item 2. Item 3. Item 4. Item 5. Item 6. Item 7. Item 7A. Item 8. Item 9. Item 9A. Item 9B. Item 10. Item 11. Item 12. Item 13. Item 14. Item 15. Item 16. Part I Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Risk Factors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unresolved Staff Comments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Mine Safety Disclosures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Part II Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Selected Financial Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Management’s Discussion and Analysis of Financial Condition and Results of Operations . . Quantitative and Qualitative Disclosures About Market Risk . . . . . . . . . . . . . . . . . . . . . . . . . . Financial Statements and Supplementary Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Changes in and Disagreements With Accountants on Accounting and Financial Disclosure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Controls and Procedures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Part III Directors, Executive Officers and Corporate Governance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Executive Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Certain Relationships and Related Transactions, and Director Independence . . . . . . . . . . . . . . Principal Accountant Fees and Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Part IV Exhibits and Financial Statement Schedules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Form 10-K Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 99 103 Page 3 4 16 22 22 23 23 24 25 26 40 41 95 95 97 97 98 98 98 98 [THIS PAGE INTENTIONALLY LEFT BLANK] 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 . . . . . . . . . . . . . . . . . . . . . . . . . . . GasReliability Infrastructure Program GSRS . . . . . . . . . . . . . . . . . . . . . . . . . . . GasSystem Reliability Surcharge LIBOR . . . . . . . . . . . . . . . . . . . . . . . . . . London Interbank Offered Rate 1998 Long-Term Incentive Plan LTIP . . . . . . . . . . . . . . . . . . . . . . . . . . . Mcf MDWQ . . . . . . . . . . . . . . . . . . . . . . . . . Maximum daily withdrawal quantity Mid-Tex ATM Cities . . . . . . . . . . . . . . Represents a coalition of 47 incorporated cities or approximately . . . . . . . . . . . . . . . . . . . . . . . . . . . . Thousand cubic feet 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 SIR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . System Integrity Rider SRF . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stable Rate Filing SSIR . . . . . . . . . . . . . . . . . . . . . . . . . . . System Safety and Integrity Rider TCJA . . . . . . . . . . . . . . . . . . . . . . . . . . . TaxCuts and Jobs Act of 2017 WNA . . . . . . . . . . . . . . . . . . . . . . . . . . . Weather Normalization Adjustment 3 The terms “we,” “our,” “us,” “Atmos Energy” and the “Company” refer to Atmos Energy Corporation and its subsidiaries, unless the context suggests otherwise. PART I 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, afford- able, efficient and abundant natural gas through regulated sales and transportation arrangements to over three 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 intend to achieve this vision by: ‰ operating our business exceptionally well ‰ investing in safety, innovation and environmental sustainability, and ‰ achieving superior financial results. Since 2011, our operating strategy has focused on modernizing our distribution and transmission system while reducing regulatory lag. This operating strategy has allowed us to increase our capital expenditures approx- imately 13 percent per year to improve safety and reliability and to reduce methane emissions from our system. Our core values include focusing on our employees and customers while conducting our business with honesty and integrity. We continue to strengthen our culture through ongoing communications with our employ- ees and enhanced employee training. Operating Segments As of September 30, 2021, we manage and review our consolidated operations through the following report- able 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 Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . . . . . . . . . Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Texas, including the Dallas/Fort Worth Metroplex Kentucky Tennessee Virginia Louisiana Amarillo, Lubbock, Midland Mississippi Colorado Kansas Louisiana . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Mississippi . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Colorado-Kansas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Communities Served 550 Customer Meters 1,791,482 230 270 80 110 170 183,937 159,461 24,746 373,207 326,419 272,993 125,241 139,763 4 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, 2021, we held 1,025 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 oper- ate. 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. 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 fluctua- tions 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 market- ers. 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 2021 were Castleton Commodities Merchant Trading L.P., Cima Energy, LP, Concord Energy LLC, EnLink Gas Marketing LP, ETC Gas Marketing LTD, Hartree Partners, L.P., Kinder Morgan Texas Pipeline LLC, Symmetry Energy Solutions, LLC, Targa Gas Marketing LLC and Twin Eagle Resources 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 2021 was on February 14, 2021, when sales to custom- ers reached approximately 4.3 Bcf. Currently, our distribution divisions utilize 35 pipeline transportation companies, both interstate and intra- state, 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 nomi- nated flowing supplies. These agreements have been negotiated with the shortest term necessary while still main- taining 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 5 anticipated market demands or immediate delivery requirements because of factors such as the physical limi- tations 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, extend- ing 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 pro- ducers. 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 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 Louisi- ana distribution division for these services is subject to regulatory approval by the Louisiana Public Service Commission. We also manage two asset management plans in Louisiana 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 oper- ate. 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 provid- ing stable, predictable margins, which benefit both our customers and the Company. As a result of our rate- making 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 qual- ifying 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. 6 ‰ 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. The following table provides a jurisdictional rate summary for our regulated operations as of September 30, 2021. This information is for regulatory purposes only and may not be representative of our actual financial posi- tion. Division Jurisdiction Atmos Pipeline — Texas . . . Texas Colorado-Kansas . . . . . . . . . Colorado Colorado SSIR Kansas Kansas GSRS Kentucky/Mid-States . . . . . . Kentucky . . . . . . . . . . . . . . . . . . . . . . . Kentucky-PRP . . . . . . . . . . . . . . . . . . . . . . . Tennessee . . . . . . . . . . . . . . . . . . . . . . . Virginia . . . . . . . . . . . . . . . . . . . . . . . Virginia-SAVE Louisiana . . . . . . . . . . . . . . . Louisiana Mid-Tex . . . . . . . . . . . . . . . . Mid-Tex Cities(6) Mid-Tex - ATM Cities Mid-Tex - Environs Dallas Mississippi . . . . . . . . . . . . . . Mississippi(7) West Texas . . . . . . . . . . . . . . West Texas Cities(8) (10) Mississippi - SIR(7) West Texas - ALDC West Texas - Environs Bad Debt Rider(2) Jurisdiction Division 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) 05/11/2021 05/03/2018 01/01/2021 04/01/2020 02/01/2021 05/08/2019 10/01/2020 06/01/2021 04/01/2019 10/01/2020 07/01/2021 12/01/2020 06/11/2021 09/01/2021 06/09/2021 11/01/2020 11/01/2020 12/01/2020 06/01/2021 06/11/2021 $2,924,585 134,726 78,265 242,314 16,917 424,929 39,368 421,189 47,827 3,509 837,325 8.87% 47/53 7.55% 44/56 7.55% 44/56 7.03% 44/56 7.03% 44/56 7.49% 42/58 7.49% 42/58 7.62% 40/60 7.43% 42/58 7.43% 42/58 (4) 7.30% 3,726,295(5) 7.53% 42/58 4,307,060(5) 7.97% 40/60 4,307,060(5) 7.97% 40/60 4,293,195(5) 7.57% 41/59 (4) 7.81% 474,216 (4) 7.81% 247,414 660,893(9) 7.53% 42/58 751,829(9) 7.35% (4) 765,101(9) 7.97% 40/60 11.50% 9.45% 9.45% 9.10% 9.10% 9.65% 9.65% 9.80% 9.20% 9.20% (4) 9.80% 9.80% 9.80% 9.80% (4) (4) 9.80% (4) 9.80% Formula Rate Infrastructure Mechanism Performance Based Rate Program(3) WNA Period Atmos Pipeline — Texas . . . . . Texas Colorado-Kansas . . . . . . . . . . . Colorado Kansas Kentucky/Mid-States . . . . . . . . Kentucky Tennessee Virginia Louisiana . . . . . . . . . . . . . . . . . Louisiana Mid-Tex Cities . . . . . . . . . . . . . Texas Mid-Tex — Dallas . . . . . . . . . . Texas Mississippi . . . . . . . . . . . . . . . . Mississippi West Texas . . . . . . . . . . . . . . . Texas No No Yes Yes Yes Yes No Yes Yes No Yes Yes No No No Yes No Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes N/A No Yes Yes Yes No No No No No No N/A N/A October-May November-April October-April January-December December-March November-April November-April November-April October-May (1) The rate base, authorized rate of return, authorized debt/equity ratio and authorized return on equity pre- sented 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 bad debts. 7 (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 December 1, 2021, which included a rate base of $4,394.5 million, an authorized return of 7.36%, 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 14, 2021, which included a rate base of $797.6 million and an authorized return of 7.81%. New rates were implemented November 1, 2021. (8) The West Texas Cities includes all West Texas Division cities except Amarillo, Channing, Dalhart and Lubbock (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 December 1, 2021, which included a rate base of $759.0 million, an authorized return of 7.36%, 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 invest- ment 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. The following table summarizes the annualized ratemaking outcomes we implemented in each of the last three fiscal years. Rate Action Annual formula rate mechanisms . . . . . . . . . . . . . . Rate case filings . . . . . . . . . . . . . . . . . . . . . . . . . . . Other ratemaking activity . . . . . . . . . . . . . . . . . . . . 2021 Annual Increase (Decrease) to Operating Income For the Fiscal Year Ended September 30 2019 2020 (In thousands) $160,857 (1,057) 353 $181,459 5,119 (877) $114,810 1,656 214 Additionally, the ratemaking outcomes for the rate activity in fiscal 2021 include the refund of excess deferred income taxes resulting from previously enacted tax reform legislation and do not reflect the true economic benefit of the outcomes because they do not include the corresponding income tax benefit. Excluding these amounts, our total fiscal 2021 rate outcomes for ratemaking activities were $226.2 million. $185,701 $160,153 $116,680 8 The following ratemaking efforts seeking $56.5 million in annual operating income were initiated during fiscal 2021 but had not been completed or implemented as of September 30, 2021: Division Rate Action Jurisdiction Kentucky/Mid-States . . . . . . . . . . . Kentucky/Mid-States . . . . . . . . . . . Kentucky/Mid-States . . . . . . . . . . . Mid-Tex . . . . . . . . . . . . . . . . . . . . . Mississippi . . . . . . . . . . . . . . . . . . . Mississippi . . . . . . . . . . . . . . . . . . . West Texas . . . . . . . . . . . . . . . . . . . Infrastructure Mechanism Rate Case Infrastructure Mechanism Formula Rate Mechanism Infrastructure Mechanism Formula Rate Mechanism Formula Rate Mechanism Virginia (1) Kentucky (2) Kentucky Mid-Tex Cities (3) Mississippi (4) Mississippi (4) West Texas Cities (5) Operating Income Requested (In thousands) $ 350 14,394 3,506 29,707 8,354 (730) 903 $56,484 (1) On August 23, 2021, the State Corporation Commission of Virginia approved a rate increase of $0.3 million effective October 1, 2021. (2) The Kentucky rate case filing also includes the $3.5 million related to the annual Kentucky pipeline replacement program. (3) The Mid-Tex Cities approved a rate increase of $21.7 million, which includes $33.8 million related to the refund of excess deferred income taxes that will be offset by lower income tax expense. New rates will be implemented on December 1, 2021. (4) The Mississippi Public Service Commission (MPSC) approved an increase in operating income of $8.4 million for the SIR filing, which includes $2.1 million related to the refund of excess deferred income taxes that will be offset by lower income tax expense. The MPSC also approved a reduction in operating income of $5.6 million for the SRF filing, which includes $4.3 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, 2021. (5) The West Texas Cities approved a rate increase of $0.2 million, which includes $3.3 million related to the refund of excess deferred income taxes that will be offset by lower income tax expense. New rates will be implemented on December 1, 2021. 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 infra- structure programs in substantially all of our distribution divisions with tariffs in place to permit the investment associated with these programs to have their surcharge rate adjusted annually to recover approved capital costs incurred in a prior test-year period. The following table summarizes our annual formula rate mechanisms by state. 9 State Infrastructure Programs Formula Rate Mechanisms Annual Formula Rate Mechanisms Colorado . . . . . . . . . . System Safety and Integrity Rider (SSIR) — Kansas . . . . . . . . . . . . Gas System Reliability Surcharge (GSRS) Kentucky . . . . . . . . . . Pipeline Replacement Program (PRP) Louisiana . . . . . . . . . . (1) Mississippi . . . . . . . . . System Integrity Rider (SIR) Tennessee . . . . . . . . . (1) Texas . . . . . . . . . . . . . Gas Reliability Infrastructure Program (GRIP), (1) Virginia . . . . . . . . . . . Steps to Advance Virginia Energy (SAVE) — — — Rate Stabilization Clause (RSC) Stable Rate Filing (SRF) Annual Rate Mechanism (ARM) Dallas Annual Rate Review (DARR), Rate Review Mechanism (RRM) (1) Infrastructure mechanisms in Texas, Louisiana and Tennessee allow for the deferral of all expenses asso- ciated 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. The following table summarizes our annual formula rate mechanisms with effective dates during the fiscal years ended September 30, 2021, 2020 and 2019: Division Jurisdiction Test Year Ended 2021 Filings: Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Environs Louisiana . . . . . . . . . . . . . . . . . . . . . . . . . . . . Louisiana (1) (4) Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ATMCities (2) West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . Triangle (2) West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . Environs (2) Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . DARR (2) (4) Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . Tennessee ARM Atmos Pipeline - Texas . . . . . . . . . . . . . . . . . Texas Colorado-Kansas . . . . . . . . . . . . . . . . . . . . . . Kansas GSRS Colorado-Kansas . . . . . . . . . . . . . . . . . . . . . . Colorado SSIR Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Mid-Tex Cities RRM West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . West Texas Cities RRM Mississippi . . . . . . . . . . . . . . . . . . . . . . . . . . . Mississippi - SIR Mississippi . . . . . . . . . . . . . . . . . . . . . . . . . . . Mississippi - SRF Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . Virginia - SAVE Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . Kentucky PRP 12/2020 12/2020 12/2020 12/2020 12/2020 09/2020 09/2020 12/2020 09/2020 12/2021 12/2019 12/2019 10/2021 10/2021 09/2021 09/2021 Increase (Decrease) in Annual Operating Income (In thousands) $ 4,632 (2,407) 11,085 416 1,267 1,708 10,260 43,868 1,695 2,366 82,645 5,645 10,556 5,856 305 1,562 Effective Date 09/01/2021 07/01/2021 06/11/2021 06/11/2021 06/11/2021 06/09/2021 06/01/2021 05/11/2021 02/01/2021 01/01/2021 12/01/2020 12/01/2020 11/01/2020 11/01/2020 10/01/2020 10/01/2020 Total 2021 Filings (4) . . . . . . . . . . . . . . . . . $181,459 10 2020 Filings: Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . DARR Louisiana . . . . . . . . . . . . . . . . . . . . . . . . . . . . Louisiana (1) West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . Environs (3) Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . Tennessee ARM Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ATMCities (3) Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Environs (3) Atmos Pipeline - Texas . . . . . . . . . . . . . . . . . Texas West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . Amarillo, Lubbock, Dalhart and Channing (3) Colorado-Kansas . . . . . . . . . . . . . . . . . . . . . . Colorado SSIR Mississippi . . . . . . . . . . . . . . . . . . . . . . . . . . . Mississippi - SIR Mississippi . . . . . . . . . . . . . . . . . . . . . . . . . . . Mississippi - SRF Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . Virginia - SAVE Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . Kentucky PRP Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Mid-Tex RRM Cities West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . West Texas Cities RRM Total 2020 Filings . . . . . . . . . . . . . . . . . . . 2019 Filings: Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ATMCities Louisiana . . . . . . . . . . . . . . . . . . . . . . . . . . . . LGS Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Environs West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . Environs Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . DARR Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . Tennessee ARM Atmos Pipeline - Texas . . . . . . . . . . . . . . . . . Texas West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . Amarillo, Lubbock, Dalhart and Channing Colorado-Kansas . . . . . . . . . . . . . . . . . . . . . . Kansas GSRS Louisiana . . . . . . . . . . . . . . . . . . . . . . . . . . . . Trans La Colorado-Kansas . . . . . . . . . . . . . . . . . . . . . . Colorado GIS Colorado-Kansas . . . . . . . . . . . . . . . . . . . . . . Colorado SSIR Mississippi . . . . . . . . . . . . . . . . . . . . . . . . . . . Mississippi - SIR Mississippi . . . . . . . . . . . . . . . . . . . . . . . . . . . Mississippi - SRF Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . Tennessee ARM Mid-Tex . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Mid-Tex RRM Cities West Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . West Texas Cities RRM 09/2019 12/2019 12/2019 05/2019 12/2019 12/2019 12/2019 12/2019 12/2020 10/2020 10/2020 09/2020 09/2020 12/2018 12/2018 12/2018 12/2018 12/2018 12/2018 09/2018 05/2020 12/2018 12/2018 12/2018 09/2018 12/2019 12/2019 10/2019 10/2019 05/2019 12/2017 12/2017 $ 14,746 14,781 1,031 714 11,148 4,440 49,251 5,937 2,082 7,586 6,886 84 2,912 34,380 4,879 $160,857 $ 6,591 7,124 2,435 1,005 9,452 2,393 49,225 5,692 1,562 4,719 87 2,147 7,135 (118) (5,032) 17,633 2,760 09/01/2020 07/01/2020 06/16/2020 06/15/2020 06/12/2020 05/20/2020 05/20/2020 04/28/2020 01/01/2020 11/01/2019 11/01/2019 10/01/2019 10/01/2019 10/01/2019 10/01/2019 09/26/2019 07/01/2019 06/04/2019 06/04/2019 06/01/2019 06/01/2019 05/07/2019 05/01/2019 05/01/2019 04/01/2019 04/01/2019 01/01/2019 11/01/2018 11/01/2018 10/15/2018 10/01/2018 10/01/2018 Total 2019 Filings . . . . . . . . . . . . . . . . . . . $114,810 (1) Beginning in fiscal 2020, our Trans La and LGS filings were combined into one filing, per Commission order. (2) The rate increases for these filings were approved based on the effective dates herein; however, the new rates were implemented beginning September 1, 2021. (3) 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. (4) The rate change for the DARR and RSC filings include $15.1 million for the DARR filing and $24.2 million for the RSC filing related to the refund of excess deferred income taxes that will be offset by lower income tax expense. Excluding the amounts related to the refund of excess deferred taxes, our total fiscal 2021 rate outcomes for our formula rate mechanisms were $220.8 million. 11 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 cases: Division State 2021 Rate Case Filings: West Texas (ALDC) (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Texas Total 2021 Rate Case Filings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2020 Rate Case Filings: West Texas (Triangle) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Texas Colorado-Kansas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Kansas Total 2020 Rate Case Filings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2019 Rate Case Filings: Mid-Tex (ATM Cities) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Texas Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Kentucky Kentucky/Mid-States . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Virginia Mid-Tex (Environs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Texas West Texas (Environs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Texas Total 2019 Rate Case Filings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increase (Decrease) in Annual Operating Income (In thousands) $ 5,119 $ 5,119 $ (808) (249) $(1,057) $ 2,113 3,441 (400) (2,674) (824) $ 1,656 Effective Date 06/01/2021 04/21/2020 04/01/2020 06/01/2019 05/08/2019 04/01/2019 01/01/2019 01/01/2019 (1) The rate change for the West Texas (ALDC) filing includes $1.2 million related to the refund of excess deferred income taxes, which will be offset by lower income tax expense. Excluding this amount related to the refund of excess deferred income taxes, the increase to operating income for this filing was $6.3 million. 12 Other Ratemaking Activity The following table summarizes other ratemaking activity during the fiscal years ended September 30, 2021, 2020 and 2019: Division Jurisdiction Rate Activity 2021 Other Rate Activity: Colorado-Kansas . . . . . . . . . . . . . . . . . . . . Total 2021 Other Rate Activity . . . . . . . 2020 Other Rate Activity: Colorado-Kansas . . . . . . . . . . . . . . . . . . . . Total 2020 Other Rate Activity . . . . . . . 2019 Other Rate Activity: Colorado-Kansas . . . . . . . . . . . . . . . . . . . . Total 2019 Other Rate Activity . . . . . . . Kansas Ad Valorem (1) Kansas Ad Valorem(1) Kansas Ad-Valorem(1) Increase (Decrease) in Annual Operating Income (In thousands) $(877) $(877) $ 353 $ 353 $ 214 $ 214 Effective Date 02/01/2021 02/01/2020 02/01/2019 (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 con- formity 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 inter- state 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. 13 However, depending on the substance of these final rules, in addition to certain international regulatory require- ments still under development that are similar to Dodd–Frank, our swap counterparties could be subject to addi- tional 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 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 pipe- lines 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 also assists management in integrating responsibility and sustainability into strategic business activities to create long-term shareholder value. Our culture respects and appreciates inclusion and diversity. Thus, we strive to have a workforce that reflects the unique 1,400 communities that we serve. At September 30, 2021, we had 4,684 employees, sub- stantially unchanged from last year. We monitor our workforce data on a calendar year basis. As of December 31, 2020, 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. WORKFORCE BY GENDER 77% Men 23% Women WORKFORCE BY RACE/ETHNICITY 1% Asian 13% Black or African American 18% Hispanic or Latino <1% Native American or Alaska Native <1% Native Hawaiian or Pacific Islander <1% Two or more races 66% White 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 phys- ical, 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. 14 RECENT HIRES BY GENDER within 5 years 69% Men 31% Women RECENT HIRES BY RACE/ETHNICITY within 5 years 2% Asian 17% Black or African American 19% Hispanic or Latino 1% Native American or Alaska Native 5% Two or more races 56% White 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, under “Publications and SEC Filings” under the “Investors” tab under “Our Company”, as soon as reasonably practicable, after we electronically file these reports with, or furnish these 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 2021, John K. Akers, certified to the New York Stock Exchange that he was not aware of any violations by the Company of NYSE corporate gover- nance 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, www.atmosenergy.com, on the “Reports” page under “Corporate Responsibility.” We will also provide copies of all corporate governance documents free of charge upon request to Shareholder Relations at the address listed above. 15 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.” However, in the last several years, a number of regulatory authorities in the states we serve have approved rate mechanisms that provide for annual adjustments to rates that allow us to recover the cost of investments made to replace existing infrastructure or reflect changes in our cost of service. These mechanisms work to effec- tively reduce the regulatory lag inherent in the ratemaking process. However, 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 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 legis- lation also requires that our facilities, sites and other properties associated with our operations be operated, main- tained, 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 pipe- line and storage capacity. FERC has adopted rules designed to prevent market power abuse and market manipu- lation and to promote 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. These rules carry increased penalties for violations. Although we have taken steps to structure current and future transactions to comply with appli- cable current FERC regulations, changes in FERC regulations or their interpretation by FERC or additional regu- lations issued by FERC in the future could also adversely affect our business, financial condition or financial results. 16 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. 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 regu- latory initiatives may attempt to control or limit the causes of climate change, including greenhouse gas emis- sions, 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 infra- structure 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 custom- ers, reduce the demand for natural gas or cause fuel switching to other energy sources, and impact the com- petitive position of natural gas and the ability to serve new or existing customers, adversely affecting our business, results of operations and cash flows. 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 com- plying 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 main- tenance programs, all of which could require a potentially significant increase in operating costs. 17 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 oper- ations 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 sup- ply 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 dis- ruptions, 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. 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 oper- ations historically have faced limited competition from other existing intrastate pipelines and gas marketers seek- ing 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. 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. 18 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, although we believe it is likely that any such resulting impacts would occur very gradually over a long period of time and thus would be difficult to quantify with any degree of specificity. 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. The inability to continue to hire, train and retain operational, technical and managerial personnel could adversely affect our results of operations. Although the average age of the employee base of Atmos Energy is not significantly changing year over year, there are still a number of employees who will become eligible to retire within the next five to 10 years. If we were unable to hire appropriate personnel or contractors to fill future needs, the Company could encounter operating challenges and increased costs, primarily due to a loss of knowledge, 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 or increased safety compliance issues. The inability to hire, train and retain new operational, technical and managerial personnel adequately and to transfer institutional knowledge and expertise could adversely affect our ability to manage and operate our business. If we were unable to hire, train and retain appropriately qualified personnel, our results of operations could be adversely affected. 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 19 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 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. 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 oper- ations. 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 finan- cial results. 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. 20 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 mar- ket 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, we have been operating in a relatively low interest-rate environment in recent years compared to historical norms for both short and long-term interest rates. However, 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 concen- tration 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 United States, especially in the states in which we oper- ate, 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 alter- native 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 collection efforts 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. 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 eligi- ble 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 provi- sion 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. 21 The costs of providing a cash-balance pension plan to eligible full-time employees prior to 2011 and post- retirement health care benefits to eligible full-time employees and related funding requirements could be influ- enced 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 benefi- ciaries 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. The outbreak of COVID-19 or any other pandemic and their impact on business and economic conditions could negatively affect our business, results of operations and financial condition. The scale and scope of the COVID-19 outbreak, the resulting pandemic, any other future pandemic, and their impact on the economy and financial markets could adversely affect the Company’s business, results of operations and financial condition. Regarding COVID-19, as an essential business, the Company continues to provide natural gas services and has implemented business continuity and emergency response plans to continue to provide natural gas services to customers and support the Company’s operations, while taking health and safety measures such as implementing worker distancing measures and using a remote workforce where possible. However, there is no assurance that the continued spread of COVID-19 and efforts to contain the virus will not materially impact our business, results of operations and financial condition. ITEM 1B. Unresolved Staff Comments. Not applicable. ITEM 2. Properties. Distribution, transmission and related assets At September 30, 2021, in our distribution segment, we owned an aggregate of 71,921 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 5,699 miles of gas transmission lines. 22 Storage Assets We own underground gas storage facilities in several states to supplement the supply of natural gas in peri- ods of peak demand. The following table summarizes certain information regarding our underground gas storage facilities at September 30, 2021: State Distribution Segment Kentucky . . . . . . . . . . . . . . . . . . . . . . . . Kansas . . . . . . . . . . . . . . . . . . . . . . . . . . Mississippi . . . . . . . . . . . . . . . . . . . . . . . Usable Capacity (Mcf) Cushion Gas (Mcf)(1) Total Capacity (Mcf) 7,956,991 3,239,000 1,907,571 9,562,283 2,300,000 2,442,917 17,519,274 5,539,000 4,350,488 Total . . . . . . . . . . . . . . . . . . . . . . . . . . 13,103,562 14,305,200 27,408,762 Maximum Daily Delivery Capability (Mcf) 146,660 32,000 29,136 207,796 Pipeline and Storage Segment Texas . . . . . . . . . . . . . . . . . . . . . . . . . . . Louisiana . . . . . . . . . . . . . . . . . . . . . . . . 46,083,549 411,040 15,878,025 256,900 61,961,574 667,940 1,710,000 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. 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, 2021: Segment Division/Company Distribution Segment Colorado-Kansas Division Kentucky/Mid-States Division Louisiana Division Mid-Tex Division Mississippi Division West Texas Division Maximum Storage Quantity (MMBtu) 6,343,728 8,175,103 2,594,875 5,000,000 5,099,536 5,500,000 Maximum Daily Withdrawal Quantity (MDWQ)(1) 147,965 226,320 177,765 190,000 164,764 176,000 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32,713,242 1,082,814 Pipeline and Storage Segment Trans Louisiana Gas Pipeline, Inc. 1,000,000 47,500 Total Contracted Storage Capacity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33,713,242 1,130,314 (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. 23 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 2021 and 2020 are listed below. Quarter ended: December 31 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . March 31 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . June 30 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 30 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fiscal 2021 Fiscal 2020 $0.625 0.625 0.625 0.625 $ 2.50 $0.575 0.575 0.575 0.575 $ 2.30 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, 2021, there were 10,590 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 2021 that were not registered under the Securities Act of 1933, as amended. Performance Graph The performance graph and table below compares the yearly percentage change in our total return to share- holders 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, 2016 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. 24 $230 $220 $210 $200 $190 $180 $170 $160 $150 $140 $130 $120 $110 $100 $90 Comparison of Five-Year Cumulative Total Return among Atmos Energy Corporation, S&P 500 Index and S&P 500 Utilities Industry Index 9/30/2016 9/30/2017 9/30/2018 9/30/2019 9/30/2020 9/30/2021 Atmos Energy Corporation S&P 500 Stock Index S&P 500 Utilities Stock Index 9/30/2016 9/30/2017 Cumulative Total Return 9/30/2019 9/30/2018 Atmos Energy Corporation . . . . . S&P 500 Stock Index . . . . . . . . . S&P 500 Utilities Stock Index . . 100.00 100.00 100.00 115.17 118.61 112.03 131.91 139.85 115.31 163.30 145.80 146.56 9/30/2020 9/30/2021 140.06 167.89 139.28 132.61 218.27 154.61 The following table sets forth the number of securities authorized for issuance under our equity compensa- tion plans at September 30, 2021. Number of securities to be issued upon exercise of outstanding options, warrants and rights (a) Weighted-average exercise price of outstanding options, warrants and rights (b) Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) (c) Equity compensation plans approved by security holders: 1998 Long-Term Incentive Plan . . . . . . . 944,962(1) Total equity compensation plans approved by security holders Equity compensation plans not approved by security holders 944,962 — Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . 944,962 $ $ — — — — 1,054,190 1,054,190 — 1,054,190 (1) Comprised of a total of 328,369 time-lapse restricted stock units, 377,385 director share units and 239,208 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. 25 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 con- solidated 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 state- ments 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 state- ments 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, mar- kets, 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; the impact of greenhouse gas emissions or other legislation or regulations intended to address climate change; possi- ble 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 avail- ability and accessibility of contracted gas supplies, interstate pipeline and/or storage services; increased competi- tion from energy suppliers and alternative forms of energy; adverse weather conditions; the impact of climate change; the inability to continue to hire, train and retain operational, technical and managerial personnel; 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; 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; 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; increased costs of providing health care benefits, along with pension and postretirement health care benefits and increased funding requirements; and the outbreak of COVID-19 and its impact on business and economic con- ditions. Accordingly, while we believe these forward-looking statements to be reasonable, there can be no assur- ance 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. 26 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 judg- ments 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 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 rate- making and accounting practices and policies of the various regulatory commissions to which we are subject. Unbilled Revenue . . . . . . . . . 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 recog- nized. 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 regu- latory 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. We follow the revenue accrual method of account- ing for distribution segment revenues whereby revenues attributable to gas delivered to custom- ers, 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 author- ities, subject to refund. We recognize this revenue and establish a reserve for amounts that could be refunded based on our experience for the juris- diction in which the rates were implemented. 27 Factors Influencing Application of the Policy Decisions of regulatory authorities Issuance of new regu- lations 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 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 esti- mated deliveries Estimates of amounts bil- led subject to refund Critical Accounting Policy Pension and other postretirement plans Factors Influencing Application of the Policy 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 experi- ence trends Participant demographic information Actuarial mortality assumptions Impact of legislation Impact of regulation Summary of Policy 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, esti- mates 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 calculat- ing the actuarial present value of our pension and postretirement obligations and net periodic pen- sion and postretirement benefit plan costs. When establishing our discount rate, we consider high quality corporate bond rates based on bonds avail- able in the marketplace that are suitable for set- tling the obligations, changes in those rates from the prior year and the implied discount rate that is derived from matching our projected benefit dis- bursements 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 post- retirement 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 per- formance. 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 approx- imately ten to twelve years. 28 Critical Accounting Policy Summary of Policy Factors Influencing Application of the Policy Impairment assessments The market-related value of our plan assets repre- sents the fair market value of the plan assets, adjusted to smooth out short-term market fluctua- tions over a five-year period. The use of this meth- odology 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 legis- lation 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. We review the carrying value of our long-lived assets, including goodwill and identifiable intangibles, whenever events or changes in circum- stance 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 dis- counted cash flows Judgment in the evalua- tion of relevant data 29 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: 2021 Net income . . . . . . . . . . . . . . . . . . . . . . . . . $665,563 Non-cash income tax benefits . . . . . . . . . . — Adjusted net income . . . . . . . . . . . . . . . . . $665,563 Diluted net income per share . . . . . . . . . . . $ 5.12 Diluted EPS from non-cash income tax benefits . . . . . . . . . . . . . . . . . . . . . . . . . . Adjusted diluted net income per share . . . $ — 5.12 RESULTS OF OPERATIONS Overview 2021 vs. 2020 For the Fiscal Year Ended September 30 2019 2020 (In thousands, except per share data) $511,406 — $511,406 4.35 $ $64,120 20,962 $85,082 0.23 $ $601,443 (20,962) $580,481 4.89 $ (0.17) 4.72 $ — 4.35 $ 0.17 0.40 $ 2020 vs. 2019 $90,037 (20,962) $69,075 0.54 $ (0.17) 0.37 $ 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 sig- nificant level of capital spending. We have the ability to begin recovering a significant portion of these invest- ments 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: Distribution segment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $445,862 Pipeline and storage segment . . . . . . . . . . . . . . . . . . . . . . . . . . . 219,701 Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $665,563 2021 For the Fiscal Year Ended September 30 2020 (In thousands) $395,664 205,779 $601,443 $328,814 182,592 $511,406 2019 During fiscal 2021, we recorded net income of $665.6 million, or $5.12 per diluted share, compared to net income of $601.4 million, or $4.89 per diluted share in the prior year. After adjusting for a nonrecurring income tax benefit recognized during fiscal 2020, adjusted net income was $580.5 million, or $4.72 per diluted share in the prior year. The year-over-year increase in adjusted net income of $85.1 million largely reflects positive rate outcomes driven by safety and reliability spending and distribution customer growth, partially offset by lower service order revenues and higher bad debt expense in our distribution segment due to the temporary suspension of collection activities during the pandemic and increased spending on system maintenance activities. During the year ended September 30, 2021, we implemented ratemaking regulatory actions which resulted in an increase in annual operating income of $185.7 million. Excluding the impact of the refund of excess deferred income taxes resulting from previously enacted tax reform legislation, our total fiscal 2021 rate out- comes were $226.2 million. Additionally, we had ratemaking efforts in progress at September 30, 2021, seeking 30 a total increase in annual operating income of $56.5 million. As of the date of this report, we have received appro- val to implement $25.0 million of this amount in the first quarter of fiscal 2022. Excluding the impact of the refund of excess deferred income taxes resulting from previously enacted tax reform legislation, we have received approval to implement $68.5 million during the first quarter of fiscal 2022. During fiscal year 2021, we refunded $55.9 million in excess deferred tax liabilities to customers. The refunds reduced operating income and reduced our annual effective income tax rate to 18.8% in fiscal 2021 compared with 19.5% in fiscal 2020. Capital expenditures for fiscal 2021 increased 2 percent period-over-period, to $2.0 billion. Over 85 percent was invested to improve the safety and reliability of our distribution and transportation systems, with a sig- nificant portion of this investment incurred under regulatory mechanisms that reduce regulatory lag to six months or less. During fiscal 2021, we completed over $3.4 billion of long-term debt and equity financing, including $2.2 billion of incremental financing issued to pay for the purchased gas costs incurred during Winter Storm Uri. As of September 30, 2021, our equity capitalization was 51.9 percent. Excluding the $2.2 billion of incremental financing, our equity capitalization was 60.6 percent. As of September 30, 2021, we had approximately $2.9 billion in total liquidity, including cash and cash equivalents and funds available through equity forward sales agreements. 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 2022. 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 compli- cated 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 ini- tiatives in more detail. During fiscal 2021, we completed regulatory proceedings in our distribution segment resulting in a $141.8 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 2021 annualized rate outcomes in our distribution segment were $182.3 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 Mis- sissippi 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 79 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. 31 Review of Financial and Operating Results Financial and operational highlights for our distribution segment for the fiscal years ended September 30, 2021, 2020 and 2019 are presented below. 2021 Operating revenues . . . . . . . . . . . . . . . . Purchased gas cost . . . . . . . . . . . . . . . . . Operating expenses . . . . . . . . . . . . . . . . $3,241,973 1,501,695 1,121,764 For the Fiscal Year Ended September 30 2019 2020 (In thousands, unless otherwise noted) $2,745,461 1,268,591 1,006,098 $2,626,993 1,071,227 1,027,523 $614,980 430,468 94,241 2021 vs. 2020 2020 vs. 2019 $(118,468) (197,364) 21,425 Operating income . . . . . . . . . . . . . . . . Other non-operating income (expense) . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . Income before income taxes . . . . . . . . Income tax expense . . . . . . . . . . . . . . . . Non-cash income tax benefit (1) . . . . . . . 618,514 528,243 470,772 90,271 57,471 (20,694) 36,629 561,191 115,329 — (1,265) 39,634 487,344 105,147 (13,467) 6,241 60,031 416,982 88,168 — (19,429) (3,005) 73,847 10,182 13,467 (7,506) (20,397) 70,362 16,979 (13,467) Net income . . . . . . . . . . . . . . . . . . . . . . $ 445,862 $ 395,664 $ 328,814 $ 50,198 $ 66,850 Consolidated distribution sales volumes — MMcf . . . . . . . . . . . . . . . Consolidated distribution transportation volumes — MMcf . . . . . . . . . . . . . . . Total consolidated distribution 308,833 291,650 315,476 17,183 (23,826) 152,513 147,387 155,078 5,126 (7,691) throughput — MMcf . . . . . . . . . . . 461,346 439,037 470,554 22,309 (31,517) Consolidated distribution average cost of gas per Mcf sold . . . . . . . . . . . . . . $ 4.86 $ 3.67 $ 4.02 $ 1.19 $ (0.35) (1) See Note 14 to the consolidated financial statements for further information. Fiscal year ended September 30, 2021 compared with fiscal year ended September 30, 2020 Operating income for our distribution segment increased 17 percent, which primarily reflects: ‰ ‰ ‰ ‰ a $150.6 million increase in rate adjustments, primarily in our Mid-Tex, Mississippi, Louisiana and West Texas Divisions. a $19.2 million increase from customer growth primarily in our Mid-Tex Division. a $3.8 million decrease in employee related costs. a $5.0 million decrease in travel and entertainment expense. Partially offset by: ‰ ‰ ‰ ‰ ‰ a $43.6 million increase in depreciation expense and property taxes associated with increased capital investments. an $18.2 million increase in bad debt expense primarily due to the temporary suspension of collec- tion activities. a $12.8 million increase in pipeline maintenance and related activities. a $5.1 million increase in insurance expense. an $8.4 million decrease in service order revenues primarily due to the temporary suspension of collection activities. 32 The year-over- year change in other non-operating expense and interest charges of $22.4 million primarily reflects increased amortization of prior service cost associated with our Retiree Medical Plan, as presented in Note 12 to the consolidated financial statements. During fiscal 2021, we refunded $29.4 million in excess deferred taxes in the distribution segment, which reduced operating income year over year and reduced the annual effective income tax rate for this segment to 20.6% compared with 21.6% in the prior year. The fiscal year ended September 30, 2020 compared with fiscal year ended September 30, 2019 for our dis- tribution 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, 2020. The following table shows our operating income by distribution division, in order of total rate base, for the fiscal years ended September 30, 2021, 2020 and 2019. 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 2021 vs. 2020 2020 2019 2020 vs. 2019 Mid-Tex . . . . . . . . . . . . . . . . . . . . . Kentucky/Mid-States . . . . . . . . . . . Louisiana . . . . . . . . . . . . . . . . . . . . West Texas . . . . . . . . . . . . . . . . . . . Mississippi . . . . . . . . . . . . . . . . . . . Colorado-Kansas . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . 2021 $310,293 73,259 72,388 51,104 65,337 32,778 13,355 $236,066 76,745 71,892 52,493 55,938 34,039 1,070 (In thousands) $202,050 73,965 70,440 44,902 46,229 34,362 (1,176) $74,227 (3,486) 496 (1,389) 9,399 (1,261) 12,285 Total . . . . . . . . . . . . . . . . . . . . . . . . $618,514 $528,243 $470,772 $90,271 $34,016 2,780 1,452 7,591 9,709 (323) 2,246 $57,471 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 intra- state 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 Louisi- ana 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 regu- latory 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 pipe- lines. 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. 33 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 12, 2021, APT made a GRIP filing that covered changes in net property, plant and equipment investment from January 1, 2020 through December 31, 2020 with a requested increase in operating income of $44.0 million. On May 11, 2021, the Texas Railroad Commission approved an increase in operating income of $43.9 million. In February 2021, the RRC approved a reduction in revenue of $106.6 million to refund excess deferred tax liabilities to cus- tomers over 35 months. On December 21, 2016, the Louisiana Public Service Commission approved an annual increase of five per- cent to the demand fee charged by our natural gas transmission pipeline for each of the next 10 years, effective October 1, 2017. Review of Financial and Operating Results Financial and operational highlights for our pipeline and storage segment for the fiscal years ended September 30, 2021, 2020 and 2019 are presented below. 2021 Mid-Tex / Affiliate transportation revenue . . Third-party transportation revenue . . . . . . . . Other revenue . . . . . . . . . . . . . . . . . . . . . . . . . $497,730 127,874 11,743 Total operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total purchased gas cost Operating expenses . . . . . . . . . . . . . . . . . . . . Operating income . . . . . . . . . . . . . . . . . . . . . Other non-operating income . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . Income before income taxes . . . . . . . . . . . . Income tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Non-cash income tax benefit (1) 637,347 1,582 349,281 286,484 18,549 46,925 258,108 38,407 — 2019 For the Fiscal Year Ended September 30 2020 2021 vs. 2020 (In thousands, unless otherwise noted) $ 23,653 430 3,925 $428,586 129,930 8,508 $474,077 127,444 7,818 609,339 1,548 311,935 295,856 8,436 44,840 259,452 61,168 (7,495) 567,024 (360) 292,098 275,286 1,163 43,122 233,327 50,735 — 28,008 34 37,346 (9,372) 10,113 2,085 (1,344) (22,761) 7,495 2020 vs. 2019 $ 45,491 (2,486) (690) 42,315 1,908 19,837 20,570 7,273 1,718 26,125 10,433 (7,495) Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . $219,701 $205,779 $182,592 $ 13,922 $ 23,187 Gross pipeline transportation volumes — MMcf . . . . . . . . . . . . . . . . . . . 799,724 822,499 939,376 (22,775) (116,877) Consolidated pipeline transportation volumes — MMcf . . . . . . . . . . . . . . . . . . . 585,857 621,371 721,998 (35,514) (100,627) (1) See Note 14 to the consolidated financial statements for further information. Fiscal year ended September 30, 2021 compared with fiscal year ended September 30, 2020 Operating income for our pipeline and storage segment decreased three percent, which primarily reflects: ‰ ‰ ‰ an $8.2 million net decrease in APT’s thru-system activities primarily associated with the tighten- ing of regional spreads driven by increased competing takeaway capacity in the Permian Basin. a $17.1 million increase in system maintenance expense primarily due to spending on hydro test- ing and in-line inspections. a $17.0 million increase in depreciation expense and property taxes associated with increased capital investments. 34 Partially offset by: ‰ a $56.2 million increase due to rate adjustments from the GRIP filings approved in May 2020 and 2021. The increase in rates was driven by increased safety and reliability spending. The year-over- year change in other non-operating income and interest charges of $8.0 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 2021. During fiscal 2021 we refunded $26.5 million in excess deferred taxes in our pipeline and storage segment, which reduced operating income year over year and reduced the annual effective tax rate for this segment to 14.9% compared with 23.6% in the prior year. The fiscal year ended September 30, 2020 compared with fiscal year ended September 30, 2019 for our pipeline and storage segment is described in Item 7 “Management’s Discussion and Analysis of Financial Con- dition and Results of Operations” of our Annual Report on Form 10-K for the fiscal year ended September 30, 2020. 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, approx- imately $3.4 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, 2021, approximately $760 million of equity is available for issuance under this ATM equity sales program. Additionally, as of September 30, 2021, we had $302.0 million in avail- able proceeds from outstanding forward sale agreements that must be settled during fiscal 2022. During fiscal 2021, we entered into forward starting interest rate swaps to effectively fix the Treasury yield component associated with $1.4 billion of planned issuances of unsecured senior notes. During fiscal 2021, we settled swaps of $600 million with a net receipt of $62.2 million. On October 1, 2021, the notes were issued as planned. The following table summarizes our existing forward starting interest rate swaps as of September 30, 2021. Planned Debt Issuance Date Effective Interest Rate Fiscal 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fiscal 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fiscal 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fiscal 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amount Hedged (In thousands) 500,000 450,000 600,000 300,000 1.66% 1.80% 1.75% 2.16% 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. $1,850,000 35 The following table presents our capitalization as of September 30, 2021 and 2020: Short-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Shareholders’ equity (2) $ September 30 2021 2020 (In thousands, except percentages) — —% $ — 4,531,944 7,330,657 6,791,203 7,906,889 48.1% 51.9% —% 40.0% 60.0% Total capitalization, including short-term debt . . . . . . . . . . . . . . $15,237,546 100.0% $11,323,147 100.0% (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 60.6%. 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. Cash flows from operating, investing and financing activities for the years ended September 30, 2021, 2020 and 2019 are presented below. Total cash provided by (used in) Operating activities . . . . . . . . . . . . . Investing activities . . . . . . . . . . . . . . Financing activities . . . . . . . . . . . . . Change in cash and cash 2021 For the Fiscal Year Ended September 30 2019 2020 (In thousands) 2021 vs. 2020 2020 vs. 2019 $(1,084,251) (1,963,655) 3,143,821 $ 1,037,999 (1,925,518) 883,777 $ 968,769 (1,683,660) 725,670 $(2,122,250) (38,137) 2,260,044 $ 69,230 (241,858) 158,107 equivalents . . . . . . . . . . . . . . . . . . 95,915 (3,742) 10,779 99,657 (14,521) Cash and cash equivalents at beginning of period . . . . . . . . . . . 20,808 24,550 13,771 (3,742) 10,779 Cash and cash equivalents at end of period . . . . . . . . . . . . . . . . . . . . . . $ 116,723 $ 20,808 $ 24,550 $ 95,915 $ (3,742) Cash flows for the fiscal year ended September 30, 2020 compared with fiscal year ended September 30, 2019 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, 2020. Cash flows from operating activities For the fiscal year ended September 30, 2021, cash flow used from operating activities was $1.1 billion compared with cash flows generated from operating activities of $1.0 billion in the prior year. The year-over-year decrease in operating cash flows reflects gas costs incurred during Winter Storm Uri and the timing of customer collections partially offset by the positive effects of successful rate case outcomes achieved in fiscal 2020 and 2021. Cash flows from investing activities Our capital expenditures are primarily used to improve the safety and reliability of our distribution and trans- mission 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. 36 For the fiscal year ended September 30, 2021, we had $1.97 billion in capital expenditures compared with $1.94 billion for the fiscal year ended September 30, 2020. Capital spending increased by $33.8 million, or two percent, as a result of planned increases to modernize our system. Cash flows from financing activities Our financing activities provided $3.1 billion and $883.8 million in cash for fiscal years 2021 and 2020. 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 gen- eral 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. During the fiscal year ended September 30, 2020, we received $1.6 billion in net proceeds from the issuance of long-term debt and equity. We completed a public offering of $300 million of 2.625% senior notes due 2029 and $500 million of 3.375% senior notes due 2049 and entered into a two year $200 million term loan. We received net proceeds from these offerings, after the underwriting discount and offering expenses, of $791.7 million. Additionally, we settled 6,101,916 shares that had been sold on a forward basis for net proceeds of approximately $624 million. The net proceeds were used primarily to support capital spending, reduce short- term debt and other general corporate purposes. Cash dividends increased due to a 9.5 percent increase in our dividend rate and an increase in shares outstanding. The following table shows the number of shares issued for the fiscal years ended September 30, 2021, 2020 and 2019: Shares issued: For the Fiscal Year Ended September 30 2020 2019 2021 Direct Stock Purchase Plan . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Retirement Savings Plan and Trust 1998 Long-Term Incentive Plan (LTIP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity Issuance (1) 79,921 84,265 242,216 6,130,875 107,989 78,941 254,706 6,101,916 110,063 81,456 299,612 7,574,111 Total shares issued . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6,537,277 6,543,552 8,065,242 (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 and Moody’s reaffirmed its long-term and short-term credit ratings and placed our ratings under negative out- look. 37 As of September 30, 2021, 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- A-2 Short-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Outlook . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Negative A1 P-1 Negative A significant degradation in our operating performance or a significant reduction in our liquidity caused by more limited access to the private and public credit markets as a result of deteriorating global or national finan- cial 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, 2021. Our debt covenants are described in Note 7 to the consolidated financial statements. Contractual Obligations and Commercial Commitments The following table provides information about contractual obligations and commercial commitments at September 30, 2021. Contractual Obligations . . . . . . . . . . . . . . . . . . Long-term debt (1) . . . . . . . . . . . . . . . . . . Interest charges (2) . . . . . . . . . . . . . . . . . . . Finance leases (3) Operating leases (4) . . . . . . . . . . . . . . . . . Financial instrument obligations (5) . . . . . Pension and postretirement benefit plan contributions (6) Uncertain tax positions (7) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Payments Due by Period Total Less than 1 year 1-3 years (In thousands) 3-5 years More than 5 years $ 7,360,000 4,268,559 29,809 271,074 5,269 $200,000 221,325 1,342 41,822 5,269 $2,200,000 418,664 2,753 68,043 — $ 10,000 412,654 2,846 39,359 — $4,950,000 3,215,916 22,868 121,850 — 315,298 32,792 26,126 — 59,252 32,792 90,829 — 139,091 — Total contractual obligations . . . . . . . . $12,282,801 $495,884 $2,781,504 $555,688 $8,449,725 (1) Long-term debt excludes our finance lease obligations, which are separately reported within this table. The $1.1 billion of 0.625% senior notes and $1.1 billion floating rate senior notes that were issued in March 2021 contractually mature in 2023; however, we intend to repay these after the receipt of securitization funds, which we expect will occur in the next twelve months. As such, we have classified the senior notes as current maturities of long-term debt as of September 30, 2021. See Notes 7 and 9 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 $11.1 million. See Note 6 to the consolidated financial statements. 38 (4) Operating lease payments shown above include interest totaling $38.6 million. See Note 6 to the con- solidated financial statements. (5) Represents liabilities for natural gas commodity financial instruments that were valued as of September 30, 2021. 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 dis- cussed 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. We maintain supply contracts with several vendors that generally cover a period of up to one year. Commit- ments 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, 2021, we were committed to pur- chase 32.4 Bcf within one year and 12.9 Bcf within two to three years under indexed contracts. At September 30, 2021, we were committed to purchase 11.9 Bcf within one year under fixed price contracts ranging from $1.86 to $7.03 per Mcf. Risk Management Activities In our distribution and pipeline and storage segments, we use a combination of physical storage, fixed phys- ical 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 instru- ment. Substantially all of our financial instruments are valued using external market quotes and indices. The following table shows the components of the change in fair value of our financial instruments for the fiscal year ended September 30, 2021 (in thousands): Fair value of contracts at September 30, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Contracts realized/settled . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fair value of new contracts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other changes in value . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 78,663 (64,205) 13,136 197,823 Fair value of contracts at September 30, 2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Netting of cash collateral . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 225,417 — Cash collateral and fair value of contracts at September 30, 2021 . . . . . . . . . . . . . . . . . . . . . $225,417 The fair value of our financial instruments at September 30, 2021, is presented below by time period and fair value source: Source of Fair Value Fair Value of Contracts at September 30, 2021 Maturity in years Less than 1 1-3 4-5 (In thousands) $81,091 — Greater than 5 Total Fair Value $— — $— $225,417 — $225,417 Prices actively quoted . . . . . . . . . . . . . . . . . . . . . . . . . . . Prices based on models and other valuation methods . . $49,804 — $94,522 — Total Fair Value . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $49,804 $94,522 $81,091 39 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 dis- tribution segment, we use a combination of physical storage, fixed-price forward contracts and financial instru- ments, 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 aver- age one percent increase in the interest rates associated with our short-term borrowings. Had interest rates asso- ciated with our short-term borrowings increased by an average of one percent, our interest expense would not have materially increased during 2021. 40 ITEM 8. Financial Statements and Supplementary Data. Index to financial statements and financial statement schedules: Report of independent registered public accounting firm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Financial statements and supplementary data: Consolidated balance sheets at September 30, 2021 and 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated statements of comprehensive income for the years ended September 30, 2021, 2020 and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated statements of shareholders’ equity for the years ended September 30, 2021, 2020 and 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Consolidated statements of cash flow for the years ended September 30, 2021, 2020 and 2019 . . . . . . . Notes to consolidated financial statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Page 42 44 45 46 47 48 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. 41 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, 2021 and 2020, the related consolidated statements of comprehensive income, shareholders‘ equity, and cash flows, for each of the three years in the period ended September 30, 2021, and the related notes (collectively referred to as the “consolidated financial statements”). In our opinion, the con- solidated financial statements present fairly, in all material respects, the financial position of the Company at September 30, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended September 30, 2021, in conformity with US 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, 2021, 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 12, 2021 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 US federal securities laws and the applicable rules and regulations of the Securities and Exchange Commis- sion 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 proce- dures 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 finan- cial 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. 42 Description of the Matter Determination of Capital Costs 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, 2021, the Company capitalized approximately $2.0 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. 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 ini- tiated 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 proj- ects. /s/ Ernst & Young LLP We have served as the Company‘s auditor since 1983. Dallas, Texas November 12, 2021 43 ATMOS ENERGY CORPORATION CONSOLIDATED BALANCE SHEETS Property, plant and equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Construction in progress . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ASSETS Less accumulated depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . September 30 2021 2020 (In thousands, except share data) $17,258,547 626,551 17,885,098 2,821,128 $15,539,166 418,055 15,957,221 2,601,874 Net property, plant and equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15,063,970 13,355,347 Current assets Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accounts receivable, less allowance for uncollectible accounts of $64,471 in 2021 and $29,949 in 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gas stored underground . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current assets (See Note 9) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Goodwill Deferred charges and other assets (See Note 9) . . . . . . . . . . . . . . . . . . . . . . . . . . . CAPITALIZATION AND LIABILITIES Shareholders’ equity Common stock, no par value (stated at $0.005 per share); 200,000,000 shares authorized; issued and outstanding: 2021 — 132,419,754 shares; 2020 — 125,882,477 shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Additional paid-in capital Accumulated other comprehensive income (loss) . . . . . . . . . . . . . . . . . . . . . . . Retained earnings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Shareholders’ equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term debt 116,723 20,808 342,967 178,116 2,200,909 2,838,715 731,257 974,720 $19,608,662 230,595 111,950 107,905 471,258 731,257 801,170 $15,359,032 $ 662 5,023,751 69,803 2,812,673 7,906,889 4,930,205 $ 629 4,377,149 (57,589) 2,471,014 6,791,203 4,531,779 Total capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12,837,094 11,322,982 Commitments and contingencies (See Note 13) Current liabilities Accounts payable and accrued liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Current maturities of long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory excess deferred taxes (See Note 14) . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory cost of removal obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred credits and other liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 423,222 686,681 2,400,452 3,510,355 1,705,809 549,227 468,688 537,489 235,775 546,461 165 782,401 1,456,569 697,764 457,188 642,128 $19,608,662 $15,359,032 See accompanying notes to consolidated financial statements. 44 ATMOS ENERGY CORPORATION CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME 2021 Year Ended September 30 2020 (In thousands, except per share data) 2019 Operating revenues Distribution segment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pipeline and storage segment Intersegment eliminations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $3,241,973 637,347 (471,830) $2,626,993 609,339 (415,195) $2,745,461 567,024 (410,637) Total operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3,407,490 2,821,137 2,901,848 Purchased gas cost Distribution segment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pipeline and storage segment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Intersegment eliminations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total purchased gas cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operation and maintenance expense . . . . . . . . . . . . . . . . . . . . . . . . . . . Depreciation and amortization expense . . . . . . . . . . . . . . . . . . . . . . . . Taxes, other than income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other non-operating income (expense) . . . . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income before income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,501,695 1,582 (470,560) 1,032,717 679,019 477,977 312,779 904,998 (2,145) 83,554 819,299 153,736 1,071,227 1,548 (413,921) 1,268,591 (360) (409,394) 658,854 629,601 429,828 278,755 824,099 7,171 84,474 746,796 145,353 858,837 630,308 391,456 275,189 746,058 7,404 103,153 650,309 138,903 Net Income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 665,563 $ 601,443 $ 511,406 Basic net income per share . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Diluted net income per share . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ $ 5.12 5.12 $ $ 4.89 4.89 $ $ 4.36 4.35 Weighted average shares outstanding: Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129,779 Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129,834 122,788 122,872 117,200 117,461 Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other comprehensive income (loss), net of tax Net unrealized holding gains (losses) on available-for-sale $ 665,563 $ 601,443 $ 511,406 securities, net of tax of $(55), $32 and $64 . . . . . . . . . . . . . . . . . . (191) 106 218 Cash flow hedges: Amortization and unrealized gains (losses) on interest rate agreements, net of tax of $36,875, $17,198 and $(6,782) . . . . . Total other comprehensive income (loss) . . . . . . . . . . . . . . . . . . . . . . . 127,583 127,392 56,888 56,994 (22,944) (22,726) Total comprehensive income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 792,955 $ 658,437 $ 488,680 See accompanying notes to consolidated financial statements. 45 ATMOS ENERGY CORPORATION CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY Common stock Number of Shares Stated Value Additional Paid-in Capital Accumulated Other Comprehensive Income (Loss) Retained Earnings Total (In thousands, except share and per share data) 111,273,683 $556 $2,974,926 — — — — — — $ (83,647) — (22,726) $1,878,116 $4,769,951 511,406 (22,726) 511,406 — — — — — — — — (245,717) (245,717) (8,210) 8,210 — 7,574,111 38 1 110,063 81,456 — 2 299,612 694,065 11,070 8,252 2,946 — — 20,935 — — — — — — — — — — 119,338,925 597 — — — — 3,712,194 — — (114,583) — 56,994 2,152,015 601,443 — 694,103 11,071 8,252 2,948 20,935 5,750,223 601,443 56,994 — — — 30 6,101,916 107,989 1 78,941 — 624,272 11,325 8,222 254,706 1 2,748 — — — — — — (282,444) (282,444) — — — — — 624,302 11,326 8,222 2,749 18,388 6,791,203 665,563 127,392 125,882,477 629 — — — — 4,377,149 — — (57,589) — 127,392 2,471,014 665,563 — — — — 6,130,875 31 79,921 — 1 84,265 1 242,216 606,636 7,715 8,125 3,091 — — 21,035 — — — — — — (323,904) (323,904) — — — — — 606,667 7,715 8,126 3,092 21,035 Balance, September 30, 2018 . . . . Net income . . . . . . . . . . . . . . . . . . . Other comprehensive loss . . . . . . . Cash dividends ($2.10 per share) . . . . . . . . . . . . . . . . . . . . . Cumulative effect of accounting change . . . . . . . . . . . . . . . . . . . . . Common stock issued: Public offering . . . . . . . . . . . . . . . Direct stock purchase plan . . . . . Retirement savings plan . . . . . . . 1998 Long-term incentive plan . . . Employee stock-based compensation . . . . . . . . . . . . . Balance, September 30, 2019 . . . . Net income . . . . . . . . . . . . . . . . . . . Other comprehensive income . . . . Cash dividends ($2.30 per share) . . . . . . . . . . . . . . . . . . . . . Common stock issued: Public offering . . . . . . . . . . . . . . . Direct stock purchase plan . . . . . Retirement savings plan . . . . . . . 1998 Long-term incentive plan . . . . . . . . . . . . . . . . . . . . . Employee stock-based Balance, September 30, 2020 . . . . Net income . . . . . . . . . . . . . . . . . . . Other comprehensive income . . . . Cash dividends ($2.50 per share) . . . . . . . . . . . . . . . . . . . . . Common stock issued: Public offering . . . . . . . . . . . . . . . Direct stock purchase plan . . . . . Retirement savings plan . . . . . . . 1998 Long-term incentive plan . . . Employee stock-based compensation . . . . . . . . . . . . . compensation . . . . . . . . . . . . . — — 18,388 Balance, September 30, 2021 . . . . 132,419,754 $662 $5,023,751 $ 69,803 $2,812,673 $7,906,889 See accompanying notes to consolidated financial statements. 46 ATMOS ENERGY CORPORATION CONSOLIDATED STATEMENTS OF CASH FLOWS CASH FLOWS FROM OPERATING ACTIVITIES Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Adjustments to reconcile net income to net cash provided by (used in) operating activities: Depreciation and amortization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . One-time income tax benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Stock-based compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of debt issuance costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Equity component of AFUDC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other Changes in assets and liabilities: (Increase) decrease in accounts receivable . . . . . . . . . . . . . . . . . . . . . . . . . (Increase) decrease in gas stored underground . . . . . . . . . . . . . . . . . . . . . . Increase in Winter Storm Uri current regulatory asset (see Note 9) . . . . . . Increase in other current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increase in Winter Storm Uri long-term regulatory asset (see Note 9) . . . . (Increase) decrease in deferred charges and other assets . . . . . . . . . . . . . . . Increase in accounts payable and accrued liabilities . . . . . . . . . . . . . . . . . . Decrease in other current liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Increase (decrease) in deferred credits and other liabilities . . . . . . . . . . . . . 2021 Year Ended September 30 2020 (In thousands) 2019 $ 665,563 $ 601,443 $ 511,406 477,977 155,355 — 11,255 14,030 (32,749) 3,731 (113,665) (66,166) (2,003,659) (84,705) (76,652) 136,809 104,242 (166,268) (109,349) 429,828 155,322 (20,962) 9,583 11,543 (23,493) 8,411 7,167 18,188 — (35,878) — (31,935) 7,359 (129,543) 30,966 391,456 132,004 — 11,121 9,464 (11,165) 1,169 18,724 35,594 — (26,590) — (58,403) 9,908 (103,895) 47,976 968,769 Net cash provided by (used in) operating activities . . . . . . . . . . . . . . . . . (1,084,251) 1,037,999 CASH FLOWS USED IN INVESTING ACTIVITIES Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Proceeds from the sale of discontinued operations . . . . . . . . . . . . . . . . . . . . . Purchases of debt and equity securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Proceeds from sale of debt and equity securities . . . . . . . . . . . . . . . . . . . . . . . Maturities of debt securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (1,969,540) — (49,879) 14,957 28,850 11,957 (1,935,676) — (50,517) 32,339 18,669 9,667 (1,693,477) 4,000 (29,153) 6,070 20,299 8,601 Net cash used in investing activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . (1,963,655) (1,925,518) (1,683,660) CASH FLOWS FROM FINANCING ACTIVITIES Net decrease in short-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Proceeds from issuance of long-term debt, net of premium/discount . . . . . . . Net proceeds from equity offering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Issuance of common stock through stock purchase and employee retirement plans . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlement of interest rate swaps . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Repayment of long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash dividends paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt issuance costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — 2,797,346 606,667 15,841 62,159 — (323,904) (14,288) Net cash provided by financing activities . . . . . . . . . . . . . . . . . . . . . . . . 3,143,821 Net increase (decrease) in cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash and cash equivalents at beginning of year 95,915 20,808 (464,915) 999,450 624,302 19,548 (4,426) — (282,444) (7,738) 883,777 (3,742) 24,550 (110,865) 1,045,221 694,103 19,323 (90,141) (575,000) (245,717) (11,254) 725,670 10,779 13,771 Cash and cash equivalents at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 116,723 $ 20,808 $ 24,550 See accompanying notes to consolidated financial statements. 47 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 regu- lated natural gas distribution and pipeline and storage businesses. Through our distribution business, we deliver natural gas through sales and transportation arrangements to over three 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 Atmos Energy Mississippi Division . . . . . . . . . . . . Mississippi Atmos Energy West Texas Division . . . . . . . . . . . . West Texas metropolitan area (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 dis- tribution 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 pipe- line and storage operations of our Atmos Pipeline–Texas (APT) Division and our natural gas transmission busi- ness 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 gen- erally 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 allow- ance 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 meas- urements and the valuation of goodwill and other long-lived assets. Actual results could differ from those esti- mates. 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 author- ities 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 48 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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 under- standing 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 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, 2021 and 2020 included the following: September 30 2021 2020 (In thousands) Regulatory assets: Pension and postretirement benefit costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Infrastructure mechanisms (1) Winter Storm Uri incremental costs (2) . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred gas costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory excess deferred taxes (3) Recoverable loss on reacquired debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred pipeline record collection costs . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 45,922 222,795 2,100,728 66,395 45,370 3,789 32,099 4,343 $ 149,089 183,943 — 40,593 — 4,894 29,839 6,283 $2,521,441 $ 414,641 Regulatory liabilities: Regulatory excess deferred taxes (3) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory cost of removal obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred gas costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Asset retirement obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . APT annual adjustment mechanism . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension and postretirement benefit costs . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 705,084 541,511 52,553 18,373 31,110 56,201 19,363 $ 718,651 531,096 19,985 20,348 57,379 — 19,554 $1,424,195 $1,367,013 (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, 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. 49 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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 deliv- ered 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 read meters and bill our customers on a monthly cycle basis. Accordingly, we estimate volumes from the last meter read to the bal- ance 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 trans- portation and storage services to our 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 Divi- sion 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 perform- ance 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 arrange- ments, 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 mecha- nism 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 account- ing standards generally accepted in the United States as they are deemed to be contracts between us and our regu- lator. 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. Purchased gas cost adjustment mechanisms provide gas distribution companies a method of recovering purchased gas costs on an ongoing basis without filing a rate case to address all of their non-gas costs. 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. 50 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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. 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, cus- tomer 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 classi- fied 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 con- tributions in aid of construction. The cost of additions includes direct construction costs, payroll related costs (taxes, pensions 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. The following table details amounts capitalized for the fiscal year ended September 30. Component of AFUDC . . . . . . . . . . . . . . . . . . . . . Debt Equity . . . . . . . . . . . . . . . . . . . . Other non-operating income (expense) Statement of Comprehensive Income Location Interest charges 2021 $11,414 32,749 2020 (In thousands) $ 8,436 23,493 2019 $ 7,643 11,165 $44,163 $31,929 $18,808 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 serv- ice life and one based on cost of removal. Accordingly, we recognize our cost of removal expense as a compo- nent 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, 3.0 percent and 3.1 percent for the fiscal years ended September 30, 2021, 2020 and 2019. 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. As of September 30, 2021 and 2020, we had asset retirement obligations of $18.4 million and $20.3 million. Additionally, we had $12.8 million and $14.4 million of asset retirement costs recorded as a component of prop- erty, plant and equipment that will be depreciated over the remaining life of the underlying associated assets. 51 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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 2021, 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 2021 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 con- ditions 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 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 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. 52 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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, 2021, 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). We regularly evaluate the performance of our available for sale debt securities on an investment by invest- ment 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 antici- pated 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 com- prehensive 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 state- ments 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. 53 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 finan- cial instruments as cash flow hedges at the time the agreements are executed. Unrealized gains and losses asso- ciated 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 compre- hensive income (loss) and recognized as a component of interest charges over the life of the related financing arrangement. As of September 30, 2021 and 2020, 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 concen- tration 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 con- dition 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 quota- tions, 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 bal- ance 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, Supple- mental Executive Benefit Plan and postretirement benefit plan consist primarily of non-exchange traded financial instruments such as corporate bonds and government securities. 54 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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 demo- graphic 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. The discount rate is utilized principally in calculating the actuarial present value of our pension and post- retirement 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 partic- ipants 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 partic- ipant census information as of the measurement date. We present only the current service cost component of the net benefit cost within operations and main- tenance 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 compre- hensive 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. 55 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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 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 6 to the consolidated financial statements regarding the commencement of finance leases, 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 securiti- zation filing in the State of Texas, 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 2021 Effective October 1, 2020, we adopted new accounting guidance that requires credit losses on most financial assets measured at amortized cost and certain other instruments to be measured using an expected credit loss model. Under this model, we estimate credit losses over the entire contractual term of the instrument from the date of initial recognition of that instrument. The new guidance also introduces a new impairment recognition model for available-for-sale debt securities that will require credit losses to be recorded through an allowance account. We adopted the new guidance using a modified retrospective method. The adoption of this standard did not have a material impact on our financial position, results of operations and cash flows and no adjustments 56 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) were made to October 1, 2020 opening balances as a result of this adoption. As required under the modified retro- spective method of adoption, results for the reporting period beginning after October 1, 2020 are presented under Accounting Standards Codification (ASC) 326, while prior period amounts are not adjusted. See Notes 5 and 16 to the consolidated financial statements for further discussion of implementation of the standard. Accounting pronouncements that will be effective after fiscal 2021 In March 2020, the Financial Accounting Standards Board (FASB) issued optional guidance which will ease the potential burden in accounting for or 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 rela- tionships and other transactions affected by the cessation of the London Interbank Offered Rate (LIBOR). The amendments can be elected immediately, as of March 12, 2020, through December 31, 2022. As we implement the cessation of LIBOR into our current contracts and hedging relationships, we expect to elect the optional guidance to ease the potential burden in accounting. We are currently evaluating the potential impact on our financial position, results of operations and cash flows. 3. Segment Information As of September 30, 2021, 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 geo- graphically dispersed, they are aggregated and reported as a single segment as each natural gas distribution divi- sion 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 charac- teristics, 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. 57 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, 2021 Distribution Pipeline and Storage Eliminations Consolidated (In thousands) Operating revenues from external parties . . . . . . . . . . . . Intersegment revenues . . . . . . . . . . . . . . . . . . . . . . . . . . $3,238,753 3,220 $168,737 468,610 $ (471,830) — $3,407,490 — Total operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased gas cost Operation and maintenance expense . . . . . . . . . . . . . . . . Depreciation and amortization expense . . . . . . . . . . . . . Taxes, other than income . . . . . . . . . . . . . . . . . . . . . . . . 3,241,973 1,501,695 501,209 345,481 275,074 Operating income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other non-operating income (expense) . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income before income taxes . . . . . . . . . . . . . . . . . . . . . . Income tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 618,514 (20,694) 36,629 561,191 115,329 637,347 1,582 179,080 132,496 37,705 286,484 18,549 46,925 258,108 38,407 Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 445,862 $219,701 Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1,454,195 $515,345 (471,830) (470,560) (1,270) — — — — — — — 3,407,490 1,032,717 679,019 477,977 312,779 904,998 (2,145) 83,554 819,299 153,736 $ $ — $ 665,563 — $1,969,540 Year Ended September 30, 2020 Distribution Pipeline and Storage Eliminations Consolidated (In thousands) Operating revenues from external parties . . . . . . . . . . . . Intersegment revenues . . . . . . . . . . . . . . . . . . . . . . . . . . $2,624,251 2,742 $196,886 412,453 $ (415,195) — $2,821,137 — Total operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Purchased gas cost Operation and maintenance expense . . . . . . . . . . . . . . . . Depreciation and amortization expense . . . . . . . . . . . . . Taxes, other than income . . . . . . . . . . . . . . . . . . . . . . . . 2,626,993 1,071,227 472,760 309,582 245,181 Operating income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other non-operating income (expense) . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income before income taxes . . . . . . . . . . . . . . . . . . . . . . Income tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 528,243 (1,265) 39,634 487,344 91,680 609,339 1,548 158,115 120,246 33,574 295,856 8,436 44,840 259,452 53,673 Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 395,664 $205,779 Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1,466,631 $469,045 (415,195) (413,921) (1,274) — — — — — — — 2,821,137 658,854 629,601 429,828 278,755 824,099 7,171 84,474 746,796 145,353 $ $ — $ 601,443 — $1,935,676 58 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Year Ended September 30, 2019 Distribution Pipeline and Storage Eliminations Consolidated (In thousands) Operating revenues from external parties . . . . . . . . . . . . Intersegment revenues . . . . . . . . . . . . . . . . . . . . . . . . . . $2,742,824 2,637 $159,024 408,000 $ (410,637) — $2,901,848 — Total operating revenues . . . . . . . . . . . . . . . . . . . . . . . Purchased gas cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operation and maintenance expense . . . . . . . . . . . . . . . . Depreciation and amortization expense . . . . . . . . . . . . . Taxes, other than income . . . . . . . . . . . . . . . . . . . . . . . . Operating income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other non-operating income . . . . . . . . . . . . . . . . . . . . . . Interest charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income before income taxes . . . . . . . . . . . . . . . . . . . . . . Income tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2,745,461 1,268,591 480,222 283,697 242,179 470,772 6,241 60,031 416,982 88,168 567,024 (360) 151,329 107,759 33,010 275,286 1,163 43,122 233,327 50,735 Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 328,814 $182,592 Capital expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1,274,613 $418,864 (410,637) (409,394) (1,243) — — — — — — — 2,901,848 858,837 630,308 391,456 275,189 746,058 7,404 103,153 650,309 138,903 $ $ — $ 511,406 — $1,693,477 The following table summarizes our revenues from external parties, excluding intersegment revenues, by products and services for the fiscal years ended September 30. 2021 2020 (In thousands) 2019 Distribution revenues: Gas sales revenues: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Public authority and other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,117,272 838,382 113,171 50,369 Total gas sales revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transportation revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other gas revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total distribution revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pipeline and storage revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3,119,194 105,554 14,005 3,238,753 168,737 $1,717,070 654,963 89,641 42,007 2,503,681 97,441 23,129 2,624,251 196,886 $1,733,548 711,284 118,046 42,613 2,605,491 95,629 41,704 2,742,824 159,024 Total operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $3,407,490 $2,821,137 $2,901,848 59 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Balance sheet information at September 30, 2021 and 2020 by segment is presented in the following tables. 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 September 30, 2020 Distribution Pipeline and Storage Eliminations Consolidated (In thousands) Property, plant and equipment, net . . . . . . . . . . . . . $ 9,944,978 $3,410,369 $ — $13,355,347 Total assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $14,578,176 $3,647,907 $(2,867,051) $15,359,032 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 vest- ing 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, dis- cussed 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: 2019 2020 2021 (In thousands, except per share data) Basic Earnings Per Share Net Income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Income allocated to participating securities . . . . . . . . . . . . . . . . . . . $665,563 465 $601,443 444 $511,406 416 Net Income available to common shareholders . . . . . . . . . . . . . . . . . . . . . $665,098 $600,999 $510,990 Basic weighted average shares outstanding . . . . . . . . . . . . . . . . . . . . . . . . 129,779 122,788 117,200 Net Income per share — Basic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5.12 $ 4.89 $ 4.36 Diluted Earnings Per Share Net Income available to common shareholders . . . . . . . . . . . . . . . . . . . . . Effect of dilutive shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $665,098 — $600,999 — $510,990 — Net Income available to common shareholders . . . . . . . . . . . . . . . . . . . . . $665,098 $600,999 $510,990 Basic weighted average shares outstanding . . . . . . . . . . . . . . . . . . . . . . . . Dilutive shares . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129,779 55 Diluted weighted average shares outstanding . . . . . . . . . . . . . . . . . . . . . . 129,834 122,788 84 122,872 117,200 261 117,461 Net Income per share — Diluted . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 5.12 $ 4.89 $ 4.35 60 ATMOS ENERGY CORPORATION 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 seg- ment and provides a reconciliation to total operating revenues, including intersegment revenues, for the periods presented. Year Ended September 30, 2021 Distribution Pipeline and Storage (In thousands) Gas sales revenues: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial Public authority and other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,129,704 841,145 113,091 50,565 $ — — — — Total gas sales revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transportation revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Revenues from contracts with customers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Alternative revenue program revenues (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3,134,505 107,822 10,971 3,253,298 (13,303) 1,978 — 646,416 14,141 660,557 (23,210) — Total operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $3,241,973 $637,347 Year Ended September 30, 2020 Distribution Pipeline and Storage Gas sales revenues: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Public authority and other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1,704,444 650,396 89,467 41,339 $ — — — — Total gas sales revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transportation revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Revenues from contracts with customers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Alternative revenue program revenues (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2,485,646 99,435 19,085 2,604,166 20,856 1,971 — 636,819 9,754 646,573 (37,234) — Total operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,626,993 $609,339 61 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Year Ended September 30, 2019 Distribution Pipeline and Storage Gas sales revenues: Residential . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Commercial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Industrial . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Public authority and other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1,755,229 716,757 118,060 42,796 $ — — — — Total gas sales revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transportation revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Revenues from contracts with customers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Alternative revenue program revenues (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2,632,842 97,495 26,050 2,756,387 (12,958) 2,032 — 623,808 8,060 631,868 (64,844) — Total operating revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,745,461 $567,024 (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 As described in Note 2 to the consolidated financial statements, 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. Due to the COVID-19 pandemic, in March 2020 we temporarily suspended disconnecting customers for nonpayment and stopped charging late fees. We resumed disconnection activity during the third quarter of fiscal 2021. We are actively working with our customers experiencing financial hardship to offer flexible payment options and directing them to aid agencies for financial assistance. Our allowance for uncollectible accounts reflects the expected impact on our customers’ ability to pay. 62 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Rollforwards of our allowance for uncollectible accounts for the year ended September 30, 2021, 2020 and 2019 are presented in the table below. The allowance excludes the gas cost portion of customers’ bills for approximately 79 percent of our customers as we have the ability to collect these gas costs through our gas cost recovery mechanisms in most of our jurisdictions. Balance, September 30, 2018 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Current period provisions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Write-offs charged against allowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recoveries of amounts previously written off Balance, September 30, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Current period provisions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Write-offs charged against allowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recoveries of amounts previously written off Balance, September 30, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Current period provisions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Write-offs charged against allowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recoveries of amounts previously written off Allowance for uncollectible accounts (In thousands) $ 14,795 18,106 (19,575) 2,573 15,899 24,796 (12,698) 1,952 29,949 43,807 (11,019) 1,734 Balance, September 30, 2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 64,471 6. Leases We adopted the provisions of the new lease accounting standard beginning on October 1, 2019, using the optional transition method, which allowed us to apply the provisions of the new standard to all leases that existed as of the date of adoption. Therefore, 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 stan- dard. 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, 2021 September 30, 2020 Weighted average remaining lease term (years) Finance leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19.0 10.2 19.1 10.6 The following table represents our weighted average discount rate: Weighted average discount rate Finance leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.7 % 2.8 % 8.0 % 2.9 % September 30, 2021 September 30, 2020 63 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Lease costs for the year ended September 30, 2021 and 2020 are presented in the table below. These costs include both amounts recognized in expense and amounts capitalized. For the year ended September 30, 2021 and 2020 we did not have material short-term lease costs or variable lease costs. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Finance lease cost Operating lease cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 30, 2021 September 30, 2020 (In thousands) $ $ 1,334 42,349 622 40,887 Total lease cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $43,683 $41,509 Our ROU assets and lease liabilities are presented as follows on the consolidated balance sheets: Balance Sheet Classification September 30, 2021 September 30, 2020 (In thousands) Assets Finance leases . . . . . . . . . . . . . . . Net Property, Plant and Equipment Operating leases . . . . . . . . . . . . . Deferred charges and other assets Total right-of-use assets . . . . . . . . . Liabilities Current $ 18,252 222,446 $240,698 Finance leases . . . . . . . . . . . . . . . Current maturities of long-term debt Operating leases . . . . . . . . . . . . . Other current liabilities $ 452 37,688 Noncurrent Finance leases . . . . . . . . . . . . . . . Long-term debt Operating leases . . . . . . . . . . . . . Deferred credits and other liabilities Total lease liabilities . . . . . . . . . . . . 18,287 194,745 $251,172 $ 8,480 227,146 $235,626 $ 165 35,716 8,466 201,071 $245,418 Finance leases for two service centers are expected to commence in the first quarter of fiscal 2022 that impact our future lease payments. The total future lease payments for these leases are $46.5 million. Other pertinent information related to leases was as follows. During the year ended September 30, 2021 and 2020, amounts paid in cash for our finance leases were not material. Cash paid amounts included in the measurement of lease liabilities Operating cash flows used for operating leases . . . . . . . . . . . . . . . . . . . . $42,013 $37,758 Right-of-use assets obtained in exchange for lease obligations Finance leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $10,333 $25,690 $ 6,083 $34,169 September 30, 2021 September 30, 2020 (In thousands) 64 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Maturities of our lease liabilities as of September 30, 2021 were as follows: 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Thereafter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total lease payments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: Imputed interest Total $ 43,164 38,690 32,106 23,927 18,278 144,718 300,883 49,711 Finance Leases (In thousands) $ 1,342 1,365 1,388 1,411 1,435 22,868 29,809 11,070 Operating Leases $ 41,822 37,325 30,718 22,516 16,843 121,850 271,074 38,641 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $251,172 $18,739 $232,433 Reported as of September 30, 2021 Short-term lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Long-term lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 38,140 213,032 $ 452 18,287 $ 37,688 194,745 Total lease liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $251,172 $18,739 $232,433 Disclosures Related to Periods Prior to Adoption of ASC 842 Consolidated lease and rental expense amounted to $40.4 million for fiscal 2019. 65 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 7. Debt Long-term debt Long-term debt at September 30, 2021 and 2020 consisted of the following: 2021 2020 (In thousands) Unsecured 0.625% Senior Notes, due 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 3.00% Senior Notes, due 2027 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 2.625% Senior Notes, due 2029 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 1.50% Senior Notes, due 2031 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 5.95% Senior Notes, due 2034 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 5.50% Senior Notes, due 2041 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 4.15% Senior Notes, due 2043 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 4.125% Senior Notes, due 2044 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 4.30% Senior Notes, due 2048 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 4.125% Senior Notes, due 2049 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unsecured 3.375% Senior Notes, due 2049 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Floating-rate term loan, due April 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Floating-rate Senior Notes, due 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Medium term Series A notes, 1995-1, 6.67%, due 2025 . . . . . . . . . . . . . . . . . . . . . . . Unsecured 6.75% Debentures, due 2028 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Finance lease obligations (see Note 6) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1,100,000 500,000 300,000 600,000 200,000 400,000 500,000 750,000 600,000 450,000 500,000 200,000 1,100,000 10,000 150,000 18,739 $ — 500,000 300,000 — 200,000 400,000 500,000 750,000 600,000 450,000 500,000 200,000 — 10,000 150,000 8,631 Total long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7,378,739 4,568,631 Less: Net original issue (premium) / discount on unsecured senior notes and debentures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Debt issuance cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Current maturities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2,811 45,271 2,400,452 583 36,104 165 $4,930,205 $4,531,779 Maturities of long-term debt, excluding our finance lease obligations, at September 30, 2021 were as fol- lows (in thousands): 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Thereafter $2,400,000 — — 10,000 — 4,950,000 $7,360,000 On October 1, 2021, we completed a public offering of $600 million of 2.85% senior notes dues 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 estimated offering expenses, of $589.6 million, will be used for general corporate purposes. On March 9, 2021, we completed a public offering of $1.1 billion of 0.625% senior notes due 2023, with an effective interest rate of 0.834%, after giving effect to the offering costs, and $1.1 billion floating rate senior 66 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) notes due 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 pay- ment 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 percent 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 2022 after the expected receipt of securitization funds. As such, we have classified the senior notes as current maturities of long-term debt as of September 30, 2021. 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 that was replaced on March 31, 2021, with a new five-year unsecured $1.5 billion credit facility that expires on March 31, 2026. The new facility bears interest at a base rate or at a LIBOR-based rate for the applicable interest period, plus a margin ranging from zero to 0.25 percent for base rate advances or a margin ranging from 0.75 percent to 1.25 percent for LIBOR-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, 2021 and September 30, 2020, there were no amounts outstanding under our commercial paper program. We had a $600 million 365-day unsecured revolving credit facility, which was replaced on March 31, 2021, with a new $900 million three-year unsecured revolving credit facility. This new facility will be used primarily to provide additional working capital funding. The new facility bears interest at a base rate or at a LIBOR-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 LIBOR-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, 2021, there were no borrow- ings outstanding under this facility. Additionally, we have a $50 million 364-day unsecured facility, which was renewed April 1, 2021 and is used to provide working capital funding. There were no borrowings outstanding under this facility as of Sep- tember 30, 2021. Finally, we have a $50 million 364-day unsecured revolving credit facility, which was renewed April 29, 2021 and is used to issue letters of credit and to provide working capital funding. At September 30, 2021, 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. 67 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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, 2021, our total-debt-to-total- capitalization ratio, as defined, was 49 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, 2021. 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. This shelf registration statement replaced our previous shelf registration statement which was filed on February 11, 2020. At September 30, 2021, approximately $4.0 billion of securities remained available for issu- ance under the shelf registration statement. Following the completion of the $600 million senior unsecured notes offering on October 1, 2021 (see Note 7 to the consolidated financial statements), approximately $3.4 billion of securities remained available for issuance under the shelf registration statement. On June 29, 2021, we filed a prospectus supplement under the shelf registration statement relating to an at-the-market (ATM) equity sales program (June 2021 ATM) under which we may 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 concurrently with the ATM equity sales program). This ATM equity sales program replaced our previous ATM equity sales program, filed on February 12, 2020 (February 2020 ATM). During the year ended September 30, 2021, we executed forward sales under the February 2020 ATM and June 2021 ATM equity sales programs with various forward sellers who borrowed and sold 5,866,604 shares of our common stock at an aggregate price of $578.4 million. During the year ended September 30, 2021, we also settled forward sale agreements with respect to 6,130,875 shares that had been borrowed and sold by various forward sellers under the February 2020 ATM for net proceeds of $606.7 million. As of September 30, 2021, $760 million of equity was available for issuance under the June 2021 ATM program. Additionally, we had $302.0 million in available proceeds from outstanding forward sale agreements, as detailed below. Maturity Shares Available Net Proceeds Available (In Thousands) Forward Price June 30, 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 30, 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,681,910 1,389,814 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3,071,724 $166,989 134,995 $301,984 99.29 97.13 98.31 68 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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). September 30, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other comprehensive income (loss) before reclassifications . . . . . . . . . . . . Amounts reclassified from accumulated other comprehensive income . . . . $ 238 (191) — Available- for-Sale Securities Interest Rate Agreement Cash Flow Hedges (In thousands) $ (57,827) 123,017 4,566 Total $ (57,589) 122,826 4,566 Net current-period other comprehensive income (loss) . . . . . . . . . . . . . . . . (191) 127,583 127,392 September 30, 2021 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 47 $ 69,756 $ 69,803 September 30, 2019 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other comprehensive income before reclassifications . . . . . . . . . . . . . . . . . Amounts reclassified from accumulated other comprehensive income . . . . $ 132 108 (2) Available- for-Sale Securities Interest Rate Agreement Cash Flow Hedges (In thousands) $(114,715) 53,241 3,647 Total $(114,583) 53,349 3,645 Net current-period other comprehensive income . . . . . . . . . . . . . . . . . . . . . 106 56,888 56,994 September 30, 2020 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 238 $ (57,827) $ (57,589) 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. 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 approx- imately $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 69 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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. 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, 2021, we have recorded a $2.1 billion regulatory asset for incremental costs, including carrying costs, incurred in Kansas ($89.0 million) and Texas ($2,011.7 million). These costs are subject to review for prudency by each commission and may be adjusted. Securitization 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. Within 25 days after a complete application is filed, the KCC shall establish a procedural schedule that requires it to issue a decision on the application within 180 days from the date a com- plete application was filed. Utilities may apply for a recovery period of up to 32 years. 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. This amount also includes an estimate of penalties, carrying costs and administrative costs that we expect to incur in connection with the resolution of this filing. Included in our filing is an allowed deferral of an equity return as part of the recoverable carrying costs. As of September 30, 2021, approximately $2.8 million is capitalized for ratemaking purposes but is not recorded as a regulatory asset on our consolidated balance sheet. We anticipate proceedings to begin in January 2022. 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, 2021. Texas On June 16, 2021, House Bill 1520 became effective. House Bill 1520 authorizes the RRC to issue a state- wide 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 sup- ply 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 other- wise 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. This amount also included an estimate of carrying costs and administrative costs that we expect to incur in connection with the resolution of this filing. 70 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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. The statutory deadline for the RRC to issue a Financing Order is March 27, 2022. The Financing Order will be issued to the Texas Public Financing Authority authorizing the issuance of customer rate relief bonds to securitize the aggregated extraordinary costs for all participating utilities within 180 days. The participating util- ities, as servicers acting on behalf of the state of the securitization financing, will bill and collect customer rate relief charges from their current and future customers and remit the collections to the state issuer of the securitization financing. Based on the RRC’s procedural schedule, we believe we will receive the securitization funds within twelve months. We will repay the $2.2 billion in public notes issued to finance the incremental gas costs incurred during Winter Storm Uri. Accordingly, we have recorded the regulatory asset for Texas in other current assets and these notes as current maturities of long-term debt as of September 30, 2021. 10. Retirement and Post-Retirement Employee Benefit Plans We have both funded and unfunded noncontributory defined benefit plans that together cover most of our employees. We also maintain post-retirement plans that provide 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 recov- erable 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 recog- nized in net periodic pension cost that have been recorded as regulatory assets or liabilities are as follows: September 30, 2021 Unrecognized prior service (credit) cost . . . . . . . . . . . . . . . . . . . . . . . . . . . Unrecognized actuarial (gain) loss . . . . September 30, 2020 Unrecognized prior service (credit) cost . . . . . . . . . . . . . . . . . . . . . . . . . . . Unrecognized actuarial loss . . . . . . . . . . Defined Benefit Plan Supplemental Executive Retirement Plans Postretirement Plans Total (In thousands) $ (353) (3,060) $ (3,413) $ (584) 78,082 $77,498 $ — 39,666 $39,666 $ — 51,045 $51,045 $(64,313) (28,141) $ (64,666) 8,465 $(92,454) $ (56,201) $ 951 9,110 $ 10,061 $ 367 138,237 $138,604 71 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Defined Benefit Plans Employee Pension Plan As of September 30, 2021, we maintained one cash balance defined benefit plan, the Atmos Energy Corpo- ration Pension Account Plan (the Plan). The 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 plan was closed to new participants. The assets of the 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 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, 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 2021, we contributed $10.0 million in cash to the Plan to achieve a desired level of funding while maximizing the tax deductibility of this payment. During fiscal 2020, we did not make a contribution to the Plan. Based upon market conditions at September 30, 2021, the current funded position of the Plan and the fund- ing requirements under the PPA, we do not anticipate a minimum required contribution for fiscal 2022. 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 recom- mendations 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 max- imize 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. The following table presents asset allocation information for the Master Trust as of September 30, 2021 and 2020. Security Class Targeted Allocation Range Actual Allocation September 30 2020 2021 Domestic equities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . International equities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fixed income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Company stock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35%-55% 44.5% 45.3% 10%-20% 16.9% 15.6% 5%-30% 16.0% 17.0% 0%-15% 10.6% 13.0% 0%-20% 12.0% 9.1% 72 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) At September 30, 2021 and 2020, the Plan held 716,700 shares of our common stock which represented 10.6 percent and 13.0 percent of total Plan assets. These shares generated dividend income for the Plan of approximately $1.8 million and $1.6 million during fiscal 2021 and 2020. Our employee 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 employee pension plans annually based upon a September 30 measurement date. The develop- ment 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 Plan was determined as of September 30, 2021 and 2020 and the actuarial assumptions used to determine the net periodic pension cost for the Plan was determined as of September 30, 2020, 2019 and 2018. In October 2021, the Society of Actuaries released its annually-updated mortality improvement scale for pension plans incorporating new assumptions surrounding life expectancies in the United States. As of September 30, 2021, we updated our assumed mortality rates to incorporate the updated mortality table. Additional assumptions are presented in the following table: Pension Liability 2021 2020 2021 Pension Cost 2020 2019 Discount rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Rate of compensation increase . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Expected return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest crediting rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.97% 2.80% 2.80% 3.29% 4.38% 3.50% 3.50% 3.50% 3.50% 3.50% 6.25% 6.25% 6.25% 6.50% 6.75% 4.69% 4.69% 4.69% 4.69% 4.69% The following table presents the Plan’s accumulated benefit obligation, projected benefit obligation and funded status as of September 30, 2021 and 2020: 2021 2020 (In thousands) Accumulated benefit obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $558,639 $565,755 Change in projected benefit obligation: Benefit obligation at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $604,221 17,369 16,883 (7,561) (34,883) $577,270 17,551 19,028 22,898 (32,526) Benefit obligation at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 596,029 604,221 Change in plan assets: Fair value of plan assets at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actual return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Employer contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 528,881 92,808 10,000 (34,883) 530,109 31,298 — (32,526) Fair value of plan assets at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 596,806 528,881 Reconciliation: Funded status . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unrecognized prior service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unrecognized net loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net amount recognized . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 777 — — 777 (75,340) — — $ (75,340) 73 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Net periodic pension cost for the Plan for fiscal 2021, 2020 and 2019 is presented in the following table. Fiscal Year Ended September 30 2020 2019 2021 (In thousands) Components of net periodic pension cost: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Service cost Interest cost (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Expected return on assets (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of prior service cost (credit) (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recognized actuarial (gain) loss (1) $ 17,369 16,883 (27,913) 8,686 (231) $ 17,551 19,028 (28,316) (231) 9,025 $ 15,311 22,071 (28,451) (232) 4,201 Net periodic pension cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 14,794 $ 17,057 $ 12,900 (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. The following tables set forth by level, within the fair value hierarchy, the Plan’s assets at fair value as of September 30, 2021 and 2020. 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 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 Plan had net accounts receivable of $2.1 million and $0.7 million at September 30, 2021 and 2020, which materially approximates fair value due to the short-term nature of these assets. Assets at Fair Value as of September 30, 2021 Level 1 Level 2 Level 3 Total (In thousands) Investments: Common stocks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Money market funds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Registered investment companies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Government securities: Mortgage-backed securities . . . . . . . . . . . . . . . . . . . . U.S. treasuries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Corporate bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $239,166 — 74,236 — 7,483 — $ — 7,060 — 14,048 34 30,834 Total investments measured at fair value . . . . . . . . . . . . . . . $320,885 $51,976 $ Investments measured at net asset value: Common/collective trusts (1) Limited partnerships (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total investments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 74 $ — $239,166 7,060 — 74,236 — — — — — 14,048 7,517 30,834 372,861 121,570 100,299 $594,730 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Assets at Fair Value as of September 30, 2020 Level 1 Level 2 Level 3 Total (In thousands) Investments: Common stocks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Money market funds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Registered investment companies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Government securities: Mortgage-backed securities . . . . . . . . . . . . . . . . . . . . U.S. treasuries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Corporate bonds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $211,244 — 29,762 — 21,755 — $ — 6,096 — 15,230 36 52,648 Total investments measured at fair value . . . . . . . . . . . . . . . $262,761 $74,010 $ Investments measured at net asset value: Common/collective trusts (1) Limited partnerships (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total investments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ — $211,244 6,096 — 29,762 — — — — — 15,230 21,791 52,648 336,771 122,207 69,176 $528,154 (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 which provide additional pension, disability and death bene- fits to our officers, division presidents and certain other employees of the Company. The first plan is referred to as the Supplemental Executive Benefits Plan (SEBP) and 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 under- lying 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 Pen- sion Account Plan. Due to the retirement of certain executives of the company 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. 75 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Similar to our employee pension plans, we review the estimates and assumptions underlying our supple- mental plans annually based upon a September 30 measurement date using the same techniques as our employee pension plans. The actuarial assumptions used to determine the pension liability for the supplemental plans were determined as of September 30, 2021 and 2020 and the actuarial assumptions used to determine the net periodic pension cost for the supplemental plans were determined as of September 30, 2020, 2019 and 2018. These assumptions are presented in the following table: Pension Liability 2021 2020 2021 Pension Cost 2020 2019 Discount rate (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Rate of compensation increase . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest crediting rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.57% 2.80% 2.90% 3.19% 4.38% 3.50% 3.50% 3.50% 3.50% 3.50% 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. The following table presents the supplemental plans’ accumulated benefit obligation, projected benefit obli- gation and funded status as of September 30, 2021 and 2020: 2021 2020 (In thousands) Accumulated benefit obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 100,981 $ 122,207 Change in projected benefit obligation: Benefit obligation at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 129,140 1,067 3,180 1,332 (4,720) (25,698) $ 143,987 1,074 4,188 7,386 (4,766) (22,729) Benefit obligation at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 104,301 129,140 Change in plan assets: Fair value of plan assets at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Employer contribution . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — 30,418 (4,720) (25,698) Fair value of plan assets at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 27,495 (4,766) (22,729) — Reconciliation: Funded status . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unrecognized prior service cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unrecognized net loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (104,301) — — (129,140) — — Accrued pension cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $(104,301) $(129,140) Assets for the supplemental plans are held in separate rabbi trusts. At September 30, 2021 and 2020, assets held in the rabbi trusts consisted of equity securities of $38.1 million and $41.9 million, which are included in our fair value disclosures in Note 16 to the consolidated financial statements. 76 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Net periodic pension cost for the supplemental plans for fiscal 2021, 2020 and 2019 is presented in the fol- lowing table. Fiscal Year Ended September 30 2020 2019 2021 (In thousands) Components of net periodic pension cost: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Service cost Interest cost (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recognized actuarial loss (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Settlements (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,067 3,180 3,560 9,151 $ 1,074 4,188 3,945 9,180 $ 869 5,127 2,227 — Net periodic pension cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $16,958 $18,387 $8,223 (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. 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) 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2027-2031 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 39,020 39,624 40,314 41,085 42,053 203,461 $ 4,925 11,384 4,496 39,769 5,665 22,079 Postretirement Benefits We sponsor the Retiree Medical Plan for Retirees and Disabled Employees of Atmos Energy Corporation (the Atmos Retiree Medical Plan). This plan provides medical and prescription drug protection to all qualified participants based on their date of retirement. The Atmos Retiree Medical Plan provides different levels of bene- fits 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 remain- ing 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 are limited to a three percent cost increase in claims and administrative costs each year, with the participant responsible for the additional costs. 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 postretirement benefits plan during fiscal 2022. We maintain a formal investment policy with respect to the assets in our postretirement benefits plan to ensure the assets funding the postretirement benefit plan are appropriately invested to maintain an acceptable level of risk. We also consider our current financial status when making recommendations and decisions regard- ing the postretirement benefits plan. 77 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) We currently invest the assets funding our postretirement benefit 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 postretirement benefit plan assets as of September 30, 2021 and 2020. Security Class Actual Allocation September 30 2020 2021 Diversified investment funds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97.9% 97.4% 2.1% 2.6% Similar to our employee pension and supplemental plans, we review the estimates and assumptions under- lying our postretirement benefit plan annually based upon a September 30 measurement date using the same techniques as our employee pension plans. The actuarial assumptions used to determine the pension liability for our postretirement plan were determined as of September 30, 2021 and 2020 and the actuarial assumptions used to determine the net periodic pension cost for the postretirement plan were determined as of September 30, 2020, 2019 and 2018. Effective January 1, 2022, the Retiree Medical Plan for Retirees and Disabled Employees will be amended. The amendments 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. The amendments were approved by the Atmos Energy Board of Directors in May 2021 and the changes were communicated to participants beginning on July 31, 2021. These amendments to the Retiree Medical Plan for Retirees and Disabled Employees have been included in the actuarial assumptions used to determine the pension liability and net periodic for the postretirement plan as of September 30, 2020. The assumptions are presented in the following table: Postretirement Liability 2021 2020 Postretirement Cost 2020 2021 2019 3.01% 2.80% 2.80% 3.29% 4.38% 4.94% 4.94% 4.94% 5.14% 5.33% 6.25% 6.25% 6.25% 6.25% 6.50% 5.00% 5.00% 5.00% 5.00% 5.00% 2027 2026 2026 2025 2022 Discount rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Expected return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . Initial trend rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ultimate trend rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ultimate trend reached in . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) The following table presents the postretirement plan’s benefit obligation and funded status as of Sep- tember 30, 2021 and 2020: 2021 2020 (In thousands) Change in benefit obligation: Benefit obligation at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Service cost Interest cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Plan participants’ contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Actuarial (gain) loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Plan amendments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $370,678 11,000 15,372 5,648 6,800 (19,610) (34,732) $ 316,033 13,466 10,612 5,849 43,412 (18,694) — Benefit obligation at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 355,156 370,678 Change in plan assets: Fair value of plan assets at beginning of year . . . . . . . . . . . . . . . . . . . . . . . . Actual return on plan assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Employer contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Plan participants’ contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Benefits paid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 208,245 53,335 20,581 5,648 (19,610) 201,901 2,356 16,833 5,849 (18,694) Fair value of plan assets at end of year . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 268,199 208,245 Reconciliation: Funded status . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unrecognized transition obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unrecognized prior service cost Unrecognized net loss . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (86,957) — — — (162,433) — — — Accrued postretirement cost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (86,957) $(162,433) Net periodic postretirement cost for fiscal 2021, 2020 and 2019 is presented in the following table. Fiscal Year Ended September 30 2020 2019 2021 (In thousands) Components of net periodic postretirement cost: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Service cost Interest cost (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Expected return on assets (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Amortization of transition obligation (1) . . . . . . . . . . . . . . . . . . . . Amortization of prior service cost (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Recognized actuarial gain (1) $ 11,000 15,372 (10,455) — 30,533 1,172 $ 13,466 10,612 (10,499) — 173 (1,337) $ 10,810 11,839 (10,659) — 173 (8,178) Net periodic postretirement cost . . . . . . . . . . . . . . . . . . . . . . . $ 47,622 $ 12,415 $ 3,985 (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. 79 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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 juris- diction 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, 2021 and 2020. 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, 2021 Level 1 Level 2 Level 3 Total (In thousands) Investments: Money market funds . . . . . . . . . . . . . . . . . . . . . . . . . Registered investment companies . . . . . . . . . . . . . . . Total investments measured at fair value . . . . . . . . . . . $ — $5,527 — $5,527 262,672 $262,672 $ $ 5,527 — $ — 262,672 — $268,199 Assets at Fair Value as of September 30, 2020 Level 1 Level 2 Level 3 Total (In thousands) Investments: Money market funds . . . . . . . . . . . . . . . . . . . . . . . . . Registered investment companies . . . . . . . . . . . . . . . $ — $5,525 — 202,720 Total investments measured at fair value . . . . . . . . . . . $202,720 $5,525 $ $ — $ — 5,525 202,720 — $208,245 Estimated Future Benefit Payments The following benefit payments paid by us, retirees and prescription drug subsidy payments for our post- retirement benefit plans, which reflect expected future service, as appropriate, are expected to be paid in the fol- lowing fiscal years. Company payments for fiscal 2021 include contributions to our postretirement plan trusts. Company Payments Retiree Payments Subsidy Payments Total Postretirement Benefits 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2027-2031 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 17,701 18,031 18,341 18,981 19,414 100,312 (In thousands) $— — — — — — $ 2,490 2,465 2,404 2,425 2,395 10,641 $ 20,191 20,496 20,745 21,406 21,809 110,953 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 80 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) compensation, as defined by the Plan, not to exceed the maximum allowed by the Internal Revenue Service. New participants are automatically enrolled in the 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, partic- ipants 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 eligi- ble 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. Matching and fixed annual contributions to the Retirement Savings Plan are expensed as incurred and amounted to $20.6 million, $17.9 million and $16.7 million for fiscal years 2021, 2020 and 2019. At Sep- tember 30, 2021 and 2020, the Retirement Savings Plan held 1.9 percent and 2.2 percent of our outstanding common stock. 11. Stock and Other Compensation Plans Stock-Based Compensation Plans Total stock-based compensation cost was $24.1 million, $21.1 million and $23.9 million for the fiscal years ended September 30, 2021, 2020 and 2019. Of this amount, $12.9 million, $11.6 million and $12.8 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, provid- ing for additional performance incentives and promoting our success by providing employees with the oppor- tunity 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, 2021, non-qualified stock options, bonus stock, time-lapse restricted stock, time-lapse restricted stock units, performance-based restricted stock units and stock units had been issued under this plan, and 1.1 million shares are available for future issu- ance. 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 tar- gets. The fair value of the awards granted is based on the market price of our stock at the date of grant. We esti- mate 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. 81 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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 recipi- ents 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 begin- ning of the applicable three-year performance period, except for accelerated vesting in the event of death, dis- ability, 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, 2021, 2020 and 2019: 2021 2020 2019 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 Number of Restricted Units Nonvested at beginning of year . . . . . . 443,279 $ 99.28 102.68 Granted . . . . . . . . . . . . . . . . . . . . . . 223,954 Vested . . . . . . . . . . . . . . . . . . . . . . . (271,435) (17,671) Forfeited . . . . . . . . . . . . . . . . . . . . . 503,072 $ 91.66 199,985 102.34 97.44 (242,975) (16,803) 538,592 241,472 85.66 (269,347) (7,645) 96.87 101.48 $80.91 98.25 76.71 86.37 Nonvested at end of year . . . . . . . . . . . 378,127 $102.45 443,279 $ 99.28 503,072 $91.66 As of September 30, 2021, there was $13.8 million of total unrecognized compensation cost related to non- vested restricted stock units granted under the LTIP. That cost is expected to be recognized over a weighted average period of 1.7 years. The fair value of restricted stock vested during the fiscal years ended September 30, 2021, 2020 and 2019 was $26.3 million, $20.7 million and $20.5 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 pro- vides 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. 82 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Other Discretionary Compensation Plans We have an annual incentive program covering substantially all employees to give each employee an oppor- tunity 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. Dur- ing 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, 2021 and 2020: September 30 2021 2020 (In thousands) Billed accounts receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unbilled revenue . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Contributions in aid of construction receivable . . . . . . . . . . . . . . . . . . . . . . . . . Insurance receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other accounts receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $218,219 97,417 18,984 53,779 19,039 $140,259 80,699 19,821 4,731 15,034 Total accounts receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: allowance for uncollectible accounts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net accounts receivable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 407,438 (64,471) $342,967 260,544 (29,949) $230,595 Other current assets Other current assets as of September 30, 2021 and 2020 were comprised of the following accounts. September 30 2021 2020 (In thousands) Deferred gas costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Winter Storm Uri incremental costs (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Prepaid expenses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Materials and supplies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Assets from risk management activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 66,395 2,011,719 48,766 15,581 55,073 3,375 $ 40,593 — 40,340 6,829 5,687 14,456 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,200,909 $107,905 (1) Includes $2,003.7 million of gas purchases and $8.0 million of carrying costs that were deferred pursuant to regulatory orders. See Note 9 to the consolidated financial statements for additional details. 83 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Property, plant and equipment Property, plant and equipment was comprised of the following as of September 30, 2021 and 2020: September 30 2021 2020 (In thousands) Storage plant . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Transmission plant . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Distribution plant . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . General plant . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Intangible plant . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 539,972 3,725,347 12,085,654 868,962 38,612 Construction in progress . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Less: accumulated depreciation and amortization . . . . . . . . . . . . . . . . . . 17,258,547 626,551 17,885,098 (2,821,128) $ 530,985 3,459,765 10,680,495 829,624 38,297 15,539,166 418,055 15,957,221 (2,601,874) Net property, plant and equipment (1) . . . . . . . . . . . . . . . . . . . . . . . . $15,063,970 $13,355,347 (1) Net property, plant and equipment includes plant acquisition adjustments of $(28.5) million and $(37.8) mil- lion at September 30, 2021 and 2020. Deferred charges and other assets Deferred charges and other assets as of September 30, 2021 and 2020 were comprised of the following accounts. September 30 2021 2020 (In thousands) Marketable securities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory assets (See Note 2) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating lease right of use assets (See Note 6) . . . . . . . . . . . . . . . . . . . . . . . . . Winter Storm Uri incremental costs (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Assets from risk management activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $108,071 351,843 222,446 89,009 175,613 27,738 $103,952 371,707 227,146 — 74,991 23,374 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $974,720 $801,170 (1) Includes $76.7 million of gas purchases and $12.3 million of carrying costs that were deferred pursuant to regulatory orders. See Note 9 to the consolidated financial statements for additional details. 84 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Accounts payable and accrued liabilities Accounts payable and accrued liabilities as of September 30, 2021 and 2020 were comprised of the follow- ing accounts. September 30 2021 2020 (In thousands) Trade accounts payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accrued gas payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accrued liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $224,873 100,699 97,650 $141,075 42,054 52,646 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $423,222 $235,775 Other current liabilities Other current liabilities as of September 30, 2021 and 2020 were comprised of the following accounts. September 30 2021 2020 (In thousands) Customer credit balances and deposits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accrued employee costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Deferred gas costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating lease liabilities (See Note 6) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Accrued interest . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liabilities from risk management activities . . . . . . . . . . . . . . . . . . . . . . . . . . . . Taxes payable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension and postretirement liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory cost of removal obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . APT annual adjustment mechanism . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Regulatory excess deferred taxes (See Note 14) . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 49,722 50,517 52,553 37,688 55,164 5,269 160,986 4,863 72,823 22,694 155,857 18,545 $ 56,485 48,057 19,985 35,716 53,554 2,015 148,292 29,609 73,908 43,893 20,887 14,060 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $686,681 $546,461 Deferred credits and other liabilities Deferred credits and other liabilities as of September 30, 2021 and 2020 were comprised of the following accounts. September 30 2021 2020 (In thousands) Pension and post retirement liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Operating lease liabilities (See Note 6) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Customer advances for construction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other regulatory liabilities (See Note 2) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Asset retirement obligation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . APT annual adjustment mechanism . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Unrecognized tax benefits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $185,617 194,745 9,879 75,506 18,373 8,416 32,792 12,161 $337,303 201,071 10,060 17,838 20,348 13,486 30,921 11,101 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $537,489 $642,128 85 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Statement of Comprehensive Income Other non-operating income (expense) Other non-operating income (expense) for the fiscal years ended September 30, 2021, 2020 and 2019 were comprised of the following accounts. Equity component of AFUDC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Performance-based rate program . . . . . . . . . . . . . . . . . . . . . . . . . . . Pension and other postretirement non-service credit (cost) . . . . . . . Interest income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Community support spending . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Miscellaneous . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2019 2021 Year Ended September 30 2020 (In thousands) $ 23,493 6,771 (3,189) 2,932 (11,728) (11,108) $ 32,749 6,362 (19,238) 2,144 (14,460) (9,702) $ 11,165 6,737 3,016 4,160 (4,771) (12,903) Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ (2,145) $ 7,171 $ 7,404 Statement of Cash Flows Supplemental disclosures of cash flow information for the fiscal years ended September 30, 2021, 2020 and 2019 were as follows: 2021 Year Ended September 30 2020 (In thousands) 2019 Cash Paid (Received) During The Period For: Interest (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Non-Cash Transactions: Capital expenditures included in current liabilities . . . . . . . . . . . $207,555 8,199 $ $ 194,993 $ (3,071) $ 184,852 $ 11,467 $184,786 $ 113,365 $ 149,993 (1) Cash paid during the period for interest, net of amounts capitalized was $81.9 million, $82.3 million and $91.3 million for the fiscal years ended September 30, 2021, 2020 and 2019. 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 mat- ters, 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 timely provided a written response on May 7, 2021. Following the release of the 86 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) NTSB’s final report, the Railroad Commission of Texas (RRC) completed its safety evaluation related to the 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 sat- isfy the administrative penalties. The NTSB is investigating a worksite accident that occurred in Farmersville, Texas on June 28, 2021 that resulted in two fatalities and injuries to two others. Together with the Railroad Commission of Texas and the Pipeline and Hazardous Materials Safety Administration, Atmos Energy is a party to the investigation and in that capacity is work- ing closely with all parties to help determine the cause of this incident. On July 16, 2021 and July 28, 2021, two civil actions were 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 ordi- nary 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, 2021, we were committed to purchase 32.4 Bcf within one year and 12.9 Bcf within two to three years under indexed contracts. At September 30, 2021, we were committed to purchase 11.9 Bcf within one year under fixed price contracts ranging from $1.86 to $7.03 per Mcf. Purchases under these contracts totaled $149.4 million, $58.5 million and $50.8 million for 2021, 2020 and 2019. Rate Regulatory Proceedings As of September 30, 2021, 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 2021, 2020 and 2019 were as fol- lows: Current 2021 2020 (In thousands) 2019 Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ — $ 252 — $ 14,193 — 8,412 Deferred Federal . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . State (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128,867 24,617 143,039 (11,879) 113,331 17,160 Income tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $153,736 $ 145,353 $ 138,903 (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. 87 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Reconciliations of the provision for income taxes computed at the statutory rate to the reported provisions for income taxes from continuing operations for 2021, 2020 and 2019 are set forth below: Tax at statutory rate (1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Common stock dividends deductible for tax reporting . . . . . . . . State taxes (net of federal benefit) . . . . . . . . . . . . . . . . . . . . . . . Amortization of excess deferred taxes . . . . . . . . . . . . . . . . . . . . Remeasurement due to state deferred tax rate change . . . . . . . . Other, net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2021 $172,053 2020 (In thousands) $ 156,827 2019 $ 136,565 (1,372) 19,647 (45,382) — 8,790 (1,419) 22,791 (16,125) (20,962) 4,241 (1,460) 20,202 (14,085) — (2,319) Income tax expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $153,736 $ 145,353 $ 138,903 (1) Tax expense is calculated at the statutory federal income tax rate of 21.0% for the years ended September 30, 2021, 2020 and 2019. 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, 2021 and 2020 are presented below: 2021 2020 (In thousands) Deferred tax assets: Employee benefit plans . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest rate swaps . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Net operating loss carryforwards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Charitable and other credit carryforwards . . . . . . . . . . . . . . . . . . . . . . Regulatory excess deferred tax . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Lease asset . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 64,316 — 911,424 7,712 148,200 52,138 33,591 $ Total deferred tax assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Valuation allowance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,217,381 (663) Net deferred tax assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1,216,718 66,991 16,719 476,507 8,712 161,565 53,118 20,424 804,036 (1,102) 802,934 Deferred tax liabilities: Difference in net book value and net tax value of assets (1) . . . . . . . . . Gas cost adjustments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Winter Storm Uri regulatory asset . . . . . . . . . . . . . . . . . . . . . . . . . . . . Lease liability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Rate deferral adjustment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Interest rate agreements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (2,258,264) (26,413) (471,025) (52,138) (47,445) (20,156) (47,086) (2,138,966) (23,209) — (53,118) (21,945) — (22,265) Total deferred tax liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (2,922,527) (2,259,503) Net deferred tax liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $(1,705,809) $ (1,456,569) Deferred credits for rate regulated entities . . . . . . . . . . . . . . . . . . . . . . . . $ 4,181 $ 2,537 (1) Includes $129.0 million of deferred tax liability related to goodwill as of September 30, 2021 and 2020. 88 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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. At September 30, 2021, we had $850.2 million (tax effected) of federal net operating loss carryforwards. The federal net operating loss carryfor- wards are available to offset future taxable income. Net operating loss carryforwards incurred prior to December 22, 2017 will begin to expire in 2029. The Company also has $6.0 million in charitable contribution carryforwards to offset future taxable income. The Company’s charitable contribution carryforwards expiration period begins in fiscal 2022. The Company also has $61.2 million (tax effected) of state net operating loss carryforwards (net of $16.2 million of federal effects) and $1.7 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 2023. We believe it is more likely than not that the benefit from certain state net operating loss carryforwards and state credit carryforwards will not be realized. Due to the uncertainty of realizing a benefit from the deferred tax asset recorded for the carryforwards, a valuation allowance of $0.7 million was established for the year ended September 30, 2021. At September 30, 2021, we had recorded liabilities associated with unrecognized tax benefits totaling $32.8 million. The following table reconciles the beginning and ending balance of our unrecognized tax benefits: Unrecognized tax benefits - beginning balance . . . . . . . . . . . . . . . . . . . . . . Increase (decrease) resulting from prior period tax positions . . . . . . . . . . Increase resulting from current period tax positions . . . . . . . . . . . . . . . . . $30,921 671 1,200 Unrecognized tax benefits - ending balance . . . . . . . . . . . . . . . . . . . . . . . . . Less: deferred federal and state income tax benefits . . . . . . . . . . . . . . . . . . . . 32,792 (6,886) 2021 2020 (In thousands) $ 27,716 2019 $ 26,203 (26) 3,231 30,921 (6,493) (923) 2,436 27,716 (5,820) Total unrecognized tax benefits that, if recognized, would impact the effective income tax rate as of the end of the year . . . . . . . . . . . . . . . . . . . . $25,906 $ 24,428 $ 21,896 The Company recognizes interest accrued related to unrecognized tax benefits in interest expense and penal- ties included within interest charges in our consolidated statements of comprehensive income. During the years ended September 30, 2021, 2020 and 2019, the Company recognized approximately $1.4 million, $0.7 million and $2.2 million in interest and penalties. The Company had approximately $10.4 million, $8.2 million and $7.9 million for the payment of interest and penalties accrued at September 30, 2021, 2020 and 2019. We file income tax returns in the U.S. federal jurisdiction as well as in various states where we have oper- ations. We have concluded substantially all U.S. federal income tax matters through fiscal year 2009 and con- cluded 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 legis- lative change enacted in fiscal 2020. As of September 30, 2021 and September 30, 2020, $155.9 million and $20.9 million is recorded in other current liabilities. This amount has increased during fiscal 2021 due to regu- latory approvals received during the fiscal year that shortened the refund period in certain of our jurisdictions. As a result, our effective income tax rate decreased to 18.8% for the fiscal year ended September 30, 2021. Our effective income tax rate in the prior year period was 19.5%, which reflected the income tax benefit recognized upon enactment of the new Kansas legislation. 89 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Currently, the regulatory excess net deferred tax liability is being returned over various periods. Of this amount, $532.3 million, is being returned to customers over 35 - 60 months. An additional $115.3 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 $12.1 million will be addressed in our next rate proceeding. 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 pay- ments 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 commod- ity 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 finan- cial instruments. For the 2020-2021 heating season (generally October through March), in the jurisdictions where we are permitted to utilize financial instruments, we hedged approximately 39 percent, or approximately 15.8 Bcf of the winter flowing gas requirements at a weighted average cost of approximately $2.86 per Mcf. We have not designated these financial instruments as hedges for accounting purposes. Interest Rate Risk Management Activities We manage interest rate risk by periodically entering into financial instruments to effectively fix the Treas- ury yield component of the interest cost associated with anticipated financings. In fiscal 2021, we entered into forward starting interest rate swaps to effectively fix the Treasury yield component associated with $1.4 billion of planned issuances of senior unsecured notes. These swaps were des- ignated as cash flow hedges at the time the agreements were executed. In September 2021, we settled forward starting interest rate swaps with a notional amount of $600 million and received $62.2 million. On October 1, 2021, the notes were issued as planned. 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, 2021, 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, 2021, we had 23,737 MMcf of net long commodity contracts outstanding. These contracts have not been designated as hedges. 90 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) 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, 2021 and 2020. 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 non- current 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 net- ting arrangements with the counterparties. However, as of September 30, 2021 and 2020, no gross amounts and no cash collateral were netted within our consolidated balance sheet. 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 Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Not Designated As Hedges: Commodity contracts . . . . . . . . . . . . . . . Other current assets / Other current liabilities Commodity contracts . . . . . . . . . . . . . . . Deferred charges and other assets / Deferred credits and other liabilities Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gross / Net Financial Instruments . . . . . . . Balance Sheet Location September 30, 2020 Designated As Hedges: Interest rate contracts . . . . . . . . . . . . . . . Deferred charges and other assets / Deferred credits and other liabilities Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Not Designated As Hedges: Commodity contracts . . . . . . . . . . . . . . . Other current assets / Other current liabilities Commodity contracts . . . . . . . . . . . . . . . Deferred charges and other assets / Deferred credits and other liabilities Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gross / Net Financial Instruments . . . . . . . Impact of Financial Instruments on the Statement of Comprehensive Income Cash Flow Hedges $169,469 $ — 169,469 — 55,073 (5,269) 6,144 61,217 — (5,269) $230,686 $(5,269) Assets Liabilities (In thousands) $73,055 $ — 73,055 — 5,687 (2,015) 1,936 7,623 — (2,015) $80,678 $(2,015) 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, 2021, 2020 and 2019 was $5.9 million, $5.5 million and $3.9 million. 91 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) The following table summarizes the gains and losses arising from hedging transactions that were recognized as a component of other comprehensive income (loss), net of taxes, for the years ended September 30, 2021 and 2020. Fiscal Year Ended September 30 2021 2020 (In thousands) Increase in fair value: Interest rate agreements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $123,017 $ 53,241 Recognition of losses in earnings due to settlements: Interest rate agreements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4,566 3,647 Total other comprehensive income from hedging, net of tax . . . . . . . . . . . . . . . $127,583 $ 56,888 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, 2021, we had $61.7 million of net realized losses 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 losses 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 2052. How- ever, 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. 2022 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2023 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2024 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2025 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2026 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Thereafter Interest Rate Agreements (In thousands) $ (2,959) (2,959) (2,959) (2,959) (2,959) (46,919) Total . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $(61,714) 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 measure- ment date (exit price). We record cash and cash equivalents, accounts receivable and accounts payable at carry- ing 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 pric- ing 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. 92 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) Fair value measurements also apply to the valuation of our pension and post-retirement 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, 2021 and 2020. 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. Assets: Financial instruments . . . . . . . . . . . . . . . . . Debt and equity securities Registered investment companies . . . . . . Bond mutual funds . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Bonds (2) Money market funds . . . . . . . . . . . . . . . . Total debt and equity securities . . . . . . . . . Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2)(1) Significant Other Unobservable Inputs (Level 3) (In thousands) Netting and Cash Collateral September 30, 2021 $ — $230,686 $ — $ — $ 230,686 35,175 34,298 — — 69,473 — — 35,655 2,943 38,598 — — — — — — — — — — 35,175 34,298 35,655 2,943 108,071 Total assets . . . . . . . . . . . . . . . . . . . . . . . . . $69,473 $ 269,284 $ — $ — $ 338,757 Liabilities: Financial instruments . . . . . . . . . . . . . . . . . $ — $ 5,269 $ — $ — $ 5,269 Quoted Prices in Active Markets (Level 1) Significant Other Observable Inputs (Level 2)(1) Significant Other Unobservable Inputs (Level 3) (In thousands) Netting and Cash Collateral September 30, 2020 Assets: Financial instruments . . . . . . . . . . . . . . . . . Debt and equity securities Registered investment companies . . . . . . Bond mutual funds . . . . . . . . . . . . . . . . . Bonds (2) . . . . . . . . . . . . . . . . . . . . . . . . . Money market funds . . . . . . . . . . . . . . . . Total debt and equity securities . . . . . . . . . $ — $ 80,678 $ 37,831 29,166 — — 66,997 — — 32,900 4,055 36,955 — — — — — — $ — — — — — — $ 80,678 37,831 29,166 32,900 4,055 103,952 Total assets . . . . . . . . . . . . . . . . . . . . . . . . . $66,997 $ 117,633 $ — $ — $ 184,630 Liabilities: Financial instruments . . . . . . . . . . . . . . . . . $ — $ 2,015 $ — $ — $ 2,015 93 ATMOS ENERGY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued) (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. As described further in Note 2 to the consolidated financial statements, we adopted ASC 326 effective October 1, 2020. In accordance with the new guidance, 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, vola- tility, current returns and any intent to sell the security. As of September 30, 2021, no allowance for credit losses was recorded for our available-for-sale debt securities. At September 30, 2021 and 2020, the amortized cost of our available-for-sale debt securities was $35.6 million and $32.6 million. At September 30, 2021 we maintained investments in bonds that have contractual maturity dates ranging from October 2021 through September 2024. 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 non- financial assets and liabilities include asset retirement obligations and pension and post-retirement 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. 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, 2021: Carrying Amount . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Fair Value . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . September 30, 2021 (In thousands) $7,360,000 $8,086,136 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 princi- pally occur in the southern and midwestern regions of the United States. We believe that this geographic concen- tration 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. 94 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, 2021 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 accord- ance 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 effective- ness 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 frame- work) (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, 2021, in providing reasonable assur- ance regarding the reliability of financial reporting and the preparation of financial statements for external pur- poses in accordance with generally accepted accounting principles. Ernst & Young LLP has issued its report on the effectiveness of the Company’s internal control over finan- cial reporting. That report appears below. /s/ JOHN K. AKERS /s/ CHRISTOPHER T. FORSYTHE John K. Akers President, Chief Executive Officer and Director Christopher T. Forsythe Senior Vice President and Chief Financial Officer November 12, 2021 95 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, 2021, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Spon- soring 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, 2021, 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 2021 consolidated financial statements of the Company and our report dated November 12, 2021 expressed an unqualified opinion thereon. Basis for Opinion The Company’s management is responsible for maintaining effective internal control over financial report- ing and for its assessment of the effectiveness of internal control over financial reporting included in the accom- panying 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 account- ing firm registered with the PCAOB and are required to be independent with respect to the Company in accord- ance 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 circum- stances. 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 compa- ny’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 mis- statements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that con- trols 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 12, 2021 96 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, 2021 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 9, 2022. Information regarding executive officers is reported below: INFORMATION ABOUT OUR EXECUTIVE OFFICERS The following table sets forth certain information as of September 30, 2021, regarding the executive officers of the Company. It is followed by a brief description of the business experience of each executive officer. Name John K. Akers . . . . . . . . . . . . . . . . . . . . . . . Christopher T. Forsythe . . . . . . . . . . . . . . . David J. Park . . . . . . . . . . . . . . . . . . . . . . . . Karen E. Hartsfield . . . . . . . . . . . . . . . . . . . John M. Robbins . . . . . . . . . . . . . . . . . . . . . Age 58 50 50 51 51 Years of Service Office Currently Held 30 18 27 6 8 President, Chief Executive Officer and Director Senior Vice President and Chief Financial Officer Senior Vice President, Utility Operations Senior Vice President, General Counsel and Corporate Secretary 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 Serv- ices 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. David J. Park was named Senior Vice President of Utility Operations, effective January 1, 2017. In this role, Mr. Park is responsible for the operations of Atmos Energy’s six utility divisions as well as gas supply. Prior to this promotion, Mr. Park served as the President of the West Texas Division from July 2012 to December 2016. Mr. Park also served as Vice President of Rates and Regulatory Affairs in the Mid-Tex Division and previously held positions in Engineering and Public Affairs. Mr. Park’s years of service include 10 years at a company acquired by Atmos Energy in 2004. 97 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 Directors is incorporated herein by reference to the Company’s Definitive Proxy Statement for the Annual Meeting of Shareholders on February 9, 2022. 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 is posted on the Company’s website at www.atmosenergy.com on the “Reports” page under “Corporate Responsibility.” In addition, any amendment to or waiver granted from a provision of the Company’s Code of Conduct will be posted on the Company’s website also on the “Reports” page under “Corporate Responsibility.” 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 9, 2022, 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 9, 2022, 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 Share- holders on February 9, 2022, 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 9, 2022, under the heading “Proposal Two – Ratification of Appointment of Independent Registered Public Accounting Firm.” 98 ITEM 15. Exhibits and Financial Statement Schedules. (a) 1. and 2. Financial statements and financial statement schedules. PART IV 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 3.1 3.2 3.3 4.1(a) 4.1(b) 4.2 4.3 4.4 4.5 4.6(a) 4.6(b) 4.6(c) 4.6(d) 4.6(e) Articles of Incorporation and Bylaws Restated Articles of Incorporation of Atmos Energy Corporation - Texas (As Amended Effective February 3, 2010) Restated Articles of Incorporation of Atmos Energy Corporation - Virginia (As Amended Effective February 3, 2010) Amended and Restated Bylaws of Atmos Energy Corporation (as of February 5, 2019) Instruments Defining Rights of Security Holders, Including Indentures Specimen Common Stock Certificate (Atmos Energy Corporation) Description of Registrant’s Securities Indenture dated as of November 15, 1995 between United Cities Gas Company and Bank of America Illinois, Trustee Indenture dated as of July 15, 1998 between Atmos Energy Corporation and U.S. Bank Trust National Association, Trustee Indenture dated as of May 22, 2001 between Atmos Energy Corporation and SunTrust Bank, Trustee Indenture dated as of March 26, 2009 between Atmos Energy Corporation and U.S. Bank National Corporation, Trustee Debenture Certificate for the 6 3/4% Debentures due 2028 Global Security for the 5.95% Senior Notes due 2034 Officers’ Certificate dated June 10, 2011 Global Security for the 5.5% Senior Notes due 2041 Officers’ Certificate dated January 11, 2013 99 Page Number or Incorporation by Reference to Exhibit 3.1 to Form 10-Q dated March 31, 2010 (File No. 1-10042) Exhibit 3.2 to Form 10-Q dated March 31, 2010 (File No. 1-10042) Exhibit 3.1 to Form 8-K dated February 5, 2019 (File No. 1-10042) Exhibit 4.1 to Form 10-K for fiscal year ended September 30, 2012 (File No. 1-10042) Exhibit 4.11(a) to Form S-3 dated August 31, 2004 (File No. 333-118706) Exhibit 4.8 to Form S-3 dated August 31, 2004 (File No. 333-118706) Exhibit 99.3 to Form 8-K dated May 22, 2001 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated March 26, 2009 (File No. 1-10042) Exhibit 99.2 to Form 8-K dated July 29, 1998 (File No. 1-10042) Exhibit 10(2)(g) to Form 10-K for fiscal year ended September 30, 2004 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated June 13, 2011 (File No. 1-10042) Exhibit 4.2 to Form 8-K dated June 13, 2011 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated January 15, 2013 (File No. 1-10042) Exhibit Number 4.6(f) 4.6(g) 4.6(h) 4.6(i) 4.6(j) 4.6(k) 4.6(l) 4.6(m) 4.6(n) 4.6(o) 4.6(p) 4.6(q) 4.6(r) 4.6(s) 4.6(t) 4.6(u) 4.6(v) 4.6(w) 4.6(x) 4.6(y) 4.6(z) 4.6(aa) 4.6(bb) 4.6(cc) Description Global Security for the 4.15% Senior Notes due 2043 Officers’ Certificate dated October 15, 2014 Global Security for the 4.125% Senior Notes due 2044 Officers’ Certificate dated June 8, 2017 Officers’ Certificate dated October 4, 2018 Global Security for the 4.300% Senior Notes due 2048 Global Security for the 4.300% Senior Notes due 2048 Officers’ Certificate dated March 4, 2019 Global Security for the 4.125% Senior Notes due 2049 Officers’ Certificate dated October 2, 2019 Global Security for the 2.625% Senior Notes due 2029 Global Security for the 3.375% Senior Notes due 2049 Officers’ Certificate dated October 1, 2020 Global Security for the 1.500% Senior Notes due 2031 Global Security for the 1.500% Senior Notes due 2031 Fixed Rate Notes Officers’ Certificate dated March 9, 2021 Floating Rate Notes Officers’ Certificate dated March 9, 2021 Global Security for the 0.625% Senior Notes due 2023 Global Security for the 0.625% Senior Notes due 2023 Global Security for the 0.625% Senior Notes due 2023 Global Security for the Floating Rate Senior Notes due 2023 Global Security for the Floating Rate Senior Notes due 2023 Global Security for the Floating Rate Senior Notes due 2023 Officers’ Certificate dated October 1, 2021 100 Page Number or Incorporation by Reference to Exhibit 4.2 to Form 8-K dated January 15, 2013 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated October 17, 2014 (File No. 1-10042) Exhibit 4.2 to Form 8-K dated October 17, 2014 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated June 8, 2017 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated October 4, 2018 (File No. 1-10042) Exhibit 4.2 to Form 8-K dated October 4, 2018 (File No. 1-10042) Exhibit 4.3 to Form 8-K dated October 4, 2018 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated March 4, 2019 (File No. 1-10042) Exhibit 4.2 to Form 8-K dated March 4, 2019 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated October 2, 2019 (File No. 1-10042) Exhibit 4.2 to Form 8-K dated October 2, 2019 (File No. 1-10042) Exhibit 4.3 to Form 8-K dated October 2, 2019 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated October 1, 2020 (File No. 1-10042) Exhibit 4.2 to Form 8-K dated October 1, 2020 (File No. 1-10042) Exhibit 4.3 to Form 8-K dated October 1, 2020 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated March 9, 2021 (File No. 1-10042) Exhibit 4.2 to Form 8-K dated March 9, 2021 (File No. 1-10042) Exhibit 4.3 to Form 8-K dated March 9, 2021 (File No. 1-10042) Exhibit 4.4 to Form 8-K dated March 9, 2021 (File No. 1-10042) Exhibit 4.5 to Form 8-K dated March 9, 2021 (File No. 1-10042) Exhibit 4.6 to Form 8-K dated March 9, 2021 (File No. 1-10042) Exhibit 4.7 to Form 8-K dated March 9, 2021 (File No. 1-10042) Exhibit 4.8 to Form 8-K dated March 9, 2021 (File No. 1-10042) Exhibit 4.1 to Form 8-K dated October 1, 2021 (File No. 1-10042) Exhibit Number 4.6(dd) 4.6(ee) 10.1 10.2 10.3 10.4(a) 10.4(b) 10.5(a) 10.5(b) 10.6(a)* 10.6(b)* 10.7(a)* 10.7(b)* Description Global Security for the 2.850% Senior Notes due 2052 Global Security for the 2.850% Senior Notes due 2052 Material Contracts 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 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 Term Loan Agreement, dated as of April 9, 2020, among Atmos Energy Corporation, Credit Agricole Corporate and Investment Bank, as the Administrative Agent, Canadian Imperial Bank of Commerce, New York Branch, as Syndication Agent, Credit Agricole Corporate and Investment Bank and Canadian Imperial Bank of Commerce, New York Branch, as Joint Lead Arrangers and Joint-Bookrunners, and the lenders named therein Equity Distribution Agreement, dated as of February 12, 2020, among Atmos Energy Corporation and the Managers and Forward Purchasers named in Schedule A thereto Form of Master Forward Sale Confirmation Equity Distribution Agreement, dated as of June 29, 2021, among Atmos Energy Corporation and the Managers and Forward Purchasers named in Schedule A thereto Form of Master Forward Sale Confirmation Executive Compensation Plans and Arrangements Form of Atmos Energy Corporation Change in Control Severance Agreement - Tier I Form of Atmos Energy Corporation Change in Control Severance Agreement - Tier II Atmos Energy Corporation Executive Retiree Life Plan Amendment No. 1 to the Atmos Energy Corporation Executive Retiree Life Plan 101 Page Number or Incorporation by Reference to Exhibit 4.2 to Form 8-K dated October 1, 2021 (File No. 1-10042) Exhibit 4.3 to Form 8-K dated October 1, 2021 (File No. 1-10042) Exhibit 10.1 to Form 8-K dated March 31, 2021 (File No. 1-10042) Exhibit 10.2 to Form 8-K dated March 31, 2021 (File No. 1-10042) Exhibit 10.1 to Form 8-K dated April 13, 2020 (File No. 1-10042) Exhibit 1.1 to Form 8-K dated February 12, 2020 (File No. 1-10042) Exhibit 1.2 to Form 8-K dated February 12, 2020 (File No. 1-10042) Exhibit 1.1 to Form 8-K dated June 29, 2021 (File No. 1-10042) Exhibit 1.2 to Form 8-K dated June 29, 2021 (File No. 1-10042) Exhibit 10.7(a) to Form 10-K for fiscal year ended September 30, 2010 (File No. 1-10042) Exhibit 10.7(b) to Form 10-K for fiscal year ended September 30, 2010 (File No. 1-10042) Exhibit 10.31 to Form 10-K for fiscal year ended September 30, 1997 (File No. 1-10042) Exhibit 10.31(a) to Form 10-K for fiscal year ended September 30, 1997 (File No. 1-10042) Page Number or Incorporation by Reference to Exhibit 10.1 to Form 8-K dated August 3, 2021 (File No. 1-10042) Exhibit 10.8(a) to Form 10-K for fiscal year ended September 30, 2008 (File No. 1-10042) Exhibit 10.3 to Form 10-Q for quarter ended December 31, 2000 (File No. 1-10042) Exhibit 10.7(a) to Form 10-K for fiscal year ended September 30, 2016 (File No. 1-10042) Exhibit 10.1 to Form 10-Q for quarter ended December 31, 2000 (File No. 1-10042) Exhibit 10.8 to Form 10-K for fiscal year ended September 30, 2016 (File No. 1-10042) Exhibit 10.28(f) to Form 10-K for fiscal year ended September 30, 2001 (File No. 1-10042) Exhibit 10.28(g) to Form 10-K for fiscal year ended September 30, 2001 (File No. 1-10042) Exhibit 10.1 to Form 10-Q for quarter ended December 31, 2002 (File No. 1-10042) Exhibit 10.1 to Form 10-Q for quarter ended December 31, 2011 (File No. 1-10042) Exhibit 10.11(a) to Form 10-K for fiscal year ended September 30, 2019 (File No. 1-10042) Exhibit 10.13(b) to Form 10-K for fiscal year ended September 20, 2020 (File No. 1-10042) Exhibit 10.13(c) to Form 10-K for fiscal year ended September 20, 2020 (File No. 1-10042) Exhibit 10.11(d) to Form 10-K for fiscal year ended September 30, 2019 (File No. 1-10042) Exhibit 10.11(e) to Form 10-K for fiscal year ended September 30, 2019 (File No. 1-10042) Exhibit Number 10.8* 10.9(a)* 10.9(b)* Description Atmos Energy Corporation Annual Incentive Plan for Management (as amended and restated August 3, 2021) Atmos Energy Corporation Supplemental Executive Benefits Plan, Amended and Restated in its Entirety August 7, 2007 Form of Individual Trust Agreement for the Supplemental Executive Benefits Plan 10.10(a)* Atmos Energy Corporation Supplemental Executive Retirement Plan (As Amended and Restated, Effective as of January 1, 2016) 10.10(b)* Atmos Energy Corporation Performance-Based 10.11* Supplemental Executive Benefits Plan Trust Agreement, Effective Date December 1, 2000 Atmos Energy Corporation Account Balance Supplemental Executive Retirement Plan (As Amended and Restated, Effective as of January 1, 2016) 10.12(a)* Mini-Med/Dental Benefit Extension Agreement dated October 1, 1994 10.12(b)* Amendment No. 1 to Mini-Med/Dental Benefit Extension Agreement dated August 14, 2001 10.13* 10.12(c)* Amendment No. 2 to Mini-Med/Dental Benefit Extension Agreement dated December 31, 2002 Atmos Energy Corporation Equity Incentive and Deferred Compensation Plan for Non-Employee Directors, Amended and Restated as of January 1, 2012 10.14(a)* Atmos Energy Corporation 1998 Long-Term Incentive Plan (as amended and restated November 6, 2019) Form of Award Agreement of Time-Lapse Restricted Stock Units under the Atmos Energy Corporation 1998 Long-Term Incentive Plan Form of Award Agreement of Performance- Based Restricted Stock Units under the Atmos Energy Corporation 1998 Long-Term Incentive Plan Form of Non-Employee Director Award Agreement of Time-Lapse Restricted Stock Units Under the Atmos Energy Corporation 1998 Long-Term Incentive Plan Form of Non-Employee Director Award Agreement of Stock Unit Awards Under The Atmos Energy Corporation 1998 Long-Term Incentive Plan Other Exhibits, as indicated Subsidiaries of the registrant 10.14(b)* 10.14(c)* 10.14(d)* 10.14(e)* 21 102 Exhibit Number 23.1 24 31 32 101.INS 101.SCH 101.CAL 101.DEF 101.LAB 101.PRE 104 Description Consent of independent registered public accounting firm, Ernst & Young LLP Power of Attorney Page Number or Incorporation by Reference to Signature page of Form 10-K for fiscal year ended September 30, 2021 Rule 13a-14(a)/15d-14(a) Certifications Section 1350 Certifications** Interactive Data File 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 Inline XBRL Taxonomy Extension Schema Inline XBRL Taxonomy Extension Calculation Linkbase Inline XBRL Taxonomy Extension Definition Linkbase Inline XBRL Taxonomy Extension Labels Linkbase Inline XBRL Taxonomy Extension Presentation Linkbase 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. 103 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. SIGNATURES ATMOS ENERGY CORPORATION (Registrant) By: /s/ CHRISTOPHER T. FORSYTHE Christopher T. Forsythe Senior Vice President and Chief Financial Officer Date: November 12, 2021 104 POWER OF ATTORNEY KNOW ALL MEN BY THESE PRESENTS, that each person whose signature appears below hereby con- stitutes 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 Kim R. Cocklin /s/ JOHN K. AKERS John K. Akers /s/ CHRISTOPHER T. FORSYTHE Christopher T. Forsythe /s/ RICHARD M. THOMAS Richard M. Thomas /s/ ROBERT W. BEST Robert W. Best /s/ KELLY H. COMPTON Kelly H. Compton /s/ SEAN DONOHUE Sean Donohue /s/ RAFAEL G. GARZA Rafael G. Garza /s/ RICHARD K. GORDON Richard K. Gordon /s/ ROBERT C. GRABLE Robert C. Grable /s/ NANCY K. QUINN Nancy K. Quinn /s/ RICHARD A. SAMPSON Richard A. Sampson /s/ STEPHEN R. SPRINGER Stephen R. Springer /s/ DIANA J. WALTERS Diana J. Walters /s/ RICHARD WARE II Richard Ware II /s/ FRANK YOHO Frank Yoho Chairman of the Board November 12, 2021 President, Chief Executive Officer and Director November 12, 2021 Senior Vice President and Chief Financial Officer November 12, 2021 Vice President and Controller (Principal Accounting Officer) November 12, 2021 Director Director Director Director Director Director Director Director Director Director Director Director 105 November 12, 2021 November 12, 2021 November 12, 2021 November 12, 2021 November 12, 2021 November 12, 2021 November 12, 2021 November 12, 2021 November 12, 2021 November 12, 2021 November 12, 2021 November 12, 2021 Forward-Looking Statements The matters discussed or incorporated by reference in this Annual Report 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 the Company 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 the Company’s 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 discussed in this report. These risks and uncertainties are discussed in the Company’s Annual Report on Form 10-K for the fiscal year ended September 30, 2021. Although the Company believes 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, the Company undertakes no obligation to update or revise any of its forward-looking statements, whether as a result of new information, future events or otherwise. Board of Directors J. Kevin Akers President and Chief Executive Officer, Atmos Energy Corporation, Dallas, Texas Board member since 2019 Robert W. Best Former Chairman of the Board, Atmos Energy Corporation, Dallas, Texas Board member since 1997 Committee: Corporate Responsibility, Sustainability, & Safety Kim R. Cocklin Chairman of the Board, Atmos Energy Corporation, Dallas, Texas Board member since 2009 Kelly H. Compton Executive Director, The Hoglund Foundation, Dallas, Texas Board member since 2016 Committees: Audit, Human Resources Sean Donohue Chief Executive Officer Dallas/Fort Worth International Airport Dallas, Texas Board member since 2018 Committees: Corporate Responsibility, Sustainability, & Safety, Nominating and Corporate Governance Rafael G. Garza President and Founder, RGG Capital Partners, LLC, Fort Worth, Texas Board member since 2016 Committees: Audit, Nominating and Corporate Governance Richard K. Gordon General Partner, Juniper Capital LP and Juniper Energy LP; Senior Advisor, Juniper Capital II and Juniper Capital III, Houston, Texas Board member since 2001 Lead Director since 2016 Committees: Corporate Responsibility, Sustainability, & Safety (Chair), Executive (Chair), Human Resources, Nominating and Corporate Governance Robert C. Grable Founding Partner, Kelly Hart & Hallman LLP Fort Worth, Texas Board member since 2009 Committees: Audit, Executive, Nominating and Corporate Governance (Chair) Nancy K. Quinn Independent Energy Consultant Key Biscayne, Florida Board member since 2004 Former Lead Director Committees: Audit, Executive, Human Resources (Chair), Corporate Responsibility, Sustainability, & Safety Richard A. Sampson General Partner and Founder, RS Core Capital, LLC, Denver, Colorado Board member since 2012 Committees: Audit (Chair), Executive, Human Resources Stephen R. Springer Retired Senior Vice President and General Manager, Midstream Division, The Williams Companies, Inc. Fort Myers Beach, Florida Board member since 2005 Committee: Corporate Responsibility, Sustainability, & Safety Diana J. Walters Founder and Managing Member, Amichel, LLC, Magnolia, Texas Board member since 2018 Committees: Corporate Responsibility, Sustainability, & Safety, Human Resources Richard Ware II Chairman, Amarillo National Bank, Amarillo, Texas Board member since 1994 Committees: Audit, Nominating and Corporate Governance Frank Yoho Former Executive Vice President and President of Natural Gas, Duke Energy Charlotte, North Carolina Board member since 2020 Committees: Audit, Corporate Responsibility, Sustainability, & Safety Charles K. Vaughan Honorary Director, Retired Chairman of the Board and Retired Lead Director, Atmos Energy Corporation, Dallas, Texas Board member from 1983 to 2012 Senior Management Team J. Kevin Akers President and Chief Executive Officer John S. McDill Senior Vice President, Utility Operations Christopher T. Forsythe Senior Vice President and Chief Financial Officer J. Matt Robbins Senior Vice President, Human Resources Karen E. Hartsfield Senior Vice President, General Counsel and Corporate Secretary Corporate Information Common Stock Listing New York Stock Exchange. Trading symbol: ATO Stock Transfer Agent and Registrar Broadridge Corporate Issuer Solutions, Inc. P.O. Box 1342 Brentwood, NY 11717 800-543-3038 To inquire about your Atmos Energy common stock, please call Broadridge at the telephone number above. You may use the agent’s interactive voice response system 24 hours a day to learn about transferring stock or to check your recent account activity, all without the assistance of a customer service representative. Please have available your Atmos Energy shareholder account number and your Social Security or federal taxpayer ID number. To speak to a Broadridge customer service representative, please call the same number between 9 a.m. and 6 pm. Eastern time, Monday through Friday. You may also find more information at https://shareholder.broadridge.com/ATO. Independent Registered Public Accounting Firm Ernst & Young LLP One Victory Park Suite 2000 2323 Victory Avenue Dallas, Texas 75219 214-969-8000 Annual Report Atmos Energy Corporation’s 2021 Annual Report including our Form 10-K is available at no charge from Investor Relations, Atmos Energy Corporation, P.O. Box 650205, Dallas, Texas 75265-0205 or by calling 972-855-3729, Monday through Friday, between 8 a.m. and 5 p.m. Central time. Atmos Energy’s 2021 Annual Report also may be viewed on Atmos Energy’s website at www.atmosenergy.com. Annual Meeting of Shareholders The 2022 Annual Meeting of Shareholders will be on Wednesday, February 9, 2022, at 9:00 a.m. Central time, and will be conducted virtually via webcast. Please see your proxy materials for further information. Direct Stock Purchase Plan Atmos Energy has a Direct Stock Purchase Plan that is available to all investors. For an Enrollment Application Form and a Plan Prospectus, please call Broadridge at 800-543-3038. The Prospectus is also available at www.atmosenergy. com. You may also obtain information by writing to Investor Relations, Atmos Energy Corporation, P.O. Box 650205, Dallas, Texas 75265-0205. This is not an offer to sell, or a solicitation to buy, any securities of Atmos Energy Corporation. Shares of Atmos Energy common stock purchased through the Direct Stock Purchase Plan will be offered only by prospectus. Atmos Energy on the Internet Information about Atmos Energy is available at www.atmosenergy.com. Our website includes news releases, current and historical financial reports, other investor data, corporate governance documents, management biographies, customer information and facts about Atmos Energy’s operations. Atmos Energy Corporation Contacts To contact Atmos Energy’s Investor Relations, call 972-855-3729, Monday through Friday, between 8 a.m. and 5 p.m. Central time or send an email message to InvestorRelations@atmosenergy.com. Securities analysts and investment managers, please contact: Dan Meziere Vice President, Investor Relations and Treasurer 972-855-3729 (voice) 972-855-3040 (fax) InvestorRelations@atmosenergy.com Atmos Energy Corporation P.O. Box 650205 Dallas, Texas 75265-0205 atmosenergy.com