10-K

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

(Mark One)

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

For the fiscal year ended September 30, 2020

OR

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

For the transition period from                      to                     

Commission file number 1-10042

Atmos Energy Corporation

(Exact name of registrant as specified in its charter)

Texas and Virginia    75-1743247

(State or other jurisdiction of    (IRS employer

incorporation or organization)    identification no.)

1800 Three Lincoln Centre

5430 LBJ Freeway

Dallas, Texas    75240

(Address of principal executive offices)    (Zip code)

Registrant’s telephone number, including area code:

(972) 934-9227

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

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

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

None

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

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

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  þ        No  ¨

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes  þ        No  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer ☑ Accelerated filer ☐ Non-accelerated filer ☐ Smaller reporting company ☐ Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

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

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

The aggregate market value of the common voting stock held by non-affiliates of the registrant as of the last business day of the registrant’s most recently completed second fiscal quarter, March 31, 2020, was $11,938,304,144.

As of November 6, 2020, the registrant had 125,889,456 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 3, 2021 are incorporated by reference into Part III of this report.

TABLE OF CONTENTS

		Page
Glossary of Key Terms		3
	Part I
Item 1.	Business	4
Item 1A.	Risk Factors	13
Item 1B.	Unresolved Staff Comments	19
Item 2.	Properties	19
Item 3.	Legal Proceedings	20
Item 4.	Mine Safety Disclosures	20
	Part II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	20
Item 6.	Selected Financial Data	22
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	23
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	34
Item 8.	Financial Statements and Supplementary Data	36
Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	84
Item 9A.	Controls and Procedures	84
Item 9B.	Other Information	86
	Part III
Item 10.	Directors, Executive Officers and Corporate Governance	86
Item 11.	Executive Compensation	87
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	87
Item 13.	Certain Relationships and Related Transactions, and Director Independence	87
Item 14.	Principal Accountant Fees and Services	87
	Part IV
Item 15.	Exhibits and Financial Statement Schedules	87
Item 16.	Form 10-K Summary	91

GLOSSARY OF KEY TERMS

Adjusted diluted net income per share	Non-GAAP measure defined as diluted net income per share before the one-time, non-cash income tax benefit
Adjusted net income	Non-GAAP measure defined as net income before the one-time, non-cash income tax benefit
AFUDC	Allowance for funds used during construction
AOCI	Accumulated Other Comprehensive Income
ARM	Annual Rate Mechanism
ATO	Trading symbol for Atmos Energy Corporation common stock on the NYSE
Bcf	Billion cubic feet
COSO	Committee of Sponsoring Organizations of the Treadway Commission
DARR	Dallas Annual Rate Review
ERISA	Employee Retirement Income Security Act of 1974
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
GAAP	Generally Accepted Accounting Principles
GRIP	Gas Reliability Infrastructure Program
GSRS	Gas System Reliability Surcharge
LIBOR	London Interbank Offered Rate
LTIP	1998 Long-Term Incentive Plan
Mcf	Thousand cubic feet
MDWQ	Maximum daily withdrawal quantity
Mid-Tex ATM Cities	Represents a coalition of 47 incorporated cities or approximately 10 percent of the Mid-Tex Division's customers.
Mid-Tex Cities	Represents all incorporated cities other than Dallas and Mid-Tex ATM Cities, or approximately 72 percent of the Mid-Tex Division’s customers.
MMcf	Million cubic feet
Moody’s	Moody’s Investor Service, Inc.
NGA	Natural Gas Act of 1938
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
SGR	Supplemental Growth Rider
SIR	System Integrity Rider
SRF	Stable Rate Filing
SSIR	System Safety and Integrity Rider
TCJA	Tax Cuts and Jobs Act of 2017
WNA	Weather Normalization Adjustment

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PART I

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

ITEM 1. Business.

Overview and Strategy

Atmos Energy Corporation, headquartered in Dallas, Texas, and incorporated in Texas and Virginia, is the country’s largest natural-gas-only distributor based on number of customers. We safely deliver reliable, affordable, efficient and abundant natural gas through regulated sales and transportation arrangements to 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 our people and infrastructure

• enhancing our culture.

Since 2011, our operating strategy has focused on modernizing our distribution and transmission system to improve safety and reliability. This operating strategy also allows us to reduce methane emissions from our system. Since that time, our capital expenditures have increased approximately 14 percent annually. Additionally, during this period, we have added new or modified existing regulatory mechanisms to reduce regulatory lag.

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 employees and enhanced employee training.

Operating Segments

As of September 30, 2020, we manage and review our consolidated operations through the following reportable segments:

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

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

Distribution Segment Overview

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

Division	Service Areas	Communities Served	Customer Meters
Mid-Tex	Texas, including the Dallas/Fort Worth Metroplex	550	1,751,898
Kentucky/Mid-States	Kentucky	230	182,639
	Tennessee		156,820
	Virginia		24,493
Louisiana	Louisiana	270	368,332
West Texas	Amarillo, Lubbock, Midland	80	320,085
Mississippi	Mississippi	110	267,482
Colorado-Kansas	Colorado	170	123,423
	Kansas		138,009

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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, 2020, we held 1,023 franchises having terms generally ranging from five to 35 years. A significant number of our franchises expire each year, which require renewal prior to the end of their terms. Historically, we have successfully renewed these franchises and believe that we will continue to be able to renew our franchises as they expire.

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

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

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

Our supply of natural gas is provided by a variety of suppliers, including independent producers, marketers and pipeline companies, withdrawals of gas from proprietary and contracted storage assets and peaking and spot purchase agreements, as needed.

Supply arrangements consist of both base load and swing supply (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 swing supply 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 that have demonstrated that they can provide reliable service. We select these suppliers based on their ability to deliver gas supply to our designated firm pipeline receipt points at the lowest reasonable cost. Major suppliers during fiscal 2020 were Castleton Commodities Merchant Trading L.P., CenterPoint Energy Services, Inc., ConocoPhillips Company, Devon Gas Services, L.P., EnLink Gas Marketing LP, Hartree Partners, L.P., Symmetry Energy Solutions, LLC, Targa Gas Marketing LLC, Texla Energy Management, Inc. and Twin Eagle Resources Management, LLC.

The combination of base load, peaking and spot purchase 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 2020 was on November 12, 2019, when sales to customers reached approximately 2.7 Bcf.

Currently, our distribution divisions utilize 37 pipeline transportation companies, both interstate and intrastate, to transport our natural gas. The pipeline transportation agreements are firm and many of them have “pipeline no-notice” storage service, which provides for daily balancing between system requirements and nominated flowing supplies. These agreements have been negotiated with the shortest term necessary while still maintaining our right of first refusal. The natural gas supply for our Mid-Tex Division is delivered primarily by our APT Division.

To maintain our deliveries to high priority customers, we have the ability, and have exercised our right, to curtail deliveries to certain customers under the terms of interruptible contracts or applicable state regulations or statutes. Our customers’ demand on our system is not necessarily indicative of our ability to meet current or anticipated market demands or immediate delivery requirements because of factors such as the physical limitations of gathering, storage and transmission systems, the duration and severity of cold weather, the availability of gas reserves from our suppliers, the ability to purchase additional supplies on a short-term basis and actions by federal and state regulatory authorities. Curtailment rights provide us the flexibility to meet the human-needs requirements of our customers on a firm 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 our customers. We do not anticipate any problems with obtaining additional gas supply as needed for our customers.

Pipeline and Storage Segment Overview

Our pipeline and storage segment consists of the pipeline and storage operations of APT and our natural gas transmission operations in Louisiana. APT is one of the largest intrastate pipeline operations in Texas with a heavy concentration in the established natural gas-producing areas of central, northern and eastern Texas, extending into or near the major producing areas

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of the Barnett Shale, the Texas Gulf Coast and the Permian Basin of West Texas. Through its system, APT provides transportation and storage services to our Mid-Tex Division, other third party local distribution companies, industrial and electric generation customers, marketers and producers. As part of its pipeline operations, APT owns and operates five underground storage reservoirs in Texas.

Revenues earned from transportation and storage services for APT are subject to traditional ratemaking governed by the RRC. Rates are updated through periodic filings made under Texas’ GRIP. GRIP allows us to include in our rate base annually approved capital costs incurred in the prior calendar year provided that we file a complete rate case at least once every five years; the most recent of which was completed in August 2017. APT’s existing regulatory mechanisms allow certain transportation and storage services to be provided under market-based rates.

Our natural gas transmission operations in Louisiana are comprised of a 21-mile pipeline located in the New Orleans, Louisiana area that is primarily used to aggregate gas supply for our distribution division in Louisiana under a long-term contract and, on a more limited basis, to third parties. The demand fee charged to our Louisiana distribution division for these services is subject to regulatory approval by the Louisiana Public Service Commission. We also manage two asset management plans 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 operate. The regulatory authorities have the responsibility of ensuring that utilities in their jurisdictions operate in the best interests of customers while providing utility companies the opportunity to earn a reasonable return on their investment. Generally, each regulatory authority reviews rate requests and establishes a rate structure intended to generate revenue sufficient to cover the costs of conducting business, including a reasonable return on invested capital.

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

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

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

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

• WNA mechanisms in seven states that serve to minimize the effects of weather on approximately 97 percent of our distribution residential and commercial revenues.

• The ability to recover the gas cost portion of bad debts in five states.

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The following table provides a jurisdictional rate summary for our regulated operations as of September 30, 2020. This information is for regulatory purposes only and may not be representative of our actual financial position.

Division	Jurisdiction	Effective Date of Last Rate/GRIP Action	Rate Base (thousands)(1)	Authorized Rate of Return(1)	Authorized Debt/ Equity Ratio(1)	Authorized Return on Equity(1)
Atmos Pipeline — Texas	Texas	05/20/2020	$2,698,343	8.87%	47/53	11.50%
Colorado-Kansas	Colorado	05/03/2018	134,726	7.55%	44/56	9.45%
	Colorado SSIR	01/01/2020	56,507	7.55%	44/56	9.45%
	Kansas	04/01/2020	242,314	7.03%	44/56	9.10%
	Kansas GSRS	05/01/2019	26,322	(4)	(4)	(4)
Kentucky/Mid-States	Kentucky	05/08/2019	424,929	7.49%	42/58	9.65%
	Kentucky-PRP	10/01/2019	27,315	7.49%	42/58	9.65%
	Tennessee	06/01/2019	389,061	7.79%	42/58	9.80%
	Virginia	04/01/2019	47,827	7.43%	42/58	9.20%
	Virginia-SAVE	10/01/2019	684	7.43%	42/58	9.20%
Louisiana	Louisiana	07/01/2020	747,021	7.57%	42/58	9.80%
Mid-Tex	Mid-Tex Cities(6)	10/01/2019	3,052,562(5)	7.83%	42/58	9.80%
	Mid-Tex - ATM Cities	06/01/2020	3,654,981(5)	7.97%	40/60	9.80%
	Mid-Tex - Environs	05/20/2020	3,654,985(5)	7.97%	40/60	9.80%
	Dallas	09/01/2020	3,510,508(5)	7.83%	40/60	9.80%
Mississippi	Mississippi(7)	11/01/2019	448,533	7.81%	(4)	(4)
	Mississippi - SIR(7)	11/01/2019	185,844	7.81%	(4)	(4)
West Texas	West Texas Cities(8) (10)	10/01/2019	591,513(9)	7.83%	42/58	9.80%
	West Texas - ALDC	04/28/2020	671,738(9)	8.57%	48/52	10.50%
	West Texas - Environs	06/16/2020	667,994(9)	7.97%	40/60	9.80%

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

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

(2) The bad debt rider allows us to recover from ratepayers the gas cost portion of bad debts.

(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, 2020, which included a rate base of $3,726.3 million, an authorized return of 7.53%, 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 6, 2020, which included a rate base of $721.6 million and an authorized return of 7.81%. New rates were implemented November 1, 2020.

(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, 2020, which included a rate base of $660.9 million, an authorized return of 7.53%, a debt/equity ratio of 42/58 and an authorized ROE of 9.80%.

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

Recent Ratemaking Activity

The amounts described in the following sections represent the annual operating income that was requested or received in each rate filing, which may not necessarily reflect the stated amount referenced in the final order, as certain operating costs may have changed as a result of the commission's or other governmental authority's final ruling. The following table summarizes the annualized ratemaking outcomes we implemented in each of the last three fiscal years.

	Annual Increase (Decrease) to Operating Income For the Fiscal Year Ended September 30
Rate Action	2020			2019		2018
	(In thousands)
Annual formula rate mechanisms	$	160,857		$	114,810	$	92,472
Rate case filings	(1,057		)	1,656		(12,853		)
Other ratemaking activity	353			214		457
	$	160,153		$	116,680	$	80,076

Additionally, the following ratemaking efforts seeking $131.9 million in annual operating income were initiated during fiscal 2020 but had not been completed or implemented as of September 30, 2020:

Division	Rate Action	Jurisdiction	Operating Income Requested
			(In thousands)
Kentucky/Mid-States	Infrastructure Mechanism	Virginia (1)	$	410
Kentucky/Mid-States	Infrastructure Mechanism	Kentucky (2)	3,049
Mid-Tex	Formula Rate Mechanism	Mid-Tex Cities (3)	94,060
Mississippi	Infrastructure Mechanism	Mississippi (4)	10,526
Mississippi	Formula Rate Mechanism	Mississippi (4)	8,379
West Texas	Formula Rate Mechanism	West Texas Cities (5)	7,057
West Texas	Rate Case	Amarillo, Lubbock, Dalhart and Channing	8,406
			$	131,887

(1) On August 21, 2020, the State Corporation Commission of Virginia approved a rate increase of $0.3 million effective October 1, 2020.

(2) On September 30, 2020, the Kentucky Public Service Commission approved a rate increase of $1.6 million effective October 1, 2020.

(3) The Mid-Tex Cities approved a rate increase of $82.6 million with new rates to be implemented on December 1, 2020.

(4) The Mississippi Public Service Commission approved an increase in operating income of $10.6 million for the SIR filing and $5.9 million for the SRF filing. New rates were implemented November 1, 2020.

(5) The West Texas Cities approved a rate increase of $5.6 million with new rates to be implemented on December 1, 2020.

Our recent ratemaking activity is discussed in greater detail below.

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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. The following table summarizes our annual formula rate mechanisms by state.

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

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

The following table summarizes our annual formula rate mechanisms with effective dates during the fiscal years ended September 30, 2020, 2019 and 2018:

Division	Jurisdiction	Test Year Ended	Increase (Decrease) in Annual Operating Income		Effective Date
			(In thousands)
2020 Filings:
Mid-Tex	DARR	09/2019	$	14,746	09/01/2020
Louisiana	Louisiana (1)	12/2019	14,781		07/01/2020
West Texas	Environs (2)	12/2019	1,031		06/16/2020
Kentucky/Mid-States	Tennessee ARM	05/2019	714		06/15/2020
Mid-Tex	ATM Cities (2)	12/2019	11,148		06/12/2020
Mid-Tex	Environs (2)	12/2019	4,440		05/20/2020
Atmos Pipeline - Texas	Texas	12/2019	49,251		05/20/2020
West Texas	Amarillo, Lubbock, Dalhart and Channing (2)	12/2019	5,937		04/28/2020
Colorado-Kansas	Colorado SSIR	12/2020	2,082		01/01/2020
Mississippi	Mississippi - SIR	10/2020	7,586		11/01/2019
Mississippi	Mississippi - SRF	10/2020	6,886		11/01/2019
Kentucky/Mid-States	Virginia - SAVE	09/2020	84		10/01/2019
Kentucky/Mid-States	Kentucky PRP	09/2020	2,912		10/01/2019
Mid-Tex	Mid-Tex RRM Cities	12/2018	34,380		10/01/2019
West Texas	West Texas Cities RRM	12/2018	4,879		10/01/2019
Total 2020 Filings			$	160,857
2019 Filings:
Mid-Tex	ATM Cities	12/2018	$	6,591	09/26/2019
Louisiana	LGS	12/2018	7,124		07/01/2019

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Mid-Tex	Environs	12/2018	2,435			06/04/2019
West Texas	Environs	12/2018	1,005			06/04/2019
Mid-Tex	DARR	09/2018	9,452			06/01/2019
Kentucky/Mid-States	Tennessee ARM	05/2020	2,393			06/01/2019
Atmos Pipeline - Texas	Texas	12/2018	49,225			05/07/2019
West Texas	Amarillo, Lubbock, Dalhart and Channing	12/2018	5,692			05/01/2019
Colorado-Kansas	Kansas GSRS	12/2018	1,562			05/01/2019
Louisiana	Trans La	09/2018	4,719			04/01/2019
Colorado-Kansas	Colorado GIS	12/2019	87			04/01/2019
Colorado-Kansas	Colorado SSIR	12/2019	2,147			01/01/2019
Mississippi	Mississippi - SIR	10/2019	7,135			11/01/2018
Mississippi	Mississippi - SRF	10/2019	(118		)	11/01/2018
Kentucky/Mid-States	Tennessee ARM	05/2019	(5,032		)	10/15/2018
Mid-Tex	Mid-Tex RRM Cities	12/2017	17,633			10/01/2018
West Texas	West Texas Cities RRM	12/2017	2,760			10/01/2018
Total 2019 Filings			$	114,810
2018 Filings:
Louisiana	LGS	12/2017	$	(1,521	)	07/01/2018
West Texas	Amarillo, Lubbock, Dalhart and Channing	12/2017	4,418			06/08/2018
Mid-Tex	Environs	12/2017	1,604			06/05/2018
West Texas	Environs	12/2017	826			06/05/2018
Atmos Pipeline - Texas	Texas	12/2017	42,173			05/22/2018
Louisiana	Trans La	09/2017	(1,913		)	05/01/2018
Colorado-Kansas	Kansas GSRS	09/2018	820			02/27/2018
Mississippi	Mississippi - SIR	10/2018	7,658			01/01/2018
Mississippi	Mississippi - SGR (3)	10/2018	1,245			01/01/2018
Mississippi	Mississippi - SRF (3)	10/2018	—			01/01/2018
Colorado-Kansas	Colorado SSIR	12/2018	2,228			12/20/2017
Atmos Pipeline - Texas	Texas	12/2016	28,988			12/05/2017
Kentucky/Mid-States	Kentucky - PRP	09/2018	5,638			10/27/2017
Kentucky/Mid-States	Virginia - SAVE	09/2017	308			10/01/2017
Total 2018 Filings			$	92,472

(1) Beginning in fiscal 2020, our Trans La and LGS filings were combined into one filing, per Commission order. These rates were implemented on July 1, 2020 subject to refund.

(2) 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.

(3) Beginning in fiscal 2019, our SGR rate base was combined with our SRF rate base, per Commission order.

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.

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The following table summarizes our recent rate cases:

Division	State	Increase (Decrease) in Annual Operating Income			Effective Date
		(In thousands)
2020 Rate Case Filings:
West Texas (Triangle)	Texas	$	(808	)	04/21/2020
Colorado-Kansas	Kansas	(249		)	04/01/2020
Total 2020 Rate Case Filings		$	(1,057	)
2019 Rate Case Filings:
Mid-Tex (ATM Cities)	Texas	$	2,113		06/01/2019
Kentucky/Mid-States	Kentucky	3,441			05/08/2019
Kentucky/Mid-States	Virginia	(400		)	04/01/2019
Mid-Tex (Environs)	Texas	(2,674		)	01/01/2019
West Texas (Environs)	Texas	(824		)	01/01/2019
Total 2019 Rate Case Filings		$	1,656
2018 Rate Case Filings:
Colorado-Kansas	Colorado	$	(241	)	05/03/2018
Kentucky/Mid-States	Kentucky	(7,504		)	05/03/2018
Mid-Tex - City of Dallas	Texas	(5,108		)	02/14/2018
Total 2018 Rate Case Filings		$	(12,853	)

Other Ratemaking Activity

The following table summarizes other ratemaking activity during the fiscal years ended September 30, 2020, 2019 and 2018:

Division	Jurisdiction	Rate Activity	Increase in Annual Operating Income		Effective Date
			(In thousands)
2020 Other Rate Activity:
Colorado-Kansas	Kansas	Ad Valorem (1)	$	353	02/01/2020
Total 2020 Other Rate Activity			$	353
2019 Other Rate Activity:
Colorado-Kansas	Kansas	Ad Valorem(1)	$	214	02/01/2019
Total 2019 Other Rate Activity			$	214
2018 Other Rate Activity:
Colorado-Kansas	Kansas	Ad-Valorem(1)	$	457	02/01/2018
Total 2018 Other Rate Activity			$	457

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

Other Regulation

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

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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 (NGA), 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 NGA. Additionally, the FERC has regulatory authority over the use and release of interstate pipeline and storage capacity. The FERC also has authority to detect and prevent market manipulation and to enforce compliance with FERC’s other rules, policies and orders by companies engaged in the sale, purchase, transportation or storage of natural gas in interstate commerce. We have taken what we believe are the necessary and appropriate steps to comply with these regulations.

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

Competition

Although our regulated distribution operations are not currently in significant direct competition with any other distributors of natural gas to residential and commercial customers within our service areas, we do compete with other natural gas suppliers and suppliers of alternative fuels for sales to industrial customers. We compete in all aspects of our business with alternative energy sources, including, in particular, electricity. Electric utilities offer electricity as a rival energy source and compete for the space heating, water heating and cooking markets. Promotional incentives, improved equipment efficiencies and promotional rates all contribute to the acceptability of electrical equipment. The principal means to compete against alternative fuels is lower prices, and natural gas historically has maintained its price advantage in the residential, commercial and industrial markets.

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

Employees

The Corporate Responsibility, Sustainability, and Safety Committee of the Board of Directors oversees matters relating to equality, 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, 2020, we had 4,694 employees, substantially unchanged from last year. We monitor our workforce data on a calendar year basis. As of December 31, 2019, 61 percent of our employees worked in field roles and 39 percent worked in support/shared services roles.

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 1,800 employees.

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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 2020, John K. Akers, certified to the New York Stock Exchange that he was not aware of any violations by the Company of NYSE corporate governance listing standards. The Board of Directors also annually reviews and updates, if necessary, the charters for each of its Audit, Human Resources, Nominating and Corporate Governance and Corporate Responsibility, Sustainability and Safety Committees. All of the foregoing documents are posted on our website, www.atmosenergy.com, under "Corporate Governance" under the "Corporate Responsibility" tab under "Our Company". We will also provide copies of all corporate governance documents free of charge upon request to Shareholder Relations at the address listed above.

ITEM 1A. Risk Factors.

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

Regulatory and Legislative Risks

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

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

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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 effectively 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 legislation also requires that our facilities, sites and other properties associated with our operations be operated, maintained, abandoned and reclaimed to the satisfaction of applicable regulatory authorities. Failure to comply with these laws, regulations, permits and licenses may expose us to fines, penalties or interruptions in our operations that could be significant to our financial results. In addition, existing environmental regulations may be revised or our operations may become subject to new regulations.

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

FERC has regulatory authority over some of our operations, including the use and release of interstate pipeline and storage capacity. FERC has adopted rules designed to prevent market power abuse and market manipulation and to promote compliance with FERC’s other rules, policies and orders by companies engaged in the sale, purchase, transportation or storage of natural gas in interstate commerce. These rules carry increased penalties for violations. Although we have taken steps to structure current and future transactions to comply with applicable current FERC regulations, changes in FERC regulations or their interpretation by FERC or additional regulations issued by FERC in the future could also adversely affect our business, financial condition or financial results.

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

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

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.

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

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”;

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•improve data collection, integration and analysis;

•repair and remediate the pipeline as necessary; and

•implement preventative and mitigating actions.

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

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

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

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

In order to meet our customers’ annual and seasonal natural gas demands, we must obtain a sufficient supply of natural gas, interstate pipeline capacity and storage capacity. If we are unable to obtain these, either from our suppliers’ inability to deliver the contracted commodity or the inability to secure replacement quantities, our financial condition and results of operations may be adversely affected. If a substantial disruption to or reduction in interstate natural gas pipelines’ transmission and storage capacity occurred due to operational failures or disruptions, legislative or regulatory actions, hurricanes, tornadoes, floods, 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 operations historically have faced limited competition from other existing intrastate pipelines and gas marketers seeking to provide or arrange transportation, storage and other services for customers. However, in the last few years, several new pipelines have been completed, which has increased the level of competition in this segment of our business.

Adverse weather conditions could affect our operations or financial results.

We have weather-normalized rates for approximately 97 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.

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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. Such climate change could 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. 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 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 operations. Also, companies in our industry may face a heightened risk of exposure to actual acts of terrorism, which could subject our operations to increased

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risks. As a result, the availability of insurance covering such risks may become more limited, which could increase the risk that an event could adversely affect our operations or financial results.

Financial, Economic and Market Risks

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

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

The liquidity required to fund our working capital, capital expenditures and other cash needs is provided from a combination of internally generated cash flows and external debt and equity financing. The cost and availability of borrowing funds from third party lenders or issuing equity is dependent on the liquidity of the credit markets, interest rates and other market conditions. This in turn may limit the amount of funds we can invest in our infrastructure.

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

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

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

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

We are subject to market risks beyond our control, including (i) commodity price volatility caused by market supply and demand dynamics, counterparty performance or counterparty creditworthiness, and (ii) interest rate risk. We are generally insulated from commodity price risk through our purchased gas cost mechanisms. With respect to interest rate risk, 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 concentration of our business in Texas means that our operations and financial results may be significantly affected by changes in the Texas economy in general, weather patterns and regulatory decisions by state and local regulatory authorities in Texas.

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

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

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

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

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

The outbreak of COVID-19 and its impact on business and economic conditions could negatively affect our business, results of operations and financial condition.

The scale and scope of the recent COVID-19 outbreak, the resulting pandemic, and the impact on the economy and financial markets could adversely affect the Company’s business, results of operations and financial condition. 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 (including, but not limited to, voluntary and mandatory quarantines, restrictions on travel, limiting gatherings of people, and reduced operations and extended closures of many businesses and institutions) will not materially impact our business, results of operations and financial condition. In particular, the continued spread of COVID-19 and efforts to contain the virus could:

• impact customer demand for natural gas, particularly from commercial and industrial customers;

• reduce the availability and productivity of our employees and contractors;

• cause us to experience an increase in costs as a result of our emergency measures, delayed payments from our customers and uncollectable accounts;

• cause the Company’s contractors, suppliers and other business partners to be unable to fulfill their contractual obligations;

• result in our inability to meet the requirements of the covenants in our existing credit facilities, including covenants regarding the ratio of indebtedness to total capitalization;

• cause a deterioration in our financial metrics or the business environment that impacts our credit ratings;

• impact our liquidity position and cost of and ability to access funds from financial institutions and capital markets; and

• cause other unpredictable events.

The situation surrounding COVID-19 remains fluid and the likelihood of an impact on the Company that could be material increases the longer the virus impacts activity levels in the United States. Therefore, it is difficult to predict with certainty the potential impact of the virus on the Company’s business, results of operations and financial condition.

To the extent the COVID-19 pandemic has an adverse impact on the Company’s business, results of operations and financial condition, it may also have the effect of heightening many of the other risk factors disclosed herein, such as those relating to 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; and the impact of adverse economic conditions on our customers.

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ITEM 1B. Unresolved Staff Comments.

Not applicable.

ITEM 2. Properties.

Distribution, transmission and related assets

At September 30, 2020, in our distribution segment, we owned an aggregate of 71,558 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 5,684 miles of gas transmission lines.

Storage Assets

We own underground gas storage facilities in several states to supplement the supply of natural gas in periods of peak demand. The following table summarizes certain information regarding our underground gas storage facilities at September 30, 2020:

State	Usable Capacity (Mcf)	Cushion Gas (Mcf)(1)	Total Capacity (Mcf)	Maximum Daily Delivery Capability (Mcf)
Distribution Segment
Kentucky	7,956,991	9,562,283	17,519,274	158,100
Kansas	3,239,000	2,300,000	5,539,000	45,000
Mississippi	1,907,571	2,442,917	4,350,488	31,000
Total	13,103,562	14,305,200	27,408,762	234,100
Pipeline and Storage Segment
Texas	46,083,549	15,878,025	61,961,574	1,710,000
Louisiana	411,040	256,900	667,940	56,000
Total	46,494,589	16,134,925	62,629,514	1,766,000
Total	59,598,151	30,440,125	90,038,276	2,000,100

(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, 2020:

Segment	Division/Company	Maximum Storage Quantity (MMBtu)	Maximum Daily Withdrawal Quantity (MDWQ)(1)
Distribution Segment
	Colorado-Kansas Division	6,343,728	147,965
	Kentucky/Mid-States Division	8,175,103	226,320
	Louisiana Division	2,594,875	177,765
	Mid-Tex Division	4,000,000	150,000
	Mississippi Division	5,099,536	164,764
	West Texas Division	5,500,000	176,000
Total		31,713,242	1,042,814
Pipeline and Storage Segment
	Trans Louisiana Gas Pipeline, Inc.	1,000,000	47,500
Total Contracted Storage Capacity		32,713,242	1,090,314

(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.

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ITEM 3. Legal Proceedings.

See Note 12 to the consolidated financial statements, which is incorporated in this Item 3 by reference.

ITEM 4. Mine Safety Disclosures.

Not applicable.

PART II

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

Our stock trades on the New York Stock Exchange under the trading symbol “ATO.” The dividends paid per share of our common stock for fiscal 2020 and 2019 are listed below.

	Fiscal 2020		Fiscal 2019
Quarter ended:
December 31	$	0.575	$	0.525
March 31	0.575		0.525
June 30	0.575		0.525
September 30	0.575		0.525
	$	2.30	$	2.10

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, 2020, there were 11,199 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 2020 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 shareholders for the last five fiscal years with the total return of the S&P 500 Stock Index (S&P 500), the total return of the S&P 500 Utilities Industry Index and the cumulative total return of the customized peer company group described in Part II, Item 5 of our Annual Report on Form 10-K for fiscal 2019, referred to herein as the Old Comparison Company Index. The Old Comparison Company Index is comprised of natural gas distribution companies with similar revenues, market capitalizations and asset bases to that of the Company. The graph and table below assume that $100.00 was invested on September 30, 2015 in our common stock, the S&P 500, the S&P 500 Utilities Industry Index and in the common stock of the companies in the Old Comparison Company Index, as well as a reinvestment of dividends paid on such investments throughout the period.

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Comparison of Five-Year Cumulative Total Return

among Atmos Energy Corporation, S&P 500 Index,

S&P 500 Utilities Industry Index and Old Comparison Company Index

	Cumulative Total Return
	9/30/2015	9/30/2016	9/30/2017	9/30/2018	9/30/2019	9/30/2020
Atmos Energy Corporation	100.00	131.10	151.00	172.94	214.09	183.63
S&P 500 Stock Index	100.00	115.43	136.91	161.43	168.30	193.80
S&P 500 Utilities Stock Index	100.00	117.37	131.49	135.34	172.02	163.47
Old Comparison Company Index(1)	100.00	123.44	143.69	152.10	198.43	188.11

(1) The Old Comparison Company Index reflects the cumulative total return of the group of utility companies described in Part II, Item 5 of our Annual Report on Form 10-K for fiscal 2019, except that Vectren Corporation has since been acquired, and as a result, its cumulative total return is not included in the graph.

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The following table sets forth the number of securities authorized for issuance under our equity compensation plans at September 30, 2020.

	Number of securities to be issued upon exercise of outstanding options, warrants and rights		Weighted-average exercise price of outstanding options, warrants and rights		Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a))
	(a)		(b)		(c)
Equity compensation plans approved by security holders:
1998 Long-Term Incentive Plan	952,586	(1)	$	—	1,288,782
Total equity compensation plans approved by security holders	952,586		—		1,288,782
Equity compensation plans not approved by security holders	—		—		—
Total	952,586		$	—	1,288,782

(1) Comprised of a total of 355,481 time-lapse restricted stock units, 361,039 director share units and 236,066 performance-based restricted stock units at the target level of performance granted under our 1998 Long-Term Incentive Plan.

ITEM 6. Selected Financial Data.

The following table sets forth selected financial data of the Company and should be read in conjunction with the consolidated financial statements included herein.

	Fiscal Year Ended September 30
	2020		2019		2018		2017		2016
	(In thousands, except per share data)
Results of Operations
Operating revenues	$	2,821,137	$	2,901,848	$	3,115,546	$	2,759,735	$	2,454,648
Operating income(1)	$	824,099	$	746,058	$	727,934	$	735,628	$	665,368
Income from continuing operations	$	601,443	$	511,406	$	603,064	$	382,711	$	345,542
Net income	$	601,443	$	511,406	$	603,064	$	396,421	$	350,104
Diluted income per share from continuing operations	$	4.89	$	4.35	$	5.43	$	3.60	$	3.33
Diluted net income per share	$	4.89	$	4.35	$	5.43	$	3.73	$	3.38
Cash dividends declared per share	$	2.30	$	2.10	$	1.94	$	1.80	$	1.68
Financial Condition
Net property, plant and equipment(2)	$	13,355,347	$	11,787,669	$	10,371,147	$	9,259,182	$	8,268,606
Total assets	$	15,359,032	$	13,367,619	$	11,874,437	$	10,749,596	$	10,010,889
Capitalization:
Shareholders’ equity	$	6,791,203	$	5,750,223	$	4,769,951	$	3,898,666	$	3,463,059
Long-term debt (excluding current maturities)	4,531,779		3,529,452		2,493,665		3,067,045		2,188,779
Total capitalization	$	11,322,982	$	9,279,675	$	7,263,616	$	6,965,711	$	5,651,838

(1) In accordance with our adoption of new accounting standards, changes in comprehensive income statement presentation were implemented on a retrospective basis and impacted previously issued financial statements for the fiscal years ended 2016 through 2018.

(2) Amounts shown are net of assets held for sale related to the divestiture of our natural gas marketing business for fiscal year 2016.

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

INTRODUCTION

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

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

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

The statements contained in this Annual Report on Form 10-K may contain “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than statements of historical fact included in this Report are forward-looking statements made in good faith by us and are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. When used in this Report, or any other of our documents or oral presentations, the words “anticipate”, “believe”, “estimate”, “expect”, “forecast”, “goal”, “intend”, “objective”, “plan”, “projection”, “seek”, “strategy” or similar words are intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed or implied in the statements relating to our strategy, operations, markets, services, rates, recovery of costs, availability of gas supply and other factors. These risks and uncertainties include the following: federal, state and local regulatory and political trends and decisions, including the impact of rate proceedings before various state regulatory commissions; increased federal regulatory oversight and potential penalties; possible increased federal, state and local regulation of the safety of our operations; the impact of greenhouse gas emissions or other legislation or regulations intended to address climate change; possible significant costs and liabilities resulting from pipeline integrity and other similar programs and related repairs; the inherent hazards and risks involved in distributing, transporting and storing natural gas; the availability and accessibility of contracted gas supplies, interstate pipeline and/or storage services; increased competition from energy suppliers and alternative forms of energy; 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; the outbreak of COVID-19 and its impact on business and economic conditions. Accordingly, while we believe these forward-looking statements to be reasonable, there can be no assurance that they will approximate actual experience or that the expectations derived from them will be realized. Further, we undertake no obligation to update or revise any of our forward-looking statements whether as a result of new information, future events or otherwise.

CRITICAL ACCOUNTING POLICIES

Our consolidated financial statements were prepared in accordance with accounting principles generally accepted in the United States. Preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and the related disclosures of contingent assets and liabilities. We base our estimates on historical experience and various other assumptions that we believe to be reasonable under the circumstances. Actual results may differ from estimates.

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

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

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

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Non-GAAP Financial Measures

As described further in Note 13 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. Additionally, the enactment of the Tax Cuts and Jobs Act of 2017 (the TCJA) required us to remeasure our deferred tax assets and liabilities at our new federal statutory income tax rate as of December 22, 2017. The remeasurement of our net deferred tax liabilities resulted in the recognition of a non-cash income tax benefit of $158.8 million for the fiscal year ended September 30, 2018. Due to the non-recurring nature of these benefits, we believe that net income and diluted net income per share before the non-cash income tax benefits provide a more relevant measure to analyze our financial performance than net income and diluted net income per share in order to allow investors to better analyze our core results and allow the information to be presented on a comparative basis. Accordingly, the following discussion and analysis of our financial performance will reference adjusted net income and adjusted diluted earnings per share, non-GAAP measures, which are calculated as follows:

	For the Fiscal Year Ended September 30
	2020			2019		2018			2020 vs. 2019			2019 vs. 2018
	(In thousands, except per share data)
Net income	$	601,443		$	511,406	$	603,064		$	90,037		$	(91,658	)
Non-cash income tax benefits	(20,962		)	—		(158,782		)	(20,962		)	158,782
Adjusted net income	$	580,481		$	511,406	$	444,282		$	69,075		$	67,124
Diluted net income per share	$	4.89		$	4.35	$	5.43		$	0.54		$	(1.08	)
Diluted EPS from non-cash income tax benefits	(0.17		)	—		(1.43		)	(0.17		)	1.43
Adjusted diluted net income per share	$	4.72		$	4.35	$	4.00		$	0.37		$	0.35

RESULTS OF OPERATIONS

Overview

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

We continue to execute our strategy well while managing the ongoing impacts of the Coronavirus Disease 2019 (COVID-19) pandemic. Approximately 95 percent of our employees continue to work remotely as we provide essential services to ensure the safety and functionality of our critical infrastructure while taking precautions to provide a safe work environment for employees and customers.

During fiscal 2020, we recorded net income of $601.4 million, or $4.89 per diluted share, compared to net income of $511.4 million, or $4.35 per diluted share in the prior year. After adjusting for a nonrecurring income tax benefit recognized during fiscal 2020, we recorded adjusted net income of $580.5 million, or $4.72 per diluted share for the year ended September 30, 2020.

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

	For the Fiscal Year Ended September 30
	2020		2019		2018
	(In thousands)
Distribution segment	$	395,664	$	328,814	$	442,966
Pipeline and storage segment	205,779		182,592		160,098
Net income	$	601,443	$	511,406	$	603,064

The year-over-year increase in adjusted net income of $69.1 million, or 14 percent, largely reflects positive rate outcomes driven by safety and reliability spending and customer growth in our distribution business. We did not experience a material change in year-over-year residential revenue in our distribution segment due to COVID-19; however, we did experience a 10

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percent year-over-year decline in nonresidential revenue, including service and other revenues, primarily during the third and fourth fiscal quarter. The decline is partially offset by a reduction in certain operating and maintenance expenses.

During the year ended September 30, 2020, we implemented ratemaking regulatory actions which resulted in an increase in annual operating income of $160.2 million and had ratemaking efforts in progress at September 30, 2020, seeking a total increase in annual operating income of $131.9 million. As of the date of this report, we have received approval to implement $106.6 million of this amount in the first quarter of fiscal 2021.

Capital expenditures for fiscal 2020 increased 14 percent period-over-period, to $1.9 billion. Over 85 percent was invested to improve the safety and reliability of our distribution and transmission systems, with a significant portion of this investment incurred under regulatory mechanisms that reduce regulatory lag to six months or less.

During fiscal 2020, we completed over $1.6 billion of long-term debt and equity financing. As of September 30, 2020, our equity capitalization was 60 percent and we had approximately $2.6 billion in total liquidity, including cash and cash equivalents and funds available through equity forward sales agreements.

As a result of the continued contribution and stability of our earnings, cash flows and capital structure, our Board of Directors increased the quarterly dividend by 8.7% percent for fiscal 2021.

Distribution Segment

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

Our ability to earn our authorized rates is based primarily on our ability to improve the rate design in our various ratemaking jurisdictions to minimize regulatory lag and, ultimately, separate the recovery of our approved rates from customer usage patterns. Improving rate design is a long-term process and is further complicated by the fact that we operate in multiple rate jurisdictions. The “Ratemaking Activity” section of this Form 10-K describes our current rate strategy, progress towards implementing that strategy and recent ratemaking initiatives in more detail.

Revenues in our Texas and Mississippi service areas include franchise fees and gross receipt taxes, which are calculated as a percentage of revenue (inclusive of gas costs). Therefore, the amount of these taxes included in revenue 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 78 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.

During fiscal 2020, we completed 17 regulatory proceedings in our distribution segment, resulting in a $110.9 million increase in annual operating income.

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Review of Financial and Operating Results

Financial and operational highlights for our distribution segment for the fiscal years ended September 30, 2020, 2019 and 2018 are presented below.

	For the Fiscal Year Ended September 30
	2020			2019		2018			2020 vs. 2019			2019 vs. 2018
	(In thousands, unless otherwise noted)
Operating revenues	$	2,626,993		$	2,745,461	$	3,003,047		$	(118,468	)	$	(257,586	)
Purchased gas cost	1,071,227			1,268,591		1,559,836			(197,364		)	(291,245		)
Operating expenses(1)	1,027,523			1,006,098		957,544			21,425			48,554
Operating income	528,243			470,772		485,667			57,471			(14,895		)
Other non-operating income (expense)(1)	(1,265		)	6,241		(6,649		)	(7,506		)	12,890
Interest charges	39,634			60,031		65,850			(20,397		)	(5,819		)
Income before income taxes	487,344			416,982		413,168			70,362			3,814
Income tax expense	105,147			88,168		107,880			16,979			(19,712		)
Non-cash income tax benefits(2)	(13,467		)	—		(137,678		)	(13,467		)	137,678
Net income	$	395,664		$	328,814	$	442,966		$	66,850		$	(114,152	)
Consolidated distribution sales volumes — MMcf	291,650			315,476		300,817			(23,826		)	14,659
Consolidated distribution transportation volumes — MMcf	147,387			155,078		150,566			(7,691		)	4,512
Total consolidated distribution throughput — MMcf	439,037			470,554		451,383			(31,517		)	19,171
Consolidated distribution average cost of gas per Mcf sold	$	3.67		$	4.02	$	5.19		$	(0.35	)	$	(1.17	)

(1) In accordance with our adoption of new accounting standards, changes in comprehensive income statement presentation were implemented on a retrospective basis and impacted previously issued financial statements for fiscal 2018.

(2) See Note 13 to the consolidated financial statements for further information.

Fiscal year ended September 30, 2020 compared with fiscal year ended September 30, 2019

Operating income for our distribution segment increased 12 percent, which primarily reflects:

• an $86.8 million net increase in rate adjustments, primarily in our Mid-Tex, Mississippi, Louisiana and West Texas Divisions.

• a $13.7 million increase from customer growth primarily in our Mid-Tex Division.

• a $11.7 million decrease in operating expense in response to COVID-19:

◦ $8.1 million associated with travel and entertainment and training.

◦ $3.6 million associated with lower overtime/standby costs and benefit costs.

Partially offset by:

• a $18.4 million decrease attributable to COVID-19:

◦ $5.9 million decrease in net consumption and transportation during the third and fourth fiscal quarter, primarily due to a 13 percent decrease in commercial volumes.

◦ $6.3 million decrease in service order revenues primarily during the third and fourth quarter due to the cessation of collection activities during the third and fourth quarters.

◦ $6.2 million increase in bad debt expense primarily due to the cessation of collection activities during the third and fourth quarters.

• a $30.6 million increase in depreciation expense and property taxes associated with increased capital investments.

• a $4.5 million increase in information technology spending to support the modernization of our systems.

The year-over-year change in other non-operating expense and interest charges of $12.9 million primarily reflects increased capitalized interest and AFUDC primarily due to increased capitalized spending, partially offset by an increase in interest expense due to the issuance of long-term debt during fiscal 2020, an increase in community support spending and an increase in pension and other postretirement non-service costs.

The fiscal year ended September 30, 2019 compared with fiscal year ended September 30, 2018 for our distribution segment is described in Item 7 "Management's Discussion and Analysis of Financial Condition and Results of Operations" of our Annual Report on Form 10-K for the fiscal year ended September 30, 2019.

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The following table shows our operating income by distribution division, in order of total rate base, for the fiscal years ended September 30, 2020, 2019 and 2018. 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
	2020		2019			2018		2020 vs. 2019			2019 vs. 2018
	(In thousands)
Mid-Tex	$	236,066	$	202,050		$	202,444	$	34,016		$	(394	)
Kentucky/Mid-States	76,745		73,965			81,105		2,780			(7,140		)
Louisiana	71,892		70,440			70,609		1,452			(169		)
West Texas	52,493		44,902			45,494		7,591			(592		)
Mississippi	55,938		46,229			47,237		9,709			(1,008		)
Colorado-Kansas	34,039		34,362			32,333		(323		)	2,029
Other	1,070		(1,176		)	6,445		2,246			(7,621		)
Total	$	528,243	$	470,772		$	485,667	$	57,471		$	(14,895	)

Pipeline and Storage Segment

Our pipeline and storage segment consists of the pipeline and storage operations of our APT Division and our natural gas transmission operations in Louisiana. Over 80 percent of this segment's revenues are derived from transportation and storage services provided by APT to our Mid-Tex Division, other third party local distribution companies, industrial and electric generation customers, as well as marketers and producers.

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

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

APT annually uses GRIP to recover capital costs incurred in the prior calendar year. On February 14, 2020, APT made a GRIP filing that covered changes in net investment from January 1, 2019 through December 31, 2019 with a requested increase in operating income of $49.3 million. On May 20, 2020, the RRC approved the Company's GRIP filing.

On December 21, 2016, the Louisiana Public Service Commission approved an annual increase of five percent to the demand fee charged by our natural gas transmission pipeline for each of the next 10 years, effective October 1, 2017.

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Review of Financial and Operating Results

Financial and operational highlights for our pipeline and storage segment for the fiscal years ended September 30, 2020, 2019 and 2018 are presented below.

	For the Fiscal Year Ended September 30
	2020			2019			2018			2020 vs. 2019			2019 vs. 2018
	(In thousands, unless otherwise noted)
Mid-Tex / Affiliate transportation revenue	$	474,077		$	428,586		$	384,500		$	45,491		$	44,086
Third-party transportation revenue	127,444			129,930			115,207			(2,486		)	14,723
Other revenue	7,818			8,508			8,006			(690		)	502
Total operating revenues	609,339			567,024			507,713			42,315			59,311
Total purchased gas cost	1,548			(360		)	1,978			1,908			(2,338		)
Operating expenses	311,935			292,098			263,468			19,837			28,630
Operating income	295,856			275,286			242,267			20,570			33,019
Other non-operating income (expense)	8,436			1,163			(3,495		)	7,273			4,658
Interest charges	44,840			43,122			40,796			1,718			2,326
Income before income taxes	259,452			233,327			197,976			26,125			35,351
Income tax expense	61,168			50,735			58,982			10,433			(8,247		)
Non-cash income tax benefits(1)	(7,495		)	—			(21,104		)	(7,495		)	21,104
Net income	$	205,779		$	182,592		$	160,098		$	23,187		$	22,494
Gross pipeline transportation volumes — MMcf	822,499			939,376			871,904			(116,877		)	67,472
Consolidated pipeline transportation volumes — MMcf	621,371			721,998			663,900			(100,627		)	58,098

(1) See Note 13 to the consolidated financial statements for further information.

Fiscal year ended September 30, 2020 compared with fiscal year ended September 30, 2019

Operating income for our pipeline and storage segment increased seven percent, which primarily reflects:

• a $53.2 million net increase due to rate adjustments from the GRIP filing approved in May 2019 and 2020. The increase in rates was driven by increased safety and reliability spending.

Partially offset by:

• a $13.6 million net decrease primarily associated with the tightening of regional spreads driven by a reduction in associated Permian Basin gas production.

• a $12.5 million increase in depreciation expense associated with increased capital investments.

• a $9.4 million increase in system maintenance expense primarily due to spending on hydro testing and in-line inspections.

The year-over-year change in other non-operating income and interest charges of $5.6 million reflects increased 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 2020.

The fiscal year ended September 30, 2019 compared with fiscal year ended September 30, 2018 for our pipeline and storage segment is described in Item 7 "Management's Discussion and Analysis of Financial Condition and Results of Operations" of our Annual Report on Form 10-K for the fiscal year ended September 30, 2019.

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. As of September 30, 2020, external debt financing is provided primarily through the issuance of long-term debt, a $1.5 billion commercial paper program and four committed revolving credit facilities with a total availability from third-party lenders of approximately $2.2 billion. 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.

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We have a shelf registration statement on file with the Securities and Exchange Commission (SEC) that allows us to issue up to $4.0 billion in common stock and/or debt securities. As of the date of this report, approximately $2.4 billion of securities remained available for issuance under the shelf registration statement, which expires February 11, 2023.

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, which expires February 11, 2023. At September 30, 2020, approximately $552 million of equity is available for issuance under this ATM equity sales program. Additionally, as of September 30, 2020, we have $345.2 million in proceeds from previously executed forward sale agreements that must be settled during fiscal 2021.

The liquidity provided by these sources is expected to be sufficient to fund the Company's working capital needs and capital expenditures program.

The following table presents our capitalization as of September 30, 2020 and 2019:

	September 30
	2020				2019
	(In thousands, except percentages)
Short-term debt	$	—	—	%	$	464,915	4.8	%
Long-term debt(1)	4,531,944		40.0	%	3,529,452		36.2	%
Shareholders’ equity	6,791,203		60.0	%	5,750,223		59.0	%
Total capitalization, including short-term debt	$	11,323,147	100.0	%	$	9,744,590	100.0	%

(1) Inclusive of our finance leases as of September 30, 2020.

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, 2020, 2019 and 2018 are presented below.

	For the Fiscal Year Ended September 30
	2020			2019			2018			2020 vs. 2019			2018 vs. 2017
	(In thousands)
Total cash provided by (used in)
Operating activities	$	1,037,999		$	968,769		$	1,124,662		$	69,230		$	(155,893	)
Investing activities	(1,925,518		)	(1,683,660		)	(1,463,566		)	(241,858		)	(220,094		)
Financing activities	883,777			725,670			326,266			158,107			399,404
Change in cash and cash equivalents	(3,742		)	10,779			(12,638		)	(14,521		)	23,417
Cash and cash equivalents at beginning of period	24,550			13,771			26,409			10,779			(12,638		)
Cash and cash equivalents at end of period	$	20,808		$	24,550		$	13,771		$	(3,742	)	$	10,779

Cash flows for the fiscal year ended September 30, 2019 compared with fiscal year ended September 30, 2018 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, 2019.

Cash flows from operating activities

For the fiscal year ended September 30, 2020, we generated cash flow from operating activities of $1,038.0 million compared with $968.8 million in the prior year. The year-over-year increase in operating cash flows reflects positive cash effects of rate case outcomes achieved in fiscal 2019 and working capital changes, primarily as a result of the timing of gas cost recoveries under our purchase gas cost mechanisms.

Cash flows from investing activities

Our capital expenditures are primarily used to improve the safety and reliability of our distribution and transmission system through pipeline replacement and system modernization and to enhance and expand our system to meet customer needs. Over the last three fiscal years, approximately 87 percent of our capital spending has been committed to improving the safety and reliability of our system.

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We allocate our capital spending among our service areas using risk management models and subject matter experts to identify, assess and develop a plan of action to address our highest risk facilities. We have regulatory mechanisms in most of our service areas that provide the opportunity to include approved capital costs in rate base on a periodic basis without being required to file a rate case. These mechanisms permit us a reasonable opportunity to earn a fair return on our investment without compromising safety or reliability.

For the fiscal year ended September 30, 2020, we had $1.9 billion in capital expenditures compared with $1.7 billion for the fiscal year ended September 30, 2019. Capital spending increased by $242.2 million, or 14 percent, as a result of planned increases to modernize our system.

Cash flows from financing activities

Our financing activities provided $883.8 million and $725.7 million in cash for fiscal years 2020 and 2019.

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, during the fiscal year ended September 30, 2020, 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.

Additionally, cash dividends increased due to a 9.5 percent increase in our dividend rate and an increase in shares outstanding.

During the fiscal year ended September 30, 2019, we received $1.7 billion in net proceeds from the issuance of long-term debt and equity. A portion of the net proceeds was used to repay at maturity our $450 million 8.50% unsecured senior notes and the related settlement of our interest rate swaps for $90.1 million, to repay at maturity our $125 million floating rate term loan, to reduce short-term debt, to support our capital spending and for other general corporate purposes. Cash dividends increased due to an 8.2 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, 2020, 2019 and 2018:

	For the Fiscal Year Ended September 30
	2020	2019	2018
Shares issued:
Direct Stock Purchase Plan	107,989	110,063	131,213
Retirement Savings Plan and Trust	78,941	81,456	94,081
1998 Long-Term Incentive Plan (LTIP)	254,706	299,612	385,351
Equity Issuance(1)	6,101,916	7,574,111	4,558,404
Total shares issued	6,543,552	8,065,242	5,169,049

(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). On December 16, 2019, Moody's upgraded our senior unsecured long-term debt rating to A1 and changed their outlook to stable, citing our strong credit metrics as a result of continued improvement in rate design to minimize regulatory lag and our balanced fiscal policy.

32

As of September 30, 2020, our outlook and current debt ratings, which are all considered investment grade are as follows:

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

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

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

Debt Covenants

We were in compliance with all of our debt covenants as of September 30, 2020. 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, 2020.

	Payments Due by Period
	Total		Less than 1 year		1-3 years		3-5 years		More than 5 years
					(In thousands)
Contractual Obligations
Long-term debt(1)	$	4,560,000	$	—	$	200,000	$	10,000	$	4,350,000
Interest charges(2)	3,925,475		194,092		381,386		378,984		2,971,013
Finance leases(3)	16,477		741		1,513		1,557		12,666
Operating leases(4)	278,181		40,049		70,176		41,573		126,383
Financial instrument obligations(5)	2,015		2,015		—		—		—
Pension and postretirement benefit plan contributions(6)	423,505		60,553		133,694		85,792		143,466
Uncertain tax positions (7)	30,921		—		30,921		—		—
Total contractual obligations	$	9,236,574	$	297,450	$	817,690	$	517,906	$	7,603,528

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

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

(3) Finance lease payments shown above include interest totaling $7.8 million. See Note 6 to the consolidated financial statements.

(4) Operating lease payments shown above include interest totaling $41.4 million. See Note 6 to the consolidated financial statements.

(5) Represents liabilities for natural gas commodity financial instruments that were valued as of September 30, 2020. The ultimate settlement amounts of these remaining liabilities are unknown because they are subject to continuing market risk until the financial instruments are settled.

(6) Represents expected contributions to our defined benefit and postretirement benefit plans, which are discussed in Note 9 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. Commitments for estimated base gas volumes are established under these contracts on a monthly basis at contractually negotiated prices. Commitments for incremental daily purchases are made as necessary during the month in accordance with the terms of individual contracts. Our Mid-Tex Division also maintains a limited number of long-term supply contracts to ensure a reliable source of gas for our customers in its service area which obligate it to purchase specified volumes at market and fixed prices.

33

At September 30, 2020, we were committed to purchase 59.3 Bcf within one year, 57.0 Bcf within two to three years and 0.1 Bcf beyond three years under indexed contracts.

Risk Management Activities

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

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

The following table shows the components of the change in fair value of our financial instruments for the fiscal year ended September 30, 2020 (in thousands):

Fair value of contracts at September 30, 2019	$	(3,990	)
Contracts realized/settled	(2,731		)
Fair value of new contracts	2,570
Other changes in value	82,814
Fair value of contracts at September 30, 2020	78,663
Netting of cash collateral	—
Cash collateral and fair value of contracts at September 30, 2020	$	78,663

The fair value of our financial instruments at September 30, 2020, is presented below by time period and fair value source:

	Fair Value of Contracts at September 30, 2020
	Maturity in years
Source of Fair Value	Less than 1		1-3		4-5		Greater than 5		Total Fair Value
	(In thousands)
Prices actively quoted	$	3,672	$	49,371	$	25,620	$	—	$	78,663
Prices based on models and other valuation methods	—		—		—		—		—
Total Fair Value	$	3,672	$	49,371	$	25,620	$	—	$	78,663

RECENT ACCOUNTING DEVELOPMENTS

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

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

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

We conduct risk management activities in our distribution and pipeline and storage segments. In our distribution segment, we use a combination of physical storage, fixed-price forward contracts and financial instruments, primarily over-the-counter swap and option contracts, in an effort to minimize the impact of natural gas price volatility on our customers during the winter heating season. Our risk management activities and related accounting treatment are described in further detail in Note 14 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.

34

Interest Rate Risk

Our earnings are exposed to changes in short-term interest rates associated with our short-term commercial paper program and other short-term borrowings. We use a sensitivity analysis to estimate our short-term interest rate risk. For purposes of this analysis, we estimate our short-term interest rate risk as the difference between our actual interest expense for the period and estimated interest expense for the period assuming a hypothetical average one percent increase in the interest rates associated with our short-term borrowings. Had interest rates associated with our short-term borrowings increased by an average of one percent, our interest expense would not have materially increased during 2020.

35

ITEM 8. Financial Statements and Supplementary Data.

Index to financial statements and financial statement schedule:

	Page
Report of independent registered public accounting firm	37
Financial statements and supplementary data:
Consolidated balance sheets at September 30, 2020 and 2019	39
Consolidated statements of comprehensive income for the years ended September 30, 2020, 2019 and 2018	40
Consolidated statements of shareholders' equity for the years ended September 30, 2020, 2019 and 2018	41
Consolidated statements of cash flow for the years ended September 30, 2020, 2019 and 2018	42
Notes to consolidated financial statements	43
Selected Quarterly Financial Data (Unaudited)	82
Financial statement schedule for the years ended September 30, 2020, 2019 and 2018
Schedule II. Valuation and Qualifying Accounts	95

All other 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.

36

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, 2020 and 2019, the related consolidated statements of comprehensive income, shareholders‘ equity, and cash flows, for each of the three years in the period ended September 30, 2020, and the related notes and financial statement schedule listed in the Index at Item 8 (collectively referred to as the "consolidated financial statements"). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of September 30, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended September 30, 2020, 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, 2020, 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 13, 2020 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 Commission and the PCAOB.

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

Critical Audit Matter

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

Determination of Capital Costs

Description of the Matter

As more fully described in Note 2 to the financial statements, the Company capitalizes the direct and indirect costs of construction. Once a project is completed, it is placed into service and included in the Company’s rate base. Costs of maintenance and repairs that are not included in the Company’s rate base are charged to expense. For the year ended September 30, 2020, the Company capitalized approximately $1.9 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 consolidated financial statements.

37

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

/s/ Ernst & Young LLP

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

Dallas, Texas

November 13, 2020

38

ATMOS ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

	September 30
	2020			2019
	(In thousands, except share data)
ASSETS
Property, plant and equipment	$	15,539,166		$	13,758,899
Construction in progress	418,055			421,694
	15,957,221			14,180,593
Less accumulated depreciation and amortization	2,601,874			2,392,924
Net property, plant and equipment	13,355,347			11,787,669
Current assets
Cash and cash equivalents	20,808			24,550
Accounts receivable, less allowance for doubtful accounts of $29,949 in 2020 and $15,899 in 2019	230,595			230,571
Gas stored underground	111,950			130,138
Other current assets	107,905			72,772
Total current assets	471,258			458,031
Goodwill	731,257			730,706
Deferred charges and other assets	801,170			391,213
	$	15,359,032		$	13,367,619
CAPITALIZATION AND LIABILITIES
Shareholders’ equity
Common stock, no par value (stated at $0.005 per share); 200,000,000 shares authorized; issued and outstanding: 2020 — 125,882,477 shares; 2019 — 119,338,925 shares	$	629		$	597
Additional paid-in capital	4,377,149			3,712,194
Accumulated other comprehensive loss	(57,589		)	(114,583		)
Retained earnings	2,471,014			2,152,015
Shareholders’ equity	6,791,203			5,750,223
Long-term debt	4,531,779			3,529,452
Total capitalization	11,322,982			9,279,675
Commitments and contingencies (See Note 12)
Current liabilities
Accounts payable and accrued liabilities	235,775			265,024
Other current liabilities	546,461			479,501
Short-term debt	—			464,915
Current maturities of long-term debt	165			—
Total current liabilities	782,401			1,209,440
Deferred income taxes	1,456,569			1,300,015
Regulatory excess deferred taxes (See Note 13)	697,764			705,101
Regulatory cost of removal obligation	457,188			473,172
Deferred credits and other liabilities	642,128			400,216
	$	15,359,032		$	13,367,619

See accompanying notes to consolidated financial statements.

39

ATMOS ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	Year Ended September 30
	2020			2019			2018
	(In thousands, except per share data)
Operating revenues
Distribution segment	$	2,626,993		$	2,745,461		$	3,003,047
Pipeline and storage segment	609,339			567,024			507,713
Intersegment eliminations	(415,195		)	(410,637		)	(395,214		)
Total operating revenues	2,821,137			2,901,848			3,115,546
Purchased gas cost
Distribution segment	1,071,227			1,268,591			1,559,836
Pipeline and storage segment	1,548			(360		)	1,978
Intersegment eliminations	(413,921		)	(409,394		)	(393,966		)
Total purchased gas cost	658,854			858,837			1,167,848
Operation and maintenance expense	629,601			630,308			594,795
Depreciation and amortization expense	429,828			391,456			361,083
Taxes, other than income	278,755			275,189			263,886
Operating income	824,099			746,058			727,934
Other non-operating income (expense)	7,171			7,404			(10,144		)
Interest charges	84,474			103,153			106,646
Income before income taxes	746,796			650,309			611,144
Income tax expense	145,353			138,903			8,080
Net Income	$	601,443		$	511,406		$	603,064
Basic net income per share	$	4.89		$	4.36		$	5.43
Diluted net income per share	$	4.89		$	4.35		$	5.43
Weighted average shares outstanding:
Basic	122,788			117,200			111,012
Diluted	122,872			117,461			111,012
Net income	$	601,443		$	511,406		$	603,064
Other comprehensive income (loss), net of tax
Net unrealized holding gains (losses) on available-for-sale securities, net of tax of $32, $64 and $(146)	106			218			(395		)
Cash flow hedges:
Amortization and unrealized gain (loss) on interest rate agreements, net of tax of $17,198, $(6,782) and $13,017	56,888			(22,944		)	44,936
Total other comprehensive income (loss)	56,994			(22,726		)	44,541
Total comprehensive income	$	658,437		$	488,680		$	647,605

See accompanying notes to consolidated financial statements.

40

ATMOS ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY

	Common stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Total
	Number of Shares	Stated Value
	(In thousands, except share and per share data)
Balance, September 30, 2017	106,104,634	$	531	$	2,536,365	$	(105,254	)	$	1,467,024		$	3,898,666
Net income	—	—		—		—			603,064			603,064
Other comprehensive income	—	—		—		44,541			—			44,541
Cash dividends ($1.94 per share)	—	—		—		—			(214,906		)	(214,906		)
Cumulative effect of accounting change	—	—		—		(22,934		)	22,934			—
Common stock issued:
Public offering	4,558,404	22		395,070		—			—			395,092
Direct stock purchase plan	131,213	1		11,322		—			—			11,323
Retirement savings plan	94,081	—		8,240		—			—			8,240
1998 Long-term incentive plan	385,351	2		3,469		—			—			3,471
Employee stock-based compensation	—	—		20,460		—			—			20,460
Balance, September 30, 2018	111,273,683	556		2,974,926		(83,647		)	1,878,116			4,769,951
Net income	—	—		—		—			511,406			511,406
Other comprehensive loss	—	—		—		(22,726		)	—			(22,726		)
Cash dividends ($2.10 per share)	—	—		—		—			(245,717		)	(245,717		)
Cumulative effect of accounting change	—	—		—		(8,210		)	8,210			—
Common stock issued:
Public offering	7,574,111	38		694,065		—			—			694,103
Direct stock purchase plan	110,063	1		11,070		—			—			11,071
Retirement savings plan	81,456	—		8,252		—			—			8,252
1998 Long-term incentive plan	299,612	2		2,946		—			—			2,948
Employee stock-based compensation	—	—		20,935		—			—			20,935
Balance, September 30, 2019	119,338,925	597		3,712,194		(114,583		)	2,152,015			5,750,223
Net income	—	—		—		—			601,443			601,443
Other comprehensive income	—	—		—		56,994			—			56,994
Cash dividends ($2.30 per share)	—	—		—		—			(282,444		)	(282,444		)
Common stock issued:
Public offering	6,101,916	30		624,272		—			—			624,302
Direct stock purchase plan	107,989	1		11,325		—			—			11,326
Retirement savings plan	78,941	—		8,222		—			—			8,222
1998 Long-term incentive plan	254,706	1		2,748		—			—			2,749
Employee stock-based compensation	—	—		18,388		—			—			18,388
Balance, September 30, 2020	125,882,477	$	629	$	4,377,149	$	(57,589	)	$	2,471,014		$	6,791,203

See accompanying notes to consolidated financial statements.

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ATMOS ENERGY CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

	Year Ended September 30
	2020			2019			2018
	(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	601,443		$	511,406		$	603,064
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	429,828			391,456			361,083
Deferred income taxes	155,322			132,004			158,271
One-time income tax benefit	(20,962		)	—			(158,782		)
Stock-based compensation	9,583			11,121			12,863
Amortization of debt issuance costs	11,543			9,464			7,865
Equity component of AFUDC	(23,493		)	(11,165		)	—
Other	8,411			1,169			5,437
Changes in assets and liabilities:
(Increase) decrease in accounts receivable	7,167			18,724			(29,208		)
Decrease in gas stored underground	18,188			35,594			18,921
(Increase) decrease in other current assets	(35,878		)	(26,590		)	60,424
Increase in deferred charges and other assets	(31,935		)	(58,403		)	(10,049		)
Increase (decrease) in accounts payable and accrued liabilities	7,359			9,908			(11,857		)
Increase (decrease) in other current liabilities	(129,543		)	(103,895		)	74,707
Increase in deferred credits and other liabilities	30,966			47,976			31,923
Net cash provided by operating activities	1,037,999			968,769			1,124,662
CASH FLOWS USED IN INVESTING ACTIVITIES
Capital expenditures	(1,935,676		)	(1,693,477		)	(1,467,591		)
Proceeds from the sale of discontinued operations	—			4,000			3,000
Purchases of debt and equity securities	(50,517		)	(29,153		)	(46,401		)
Proceeds from sale of debt and equity securities	32,339			6,070			22,360
Maturities of debt securities	18,669			20,299			15,716
Other, net	9,667			8,601			9,350
Net cash used in investing activities	(1,925,518		)	(1,683,660		)	(1,463,566		)
CASH FLOWS FROM FINANCING ACTIVITIES
Net increase (decrease) in short-term debt	(464,915		)	(110,865		)	128,035
Proceeds from issuance of long-term debt, net of premium/discount	999,450			1,045,221			—
Net proceeds from equity offering	624,302			694,103			395,092
Issuance of common stock through stock purchase and employee retirement plans	19,548			19,323			19,563
Settlement of interest rate swaps	(4,426		)	(90,141		)	—
Repayment of long-term debt	—			(575,000		)	—
Cash dividends paid	(282,444		)	(245,717		)	(214,906		)
Debt issuance costs	(7,738		)	(11,254		)	—
Other	—			—			(1,518		)
Net cash provided by financing activities	883,777			725,670			326,266
Net increase (decrease) in cash and cash equivalents	(3,742		)	10,779			(12,638		)
Cash and cash equivalents at beginning of year	24,550			13,771			26,409
Cash and cash equivalents at end of year	$	20,808		$	24,550		$	13,771

See accompanying notes to consolidated financial statements.

42

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1.    Nature of Business

Atmos Energy Corporation (Atmos Energy or the “Company”) and its subsidiaries are engaged in the regulated natural gas distribution and pipeline and storage businesses. Through our distribution business, we deliver natural gas through sales and transportation arrangements to 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 metropolitan area
Atmos Energy Mississippi Division	Mississippi
Atmos Energy West Texas Division	West Texas

 

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

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

Our pipeline and storage business, which is also subject to federal and state regulation, consists of the pipeline and storage operations of our Atmos Pipeline–Texas (APT) Division and our natural gas transmission business in Louisiana. The APT division provides transportation and storage services to our Mid-Tex Division, other third-party local distribution companies, industrial and electric generation customers, as well as marketers and producers. As part of its pipeline operations, APT manages five underground storage facilities in Texas. We also provide ancillary services customary to the pipeline industry including parking arrangements, lending and sales of inventory on hand. Our natural gas transmission operations in Louisiana are comprised of a 21-mile pipeline located in the New Orleans, Louisiana area that is primarily used to aggregate gas supply for our distribution division in Louisiana under a long-term contract and on a more limited basis, to third parties.

2.    Summary of Significant Accounting Policies

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

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

Regulation — Our distribution and pipeline and storage operations are subject to regulation with respect to rates, service, maintenance of accounting records and various other matters by the respective regulatory authorities in the states in which we operate. Our accounting policies recognize the financial effects of the ratemaking and accounting practices and policies of the various regulatory commissions. Accounting principles generally accepted in the United States require cost-based, rate-regulated entities that meet certain criteria to reflect the authorized recovery of costs due to regulatory decisions in their financial statements. As a result, certain costs are permitted to be capitalized rather than expensed because they can be recovered through rates. We record certain costs as regulatory assets when future recovery through customer rates is considered probable. Regulatory liabilities are recorded when it is probable that revenues will be reduced for amounts that will be credited to customers through the ratemaking process. The amounts to be recovered or recognized are based upon historical experience and our understanding of the regulations. Further, regulation may impact the period in which revenues or expenses are recognized.

Substantially all of our regulatory assets are recorded as a component of 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

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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, 2020 and 2019 included the following:

	September 30
	2020		2019
	(In thousands)
Regulatory assets:
Pension and postretirement benefit costs	$	149,089	$	86,089
Infrastructure mechanisms(1)	183,943		131,894
Deferred gas costs	40,593		23,766
Recoverable loss on reacquired debt	4,894		6,551
Deferred pipeline record collection costs	29,839		26,418
Other	6,283		9,829
	$	414,641	$	284,547
Regulatory liabilities:
Regulatory excess deferred taxes(2)	$	718,651	$	726,307
Regulatory cost of service reserve	1,716		5,238
Regulatory cost of removal obligation	531,096		528,893
Deferred gas costs	19,985		14,112
Asset retirement obligation	20,348		17,054
APT annual adjustment mechanism	57,379		78,402
Other	17,838		16,120
	$	1,367,013	$	1,386,126

(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) Due to the passage of the Kansas House Bill 2585, on June 1, 2020, we remeasured our deferred tax liability and updated our state deferred tax rate resulting in a $12.1 million regulatory liability as of September 30, 2020. The remaining amount reflects the remeasurement of the net deferred tax liability included in our rate base as a result of the Tax Cuts and Jobs Act of 2017 (the TCJA). Of this amount, $20.9 million as of September 30, 2020 and $21.2 million as of September 30, 2019 is recorded in other current liabilities. See Note 13 for further information.

As of September 30, 2020, we received regulatory orders in most states to defer into a regulatory asset all expenses, beyond the normal course of business, related to Coronavirus Disease 2019 (COVID-19), including bad debt expense. As of September 30, 2020, no amounts have been recorded as regulatory assets or liabilities for expenses related to COVID-19.

Revenue recognition

Distribution Revenues

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

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

Pipeline and Storage Revenues

Pipeline and storage revenues primarily represent the transportation and storage of natural gas on our APT system and the transmission of natural gas through our 21-mile pipeline in Louisiana. APT provides transportation and storage services to our Mid-Tex Division, other third party local distribution companies and certain industrial customers under tariff rates approved by

44

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Alternative Revenue Program Revenues

In our distribution segment, we have weather-normalization adjustment mechanisms that serve to minimize the effects of weather on our residential and commercial revenues. Additionally, APT has a regulatory mechanism that requires that we share with its tariffed customers 75% of the difference between the total non-tariffed revenues earned during a test period and a revenue benchmark of $69.4 million that was established in its most recent rate case. Differences between actual revenues and revenues calculated under these mechanisms adjust the amount billed to customers. These mechanisms are considered to be alternative revenue programs under accounting standards generally accepted in the United States as they are deemed to be contracts between us and our regulator. Accordingly, revenue under these mechanisms are excluded from revenue from contracts with customers.

Purchased gas costs — Rates established by regulatory authorities are adjusted for increases and decreases in our purchased gas costs through purchased gas cost adjustment mechanisms. 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.

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 doubtful accounts — Accounts receivable arise from natural gas sales to residential, commercial, industrial, public authority and other customers. We establish an allowance for doubtful accounts to reduce the net receivable balance to the amount we reasonably expect to collect based on our collection experience or where we are aware of a specific customer’s inability or reluctance to pay. However, if circumstances change, our estimate of the recoverability of accounts receivable could be affected. Circumstances which could affect our estimates include, but are not limited to, customer credit issues, the level of natural gas prices, customer deposits and general economic conditions. Accounts are written off once they are deemed to be uncollectible.

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

Property, plant and equipment — Regulated property, plant and equipment is stated at original cost, net of contributions in aid of construction. The cost of additions includes direct construction costs, payroll related costs (taxes, pensions and other benefits), administrative and general costs and an allowance for funds used during construction. The allowance for funds used during construction (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.

		2020		2019		2018
Component of AFUDC	Statement of Comprehensive Income Location	(In thousands)
Debt	Interest charges	$	8,436	$	7,643	$	6,810
Equity	Other non-operating income (expense)	23,493		11,165		—
		$	31,929	$	18,808	$	6,810

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

45

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

large projects are accumulated in construction in progress until the project is completed. When the project is completed, tested and placed in service, the balance is transferred to the regulated plant in service account included in the rate base and depreciation begins.

Regulated property, plant and equipment is depreciated at various rates on a straight-line basis. These rates are approved by our regulatory commissions and are comprised of two components: one based on average service life and one based on cost of removal. Accordingly, we recognize our cost of removal expense as a component of depreciation expense. The related cost of removal accrual is reflected as a regulatory liability on the consolidated balance sheet. At the time property, plant and equipment is retired, removal expenses less salvage, are charged to the regulatory cost of removal accrual. The composite depreciation rate was 3.0 percent, 3.1 percent and 3.2 percent for the fiscal years ended September 30, 2020, 2019 and 2018.

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. Accretion of the asset retirement obligation due to the passage of time is recorded as an operating expense.

As of September 30, 2020 and 2019, we had asset retirement obligations of $20.3 million and $17.1 million. Additionally, we had $14.4 million and $11.3 million of asset retirement costs recorded as a component of property, plant and equipment that will be depreciated over the remaining life of the underlying associated assets.

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 2020, we completed our annual goodwill impairment assessment using a qualitative assessment, as permitted under U.S. GAAP. 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 2020 analysis, if the qualitative 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 assets and lease liabilities within the consolidated balance sheet. See Note 6 for further discussion regarding the accounting polices for these leases.

Marketable securities — As of September 30, 2020, we hold marketable securities classified as either equity or debt securities. Beginning on October 1, 2018, 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). During fiscal 2018 and under the previous accounting guidance, all our debt and equity securities were considered available for sale securities.

We regularly evaluate the performance of our available for sale debt securities on an investment by investment basis for impairment, taking into consideration the securities’ purpose, volatility and current returns. If a determination is made that a decline in fair value is other than temporary, the related investment is written down to its estimated fair value.

46

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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 14.

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

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

Financial Instruments Associated with Commodity Price Risk

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

Financial Instruments Associated with Interest Rate Risk

In connection with the planned issuance of long-term debt, we may use financial instruments to manage interest rate risk. We currently manage this risk through the use of forward starting interest rate swaps to fix the Treasury yield component of the interest cost associated with anticipated financings. We designate these financial instruments as cash flow hedges at the time the agreements are executed. Unrealized gains and losses associated with the instruments are recorded as a component of accumulated other comprehensive income (loss). When the instruments settle, the realized gain or loss is recorded as a component of accumulated other comprehensive income (loss) and recognized as a component of interest charges over the life of the related financing arrangement. As of September 30, 2020 and 2019, no cash was required to be held in margin accounts.

Fair Value Measurements — We report certain assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We primarily use quoted market prices and other observable market pricing information in valuing our financial assets and liabilities and minimize the use of unobservable pricing inputs in our measurements.

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

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

Authoritative accounting literature establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority given to unobservable inputs (Level 3). The levels of the hierarchy are described below:

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

47

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

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

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

Pension and other postretirement plans — Pension and other postretirement plan costs and liabilities are determined on an actuarial basis and are affected by numerous assumptions and estimates including the market value of plan assets, estimates of the expected return on plan assets, assumed discount rates and current demographic and actuarial mortality data. Our measurement date is September 30. The assumed discount rate and the expected return are the assumptions that generally have the most significant impact on our pension costs and liabilities. The assumed discount rate, the assumed health care cost trend rate and assumed rates of retirement generally have the most significant impact on our postretirement plan costs and liabilities. For the valuation performed as of September 30, 2020, decreases in the discount rate resulted in actuarial losses that increased our plan obligations.

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

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

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

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

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

On October 1, 2018 we adopted new accounting guidance, which required we present only the current service cost component of the net benefit cost within operations and maintenance expense in the consolidated statements of comprehensive income. The remaining components of net benefit cost are recorded in other non-operating income (expense) in our consolidated statements of comprehensive income. The change in presentation of these costs was implemented on a retrospective basis as required by the guidance. In lieu of determining how each component of the net periodic benefit cost was actually reflected in the fiscal 2018 statement of comprehensive income, we elected to utilize a practical expedient that permits the use of the amounts disclosed for these costs in our pension and post-retirement benefit plans footnote as the basis to retroactively apply this standard.

48

ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

In addition, only the service cost component of net benefit cost is eligible for capitalization and we continue to capitalize these costs into property, plant and equipment. Additionally, we defer into a regulatory asset the portion of non-service components of net periodic benefit cost that are capitalizable for regulatory purposes.

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

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

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

Contingencies — In the normal course of business, we are confronted with issues or events that may result in a contingent liability. These generally relate to lawsuits, claims made by third parties or the action of various regulatory agencies. For such matters, we record liabilities when they are considered probable and estimable, based on currently available facts and our estimates of the ultimate outcome or resolution of the liability in the future. Actual results may differ from estimates, depending on actual outcomes or changes in the facts or expectations surrounding each potential exposure.

Subsequent events — Except as noted in Note 7 regarding the public offering of senior notes, no events occurred subsequent to the balance sheet date that would require recognition or disclosure in the financial statements.

Recent accounting pronouncements

Accounting pronouncements adopted in fiscal 2020

In February 2016, the Financial Accounting Standards Board (FASB) issued a comprehensive new leasing standard that requires lessees to recognize a lease liability and a right-of-use (ROU) asset for all leases, including operating leases on its balance sheet. The new standard was effective for us beginning on October 1, 2019. See Note 6 to the consolidated financial statements for further details regarding our adoption of the new lease standard and the related disclosures.

Accounting pronouncements that will be effective after fiscal 2020

In March 2020, the 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 relationships 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. We are currently evaluating if we will apply the optional guidance as we assess the impact of the cessation of LIBOR on our current contracts and hedging relationships and the potential impact on our financial position, results of operations and cash flows.

In December 2019, the FASB issued new guidance related to accounting for income taxes which removes certain exceptions for recognizing deferred taxes for investments, performing intraperiod allocations and calculating income taxes in interim periods. The new standard also adds guidance to reduce complexity in certain areas, such as recognizing deferred taxes for tax goodwill and allocating taxes to members of a consolidated group. The new standard will be effective for us beginning on October 1, 2021; early adoption is permitted. We do not believe the new standard will have a material impact on our financial position, results of operations and cash flows. 

In June 2016, the FASB issued new guidance which will require 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, entities will estimate credit losses over the entire contractual term of the instrument from the date of initial recognition of that instrument. In contrast, current U.S. GAAP is based on an incurred loss model that delays recognition of credit losses until it is probable the loss has been incurred. The new guidance also introduces a new impairment recognition model for available-for-sale debt

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securities that will require credit losses for available-for-sale debt securities to be recorded through an allowance account. The new standard was effective for us beginning on October 1, 2020. We do not anticipate the adoption of this standard will have a material impact to our financial position, results of operations and cash flows. 

3.    Segment Information

As of September 30, 2020, we manage and review our consolidated operations through the following two reportable segments:

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

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

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

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

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

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

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	Year Ended September 30, 2019
	Distribution		Pipeline and Storage			Eliminations			Consolidated
	(In thousands)
Operating revenues from external parties	$	2,742,824	$	159,024		$	—		$	2,901,848
Intersegment revenues	2,637		408,000			(410,637		)	—
Total operating revenues	2,745,461		567,024			(410,637		)	2,901,848
Purchased gas cost	1,268,591		(360		)	(409,394		)	858,837
Operation and maintenance expense	480,222		151,329			(1,243		)	630,308
Depreciation and amortization expense	283,697		107,759			—			391,456
Taxes, other than income	242,179		33,010			—			275,189
Operating income	470,772		275,286			—			746,058
Other non-operating income	6,241		1,163			—			7,404
Interest charges	60,031		43,122			—			103,153
Income before income taxes	416,982		233,327			—			650,309
Income tax expense	88,168		50,735			—			138,903
Net income	$	328,814	$	182,592		$	—		$	511,406
Capital expenditures	$	1,274,613	$	418,864		$	—		$	1,693,477

	Year Ended September 30, 2018
	Distribution			Pipeline and Storage			Eliminations			Consolidated
	(In thousands)
Operating revenues from external parties	$	3,000,404		$	115,142		$	—		$	3,115,546
Intersegment revenues	2,643			392,571			(395,214		)	—
Total operating revenues	3,003,047			507,713			(395,214		)	3,115,546
Purchased gas cost	1,559,836			1,978			(393,966		)	1,167,848
Operation and maintenance expense	461,048			134,995			(1,248		)	594,795
Depreciation and amortization expense	264,930			96,153			—			361,083
Taxes, other than income	231,566			32,320			—			263,886
Operating income	485,667			242,267			—			727,934
Other non-operating expense	(6,649		)	(3,495		)	—			(10,144		)
Interest charges	65,850			40,796			—			106,646
Income before income taxes	413,168			197,976			—			611,144
Income tax expense (benefit)	(29,798		)	37,878			—			8,080
Net income	$	442,966		$	160,098		$	—		$	603,064
Capital expenditures	$	1,025,800		$	441,791		$	—		$	1,467,591

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

	2020		2019		2018
	(In thousands)
Distribution revenues:
Gas sales revenues:
Residential	$	1,717,070	$	1,733,548	$	1,916,101
Commercial	654,963		711,284		797,073
Industrial	89,641		118,046		131,267
Public authority and other	42,007		42,613		47,714
Total gas sales revenues	2,503,681		2,605,491		2,892,155
Transportation revenues	97,441		95,629		99,250
Other gas revenues	23,129		41,704		8,999
Total distribution revenues	2,624,251		2,742,824		3,000,404
Pipeline and storage revenues	196,886		159,024		115,142
Total operating revenues	$	2,821,137	$	2,901,848	$	3,115,546

Balance sheet information at September 30, 2020 and 2019 by segment is presented in the following tables.

	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

	September 30, 2019
	Distribution		Pipeline and Storage		Eliminations			Consolidated
	(In thousands)
Property, plant and equipment, net	$	8,737,590	$	3,050,079	$	—		$	11,787,669
Total assets	$	12,579,741	$	3,279,323	$	(2,491,445	)	$	13,367,619

 

4.    Earnings Per Share

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

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

	2020		2019		2018
	(In thousands, except per share data)
Basic Earnings Per Share
Net Income	$	601,443	$	511,406	$	603,064
Less: Income allocated to participating securities	444		416		580
Net Income available to common shareholders	$	600,999	$	510,990	$	602,484
Basic weighted average shares outstanding	122,788		117,200		111,012
Net Income per share — Basic	$	4.89	$	4.36	$	5.43
Diluted Earnings Per Share
Net Income available to common shareholders	$	600,999	$	510,990	$	602,484
Effect of dilutive shares	—		—		—
Net Income available to common shareholders	$	600,999	$	510,990	$	602,484
Basic weighted average shares outstanding	122,788		117,200		111,012
Dilutive shares	84		261		—
Diluted weighted average shares outstanding	122,872		117,461		111,012
Net Income per share — Diluted	$	4.89	$	4.35	$	5.43

5.    Revenue

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

	Year Ended September 30, 2020					Year Ended September 30, 2019
	Distribution		Pipeline and Storage			Distribution			Pipeline and Storage
	(In thousands)
Gas sales revenues:
Residential	$	1,704,444	$	—		$	1,755,229		$	—
Commercial	650,396		—			716,757			—
Industrial	89,467		—			118,060			—
Public authority and other	41,339		—			42,796			—
Total gas sales revenues	2,485,646		—			2,632,842			—
Transportation revenues	99,435		636,819			97,495			623,808
Miscellaneous revenues	19,085		9,754			26,050			8,060
Revenues from contracts with customers	2,604,166		646,573			2,756,387			631,868
Alternative revenue program revenues(1)	20,856		(37,234		)	(12,958		)	(64,844		)
Other revenues	1,971		—			2,032			—
Total operating revenues	$	2,626,993	$	609,339		$	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.

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 standard.

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The new guidance included several practical expedients to facilitate the implementation of the new standard. The following summarizes the practical expedients we used to implement the standard.

•We elected to bundle our lease and non-lease components as a single component for all asset classes.

•We elected not to perform the following:

◦Evaluate existing or expired land easements prior to October 1, 2019 to determine if they are leases.

◦Include short-term leases in the calculation of our lease liability.

◦Evaluate existing or expired contracts to determine if they are leases.

◦Assess lease classification for existing or expired leases.

◦Review initial direct costs for existing leases.

◦Use hindsight in order to determine the lease term or impairment of our ROU assets.

Upon adoption of this new guidance, we recorded ROU assets and lease liabilities of $231.3 million. Additionally, we reclassified a net $6.5 million of accrued and prepaid lease costs to the ROU asset and $2.5 million related to an existing finance lease from deferred credits and other liabilities to long-term debt.

Implementation of the new lease accounting guidance had no material impact on our consolidated statements of comprehensive income or our consolidated statements of cash flows. Additionally, we did not record a cumulative-effect adjustment to retained earnings on the opening balance sheet.

New Lease Accounting Policy

We determine if an arrangement is a lease at the inception of the agreement based on the terms and conditions in the contract. A contract contains a lease if there is an identified asset and we have the right to control the asset. We are the lessee for substantially all of our leasing 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.

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

	September 30, 2020
Weighted average remaining lease term (years)
Finance leases	19.1
Operating leases	10.6

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

The following table represents our weighted average discount rate:

	September 30, 2020
Weighted average discount rate
Finance leases	8.0	%
Operating leases	2.9	%

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.

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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.

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

	September 30, 2020
	(In thousands)
Finance lease cost	$	622
Operating lease cost	40,887
Total lease cost	$	41,509

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

	Balance Sheet Classification	September 30, 2020
		(In thousands)
Assets
Finance leases	Net Property, Plant and Equipment	$	8,480
Operating leases	Deferred charges and other assets	227,146
Total right-of-use assets		$	235,626
Liabilities
Current
Finance leases	Current maturities of long-term debt	$	165
Operating leases	Other current liabilities	35,716
Noncurrent
Finance leases	Long-term debt	8,466
Operating leases	Deferred credits and other liabilities	201,071
Total lease liabilities		$	245,418

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

	September 30, 2020
	(In thousands)
Cash paid amounts included in the measurement of lease liabilities
Operating cash flows used for operating leases	$	37,758
Right-of-use assets obtained in exchange for lease obligations
Finance leases	$	6,083
Operating leases	$	34,169

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Maturities of our lease liabilities as of September 30, 2020 were as follows:

	Total		Finance Leases		Operating Leases
	(In thousands)
2021	$	40,790	$	741	$	40,049
2022	38,423		751		37,672
2023	33,266		762		32,504
2024	25,464		773		24,691
2025	17,666		784		16,882
Thereafter	139,049		12,666		126,383
Total lease payments	294,658		16,477		278,181
Less: Imputed interest	49,240		7,846		41,394
Total	$	245,418	$	8,631	$	236,787
Reported as of September 30, 2020
Short-term lease liabilities	$	35,881	$	165	$	35,716
Long-term lease liabilities	209,537		8,466		201,071
Total lease liabilities	$	245,418	$	8,631	$	236,787

Disclosures Related to Prior Periods

The future minimum lease payments as of September 30, 2019 were as follows:

	Operating Leases(1)		Capital Lease
	(In thousands)
2020	$	21,017	$	243
2021	20,416		248
2022	19,370		253
2023	18,071		258
2024	15,718		263
Thereafter	105,544		4,343
Total minimum lease payments	$	200,136	5,608
Less amount representing interest			3,018
Present value of net minimum lease payments			$	2,590

(1) Future minimum lease payments do not include amounts for fleet leases and other de minimis items that can be renewed beyond the initial lease term. The Company anticipates renewing the leases beyond the initial term, but the anticipated payments associated with the renewals do not meet the definition of expected minimum lease payments and therefore are not included above. Expected payments are $17.6 million in 2020, $18.0 million in 2021, $11.8 million in 2022, $8.5 million in 2023, $5.4 million in 2024 and $2.7 million thereafter.

Consolidated lease and rental expense amounted to $40.4 million and $33.8 million for fiscal 2019 and 2018.

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7.    Debt

Long-term debt

Long-term debt at September 30, 2020 and 2019 consisted of the following:

	2020		2019
	(In thousands)
Unsecured 3.00% Senior Notes, due 2027	$	500,000	$	500,000
Unsecured 2.625% Senior Notes, due 2029	300,000		—
Unsecured 5.95% Senior Notes, due 2034	200,000		200,000
Unsecured 5.50% Senior Notes, due 2041	400,000		400,000
Unsecured 4.15% Senior Notes, due 2043	500,000		500,000
Unsecured 4.125% Senior Notes, due 2044	750,000		750,000
Unsecured 4.30% Senior Notes, due 2048	600,000		600,000
Unsecured 4.125% Senior Notes, due 2049	450,000		450,000
Unsecured 3.375% Senior Notes, due 2049	500,000		—
Floating-rate term loan, due 2022	200,000		—
Medium term Series A notes, 1995-1, 6.67%, due 2025	10,000		10,000
Unsecured 6.75% Debentures, due 2028	150,000		150,000
Finance lease obligations (see Note 6)	8,631		—
Total long-term debt	4,568,631		3,560,000
Less:
Net original issue (premium) / discount on unsecured senior notes and debentures	583		193
Debt issuance cost	36,104		30,355
Current maturities	165		—
	$	4,531,779	$	3,529,452

    

Maturities of long-term debt, excluding our finance lease obligations, at September 30, 2020 were as follows (in thousands):

2021	$	—
2022	200,000
2023	—
2024	—
2025	10,000
Thereafter	4,350,000
	$	4,560,000

On October 1, 2020, we completed a public offering of $600 million of 1.50% senior notes due 2031. The net proceeds from the offering, after the underwriting discount and estimated offering expenses, of $592.5 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. The effective interest rate on these notes is 1.71%, after giving effect to the offering costs.

On April 9, 2020, we entered into a two year, $200 million term loan agreement that bears interest at a rate of LIBOR plus 1.25 percent. The term loan was used to pay down borrowings pursuant to our commercial paper program.

On October 2, 2019, 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. We received net proceeds from the offering, after the underwriting discount and offering expenses, of $791.7 million, that were used for general corporate purposes, including the repayment of working capital

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borrowings pursuant to our commercial paper program. The effective interest rate on these notes was 2.72% and 3.42%, after giving effect to the offering costs.

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-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. Changes in the price of natural gas and the amount of natural gas we need to supply our customers’ needs could significantly affect our borrowing requirements. Our short-term borrowings typically reach their highest levels in the winter months.

As of September 30, 2020, our short-term borrowing requirements were satisfied through a combination of a $1.5 billion commercial paper program and four committed revolving credit facilities with third-party lenders that provide $2.2 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 expires on September 25, 2023. The 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 1.25 percent, 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, 2020, there were no amounts outstanding under our commercial paper program. At September 30, 2019, a total of $464.9 million was outstanding with weighted average interest rates of 2.24% and weighted average maturities of less than one month.

Additionally, we had a $25 million 364-day unsecured facility that was renewed on April 1, 2020 and increased to $50 million, which is used to provide working capital funding. There were no borrowings outstanding under this facility as of September 30, 2020.

Finally, we had a $10 million 364-day unsecured revolving credit facility, which was replaced on April 30, 2020, with a new $50 million 364-day unsecured revolving credit facility, which is used to issue letters of credit and to provide working capital funding. At September 30, 2020, there were no borrowings outstanding under the new facility; however, outstanding letters of credit reduced the total amount available to us under our $50 million unsecured revolving facility to $44.4 million.

On April 23, 2020, we executed a new $600 million 364-day unsecured revolving credit facility to provide additional working capital funding. The 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 1.25 percent, based on the Company's credit ratings. At September 30, 2020, there were no borrowings outstanding under this facility.

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, 2020, our total-debt-to-total-capitalization ratio, as defined, was 42 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, 2020. 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 February 11, 2020, we filed a shelf registration statement with the Securities and Exchange Commission (SEC) that allows us to issue up to $4.0 billion in common stock and/or debt securities, which expires February 11, 2023. This shelf registration statement replaced our previous shelf registration statement which was filed on November 13, 2018 (2018 Registration Statement). At September 30, 2020, approximately $3.0 billion of securities remained available for issuance under

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the shelf registration statement. Following the completion of the $600 million senior unsecured note offering on October 1, 2020 (see Note 7), approximately $2.4 billion of securities remained available for issuance under the shelf registration statement.

On February 12, 2020, we filed a prospectus supplement under the shelf registration statement relating to an at-the-market (ATM) equity sales program (February 2020 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 November 19, 2018 (November 2018 ATM), which was exhausted during the second quarter of fiscal 2020.

During the year ended September 30, 2020, we executed forward sales under the February 2020 ATM and the November 2018 ATM equity sales programs with various forward sellers who borrowed and sold 4,808,051 shares of our common stock for $523.2 million. Additionally, during the year ended September 30, 2020, we settled forward sale agreements with respect to 5,616,727 shares that had been borrowed and sold by various forward sellers under the November 2018 ATM and the February 2020 ATM for net proceeds of $581.5 million. As of September 30, 2020, the February 2020 ATM program had approximately $552 million of equity available for issuance.

On November 30, 2018, we filed a prospectus supplement under the registration statement relating to an underwriting agreement to sell 5,390,836 shares of our common stock for $500 million. After expenses, net proceeds from the offering were $494.1 million. Concurrently, we entered into separate forward sale agreements with two forward sellers who borrowed and sold 2,668,464 shares of our common stock for $247.5 million. During the year ended September 30, 2019, we settled forward sale agreements with respect to 2,183,275 of the shares that had been borrowed and sold for net proceeds of $200.0 million. During the year ended September 30, 2020, we settled the remaining 485,189 shares for net proceeds of $44.4 million.

During the year ended September 30, 2019, we executed forward sales under the November 2018 ATM with various forward sellers who borrowed and sold 4,144,671 shares of our common stock at an aggregate price of $425.0 million.

If we had settled all shares that remain available under our outstanding forward sale agreements as of September 30, 2020, we would have received proceeds of $345.2 million, based on a net price of $103.48 per share. Additional details are presented below.

Maturity	Shares Available	Net Proceeds Available (In Thousands)		Forward Price
March 31, 2021	1,281,578	$	134,660	$	105.07
June 30, 2021	1,394,423	142,388		$	102.11
September 30, 2021	659,994	68,158		$	103.27
Total	3,335,995	$	345,206

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).

	Available- for-Sale Securities			Interest Rate Agreement Cash Flow Hedges			Total
	(In thousands)
September 30, 2019	$	132		$	(114,715	)	$	(114,583	)
Other comprehensive income before reclassifications	108			53,241			53,349
Amounts reclassified from accumulated other comprehensive income	(2		)	3,647			3,645
Net current-period other comprehensive income	106			56,888			56,994
September 30, 2020	$	238		$	(57,827	)	$	(57,589	)

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	Available- for-Sale Securities			Interest Rate Agreement Cash Flow Hedges			Total
	(In thousands)
September 30, 2018	$	8,124		$	(91,771	)	$	(83,647	)
Other comprehensive income (loss) before reclassifications	219			(25,966		)	(25,747		)
Amounts reclassified from accumulated other comprehensive income	(1		)	3,022			3,021
Net current-period other comprehensive income (loss)	218			(22,944		)	(22,726		)
Cumulative effect of accounting change	(8,210		)	—			(8,210		)
September 30, 2019	$	132		$	(114,715	)	$	(114,583	)

9.    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 recoverable through our rates over a period of up to 15 years. A portion of these costs is capitalized into our rate base or deferred as a regulatory asset or liability. The remaining costs are recorded as a component of operation and maintenance expense or other non-operating expense. Additionally, the amounts that have not yet been recognized in net periodic pension cost that have been recorded as regulatory assets or liabilities are as follows:

	Defined Benefit Plan			Supplemental Executive Retirement Plans		Postretirement Plans			Total
	(In thousands)
September 30, 2020
Unrecognized prior service (credit) cost	$	(584	)	$	—	$	951		$	367
Unrecognized actuarial loss	78,082			51,045		9,110			138,237
	$	77,498		$	51,045	$	10,061		$	138,604
September 30, 2019
Unrecognized prior service (credit) cost	$	(815	)	$	—	$	1,125		$	310
Unrecognized actuarial (gain) loss	67,191			56,784		(43,782		)	80,193
	$	66,376		$	56,784	$	(42,657	)	$	80,503

Defined Benefit Plans

Employee Pension Plan

As of September 30, 2020, we maintained one cash balance defined benefit plan, the Atmos Energy Corporation 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.

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During fiscal 2020, we did not make a contribution to the Plan. During fiscal 2019 we contributed $8.5 million in cash to the Plan to achieve a desired level of funding while maximizing the tax deductibility of this payment. Based upon market conditions at September 30, 2020, the current funded position of the Plan and the funding requirements under the PPA, we do not anticipate a minimum required contribution for fiscal 2021. However, we may consider whether a voluntary contribution is prudent to maintain certain funding levels.

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

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

The following table presents asset allocation information for the Master Trust as of September 30, 2020 and 2019.

	Targeted Allocation  Range	Actual Allocation September 30
Security Class		2020	2019
Domestic equities	35%-55%	45.3%	40.6%
International equities	10%-20%	15.6%	14.5%
Fixed income	5%-30%	17.0%	18.8%
Company stock	0%-15%	13.0%	15.4%
Other assets	0%-20%	9.1%	10.7%

At September 30, 2020 and 2019, the Plan held 716,700 shares of our common stock which represented 13.0 percent and 15.4 percent of total Plan assets. These shares generated dividend income for the Plan of approximately $1.6 million and $1.5 million during fiscal 2020 and 2019.

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 development of our assumptions is fully described in our significant accounting policies in Note 2. The actuarial assumptions used to determine the pension liability for the Plan was determined as of September 30, 2020 and 2019 and the actuarial assumptions used to determine the net periodic pension cost for the Plan was determined as of September 30, 2019, 2018 and 2017. On October 21, 2020, 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, 2020, we updated our assumed mortality rates to incorporate the updated mortality table.

Additional assumptions are presented in the following table:

	Pension Liability				Pension Cost
	2020		2019		2020		2019		2018
Discount rate	2.80	%	3.29	%	3.29	%	4.38	%	3.89	%
Rate of compensation increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%
Expected return on plan assets	6.25	%	6.50	%	6.50	%	6.75	%	6.75	%
Interest crediting rate	4.69	%	4.69	%	4.69	%	4.69	%	4.69	%

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The following table presents the Plan’s accumulated benefit obligation, projected benefit obligation and funded status as of September 30, 2020 and 2019:

	2020			2019
	(In thousands)
Accumulated benefit obligation	$	565,755		$	541,287
Change in projected benefit obligation:
Benefit obligation at beginning of year	$	577,270		$	504,719
Service cost	17,551			15,311
Interest cost	19,028			22,071
Actuarial (gain) loss	22,898			71,139
Benefits paid	(32,526		)	(35,970		)
Benefit obligation at end of year	604,221			577,270
Change in plan assets:
Fair value of plan assets at beginning of year	530,109			531,691
Actual return on plan assets	31,298			25,888
Employer contributions	—			8,500
Benefits paid	(32,526		)	(35,970		)
Fair value of plan assets at end of year	528,881			530,109
Reconciliation:
Funded status	(75,340		)	(47,161		)
Unrecognized prior service cost	—			—
Unrecognized net loss	—			—
Net amount recognized	$	(75,340	)	$	(47,161	)

Net periodic pension cost for the Plan for fiscal 2020, 2019 and 2018 is presented in the following table.

	Fiscal Year Ended September 30
	2020			2019			2018
	(In thousands)
Components of net periodic pension cost:
Service cost	$	17,551		$	15,311		$	17,264
Interest cost(1)	19,028			22,071			20,803
Expected return on assets(1)	(28,316		)	(28,451		)	(27,666		)
Amortization of prior service credit(1)	(231		)	(232		)	(231		)
Recognized actuarial loss(1)	9,025			4,201			9,114
Net periodic pension cost	$	17,057		$	12,900		$	19,284

(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.

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The following tables set forth by level, within the fair value hierarchy, the Plan's assets at fair value as of September 30, 2020 and 2019. 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. 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 $0.7 million and $1.3 million at September 30, 2020 and 2019, which materially approximates fair value due to the short-term nature of these assets.

	Assets at Fair Value as of September 30, 2020
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Common stocks	$	211,244	$	—	$	—	$	211,244
Money market funds	—		6,096		—		6,096
Registered investment companies	29,762		—		—		29,762
Government securities:
Mortgage-backed securities	—		15,230		—		15,230
U.S. treasuries	21,755		36		—		21,791
Corporate bonds	—		52,648		—		52,648
Total investments measured at fair value	$	262,761	$	74,010	$	—	336,771
Investments measured at net asset value:
Common/collective trusts (1)							122,207
Limited partnerships (1)							69,176
Total investments							$	528,154

	Assets at Fair Value as of September 30, 2019
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Common stocks	$	212,785	$	—	$	—	$	212,785
Money market funds	—		16,419		—		16,419
Registered investment companies	26,326		—		—		26,326
Government securities:
Mortgage-backed securities	—		19,986		—		19,986
U.S. treasuries	22,930		885		—		23,815
Corporate bonds	—		55,774		—		55,774
Total investments measured at fair value	$	262,041	$	93,064	$	—	355,105
Investments measured at net asset value:
Common/collective trusts (1)							108,975
Limited partnerships (1)							64,718
Total investments							$	528,798

(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 benefits to our officers, division presidents and certain other employees of the Company.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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 underlying qualified defined benefit plan are an offset to the benefits under the SERP.

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

Due to the retirement of an executive of the company during fiscal 2020, we recognized a one-time settlement charge of $9.2 million and paid a $22.7 million lump sum in relation to the retirement.

Similar to our employee pension plans, we review the estimates and assumptions underlying our supplemental 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, 2020 and 2019 and the actuarial assumptions used to determine the net periodic pension cost for the supplemental plans were determined as of September 30, 2019, 2018 and 2017. These assumptions are presented in the following table:

	Pension Liability				Pension Cost
	2020		2019		2020		2019		2018
Discount rate(1)	2.80	%	3.29	%	3.19	%	4.38	%	4.08	%
Rate of compensation increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%
Interest crediting rate	4.69	%	4.69	%	4.69	%	4.69	%	4.69	%

 (1) Reflects a weighted average discount rate for pension cost for fiscal 2020 and 2018 due to the settlements during the year.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The following table presents the supplemental plans’ accumulated benefit obligation, projected benefit obligation and funded status as of September 30, 2020 and 2019:

	2020			2019
	(In thousands)
Accumulated benefit obligation	$	122,207		$	138,772
Change in projected benefit obligation:
Benefit obligation at beginning of year	$	143,987		$	121,370
Service cost	1,074			869
Interest cost	4,188			5,127
Actuarial (gain) loss	7,386			25,099
Benefits paid	(4,766		)	(8,478		)
Settlements	(22,729		)	—
Benefit obligation at end of year	129,140			143,987
Change in plan assets:
Fair value of plan assets at beginning of year	—			—
Employer contribution	27,495			8,478
Benefits paid	(4,766		)	(8,478		)
Settlements	(22,729		)	—
Fair value of plan assets at end of year	—			—
Reconciliation:
Funded status	(129,140		)	(143,987		)
Unrecognized prior service cost	—			—
Unrecognized net loss	—			—
Accrued pension cost	$	(129,140	)	$	(143,987	)

Assets for the supplemental plans are held in separate rabbi trusts. At September 30, 2020 and 2019, assets held in the rabbi trusts consisted of equity securities of $41.9 million and $44.0 million, which are included in our fair value disclosures in Note 15.

Net periodic pension cost for the supplemental plans for fiscal 2020, 2019 and 2018 is presented in the following table.

	Fiscal Year Ended September 30
	2020		2019		2018
	(In thousands)
Components of net periodic pension cost:
Service cost	$	1,074	$	869	$	1,332
Interest cost(1)	4,188		5,127		4,988
Recognized actuarial loss(1)	3,945		2,227		3,079
Settlements(1)	9,180		—		4,159
Net periodic pension cost	$	18,387	$	8,223	$	13,558

(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.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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)
2021	$	37,523	$	30,021
2022	37,804		17,117
2023	39,053		5,124
2024	40,036		4,472
2025	41,016		32,550
2026-2030	204,582		22,308

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 benefits depending on the level of coverage chosen by the participants and the terms of predecessor plans; however, we generally pay 80 percent of the projected net claims and administrative costs and participants pay the remaining 20 percent. Effective January 1, 2015, for employees who had not met the participation requirements by September 30, 2009, the contribution rates for the Company 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 2021.

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 regarding the postretirement benefits plan.

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, 2020 and 2019.

	Actual Allocation September 30
Security Class	2020	2019
Diversified investment funds	97.4%	97.1%
Cash and cash equivalents	2.6%	2.9%

Similar to our employee pension and supplemental plans, we review the estimates and assumptions underlying 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, 2020 and 2019 and the actuarial assumptions used to determine the net periodic pension cost for the postretirement plan were determined as of September 30, 2019, 2018 and 2017.

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The assumptions are presented in the following table:

	Postretirement Liability				Postretirement Cost
	2020		2019		2020		2019		2018
Discount rate	2.80	%	3.29	%	3.29	%	4.38	%	3.89	%
Expected return on plan assets	4.94	%	5.14	%	5.14	%	5.33	%	4.29	%
Initial trend rate	6.25	%	6.25	%	6.25	%	6.50	%	7.00	%
Ultimate trend rate	5.00	%	5.00	%	5.00	%	5.00	%	5.00	%
Ultimate trend reached in	2026		2025		2025		2022		2022

The following table presents the postretirement plan’s benefit obligation and funded status as of September 30, 2020 and 2019:

	2020			2019
	(In thousands)
Change in benefit obligation:
Benefit obligation at beginning of year	$	316,033		$	265,986
Service cost	13,466			10,810
Interest cost	10,612			11,839
Plan participants’ contributions	5,849			5,901
Actuarial (gain) loss	43,412			39,472
Benefits paid	(18,694		)	(17,975		)
Benefit obligation at end of year	370,678			316,033
Change in plan assets:
Fair value of plan assets at beginning of year	201,901			199,361
Actual return on plan assets	2,356			1,125
Employer contributions	16,833			13,489
Plan participants’ contributions	5,849			5,901
Benefits paid	(18,694		)	(17,975		)
Fair value of plan assets at end of year	208,245			201,901
Reconciliation:
Funded status	(162,433		)	(114,132		)
Unrecognized transition obligation	—			—
Unrecognized prior service cost	—			—
Unrecognized net loss	—			—
Accrued postretirement cost	$	(162,433	)	$	(114,132	)

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Net periodic postretirement cost for fiscal 2020, 2019 and 2018 is presented in the following table.

	Fiscal Year Ended September 30
	2020			2019			2018
	(In thousands)
Components of net periodic postretirement cost:
Service cost	$	13,466		$	10,810		$	12,078
Interest cost(1)	10,612			11,839			10,907
Expected return on assets(1)	(10,499		)	(10,659		)	(8,006		)
Amortization of transition obligation(1)	—			—			—
Amortization of prior service cost (credit)(1)	173			173			11
Recognized actuarial gain(1)	(1,337		)	(8,178		)	(6,473		)
Net periodic postretirement cost	$	12,415		$	3,985		$	8,517

(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.

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

The following tables set forth by level, within the fair value hierarchy, the Retiree Medical Plan’s assets at fair value as of September 30, 2020 and 2019. The methods used to determine fair value for the assets held by the Retiree Medical Plan are fully described in Note 2.

	Assets at Fair Value as of September 30, 2020
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Money market funds	$	—	$	5,525	$	—	$	5,525
Registered investment companies	202,720		—		—		202,720
Total investments measured at fair value	$	202,720	$	5,525	$	—	$	208,245

	Assets at Fair Value as of September 30, 2019
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Money market funds	$	—	$	5,972	$	—	$	5,972
Registered investment companies	195,929		—		—		195,929
Total investments measured at fair value	$	195,929	$	5,972	$	—	$	201,901

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Estimated Future Benefit Payments

The following benefit payments paid by us, retirees and prescription drug subsidy payments for our postretirement benefit plans, which reflect expected future service, as appropriate, are expected to be paid in the following fiscal years. Company payments for fiscal 2020 include contributions to our postretirement plan trusts.

	Company Payments		Retiree Payments		Subsidy Payments		Total Postretirement Benefits
	(In thousands)
2021	$	22,632	$	4,368	$	—	$	27,000
2022	16,263		4,772		—		21,035
2023	16,590		5,144		—		21,734
2024	17,517		5,651		—		23,168
2025	18,353		6,104		—		24,457
2026-2030	101,158		35,039		—		136,197

Defined Contribution Plan

The Atmos Energy Corporation Retirement Savings Plan and Trust (the Retirement Savings Plan) covers substantially all employees and is subject to the provisions of Section 401(k) of the Internal Revenue Code. Effective January 1, 2007, employees automatically become participants of the Retirement Savings Plan on the date of employment. Participants may elect a salary reduction up to a maximum of 65 percent of eligible compensation, as defined by the 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. Participants are eligible to receive matching contributions after completing one year of service, in which they are immediately vested. Effective January 1, 2021, participants are eligible to receive matching contributions immediately upon enrollment in the Retirement Savings Plan. This matching contribution vests after completing one year of service. Participants are also permitted to take out a loan against their accounts subject to certain restrictions. Employees hired on or after October 1, 2010 participate in the enhanced plan in which participants receive a fixed annual contribution of four percent of eligible earnings to their Retirement Savings Plan account. Participants will continue to be eligible for company matching contributions of up to four percent of their eligible earnings and will be fully vested in the fixed annual contribution after three years of service.

Matching and fixed annual contributions to the Retirement Savings Plan are expensed as incurred and amounted to $17.9 million, $16.7 million and $16.2 million for fiscal years 2020, 2019 and 2018. At September 30, 2020 and 2019, the Retirement Savings Plan held 2.2 percent and 2.6 percent of our outstanding common stock.

10.    Stock and Other Compensation Plans

Stock-Based Compensation Plans

Total stock-based compensation cost was $21.1 million, $23.9 million and $23.9 million for the fiscal years ended September 30, 2020, 2019 and 2018. Of this amount, $11.6 million, $12.8 million and $11.1 million was capitalized.

1998 Long-Term Incentive Plan

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

We were originally 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, 2020, 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 1.3 million shares are available for future issuance through September 30, 2021.

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Restricted Stock Units Award Grants

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

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

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

The following summarizes information regarding the restricted stock units granted under the plan during the fiscal years ended September 30, 2020, 2019 and 2018:

	2020				2019				2018
	Number of Restricted Units		Weighted Average Grant-Date Fair Value		Number of Restricted Units		Weighted Average Grant-Date Fair Value		Number of Restricted Units		Weighted Average Grant-Date Fair Value
Nonvested at beginning of year	503,072		$	91.66	538,592		$	80.91	570,814		$	69.45
Granted	199,985		102.34		241,472		98.25		248,710		85.62
Vested	(242,975	)	85.66		(269,347	)	76.71		(274,392	)	64.43
Forfeited	(16,803	)	96.87		(7,645	)	86.37		(6,540	)	74.87
Nonvested at end of year	443,279		$	99.28	503,072		$	91.66	538,592		$	80.91

As of September 30, 2020, there was $13.0 million of total unrecognized compensation cost related to nonvested restricted stock units granted under the LTIP. That cost is expected to be recognized over a weighted average period of 1.5 years. The fair value of restricted stock vested during the fiscal years ended September 30, 2020, 2019 and 2018 was $20.7 million, $20.5 million and $17.2 million.

Other Plans

Direct Stock Purchase Plan

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

Equity Incentive and Deferred Compensation Plan for Non-Employee Directors

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

Other Discretionary Compensation Plans

We have an annual incentive program covering substantially all employees to give each employee an opportunity to share in our financial success based on the achievement of key performance measures considered critical to achieving business

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objectives for a given year with minimum and maximum thresholds. The Company must meet the minimum threshold for the plan to be funded and distributed to employees. These performance measures may include earnings growth objectives, improved cash flow objectives or crucial customer satisfaction and safety results. We monitor progress towards the achievement of the performance measures throughout the year and record accruals based upon the expected payout using the best estimates available at the time the accrual is recorded. During the last several fiscal years, we have used earnings per share as our sole performance measure.

11.    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, 2020 and 2019:

	September 30
	2020			2019
	(In thousands)
Billed accounts receivable	$	140,259		$	126,984
Unbilled revenue	80,699			78,986
Contributions in aid of construction receivable	19,821			22,378
Other accounts receivable	19,765			18,122
Total accounts receivable	260,544			246,470
Less: allowance for doubtful accounts	(29,949		)	(15,899		)
Net accounts receivable	$	230,595		$	230,571

Other current assets

Other current assets as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Deferred gas costs	$	40,593	$	23,766
Prepaid expenses	40,340		38,895
Materials and supplies	6,829		5,916
Assets from risk management activities	5,687		1,586
Other	14,456		2,609
Total	$	107,905	$	72,772

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Property, plant and equipment

Property, plant and equipment was comprised of the following as of September 30, 2020 and 2019:

	September 30
	2020			2019
	(In thousands)
Storage plant	$	530,985		$	431,286
Transmission plant	3,459,765			3,157,316
Distribution plant	10,680,495			9,333,011
General plant	829,624			799,095
Intangible plant	38,297			38,191
	15,539,166			13,758,899
Construction in progress	418,055			421,694
	15,957,221			14,180,593
Less: accumulated depreciation and amortization	(2,601,874		)	(2,392,924		)
Net property, plant and equipment(1)	$	13,355,347		$	11,787,669

(1) Net property, plant and equipment includes plant acquisition adjustments of $(37.8) million and $(46.7) million at September 30, 2020 and 2019.

Goodwill

The following presents our goodwill balance allocated by segment and changes in the balance for the fiscal year ended September 30, 2020:

	Distribution			Pipeline and Storage		Total
	(In thousands)
Balance as of September 30, 2019	$	587,604		$	143,102	$	730,706
Deferred tax adjustments on prior acquisitions(1)	(768		)	1,319		551
Balance as of September 30, 2020	$	586,836		$	144,421	$	731,257

(1) We annually adjust certain deferred taxes recorded in connection with an acquisition completed in fiscal 2005, which resulted in an increase to goodwill and net deferred tax liabilities of $0.6 million for fiscal 2020.

Deferred charges and other assets

Deferred charges and other assets as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Marketable securities	$	103,952	$	101,883
Regulatory assets (See Note 2)	371,707		260,220
Operating lease right of use assets (See Note 6)	227,146		—
Assets from risk management activities	74,991		225
Tax receivable	—		10,099
Other	23,374		18,786
Total	$	801,170	$	391,213

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Accounts payable and accrued liabilities

Accounts payable and accrued liabilities as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Trade accounts payable	$	141,075	$	176,581
Accrued gas payable	42,054		36,817
Accrued liabilities	52,646		51,626
Total	$	235,775	$	265,024

Other current liabilities

Other current liabilities as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Customer credit balances and deposits	$	56,485	$	54,617
Accrued employee costs	57,057		55,216
Deferred gas costs	19,985		14,112
Operating lease liabilities (See Note 6)	35,716		—
Accrued interest	53,554		51,381
Liabilities from risk management activities	2,015		4,552
Taxes payable	148,292		135,597
Pension and postretirement liabilities	29,609		26,197
Regulatory cost of service reserve	1,716		4,209
Regulatory cost of removal obligation	73,908		55,721
APT annual adjustment mechanism	43,893		52,856
Regulatory excess deferred taxes (See Note 13)	20,887		21,206
Other	3,344		3,837
Total	$	546,461	$	479,501

Deferred credits and other liabilities

Deferred credits and other liabilities as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Pension and post retirement liabilities	$	337,303	$	279,083
Operating lease liabilities (See Note 6)	201,071		—
Customer advances for construction	10,060		12,566
Other regulatory liabilities (See Note 2)	17,838		16,120
Asset retirement obligation	20,348		17,054
Liabilities from risk management activities	—		1,249
APT annual adjustment mechanism	13,486		25,545
Unrecognized tax benefits	30,921		27,716
Other	11,101		20,883
Total	$	642,128	$	400,216

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Statement of Comprehensive Income

Other non-operating income (expense)

Other non-operating income (expense) for the fiscal years ended September 30, 2020, 2019 and 2018 were comprised of the following accounts.

	Year Ended September 30
	2020			2019			2018
	(In thousands)
Equity component of AFUDC	$	23,493		$	11,165		$	—
Performance-based rate program	6,771			6,737			6,745
Pension and other postretirement non-service credit (cost)	(3,189		)	3,016			(5,770		)
Interest income	2,932			4,160			1,450
Community support spending	(11,728		)	(4,771		)	(6,053		)
Miscellaneous	(11,108		)	(12,903		)	(6,516		)
Total	$	7,171		$	7,404		$	(10,144	)

Statement of Cash Flows

Supplemental disclosures of cash flow information for the fiscal years ended September 30, 2020, 2019 and 2018 were as follows:

	Year Ended September 30
	2020			2019		2018
	(In thousands)
Cash Paid (Received) During The Period For:
Interest(1)	$	194,993		$	184,852	$	169,987
Income taxes	$	(3,071	)	$	11,467	$	6,102
Non-Cash Transactions:
Capital expenditures included in current liabilities	$	113,365		$	149,993	$	112,211

(1) Cash paid during the period for interest, net of amounts capitalized was $82.3 million, $91.3 million and $106.8 million for the fiscal years ended September 30, 2020, 2019 and 2018.

12.    Commitments and Contingencies

Litigation and Environmental Matters

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

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.

The National Transportation Safety Board (NTSB) is investigating an incident that occurred at a Dallas, Texas residence on February 23, 2018 that resulted in one fatality and injuries to four other residents. Together with the Railroad Commission of Texas (RRC) and the Pipeline and Hazardous Materials Safety Administration (PHMSA), Atmos Energy is a party to the investigation and in that capacity is working closely with the NTSB to help determine the cause of this incident.

We are a party to various other litigation and environmental-related matters or claims that have arisen in the ordinary course of our business. While the results of such litigation and response actions to such environmental-related matters or claims

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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 indexed to natural gas trading hubs. At September 30, 2020, we were committed to purchase 59.3 Bcf within one year, 57.0 Bcf within two to three years and 0.1 Bcf beyond three years under indexed contracts. Purchases under these contracts totaled $58.5 million, $50.8 million and $57.2 million for 2020, 2019 and 2018.

Rate Regulatory Proceedings

As of September 30, 2020, 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.

13.    Income Taxes

Income Tax Expense

The components of income tax expense from continuing operations for 2020, 2019 and 2018 were as follows:

	2020			2019		2018
	(In thousands)
Current
Federal	$	—		$	—	$	(10,099	)
State	14,193			8,412		11,075
Deferred
Federal	143,039			113,331		150,556
State (1)	(11,879		)	17,160		15,330
TCJA Impact	—			—		(158,782		)
Income tax expense	$	145,353		$	138,903	$	8,080

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

Reconciliations of the provision for income taxes computed at the statutory rate to the reported provisions for income taxes from continuing operations for 2020, 2019 and 2018 are set forth below:

	2020			2019			2018
	(In thousands)
Tax at statutory rate(1)	$	156,827		$	136,565		$	149,730
Common stock dividends deductible for tax reporting	(1,419		)	(1,460		)	(1,745		)
State taxes (net of federal benefit)	22,791			20,202			19,826
Amortization of excess deferred taxes	(16,125		)	(14,085		)	(1,219		)
Remeasurement due to TCJA	—			—			(158,782		)
Remeasurement due to state deferred tax rate change	(20,962		)	—			—
Other, net	4,241			(2,319		)	270
Income tax expense	$	145,353		$	138,903		$	8,080

(1) Tax expense is calculated at the statutory federal income tax rate of 21.0%, 21.0%, 24.5% for the year ended September 30, 2020, 2019 and 2018.

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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, 2020 and 2019 are presented below:

	2020			2019
	(In thousands)
Deferred tax assets:
Employee benefit plans	$	66,991		$	70,929
Interest rate swaps	16,719			33,918
Net operating loss carryforwards	476,507			485,133
Charitable and other credit carryforwards	8,712			8,241
Regulatory excess deferred tax	161,565			165,701
Other	73,542			13,186
Total deferred tax assets	804,036			777,108
Valuation allowance	(1,102		)	(1,894		)
Net deferred tax assets	802,934			775,214
Deferred tax liabilities:
Difference in net book value and net tax value of assets(1)	(2,138,966		)	(2,004,516		)
Pension funding	(484		)	(4,384		)
Gas cost adjustments	(23,209		)	(18,072		)
Other	(96,844		)	(48,257		)
Total deferred tax liabilities	(2,259,503		)	(2,075,229		)
Net deferred tax liabilities	$	(1,456,569	)	$	(1,300,015	)
Deferred credits for rate regulated entities	$	2,537		$	2,582

(1) Includes $129.0 million and $131.0 million of deferred tax liability related to goodwill as of September 30, 2020 and 2019.

At September 30, 2020, we had $446.9 million (tax effected) of federal net operating loss carryforwards. The federal net operating loss carryforwards are available to offset taxable income and will begin to expire in 2029. The Company also had $10.1 million of federal alternative minimum tax credit carryforwards as of September 30, 2019, which did not expire and were fully refunded to us during fiscal 2020. In addition, the Company has $6.9 million in charitable contribution carryforwards to offset future taxable income. The Company’s charitable contribution carryforwards expiration period begins in fiscal 2021.

The Company also has $29.6 million (tax effected) of state net operating loss carryforwards (net of $7.9 million of federal effects) and $1.8 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 2021.

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 $1.1 million was established for the year ended September 30, 2020.

At September 30, 2020, we had recorded liabilities associated with unrecognized tax benefits totaling $30.9 million. The following table reconciles the beginning and ending balance of our unrecognized tax benefits:

	2020			2019			2018
	(In thousands)
Unrecognized tax benefits - beginning balance	$	27,716		$	26,203		$	23,719
Increase (decrease) resulting from prior period tax positions	(26		)	(923		)	22
Increase resulting from current period tax positions	3,231			2,436			2,462
Unrecognized tax benefits - ending balance	30,921			27,716			26,203
Less: deferred federal and state income tax benefits	(6,493		)	(5,820		)	(5,503		)
Total unrecognized tax benefits that, if recognized, would impact the effective income tax rate as of the end of the year	$	24,428		$	21,896		$	20,700

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

The Company recognizes interest accrued related to unrecognized tax benefits in interest expense and penalties included within interest charges in our consolidated statements of comprehensive income. During the years ended September 30, 2020, 2019 and 2018, the Company recognized approximately $0.7 million, $2.2 million and $1.6 million in interest and penalties. The Company had approximately $8.2 million, $7.9 million and $6.1 million for the payment of interest and penalties accrued at September 30, 2020, 2019 and 2018.

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

On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”) was signed into law. The CARES Act, among other things, includes provisions relating to refundable payroll tax credits, deferment of employer side social security payments, net operating loss carryback periods, alternative minimum tax credit refunds, modifications to the net interest deduction limitations and technical corrections to tax depreciation methods for qualified improvement property. The CARES Act did not have an impact on our consolidated financial statements for the year ended September 30, 2020.

Excess Deferred Taxes

On June 1, 2020, the Kansas legislature passed House Bill 2585 which eliminated the assessment of state income taxes on regulated utilities. This legislation was effective for the Company on October 1, 2020. Due to the change in the Kansas state tax law and the result of a study to estimate the rate at which state deferred taxes will reverse in the future, we reduced our deferred tax liability by $32.5 million during the fiscal third quarter of 2020. We established a $12.1 million regulatory liability for excess deferred taxes that will be returned to Kansas customers. We are currently working with the Kansas Corporation Commission to determine the amortization period for this liability. We recognized a $21.0 million income tax benefit in our consolidated statement of comprehensive income for the year ended September 30, 2020.

On December 22, 2017, the Tax Cuts and Jobs Act of 2017 (the "TCJA") was signed into law. As a result of the implementation of the TCJA, we recognized a $158.8 million income tax benefit in our consolidated statement of comprehensive income for the year ended September 30, 2018 related to a change in deferred taxes that were not related to our cost of service ratemaking. The change in deferred taxes related to our cost of service ratemaking (referred to as excess deferred taxes) was reclassified into a regulatory liability and as approved by our regulators, will be returned to ratepayers on a provisional basis over periods ranging from 15 to 46 years. As of September 30, 2020 and 2019, this liability totaled $706.7 million and $726.3 million.

During fiscal 2019, we received approval from regulators to update our cost of service rates to reflect the decrease in the statutory income tax rate in all of our service areas. Additionally, as of September 30, 2020, we have returned the separate regulatory liability to customers in substantially all of our service areas for the difference in taxes included in our rates that were calculated based on a 35% statutory income tax rate until new rates could be established based on the new 21% statutory income tax rate.

14.    Financial Instruments

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

As discussed in Note 2, we report our financial instruments as risk management assets and liabilities, each of which is classified as current or noncurrent based upon the anticipated settlement date of the underlying financial instrument. The following table shows the fair values of our risk management assets and liabilities at September 30, 2020 and 2019.

	September 30
	2020			2019
	(In thousands)
Assets from risk management activities, current	$	5,687		$	1,586
Assets from risk management activities, noncurrent	74,991			225
Liabilities from risk management activities, current	(2,015		)	(4,552		)
Liabilities from risk management activities, noncurrent	—			(1,249		)
Net assets (liabilities)	$	78,663		$	(3,990	)

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

Commodity Risk Management Activities

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

In jurisdictions where we are permitted to mitigate commodity price risk through financial instruments, the relevant regulatory authorities may establish the level of heating season gas purchases that can be hedged. Our distribution gas supply department is responsible for executing this segment’s commodity risk management activities in conformity with regulatory requirements. Historically, if the regulatory authority does not establish this level, we seek to hedge between 25 and 50 percent of anticipated heating season gas purchases using financial instruments. For the 2019-2020 heating season (generally October through March), in the jurisdictions where we are permitted to utilize financial instruments, we hedged approximately 49 percent, or approximately 19.9 Bcf of the winter flowing gas requirements at a weighted average cost of approximately $2.84 per Mcf. We have not designated these financial instruments as hedges for accounting purposes.

Interest Rate Risk Management Activities

In fiscal 2020, we entered into forward starting interest rate swaps to effectively fix the Treasury yield component associated with $500 million of a planned issuance of unsecured senior notes in fiscal 2021 at 0.69%; these swaps were settled in September 2020 with a net payment of $4.4 million. On October 1, 2020, the notes were issued as planned.

Additionally, in fiscal 2020, we entered into forward starting interest rate swaps to effectively fix the Treasury yield component associated with $450 million of a planned issuance of unsecured senior notes in fiscal 2022 at 1.33%, $300 million of a planned issuance of unsecured senior notes in fiscal 2023 at 1.36% and $300 million of a planned issuance of unsecured senior notes in fiscal 2025 at 1.35%, which we designated as cash flow hedges at the time the agreements were executed.

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, 2020, 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, 2020, we had 18,191 MMcf of net long commodity contracts outstanding. These contracts have not been designated as hedges.

78

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, 2020 and 2019. The gross amounts of recognized assets and liabilities are netted within our consolidated balance sheets to the extent that we have netting arrangements with the counterparties. However, as of September 30, 2020 and 2019, no gross amounts and no cash collateral were netted within our consolidated balance sheet.

	Balance Sheet Location	Assets		Liabilities
		(In thousands)
September 30, 2020
Designated As Hedges:
Interest rate contracts	Deferred charges and other assets / Deferred credits and other liabilities	$	73,055	$	—
Total		73,055		—
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	5,687		(2,015		)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	1,936		—
Total		7,623		(2,015		)
Gross / Net Financial Instruments		$	80,678	$	(2,015	)

	Balance Sheet Location	Assets		Liabilities
		(In thousands)
September 30, 2019
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	$	1,586	$	(4,552	)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	225		(1,249		)
Total		1,811		(5,801		)
Gross / Net Financial Instruments		$	1,811	$	(5,801	)

Impact of Financial Instruments on the Statement of Comprehensive Income

Cash Flow Hedges

As discussed above, the interest rate agreements we executed in prior years were designated as cash flow hedges when those 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, 2020, 2019 and 2018 was $5.5 million, $3.9 million and $2.4 million.

79

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), for the years ended September 30, 2020 and 2019. The amounts included in the table below exclude gains and losses arising from ineffectiveness because these amounts are immediately recognized in the statement of comprehensive income as incurred.

	Fiscal Year Ended September 30
	2020		2019
	(In thousands)
Increase (decrease) in fair value:
Interest rate agreements	$	53,241	$	(25,966	)
Recognition of losses in earnings due to settlements:
Interest rate agreements	3,647		3,022
Total other comprehensive income (loss) from hedging, net of tax	$	56,888	$	(22,944	)

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, 2020, we had $114.5 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 2049. However, the table below does not include the expected recognition in earnings of our outstanding interest rate agreements as those financial instruments have not yet settled.

	Interest Rate Agreements
	(In thousands)
2021	$	(4,569	)
2022	(4,569		)
2023	(4,569		)
2024	(4,569		)
2025	(4,569		)
Thereafter	(91,657		)
Total	$	(114,502	)

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.

15.    Fair Value Measurements

We report certain assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We record cash and cash equivalents, accounts receivable and accounts payable at carrying value, which substantially approximates fair value due to the short-term nature of these assets and liabilities. For other financial assets and liabilities, we primarily use quoted market prices and other observable market pricing information to minimize the use of unobservable pricing inputs in our measurements when determining fair value. The methods used to determine fair value for our assets and liabilities are fully described in Note 2.

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 9.

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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, 2020 and 2019. 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.

	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)(1)		Significant Other Unobservable Inputs (Level 3)		Netting and Cash Collateral		September 30, 2020
	(In thousands)
Assets:
Financial instruments	$	—	$	80,678	$	—	$	—	$	80,678
Debt and equity securities
Registered investment companies	37,831		—		—		—		37,831
Bond mutual funds	29,166		—		—		—		29,166
Bonds(2)	—		32,900		—		—		32,900
Money market funds	—		4,055		—		—		4,055
Total debt and equity securities	66,997		36,955		—		—		103,952
Total assets	$	66,997	$	117,633	$	—	$	—	$	184,630
Liabilities:
Financial instruments	$	—	$	2,015	$	—	$	—	$	2,015

	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)(1)		Significant Other Unobservable Inputs (Level 3)		Netting and Cash Collateral		September 30, 2019
	(In thousands)
Assets:
Financial instruments	$	—	$	1,811	$	—	$	—	$	1,811
Debt and equity securities
Registered investment companies	41,406		—		—		—		41,406
Bond mutual funds	25,966		—		—		—		25,966
Bonds(2)	—		31,915		—		—		31,915
Money market funds	—		2,596		—		—		2,596
Total debt and equity securities	67,372		34,511		—		—		101,883
Total assets	$	67,372	$	36,322	$	—	$	—	$	103,694
Liabilities:
Financial instruments	$	—	$	5,801	$	—	$	—	$	5,801

(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.

At September 30, 2020 and 2019, the amortized cost of our available-for-sale debt securities was $32.6 million and $31.7 million. At September 30, 2020 we maintained investments in bonds that have contractual maturity dates ranging from October 2020 through May 2023.

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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 and debt, which are recorded at carrying value. The nonfinancial assets and liabilities include asset retirement obligations and pension and post-retirement plan assets. For cash and cash equivalents, accounts receivable and accounts payable, 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 carrying value of our finance leases materially approximates fair value. The following table presents the carrying value and fair value of our long-term debt, excluding finances leases, debt issuance costs and original issue premium or discount, as of September 30, 2020:

	September 30, 2020
	(In thousands)
Carrying Amount	$	4,560,000
Fair Value	$	5,597,183

16.    Concentration of Credit Risk

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

17.    Selected Quarterly Financial Data (Unaudited)

Summarized unaudited quarterly financial data is presented below. The sum of net income per share by quarter may not equal the net income per share for the fiscal year due to variations in the weighted average shares outstanding used in computing such amounts. Our businesses are seasonal due to weather conditions in our service areas. For further information on its effects on quarterly results, see the “Results of Operations” discussion included in the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” section herein.

	Quarter Ended
	December 31			March 31			June 30			September 30
	(In thousands, except per share data)
Fiscal year 2020:
Operating revenues
Distribution	$	828,504		$	933,005		$	435,308		$	430,176
Pipeline and storage	148,176			146,237			158,008			156,918
Intersegment eliminations	(101,117		)	(101,577		)	(100,321		)	(112,180		)
Total operating revenues	875,563			977,665			492,995			474,914
Purchased gas cost	296,868			317,883			26,072			18,031
Operating income	252,781			331,438			139,035			100,845
Net Income	178,673			239,646			117,791			65,333
Basic net income per share	$	1.47		$	1.95		$	0.96		$	0.53
Diluted net income per share	$	1.47		$	1.95		$	0.96		$	0.53

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ATMOS ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

	Quarter Ended
	December 31			March 31			June 30			September 30
	(In thousands, except per share data)
Fiscal year 2019:
Operating revenues
Distribution	$	838,835		$	1,057,889		$	444,944		$	403,793
Pipeline and storage	134,470			135,650			149,198			147,706
Intersegment eliminations	(95,523		)	(98,894		)	(108,404		)	(107,816		)
Total operating revenues	877,782			1,094,645			485,738			443,683
Purchased gas cost	342,165			471,676			31,326			13,670
Operating income	236,464			297,677			122,202			89,715
Net Income	157,646			214,888			80,466			58,406
Basic net income per share	$	1.38		$	1.83		$	0.68		$	0.49
Diluted net income per share	$	1.38		$	1.82		$	0.68		$	0.49

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

None. 

ITEM 9A. Controls and Procedures.

Management’s Evaluation of Disclosure Controls and Procedures

We carried out an evaluation, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, of the effectiveness of the Company’s disclosure controls and procedures, as such term is defined in Rule 13a-15(e) under the Securities Exchange Act of 1934, as amended (Exchange Act). Based on this evaluation, the Company’s principal executive officer and principal financial officer have concluded that the Company’s disclosure controls and procedures were effective as of September 30, 2020 to provide reasonable assurance that information required to be disclosed by us, including our consolidated entities, in the reports that we file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified by the SEC’s rules and forms, including a reasonable level of assurance that such information is accumulated and communicated to our management, including our principal executive and principal financial officers, as appropriate to allow timely decisions regarding required disclosure.

Management’s Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f), in providing reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we evaluated the effectiveness of our internal control over financial reporting based on the framework in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (COSO). Based on our evaluation under the framework in Internal Control-Integrated Framework issued by COSO and applicable Securities and Exchange Commission rules, our management concluded that our internal control over financial reporting was effective as of September 30, 2020, in providing reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.

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

/s/    JOHN K. AKERS	/s/    CHRISTOPHER T. FORSYTHE
John K. Akers	Christopher T. Forsythe
President, Chief Executive Officer and Director	Senior Vice President and Chief Financial Officer
November 13, 2020

84

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, 2020, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO criteria). In our opinion, Atmos Energy Corporation (the Company) maintained, in all material respects, effective internal control over financial reporting as of September 30, 2020, 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 2020 consolidated financial statements of the Company and our report dated November 13, 2020 expressed an unqualified opinion thereon.

Basis for Opinion

The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

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

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

Definition and Limitations of Internal Control Over Financial Reporting

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

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

/s/ Ernst & Young LLP

Dallas, Texas

November 13, 2020

85

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, 2020 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 and delinquent Section 16(a) reports, if applicable, is incorporated herein by reference to the Company’s Definitive Proxy Statement for the Annual Meeting of Shareholders on February 3, 2021. Information regarding executive officers is reported below:

INFORMATION ABOUT OUR EXECUTIVE OFFICERS

The following table sets forth certain information as of September 30, 2020, regarding the executive officers of the Company. It is followed by a brief description of the business experience of each executive officer.

Name	Age	Years of Service	Office Currently Held
Kim R. Cocklin	69	14	Executive Chairman of the Board
John K. Akers	57	29	President, Chief Executive Officer and Director
Christopher T. Forsythe	49	17	Senior Vice President and Chief Financial Officer
David J. Park	49	26	Senior Vice President, Utility Operations
Karen E. Hartsfield	50	5	Senior Vice President, General Counsel and Corporate Secretary
John M. Robbins	50	7	Senior Vice President, Human Resources

Kim R. Cocklin was named Executive Chairman of the Board on October 1, 2017. From October 1, 2010 through September 30, 2015, Mr. Cocklin served the Company as President and Chief Executive Officer and from October 1, 2015 through September 30, 2017, as Chief Executive Officer. Mr. Cocklin joined the Company in June 2006 and served as President and Chief Operating Officer of the Company from October 1, 2008 through September 30, 2010, after having served as Senior Vice President, Regulated Operations from October 2006 through September 2008. Mr. Cocklin was appointed to the Board of Directors on November 10, 2009.

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

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

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.

86

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 3, 2021.

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, under "Corporate Governance" under the "Corporate Responsibility" tab. 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 under "Corporate Governance" under the "Corporate Responsibility" tab.

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 3, 2021, under the captions "Human Resources Committee Report," "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 3, 2021, under the heading "Beneficial Ownership of Common Stock." Information concerning our equity compensation plans is provided in Part II, Item 5, “Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities”, of this Annual Report on Form 10-K.

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

Information on certain relationships and related transactions as well as director independence is incorporated herein by reference to the Company’s Definitive Proxy Statement for the Annual Meeting of Shareholders on February 3, 2021, under the heading "Corporate Governance and Other Board Matters," "Proposal One – Election of Directors," and "Director Compensation."

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 3, 2021, under the heading "Proposal Three – Ratification of Appointment of Independent Registered Public Accounting Firm."

PART IV

ITEM 15. Exhibits and Financial Statement Schedules.

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

The financial statements and financial statement schedule listed in the Index to Financial Statements in Item 8 are filed as part of this Form 10-K.

3.     Exhibits

87

Exhibit Number	Description	Page Number or Incorporation by Reference to
	Articles of Incorporation and Bylaws
3.1	Restated Articles of Incorporation of Atmos Energy Corporation - Texas (As Amended Effective February 3, 2010)	Exhibit 3.1 to Form 10-Q dated March 31, 2010 (File No. 1-10042)
3.2	Restated Articles of Incorporation of Atmos Energy Corporation - Virginia (As Amended Effective February 3, 2010)	Exhibit 3.2 to Form 10-Q dated March 31, 2010 (File No. 1-10042)
3.3	Amended and Restated Bylaws of Atmos Energy Corporation (as of February 5, 2019)	Exhibit 3.1 to Form 8-K dated February 5, 2019 (File No. 1-10042)
	Instruments Defining Rights of Security Holders, Including Indentures
4.1(a)	Specimen Common Stock Certificate (Atmos Energy Corporation)	Exhibit 4.1 to Form 10-K for fiscal year ended September 30, 2012 (File No. 1-10042)
4.1(b)	Description of Registrant's Securities	Exhibit 4.1(b) to Form 10-K for fiscal year ended September 30, 2019 (File No. 1-10042)
4.2	Indenture dated as of November 15, 1995 between United Cities Gas Company and Bank of America Illinois, Trustee	Exhibit 4.11(a) to Form S-3 dated August 31, 2004 (File No. 333-118706)
4.3	Indenture dated as of July 15, 1998 between Atmos Energy Corporation and U.S. Bank Trust National Association, Trustee	Exhibit 4.8 to Form S-3 dated August 31, 2004 (File No. 333-118706)
4.4	Indenture dated as of May 22, 2001 between Atmos Energy Corporation and SunTrust Bank, Trustee	Exhibit 99.3 to Form 8-K dated May 22, 2001 (File No. 1-10042)
4.5	Indenture dated as of March 26, 2009 between Atmos Energy Corporation and U.S. Bank National Corporation, Trustee	Exhibit 4.1 to Form 8-K dated March 26, 2009 (File No. 1-10042)
4.6(a)	Debenture Certificate for the 6 3/4% Debentures due 2028	Exhibit 99.2 to Form 8-K dated July 29, 1998 (File No. 1-10042)
4.6(b)	Global Security for the 5.95% Senior Notes due 2034	Exhibit 10(2)(g) to Form 10-K for fiscal year ended September 30, 2004 (File No. 1-10042)
4.6(c)	Global Security for the 5.5% Senior Notes due 2041	Exhibit 4.2 to Form 8-K dated June 13, 2011 (File No. 1-10042)
4.6(d)	Global Security for the 4.15% Senior Notes due 2043	Exhibit 4.2 to Form 8-K dated January 11, 2013 (File No. 1-10042)
4.6(e)	Global Security for the 4.125% Senior Notes due 2044	Exhibit 4.2 to Form 8-K dated October 17, 2014 (File No. 1-10042)
4.6(f)	Global Security for the 3.000% Senior Notes due 2027	Exhibit 4.2 to Form 8-K dated June 8, 2017 (File No. 1-10042)
4.6(g)	Global Security for the 4.125% Senior Notes due 2044	Exhibit 4.3 to Form 8-K dated June 8, 2017 (File No. 1-10042)
4.6(h)	Global Security for the 4.300% Senior Notes due 2048	Exhibit 4.2 to Form 8-K dated October 4, 2018 (File No. 1-10042)
4.6(i)	Global Security for the 4.300% Senior Notes due 2048	Exhibit 4.3 to Form 8-K dated October 4, 2018 (File No. 1-10042)
4.6(j)	Global Security for the 4.125% Senior Notes due 2049	Exhibit 4.2 to Form 8-K dated March 4, 2019 (File No. 1-10042)
4.6(k)	Global Security for the 2.625% Senior Notes due 2029	Exhibit 4.2 to Form 8-K dated October 2, 2019 (File No. 1-10042)

88

4.6(l)	Global Security for the 3.375% Senior Notes due 2049	Exhibit 4.3 to Form 8-K dated October 2, 2019 (File No. 1-10042)
4.6(m)	Global Security for the 1.500% Senior Notes due 2031	Exhibit 4.2 to Form 8-K dated October 1, 2020 (File No. 1-10042)
4.6(n)	Global Security for the 1.500% Senior Notes due 2031	Exhibit 4.3 to Form 8-K dated October 1, 2020 (File No. 1-10042)
	Material Contracts
10.1(a)	Revolving Credit Agreement, dated as of September 25, 2015 among Atmos Energy Corporation, the Lenders from time to time parties thereto, Crédit Agricole Corporate and Investment Bank as Administrative Agent, and Mizuho Bank Ltd., as Syndication Agent	Exhibit 10.1 to Form 8-K dated October 1, 2015 (File No. 1-10042)
10.1(b)	First Amendment to Revolving Credit Agreement, dated as of October 5, 2016, by and among Atmos Energy Corporation, the lenders from time to time parties thereto (the "Lenders") and Credit Agricole Corporate and Investment Bank, in its capacity as administrative agent for the Lenders	Exhibit 10.1 to Form 8-K dated October 11, 2016 (File No. 1-10042)
10.1(c)	Second Amendment to Revolving Credit Agreement, dated as of September 7, 2017, by and among Atmos Energy Corporation, the lenders from time to time parties thereto (the "Lenders") and Credit Agricole Corporate and Investment Bank, in its capacity as administrative agent for the Lenders	Exhibit 10.1(c) to Form 10-K for fiscal year ended September 30, 2018 (File No. 1-10042)
10.2	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	Exhibit 10.1 to Form 8-K dated April 13, 2020 (File No. 1-10042)
10.3	364-Day Revolving Credit Agreement, dated as of April 23, 2020, among Atmos Energy Corporation, Mizuho Bank, Ltd., as the Administrative Agent, the agents, arrangers and bookrunners named therein, and the lenders named therein	Exhibit 10.1 to Form 8-K dated April 24, 2020 (File No. 1-10042)
10.4(a)	Equity Distribution Agreement, dated as of February 12, 2020, among Atmos Energy Corporation and the Managers and Forward Purchasers named in Schedule A thereto	Exhibit 1.1 to Form 8-K dated February 12, 2020 (File No. 1-10042)
10.4(b)	Form of Master Forward Sale Confirmation	Exhibit 1.2 to Form 8-K dated February 12, 2020 (File No. 1-10042)
	Executive Compensation Plans and Arrangements
10.5(a)*	Form of Atmos Energy Corporation Change in Control Severance Agreement - Tier I	Exhibit 10.7(a) to Form 10-K for fiscal year ended September 30, 2010 (File No. 1-10042)
10.5(b)*	Form of Atmos Energy Corporation Change in Control Severance Agreement - Tier II	Exhibit 10.7(b) to Form 10-K for fiscal year ended September 30, 2010 (File No. 1-10042)
10.6(a)*	Atmos Energy Corporation Executive Retiree Life Plan	Exhibit 10.31 to Form 10-K for fiscal year ended September 30, 1997 (File No. 1-10042)

89

10.6(b)*	Amendment No. 1 to the Atmos Energy Corporation Executive Retiree Life Plan	Exhibit 10.31(a) to Form 10-K for fiscal year ended September 30, 1997 (File No. 1-10042)
10.7*	Atmos Energy Corporation Annual Incentive Plan for Management (as amended and restated October 1, 2016)	Exhibit 10.5 to Form 10-K for fiscal year ended September 30, 2016 (File No. 1-10042)
10.8(a)*	Atmos Energy Corporation Supplemental Executive Benefits Plan, Amended and Restated in its Entirety August 7, 2007	Exhibit 10.8(a) to Form 10-K for fiscal year ended September 30, 2008 (File No. 1-10042)
10.8(b)*	Form of Individual Trust Agreement for the Supplemental Executive Benefits Plan	Exhibit 10.3 to Form 10-Q for quarter ended December 31, 2000 (File No. 1-10042)
10.9(a)*	Atmos Energy Corporation Supplemental Executive Retirement Plan (As Amended and Restated, Effective as of January 1, 2016)	Exhibit 10.7(a) to Form 10-K for fiscal year ended September 30, 2016 (File No. 1-10042)
10.9(b)*	Atmos Energy Corporation Performance-Based Supplemental Executive Benefits Plan Trust Agreement, Effective Date December 1, 2000	Exhibit 10.1 to Form 10-Q for quarter ended December 31, 2000 (File No. 1-10042)
10.10*	Atmos Energy Corporation Account Balance Supplemental Executive Retirement Plan (As Amended and Restated, Effective as of January 1, 2016)	Exhibit 10.8 to Form 10-K for fiscal year ended September 30, 2016 (File No. 1-10042)
10.11(a)*	Mini-Med/Dental Benefit Extension Agreement dated October 1, 1994	Exhibit 10.28(f) to Form 10-K for fiscal year ended September 30, 2001 (File No. 1-10042)
10.11(b)*	Amendment No. 1 to Mini-Med/Dental Benefit Extension Agreement dated August 14, 2001	Exhibit 10.28(g) to Form 10-K for fiscal year ended September 30, 2001 (File No. 1-10042)
10.11(c)*	Amendment No. 2 to Mini-Med/Dental Benefit Extension Agreement dated December 31, 2002	Exhibit 10.1 to Form 10-Q for quarter ended December 31, 2002 (File No. 1-10042)
10.12*	Atmos Energy Corporation Equity Incentive and Deferred Compensation Plan for Non-Employee Directors, Amended and Restated as of January 1, 2012	Exhibit 10.1 to Form 10-Q for quarter ended December 31, 2011 (File No. 1-10042)
10.13(a)*	Atmos Energy Corporation 1998 Long-Term Incentive Plan (as amended and restated November 6, 2019)	Exhibit 10.11(a) to Form 10-K for fiscal year ended September 30, 2019 (File No. 1-10042)
10.13(b)*	Form of Award Agreement of Time-Lapse Restricted Stock Units under the Atmos Energy Corporation 1998 Long-Term Incentive Plan
10.13(c)*	Form of Award Agreement of Performance-Based Restricted Stock Units under the Atmos Energy Corporation 1998 Long-Term Incentive Plan
10.13(d)*	Form of Non-Employee Director Award Agreement of Time-Lapse Restricted Stock Units Under the Atmos Energy Corporation 1998 Long-Term Incentive Plan	Exhibit 10.11(d) to Form 10-K for fiscal year ended September 30, 2019 (File No. 1-10042)
10.13(e)*	Form of Non-Employee Director Award Agreement of Stock Unit Awards Under The Atmos Energy Corporation 1998 Long-Term Incentive Plan	Exhibit 10.11(e) to Form 10-K for fiscal year ended September 30, 2019 (File No. 1-10042)
	Other Exhibits, as indicated
21	Subsidiaries of the registrant
23.1	Consent of independent registered public accounting firm, Ernst & Young LLP
24	Power of Attorney	Signature page of Form 10-K for fiscal year ended September 30, 2020

90

31	Rule 13a-14(a)/15d-14(a) Certifications
32	Section 1350 Certifications**
	Interactive Data File
101.INS	XBRL Instance Document - the Instance Document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH	Inline XBRL Taxonomy Extension Schema
101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase
101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase
101.LAB	Inline XBRL Taxonomy Extension Labels Linkbase
101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File - the cover page interactive data file does not appear in the interactive data file because its XBRL tags are embedded within the Inline XBRL document

*

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

**

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

ITEM 16. Form 10-K Summary.

Not applicable.

91

SIGNATURES

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

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

Date: November 13, 2020

92

POWER OF ATTORNEY

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

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

93

/s/    KIM R. COCKLIN	Executive Chairman of the Board	November 13, 2020
Kim R. Cocklin
/s/    JOHN K. AKERS	President, Chief Executive Officer and Director	November 13, 2020
John K. Akers
/s/    CHRISTOPHER T. FORSYTHE	Senior Vice President and Chief Financial Officer	November 13, 2020
Christopher T. Forsythe
/s/    RICHARD M. THOMAS	Vice President and Controller (Principal Accounting Officer)	November 13, 2020
Richard M. Thomas
/s/    ROBERT W. BEST	Director	November 13, 2020
Robert W. Best
/s/    KELLY H. COMPTON	Director	November 13, 2020
Kelly H. Compton
/s/ SEAN DONOHUE	Director	November 13, 2020
Sean Donohue
/s/    RAFAEL G. GARZA	Director	November 13, 2020
Rafael G. Garza
/s/    RICHARD K. GORDON	Director	November 13, 2020
Richard K. Gordon
/s/    ROBERT C. GRABLE	Director	November 13, 2020
Robert C. Grable
/s/    NANCY K. QUINN	Director	November 13, 2020
Nancy K. Quinn
/s/    RICHARD A. SAMPSON	Director	November 13, 2020
Richard A. Sampson
/s/    STEPHEN R. SPRINGER	Director	November 13, 2020
Stephen R. Springer
/s/ DIANA J. WALTERS	Director	November 13, 2020
Diana J. Walters
/s/    RICHARD WARE II	Director	November 13, 2020
Richard Ware II
/s/    FRANK YOHO	Director	November 13, 2020
Frank Yoho

94

Schedule II

ATMOS ENERGY CORPORATION

Valuation and Qualifying Accounts

Three Years Ended September 30, 2020

			Additions
	Balance at beginning of period		Charged to cost & expenses		Charged to other accounts		Deductions			Balance at end of period
			(In thousands)
2020
Allowance for doubtful accounts	$	15,899	$	23,837	$	—	$	9,787	(1)	$	29,949
2019
Allowance for doubtful accounts	$	14,795	$	17,633	$	—	$	16,529	(1)	$	15,899
2018
Allowance for doubtful accounts	$	10,865	$	14,894	$	—	$	10,964	(1)	$	14,795

⁽¹⁾  Uncollectible accounts written off.

95

EX-10.13B

Exhibit 10.13(b)

AWARD AGREEMENT OF TIME-LAPSE

RESTRICTED STOCK UNITS

UNDER THE ATMOS ENERGY CORPORATION

1998 LONG-TERM INCENTIVE PLAN

This Award Agreement of Time-Lapse Restricted Stock Units (“Award Agreement”) is dated as of {Date}, by and between Atmos Energy Corporation, a Texas and Virginia corporation (the "Company"), and you ("Grantee"), pursuant to the Company's 1998 Long-Term Incentive Plan (the "Plan"). Capitalized terms that are used, but not defined, in this Award Agreement shall have the meaning set forth in the Plan.

1.Grant and Description of Units.

Pursuant to authorization by the Human Resources Committee of the Board (the "Committee”), which has been designated by the Board to administer the Plan, the Company hereby grants to the Grantee time-lapse restricted stock units (“Units”) under the Plan, for no consideration from the Grantee, with the restrictions set forth below. Each such Unit shall be a notional share of common stock of the Company (“Common Stock”), with the value of each Unit being equal to the Fair Market Value of a share of Common Stock at any time. No physical certificates representing the number of Units awarded shall be issued to the Grantee, but an account shall be established and maintained for the Grantee, in which each grant of Units to the Grantee shall be recorded. During the time of the restriction period provided for in Section 2 below, the Grantee shall not have any of the rights of a shareholder of the Company with respect to the Units, except with respect to the payment of cash dividend equivalents during such period, as provided for in Section 6 below.

2. Restrictions on Alienation of Units.

Units awarded hereunder may not be sold, transferred, pledged, assigned, or otherwise alienated in any manner, whether voluntarily, by operation of law, or otherwise, until the restrictions on the Units are removed and the Units are delivered to the Grantee in the form of shares of Common Stock in the manner described below in Section 8.

3.Vesting of Units.

If the Grantee has attained the age of 55 and completed three (3) consecutive years of service with the Company (referred to as “Retirement Eligible”) on the date of the grant of the Units, he or she shall be vested in the Units on the later of June 1 of the year in which the grant is made or the date of the grant. If the Grantee becomes Retirement Eligible after the date of grant and prior to the date for distribution of shares of Common Stock represented by the Units, the Grantee shall be vested in the Units at the later of June 1 of the year in which he or she becomes Retirement Eligible or the actual date during such year that he or she becomes Retirement Eligible. However, the Grantee shall not be entitled to the removal of the restrictions on such Units provided for in Section 2 above or to a distribution of shares of Common Stock represented by the number of Units until the time provided for in Section 8 below. In addition, the Grantee’s portion of applicable payroll (FICA) taxes shall be withheld from the first scheduled bi-weekly paycheck in December of the year in which such vesting occurs. The amount of payroll taxes due shall be based on the Fair Market Value of the shares of Common Stock represented by the number of Units as of the last business day of the pay period to which the first scheduled payroll check in December applies.

4. Forfeiture of Units.

If the Grantee is not otherwise vested as provided in Section 3 above, all Units granted shall be forfeited if the Grantee has a voluntary or involuntary Termination of Service for any reason other than as described below in Section 5. Each Grantee, by his or her acceptance of the Units, agrees to execute any documents requested by the Company in connection with such forfeiture. Such provisions with respect to forfeited Units shall be specifically performable by the Company in a court of equity or law. Upon any forfeiture, all rights of the Grantee with respect to the forfeited Units shall cease and terminate, without any further obligation on the part of the Company.

5. Removal of Restrictions.

(a) Death, Disability, Certain Involuntary Terminations and Terminations following a Change in Control.

At the time and on the date of the Grantee's death, Termination of Service due to Total and Permanent Disability, involuntary Termination of Service due to a general reduction in force or specific elimination of the Grantee's job, or Termination of Service for any reason following a Change in Control, while employed by the Company or a Subsidiary, all Units shall be vested and all other restrictions placed on the Units shall be removed. The Grantee, or his or her legal representatives, beneficiaries or heirs shall then be entitled to a distribution, as provided in Section 8 below, of shares of Common Stock equal in number to the number of Units set forth in Section 1 above.

(b) Retirement.

At the time and on the date of the Grantee's Retirement on or after becoming Retirement Eligible, no distribution of Units shall occur and the restrictions provided for in Section 2 above shall remain in place until such time as the Grantee, or his or her legal representatives, beneficiaries or heirs shall be entitled to a distribution, as provided in Section 8 below, of shares of Common Stock equal in number to the number of Units set forth in Section 1 above.

6. Payment of Cash Dividend Equivalents.

Cash dividend equivalents shall be paid on the Units to the Grantee through the Company payroll system in an amount equal to the cash dividends actually paid each calendar quarter on the Company’s issued and outstanding shares of Common Stock. Such cash dividend equivalents shall be paid at the end of the payroll period in which such cash dividends are actually paid to the Company’s shareholders and shall cease as of the Distribution Date (as defined in Section 8 below). However, the payment of cash dividend equivalents shall not be considered to be “eligible compensation,” as such term is defined under either the Company’s Retirement Savings Plan or Pension Account Plan.

7. Adjustment Upon Changes in Stock.

If there shall be any change in the number of shares of Common Stock outstanding resulting from subdivision, combination, or reclassification of shares, or through merger, consolidation, reorganization, recapitalization, stock dividend, stock split or other change in the corporate structure, an appropriate adjustment in the number of Units with respect to which restrictions have not lapsed shall be made by the Committee. Depending upon the change in corporate structure, the Committee shall issue additional Units or substitute Units to the Grantee for his or her account, which shall have the same restrictions, terms and conditions as the original Units. Any such adjustment shall be in accordance with the applicable

provisions of Section 14 and/or Section 15 of the Plan.

8. Distribution of Common Stock or Cash.

As soon as administratively possible, as determined solely by the Company, following the earlier of the date of the occurrence of a termination event described in Section 5(a) above or the date which is three (3) years from the date of grant of the Units (such date being referred to as the “Distribution Date”), but in no event later than 90 days following the Distribution Date, the Grantee shall receive a distribution, as provided herein, of shares of Common Stock equal in number to the number of Units set forth in Section 1 above (subject to the withholding requirements set forth in Section 9 below), provided the Grantee has been an employee of the Company or a Subsidiary with continuous service from the date of grant to the Distribution Date, except in the event of the Grantee’s Termination of Service or Retirement as discussed in Section 5 above. Notwithstanding the immediately preceding sentence, in the case of a distribution of shares of Common Stock on account of any Termination of Service as provided for above in Section 5 above, other than death, a distribution of the number of such shares, determined after application of the withholding requirements set forth in Section 9 below, plus any dividends payable with respect to such number of shares, on behalf of the Grantee, if the Grantee is a "specified employee" as defined in §1.409A-1(i) of the Final Regulations under Code Section 409A, to the extent otherwise required under Section 409A, shall not occur until the date which is six (6) months following the date of the Grantee’s Termination of Service (or, if earlier, the date of death of the Grantee). Upon a distribution of shares of Common Stock as provided herein, the Company shall cause the Common Stock then being distributed to be registered in the Grantee’s name, but shall not issue certificates for the Common Stock unless the Grantee requests delivery of the certificates for the Common Stock, in writing in accordance with the procedures established by the Company. The Company shall deliver certificates to the Grantee as soon as administratively practicable following the Company’s receipt of a written request from the Grantee for delivery of the certificates. From and after the date of receipt of such distribution, the Grantee or the Grantee's legal representatives, beneficiaries or heirs, as the case may be, shall have full rights of transfer or resale with respect to such shares subject to applicable state and federal regulations. Notwithstanding any provisions of this Award Agreement to the contrary, in lieu of a distribution of shares of Common Stock, the Company shall have the option to settle the payment of some or all of the Units in an economically equivalent amount of cash.

9. Withholding Requirements.

Upon the removal or lapse of the restrictions on the Units, the number of shares of Common Stock to be distributed by the Company to the Grantee, which are equal to the number of Units set forth in Section 1 above, or an economically equivalent amount of cash, as discussed in Section 8 above, shall be subject to applicable withholding requirements for income and employment taxes (unless withheld earlier at the time of vesting, as described in Section 3 above) arising from the removal or lapse of the restrictions on the Units. However, if the Grantee is a "specified employee" as defined in §1.409A-1(i) of the Final Regulations under Code Section 409A who is subject to the six (6) months delay provided for in Section 8 above, the Company shall, on the date of the Grantee’s Termination of Service, based on the value of a share of Common Stock on such date, withhold the number of shares attributable to any employment taxes not withheld earlier and shall, on the date which occurs six (6) months following the date of the Grantee’s Termination of Service (or, if earlier, the date of death of the Grantee), basedon the value of a share of Common Stock on such date, withhold the number of shares attributable to income taxes. Dividends will also be payable on such date to the Grantee for such delay period based on the net number of shares.

10. Modification.

This Award Agreement may be changed or modified without the Grantee's consent or signature, if the Company determines, in its sole discretion, that such change or modification is necessary for purposes of compliance with or exemption from the requirements of Section 409A of the Code and any regulations or other guidance issued thereunder, or otherwise to comply with any law.

Grantee acknowledges that as of the grant date, this Award Agreement and the Plan set forth the entire understanding between Grantee and the Company regarding the acquisition of the Units granted under the Plan and supersede all prior oral and written agreements on this subject. By Grantee’s electronic acceptance and the signature of the Company’s representative below, Grantee and the Company agree that the Units are granted under and governed by this Award Agreement and the Plan. Grantee has reviewed and fully understands all provisions of this Award Agreement and the Plan in their entirety.

ATMOS ENERGY CORPORATION

By: /s/ Kevin Akers

Kevin Akers

President and

Chief Executive Officer

EX-10.13C

Exhibit 10.13(c)

AWARD AGREEMENT OF PERFORMANCE-BASED

RESTRICTED STOCK UNITS

UNDER THE ATMOS ENERGY CORPORATION

1998 LONG-TERM INCENTIVE PLAN

This Award Agreement of Performance-Based Restricted Stock Units (“Award Agreement”) is dated as of {Date}, by and between Atmos Energy Corporation, a Texas and Virginia corporation (the "Company"), and you ("Grantee"), pursuant to the Company's 1998 Long-Term Incentive Plan (the "Plan"). Capitalized terms that are used, but not defined, in this Award Agreement shall have the meaning set forth in the Plan.

1.Grant and Description of Units.

Pursuant to authorization by the Human Resources Committee of the Board (the “Committee”), which has been designated by the Board to administer the Plan, the Company hereby grants to the Grantee performance-based restricted stock units (“Units”) under the Plan, for no consideration from the Grantee, with the restrictions set forth below. Each such Unit shall be a notional share of common stock of the Company (“Common Stock”), with the value of each Unit being equal to the Fair Market Value of a share of Common Stock at any time. No physical certificates representing the number of Units awarded shall be issued to the Grantee, but an account shall be established and maintained for the Grantee, in which each grant of Units to the Grantee shall be recorded, with the final number of Units as determined in accordance with Section 3 or Section 5 below. Until the final number of Units is determined, the Grantee shall not have any of the rights of a shareholder of the Company with respect to the Units, except for the crediting of dividend equivalents as provided for in Section 6 below.

2. Restrictions on Alienation of Units.

Units awarded hereunder may not be sold, transferred, pledged, assigned, or otherwise alienated in any manner, whether voluntarily, by operation of law, or otherwise, until the restrictions on the Units are removed and the Units are delivered to the Grantee in the form of shares of Common Stock in the manner described below in Section 8.

3.Number of Units Awarded.

Except as provided in Section 5(a) below, the number of Units ultimately to be awarded to the Grantee upon vesting is contingent upon the cumulative amount of earnings per share achieved by the Company for the three year measurement cycle, Fiscal Years {Year} through {Year} (October 1, {Year} through September 30, {Year}). The percentage of Units earned for each level of the cumulative amount of earnings per share is illustrated in the performance schedule below. In addition, should the performance levels achieved be between the stated criteria below, straight-line interpolation shall be used. For example, should the cumulative amount of earnings per share for the three-year period be ${Amount}, the percentage of Units earned would be {Amount}% of the number of Units originally granted.

Performance-Based Restricted Stock Units Performance Schedule for Grant of Performance Period FY
Performance Level	Cumulative 3-Yr. EPS	Restricted Stock Units Earned
Below Threshold	Less than $	0%
Threshold	$	50%
Target	$	100%
Maximum	$	200%

4. Forfeiture of Units.

All Units granted shall be forfeited if, prior to the removal of restrictions on the Units awarded hereunder as provided below in Section 8, the Grantee has a voluntary or involuntary Termination of Service for any reason other than as described below in Section 5. Each Grantee, by his or her acceptance of the Units, agrees to execute any documents requested by the Company in connection with such forfeiture. Such provisions with respect to forfeited Units shall be specifically performable by the Company in a court of equity or law. Upon any forfeiture, all rights of the Grantee with respect to the forfeited Units shall cease and terminate, without any further obligation on the part of the Company.

5. Removal of Restrictions.

(a) Death, Disability, Certain Involuntary Terminations and Terminations following a Change in Control.

At the time and on the date of the Grantee's death, Termination of Service due to Total and Permanent Disability, involuntary Termination of Service due to a general reduction in force or specific elimination of the Grantee's job, or Termination of Service for any reason following a Change in Control, while employed by the Company or a Subsidiary, all restrictions placed on each Unit awarded shall be removed, and the measurement cycle for purposes of Section 6 and Section 8 below shall be deemed to have ended. The prorated number of Units awarded shall be determined by multiplying the percentage of Units awarded at the “Target” performance level discussed above in Section 3, by the ratio of actual months of service to 36 months of the original measurement cycle, with the resulting product being increased, if appropriate, as provided below in Section 6. The Grantee, or his or her legal representatives, beneficiaries or heirs shall be entitled to a distribution, as provided in Section 8 below, of shares of Common Stock equal in number to such prorated number of Units.

(b) Retirement.

At the time and on the date of the Grantee's Retirement on or after attaining the age of 55 and completing at least three (3) consecutive years of service with the Company at the time of such Retirement, the restrictions placed on the Units under Section 2 above shall not be removed and the percentage of Units earned shall not be determined until the end of the measurement cycle. The number of Units awarded shall be determined by multiplying the ratio of actual months of service to 36 months of the original measurement cycle by the percentage of Units earned, based on the actual performance achieved over the original measurement cycle, as discussed above in Section 3, with the resulting product being increased, if appropriate, as provided below in Section 6. The Grantee, or his or her legal representatives, beneficiaries or heirs shall be entitled to a distribution, as provided in Section 8 below, of shares of Common Stock equal in number to such prorated number of Units.

6. Credit of Dividend Equivalents.

Immediately prior to distribution of Units as described above in Section 5 or below in Section 8, the Grantee’s account shall be credited with a number of Units which are based on the amount of dividends that are declared and paid on shares of Common Stock during each fiscal quarter of the measurement cycle, determined in accordance with Section 3 or Section 5 above (“dividend equivalents”). The number of Units upon which dividend equivalents shall be credited for the benefit of the Grantee is the total number of Units finally determined to have been earned by the Grantee at the end of the measurement cycle in accordance with Section 3 or Section 5 above, as appropriate. The total amount of each quarterly dividend equivalent shall be converted to the number of Units attributable to that quarterly dividend equivalent, by dividing such dividend equivalent amount by the average of the high and low prices of the Common Stock on the last trading day of the month during each quarter that such dividends are paid during the appropriate measurement cycle.

7. Adjustment Upon Changes in Stock.

If there shall be any change in the number of shares of Common Stock outstanding resulting from subdivision, combination, or reclassification of shares, or through merger, consolidation, reorganization, recapitalization, stock dividend, stock split or other change in the corporate structure, an appropriate adjustment in the number of Units with respect to which restrictions have not lapsed shall be made by the Committee. Depending upon the change in corporate structure, the Committee shall issue additional Units or substitute Units to the Grantee for his or her account, which shall have the same restrictions, terms and conditions as the original Units. Any such adjustment shall be in accordance with the applicable provisions of Section 14 and/or Section 15 of the Plan.

8. Distribution of Common Stock or Cash.

The Grantee shall receive a distribution of whole shares of Common Stock equal in number to the number of Units finally determined to be earned as set forth in Section 3 or Section 5(a) above, as the case may be, increased, if appropriate, as provided in Section 6 above (subject to the withholding requirements set forth in Section 9 below), provided the Grantee has been an employee of the Company or a Subsidiary with continuous service during the entire term of the measurement cycle, except in the event of the Grantee’s Termination of Service or Retirement as discussed above in Section 5. Distribution of shares of Common Stock shall occur as soon as administratively possible, as determined solely by the Company, following the last trading day of the quarter in which the measurement cycle ends as provided for in either Section 3 or Section 5(a) above, as the case may be (such day being referred to as the “Distribution Date”), but in no event later than 90 days following the Distribution Date. Notwithstanding the immediately preceding sentence, in the case of a distribution of shares of Common Stock on account of any Termination of Service as provided for in Section 5 above, other than death, a distribution of the number of such shares, determined after application of the withholding requirements set forth in Section 9 below, plus any dividends payable with respect to such number of shares, on behalf of the Grantee, if the Grantee is a "specified employee" as defined in §1.409A-1(i) of the Final Regulations under Code Section 409A, to the extent otherwise required under Section 409A, shall not occur until the date which is six (6) months following the date of the Grantee’s Termination of Service (or, if earlier, the date of death of the Grantee). Upon a distribution of shares of Common Stock as provided herein, the Company shall cause the Common Stock then being distributed to be registered in the Grantee’s name, but shall not issue certificates for the Common Stock unless the Grantee requests delivery of the certificates for the Common Stock, in writing in accordance with the procedures established by the Company. The Company shall deliver certificates to the Grantee as soon as administratively practicable following the Company’s receipt of a written request from the Grantee for delivery of the certificates. From and after the date of receipt of

such distribution, the Grantee or the Grantee's legal representatives, beneficiaries or heirs, as the case may be, shall have full rights of transfer or resale with respect to such shares subject to applicable state and federal regulations. Notwithstanding any provisions of this Award Agreement to the contrary, in lieu of a distribution of shares of Common Stock, the Company shall have the option to settle the payment of some or all of the Units in an economically equivalent amount of cash.

9. Withholding Requirements.

Upon the removal or lapse of the restrictions on the Units, the number of shares of Common Stock to be distributed by the Company to the Grantee, which are equal to the number of Units finally determined to be earned by the Grantee as set forth in Sections 3 or Section 5(a) and Section 6 above, or an economically equivalent amount of cash, as discussed in Section 8 above, shall be subject to applicable withholding requirements for income and employment taxes arising from the removal or lapse of the restrictions on the Units. However, if the Grantee is a "specified employee" as defined in §1.409A-1(i) of the Final Regulations under Code Section 409A who is subject to the six (6) months delay provided for in Section 8 above, the Company shall, on the date of the Grantee’s Termination of Service, based on the value of a share of Common Stock on such date, withhold the number of shares attributable to any employment taxes and shall, on the date which occurs six (6) months following the date of the Grantee’s Termination of Service (or, if earlier, the date of death of the Grantee), basedon the value of a share of Common Stock on such date, withhold the number of shares attributable to income taxes. Dividends for such delay period will also be payable to the Grantee on such date based on the final net number of shares.  

10. Modification.

This Award Agreement may be changed or modified without the Grantee's consent or signature, if the Company determines, in its sole discretion, that such change or modification is necessary for purposes of compliance with or exemption from the requirements of Section 409A of the Code and any regulations or other guidance issued thereunder, or otherwise to comply with any law.

Grantee acknowledges that as of the grant date, this Award Agreement and the Plan set forth the entire understanding between Grantee and the Company regarding the acquisition of the Units granted under the Plan and supersede all prior oral and written agreements on this subject. By Grantee’s electronic acceptance and the signature of the Company’s representative below, Grantee and the Company agree that the Units are granted under and governed by this Award Agreement and the Plan. Grantee has reviewed and fully understands all provisions of this Award Agreement and the Plan in their entirety.

ATMOS ENERGY CORPORATION

By: /s/ Kevin Akers        

Kevin Akers

President and

Chief Executive Officer

EX-21

Exhibit 21

SUBSIDIARIES OF ATMOS ENERGY CORPORATION

Name	State of Incorporation	Percent of Ownership
ATMOS ENERGY HOLDINGS, INC. (wholly owned by Atmos Energy Corporation)	Delaware	100%
BLUE FLAME INSURANCE SERVICES, LTD (wholly owned by Atmos Energy Corporation)	Bermuda	100%
ATMOS ENERGY LOUISIANA INDUSTRIAL GAS, LLC (a limited liability company) (wholly owned by Atmos Energy Holdings, Inc.)	Delaware	100%
ATMOS ENERGY SERVICES, LLC (a limited liability company) (wholly owned by Atmos Energy Holdings, Inc.)	Delaware	100%
EGASCO, LLC (a limited liability company) (wholly owned by Atmos Energy Holdings, Inc.)	Texas	100%
ATMOS POWER SYSTEMS, INC. (wholly owned by Atmos Energy Holdings, Inc.)	Georgia	100%
ATMOS PIPELINE AND STORAGE, LLC (a limited liability company) (wholly owned by Atmos Energy Holdings, Inc.)	Delaware	100%
UCG STORAGE, INC. (wholly owned by Atmos Pipeline and Storage, LLC)	Delaware	100%
WKG STORAGE, INC. (wholly owned by Atmos Pipeline and Storage, LLC)	Delaware	100%
ATMOS EXPLORATION AND PRODUCTION, INC. (wholly owned by Atmos Pipeline and Storage, LLC)	Delaware	100%
TRANS LOUISIANA GAS PIPELINE, INC. (wholly owned by Atmos Pipeline and Storage, LLC)	Louisiana	100%
TRANS LOUISIANA GAS STORAGE, INC. (wholly owned by Atmos Pipeline and Storage, LLC)	Delaware	100%
ATMOS GATHERING COMPANY, LLC (a limited liability company) (wholly owned by Atmos Pipeline and Storage, LLC)	Delaware	100%
PHOENIX GAS GATHERING COMPANY (wholly owned by Atmos Gathering Company, LLC)	Delaware	100%
FORT NECESSITY GAS STORAGE, LLC (a limited liability company) (wholly owned by Atmos Pipeline and Storage, LLC)	Delaware	100%

EX-23

Exhibit 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in the Registration Statements (Form S-3, No. 33-37869; Form S-3, No. 33-58220; Form S-3D/A, No. 33-70212; Form S-3, No. 33-56915; Form S-3/A, No. 333-03339; Form S-3/A, No. 333-32475; Form S-3/A, No. 333-50477; Form S-3, No. 333-95525; Form S-3/A, No. 333-93705; Form S-3, No. 333-75576; Form S-3D, No. 333-113603; Form S-3, No. 333-118706; Form S-3D, No. 333-155666; Form S-3D, No. 333-208317; Form S-3ASR, No. 333-236369; Form S-4, No. 333-13429; Form S-8, No. 33-57687; Form S-8, No. 33-57695; Form S-8, No. 333-32343; Form S-8, No. 333-46337; Form S-8, No. 333-73143; Form S-8, No. 333-73145; Form S-8, No. 333-63738; Form S-8, No. 333-88832; Form S-8, No. 333-116367; Form S-8, No. 333-138209; Form S-8, No. 333-145817; Form S-8, No. 333-155570; Form S-8, No. 333-166639; Form S-8, No. 333-177593; Form S-8, No. 333-199301; Form S-8, No. 333-210461; and Form S-8, No. 333-217739) of Atmos Energy Corporation and in the related Prospectuses of our reports dated November 13, 2020, with respect to the consolidated financial statements and schedule of Atmos Energy Corporation and the effectiveness of internal control over financial reporting of Atmos Energy Corporation, included in this Annual Report (Form 10-K) for the year ended September 30, 2020.

/s/ ERNST & YOUNG LLP

Dallas, Texas

November 13, 2020

EX-31

EXHIBIT 31

RULE 13a-14(a)/15d-14(a) CERTIFICATIONS

I, John K. Akers, certify that:

1. I have reviewed this Annual Report on Form 10-K of Atmos Energy Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and     

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: November 13, 2020

/s/ JOHN K. AKERS

John K. Akers

President and

Chief Executive Officer

I, Christopher T. Forsythe, certify that:

1. I have reviewed this Annual Report on Form 10-K of Atmos Energy Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and     

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing equivalent functions):

(a) All significant deficiencies or material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: November 13, 2020

/s/ CHRISTOPHER T. FORSYTHE

Christopher T. Forsythe

Senior Vice President and

Chief Financial Officer

EX-32

Exhibit 32

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

(18 U.S.C. SECTION 1350)

In connection with the Annual Report of Atmos Energy Corporation (the “Company”) on Form 10-K for the fiscal year ended September 30, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John K. Akers, President and Chief Executive Officer of the Company, certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to the best of my knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

November 13, 2020

/s/ JOHN K. AKERS

John K. Akers

President and

Chief Executive Officer

A signed original of this written statement has been provided to Atmos Energy Corporation and will be retained by Atmos Energy Corporation and furnished to the Securities and Exchange Commission or its staff upon request.

CERTIFICATION OF CHIEF FINANCIAL OFFICER

PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

(18 U.S.C. SECTION 1350)

In connection with the Annual Report of Atmos Energy Corporation (the “Company”) on Form 10-K for the fiscal year ended September 30, 2020, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Christopher T. Forsythe, Senior Vice President and Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to the best of my knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

November 13, 2020

/s/ CHRISTOPHER T. FORSYTHE

Christopher T. Forsythe

Senior Vice President and

Chief Financial Officer

A signed original of this written statement has been provided to Atmos Energy Corporation and will be retained by Atmos Energy Corporation and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Cover - USD ($)

12 Months Ended

Sep. 30, 2020

Nov. 06, 2020

Mar. 31, 2020

Cover [Abstract]

Document Type

10-K

Document Annual Report

true

Document Period End Date

Sep. 30, 2020

Document Transition Report

false

Entity File Number

1-10042

Entity Registrant Name

Atmos Energy Corp

Entity Incorporation, State or Country Code

TX

Entity Tax Identification Number

75-1743247

Entity Address, Address Line One

1800 Three Lincoln Centre

Entity Address, Address Line Two

5430 LBJ Freeway

Entity Address, City or Town

Dallas

Entity Address, State or Province

TX

Entity Address, Postal Zip Code

75240

City Area Code

972

Local Phone Number

934-9227

Title of 12(b) Security

Common stock

Trading Symbol

ATO

Security Exchange Name

NYSE

Entity Well Known Seasoned Issuer

Yes

Entity Voluntary Filers

No

Entity Current Reporting Status

Yes

Entity Interactive Data Current

Yes

ICFR Auditor Attestation Flag

true

Entity Filer Category

Large Accelerated Filer

Entity Small Business

false

Entity Emerging Growth Company

false

Entity Shell Company

false

Entity Public Float

$ 11,938,304,144

Entity Common Stock Shares Outstanding

125,889,456

Documents Incorporated by Reference

Portions of the registrant’s Definitive Proxy Statement to be filed for the Annual Meeting of Shareholders on February 3, 2021 are incorporated by reference into Part III of this report.

Entity Central Index Key

0000731802

Current Fiscal Year End Date

--09-30

Document Fiscal Year Focus

2020

Document Fiscal Period Focus

FY

Amendment Flag

false

XML

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
ASSETS
Property, plant and equipment	$ 15,539,166	$ 13,758,899
Construction in progress	418,055	421,694
Total property, plant and equipment and construction in progress	15,957,221	14,180,593
Less accumulated depreciation and amortization	2,601,874	2,392,924
Net property, plant and equipment	13,355,347	11,787,669
Current assets
Cash and cash equivalents	20,808	24,550
Accounts receivable, less allowance for doubtful accounts	230,595	230,571
Gas stored underground	111,950	130,138
Other current assets	107,905	72,772
Total current assets	471,258	458,031
Goodwill	731,257	730,706
Deferred charges and other assets	801,170	391,213
Total assets	15,359,032	13,367,619
Shareholders’ equity
Common stock, no par value (stated at $.005 per share); 200,000,000 shares authorized; issued and outstanding	629	597
Additional paid-in capital	4,377,149	3,712,194
Accumulated other comprehensive loss	(57,589)	(114,583)
Retained earnings	2,471,014	2,152,015
Shareholders’ equity	6,791,203	5,750,223
Long-term debt	4,531,779	3,529,452
Total capitalization	11,322,982	9,279,675
Commitments and contingencies
Current liabilities
Accounts payable and accrued liabilities	235,775	265,024
Other current liabilities	546,461	479,501
Short-term debt	0	464,915
Current maturities of long-term debt	165	0
Total current liabilities	782,401	1,209,440
Deferred income taxes	1,456,569	1,300,015
Regulatory excess deferred taxes	697,764	705,101
Regulatory cost of removal obligation	457,188	473,172
Deferred credits and other liabilities	642,128	400,216
Total shareholders' equity and liabilities	$ 15,359,032	$ 13,367,619

XML

CONSOLIDATED BALANCE SHEETS (PARENTHETICAL) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 29,949	$ 15,899
Common stock stated value per share (in dollars per share)	$ 0.005	$ 0.005
Common stock shares authorized (in shares)	200,000,000	200,000,000
Common stock shares issued (in shares)	125,882,477	119,338,925
Common stock shares outstanding (in shares)	125,882,477	119,338,925

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Operating revenues
Total operating revenues	$ 2,821,137	$ 2,901,848	$ 3,115,546
Total purchased gas cost	658,854	858,837	1,167,848
Operation and maintenance expense	629,601	630,308	594,795
Depreciation and amortization expense	429,828	391,456	361,083
Taxes, other than income	278,755	275,189	263,886
Operating income	824,099	746,058	727,934
Other non-operating income (expense)	7,171	7,404	(10,144)
Interest charges	84,474	103,153	106,646
Income from continuing operations before income taxes	746,796	650,309	611,144
Income tax expense	145,353	138,903	8,080
Net Income	$ 601,443	$ 511,406	$ 603,064
Basic net income per share	$ 4.89	$ 4.36	$ 5.43
Diluted net income per share	$ 4.89	$ 4.35	$ 5.43
Weighted average shares outstanding - basic	122,788	117,200	111,012
Weighted average shares outstanding - diluted	122,872	117,461	111,012
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Net unrealized holding gains (losses) on available-for-sale securities, net of tax	$ 106	$ 218	$ (395)
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), after Reclassification and Tax, Parent	56,888	(22,944)	44,936
Total other comprehensive income (loss)	56,994	(22,726)	44,541
Total comprehensive income	658,437	488,680	647,605
Natural Gas, US Regulated
Operating revenues
Total purchased gas cost	658,854	858,837	1,167,848
Distribution
Operating revenues
Total operating revenues	2,624,251	2,742,824	3,000,404
Pipeline and Storage
Operating revenues
Total operating revenues	196,886	159,024	115,142
Operating Segments | Distribution
Operating revenues
Total operating revenues	2,626,993	2,745,461	3,003,047
Total purchased gas cost	1,071,227	1,268,591	1,559,836
Operation and maintenance expense	472,760	480,222	461,048
Depreciation and amortization expense	309,582	283,697	264,930
Taxes, other than income	245,181	242,179	231,566
Operating income	528,243	470,772	485,667
Other non-operating income (expense)	(1,265)	6,241	(6,649)
Interest charges	39,634	60,031	65,850
Income from continuing operations before income taxes	487,344	416,982	413,168
Income tax expense	91,680	88,168	(29,798)
Net Income	395,664	328,814	442,966
Operating Segments | Distribution | Natural Gas, US Regulated
Operating revenues
Total purchased gas cost	1,071,227	1,268,591	1,559,836
Operating Segments | Pipeline and Storage
Operating revenues
Total operating revenues	609,339	567,024	507,713
Total purchased gas cost	1,548	(360)	1,978
Operation and maintenance expense	158,115	151,329	134,995
Depreciation and amortization expense	120,246	107,759	96,153
Taxes, other than income	33,574	33,010	32,320
Operating income	295,856	275,286	242,267
Other non-operating income (expense)	8,436	1,163	(3,495)
Interest charges	44,840	43,122	40,796
Income from continuing operations before income taxes	259,452	233,327	197,976
Income tax expense	53,673	50,735	37,878
Net Income	205,779	182,592	160,098
Operating Segments | Pipeline and Storage | Natural Gas, US Regulated
Operating revenues
Total purchased gas cost	1,548	(360)	1,978
Eliminations
Operating revenues
Total operating revenues	(415,195)	(410,637)	(395,214)
Total purchased gas cost	(413,921)	(409,394)	(393,966)
Operation and maintenance expense	(1,274)	(1,243)	(1,248)
Depreciation and amortization expense	0	0	0
Taxes, other than income	0	0	0
Operating income	0	0	0
Other non-operating income (expense)	0	0	0
Interest charges	0	0	0
Income from continuing operations before income taxes	0	0	0
Income tax expense	0	0	0
Net Income	0	0	0
Eliminations | Natural Gas, US Regulated
Operating revenues
Total purchased gas cost	(413,921)	(409,394)	(393,966)
Eliminations | Distribution
Operating revenues
Total operating revenues	2,742	2,637	2,643
Eliminations | Pipeline and Storage
Operating revenues
Total operating revenues	$ 412,453	$ 408,000	$ 392,571

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (PARENTHETICAL) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Statement of Comprehensive Income [Abstract]
Net unrealized holding gains (losses) on available-for-sale securities, tax	$ 32	$ 64	$ (146)
Amortization and unrealized gain (loss) on interest rate agreements, tax	$ 17,198	$ (6,782)	$ 13,017

XML

CONSOLIDATED STATEMENT OF SHAREHOLDERS' EQUITY - USD ($) $ in Thousands	Total	Common stock	Additional Paid-in Capital	Accumulated Other Comprehensive Income (Loss)	Retained Earnings	Cumulative effect of accounting change Accumulated Other Comprehensive Income (Loss)	Cumulative effect of accounting change Retained Earnings
Common stock shares outstanding, balance (in shares) at Sep. 30, 2017		106,104,634
Shareholders' equity, beginning balance at Sep. 30, 2017	$ 3,898,666	$ 531	$ 2,536,365	$ (105,254)	$ 1,467,024	$ (22,934)	$ 22,934
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	603,064				603,064
Other comprehensive income (loss)	44,541			44,541
Cash dividends	(214,906)				(214,906)
Common stock issued:
Public offering (in shares)		4,558,404
Public offering	395,092	$ 22	395,070
Direct stock purchase plan (in shares)		131,213
Direct stock purchase plan	11,323	$ 1	11,322
Retirement savings plan (in shares)		94,081
Retirement savings plan	8,240	$ 0	8,240
1998 Long-term incentive plan (in shares)		385,351
1998 Long-term incentive plan	3,471	$ 2	3,469
Employee stock-based compensation	20,460		20,460
Common stock shares outstanding, ending balance (in shares) at Sep. 30, 2018		111,273,683
Shareholders' equity, ending balance at Sep. 30, 2018	4,769,951	$ 556	2,974,926	(83,647)	1,878,116	(8,210)	$ 8,210
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	511,406				511,406
Other comprehensive income (loss)	(22,726)			(22,726)
Cash dividends	(245,717)				(245,717)
Common stock issued:
Public offering (in shares)		7,574,111
Public offering	694,103	$ 38	694,065
Direct stock purchase plan (in shares)		110,063
Direct stock purchase plan	11,071	$ 1	11,070
Retirement savings plan (in shares)		81,456
Retirement savings plan	8,252	$ 0	8,252
1998 Long-term incentive plan (in shares)		299,612
1998 Long-term incentive plan	2,948	$ 2	2,946
Employee stock-based compensation	$ 20,935		20,935
Common stock shares outstanding, ending balance (in shares) at Sep. 30, 2019	119,338,925	119,338,925
Shareholders' equity, ending balance at Sep. 30, 2019	$ 5,750,223	$ 597	3,712,194	(114,583)	2,152,015	$ (8,210)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	601,443				601,443
Other comprehensive income (loss)	56,994			56,994
Cash dividends	(282,444)				(282,444)
Common stock issued:
Public offering (in shares)		6,101,916
Public offering	624,302	$ 30	624,272
Direct stock purchase plan (in shares)		107,989
Direct stock purchase plan	11,326	$ 1	11,325
Retirement savings plan (in shares)		78,941
Retirement savings plan	8,222		8,222
1998 Long-term incentive plan (in shares)		254,706
1998 Long-term incentive plan	2,749	$ 1	2,748
Employee stock-based compensation	$ 18,388		18,388
Common stock shares outstanding, ending balance (in shares) at Sep. 30, 2020	125,882,477	125,882,477
Shareholders' equity, ending balance at Sep. 30, 2020	$ 6,791,203	$ 629	$ 4,377,149	$ (57,589)	$ 2,471,014

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CONSOLIDATED STATEMENT OF SHAREHOLDERS' EQUITY (PARENTHETICAL) - $ / shares	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Statement of Stockholders' Equity [Abstract]
Cash dividends per share (in dollars per share)	$ 2.30	$ 2.10	$ 1.94

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CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	$ 601,443	$ 511,406	$ 603,064
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	429,828	391,456	361,083
Deferred income taxes	155,322	132,004	158,271
One-time income tax benefit	(20,962)	0	(158,782)
Stock-based compensation	9,583	11,121	12,863
Amortization of debt issuance costs	11,543	9,464	7,865
Equity component of AFUDC	(23,493)	(11,165)	0
Other	8,411	1,169	5,437
Changes in assets and liabilities:
(Increase) decrease in accounts receivable	7,167	18,724	(29,208)
Decrease in gas stored underground	18,188	35,594	18,921
(Increase) decrease in other current assets	(35,878)	(26,590)	60,424
Increase in deferred charges and other assets	(31,935)	(58,403)	(10,049)
Increase (decrease) in accounts payable and accrued liabilities	7,359	9,908	(11,857)
Increase (decrease) in other current liabilities	(129,543)	(103,895)	74,707
Increase in deferred credits and other liabilities	30,966	47,976	31,923
Net cash provided by operating activities	1,037,999	968,769	1,124,662
CASH FLOWS USED IN INVESTING ACTIVITIES
Capital expenditures	(1,935,676)	(1,693,477)	(1,467,591)
Proceeds from the sale of discontinued operations	0	4,000	3,000
Purchases of debt and equity securities	(50,517)	(29,153)	(46,401)
Proceeds from sale of debt and equity securities	32,339	6,070	22,360
Maturities of debt securities	18,669	20,299	15,716
Other, net	9,667	8,601	9,350
Net cash used in investing activities	(1,925,518)	(1,683,660)	(1,463,566)
CASH FLOWS FROM FINANCING ACTIVITIES
Net increase (decrease) in short-term debt	(464,915)	(110,865)	128,035
Proceeds from issuance of long-term debt, net of premium/discount	999,450	1,045,221	0
Net proceeds from equity offering	624,302	694,103	395,092
Issuance of common stock through stock purchase and employee retirement plans	19,548	19,323	19,563
Settlement of interest rate swaps	(4,426)	(90,141)	0
Repayment of long-term debt	0	(575,000)	0
Cash dividends paid	(282,444)	(245,717)	(214,906)
Debt issuance costs	(7,738)	(11,254)	0
Other	0	0	(1,518)
Net cash provided by financing activities	883,777	725,670	326,266
Net increase (decrease) in cash and cash equivalents	(3,742)	10,779	(12,638)
Cash and cash equivalents at beginning of year	24,550	13,771	26,409
Cash and cash equivalents at end of year	$ 20,808	$ 24,550	$ 13,771

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Nature of Business

12 Months Ended

Sep. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Nature of Business

Nature of Business

Atmos Energy Corporation (Atmos Energy or the “Company”) and its subsidiaries are engaged in the regulated natural gas distribution and pipeline and storage businesses. Through our distribution business, we deliver natural gas through sales and transportation arrangements to 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 metropolitan area
Atmos Energy Mississippi Division	Mississippi
Atmos Energy West Texas Division	West Texas

 

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

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

Our pipeline and storage business, which is also subject to federal and state regulation, consists of the pipeline and storage operations of our Atmos Pipeline–Texas (APT) Division and our natural gas transmission business in Louisiana. The APT division provides transportation and storage services to our Mid-Tex Division, other third-party local distribution companies, industrial and electric generation customers, as well as marketers and producers. As part of its pipeline operations, APT manages five underground storage facilities in Texas. We also provide ancillary services customary to the pipeline industry including parking arrangements, lending and sales of inventory on hand. Our natural gas transmission operations in Louisiana are comprised of a 21-mile pipeline located in the New Orleans, Louisiana area that is primarily used to aggregate gas supply for our distribution division in Louisiana under a long-term contract and on a more limited basis, to third parties.

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Summary of Significant Accounting Policies

12 Months Ended

Sep. 30, 2020

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

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

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

Regulation — Our distribution and pipeline and storage operations are subject to regulation with respect to rates, service, maintenance of accounting records and various other matters by the respective regulatory authorities in the states in which we operate. Our accounting policies recognize the financial effects of the ratemaking and accounting practices and policies of the various regulatory commissions. Accounting principles generally accepted in the United States require cost-based, rate-regulated entities that meet certain criteria to reflect the authorized recovery of costs due to regulatory decisions in their financial statements. As a result, certain costs are permitted to be capitalized rather than expensed because they can be recovered through rates. We record certain costs as regulatory assets when future recovery through customer rates is considered probable. Regulatory liabilities are recorded when it is probable that revenues will be reduced for amounts that will be credited to customers through the ratemaking process. The amounts to be recovered or recognized are based upon historical experience and our understanding of the regulations. Further, regulation may impact the period in which revenues or expenses are recognized.

Substantially all of our regulatory assets are recorded as a component of 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, 2020 and 2019 included the following:

	September 30
	2020		2019
	(In thousands)
Regulatory assets:
Pension and postretirement benefit costs	$	149,089	$	86,089
Infrastructure mechanisms(1)	183,943		131,894
Deferred gas costs	40,593		23,766
Recoverable loss on reacquired debt	4,894		6,551
Deferred pipeline record collection costs	29,839		26,418
Other	6,283		9,829
	$	414,641	$	284,547
Regulatory liabilities:
Regulatory excess deferred taxes(2)	$	718,651	$	726,307
Regulatory cost of service reserve	1,716		5,238
Regulatory cost of removal obligation	531,096		528,893
Deferred gas costs	19,985		14,112
Asset retirement obligation	20,348		17,054
APT annual adjustment mechanism	57,379		78,402
Other	17,838		16,120
	$	1,367,013	$	1,386,126

(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) Due to the passage of the Kansas House Bill 2585, on June 1, 2020, we remeasured our deferred tax liability and updated our state deferred tax rate resulting in a $12.1 million regulatory liability as of September 30, 2020. The remaining amount reflects the remeasurement of the net deferred tax liability included in our rate base as a result of the Tax Cuts and Jobs Act of 2017 (the TCJA). Of this amount, $20.9 million as of September 30, 2020 and $21.2 million as of September 30, 2019 is recorded in other current liabilities. See Note 13 for further information.

As of September 30, 2020, we received regulatory orders in most states to defer into a regulatory asset all expenses, beyond the normal course of business, related to Coronavirus Disease 2019 (COVID-19), including bad debt expense. As of September 30, 2020, no amounts have been recorded as regulatory assets or liabilities for expenses related to COVID-19.

Revenue recognition

Distribution Revenues

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

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

Pipeline and Storage Revenues

Pipeline and storage revenues primarily represent the transportation and storage of natural gas on our APT system and the transmission of natural gas through our 21-mile pipeline in Louisiana. APT provides transportation and storage services to our Mid-Tex Division, other third party local distribution companies and certain industrial customers under tariff rates approved by

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

Alternative Revenue Program Revenues

In our distribution segment, we have weather-normalization adjustment mechanisms that serve to minimize the effects of weather on our residential and commercial revenues. Additionally, APT has a regulatory mechanism that requires that we share with its tariffed customers 75% of the difference between the total non-tariffed revenues earned during a test period and a revenue benchmark of $69.4 million that was established in its most recent rate case. Differences between actual revenues and revenues calculated under these mechanisms adjust the amount billed to customers. These mechanisms are considered to be alternative revenue programs under accounting standards generally accepted in the United States as they are deemed to be contracts between us and our regulator. Accordingly, revenue under these mechanisms are excluded from revenue from contracts with customers.

Purchased gas costs — Rates established by regulatory authorities are adjusted for increases and decreases in our purchased gas costs through purchased gas cost adjustment mechanisms. 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.

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 doubtful accounts — Accounts receivable arise from natural gas sales to residential, commercial, industrial, public authority and other customers. We establish an allowance for doubtful accounts to reduce the net receivable balance to the amount we reasonably expect to collect based on our collection experience or where we are aware of a specific customer’s inability or reluctance to pay. However, if circumstances change, our estimate of the recoverability of accounts receivable could be affected. Circumstances which could affect our estimates include, but are not limited to, customer credit issues, the level of natural gas prices, customer deposits and general economic conditions. Accounts are written off once they are deemed to be uncollectible.

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

Property, plant and equipment — Regulated property, plant and equipment is stated at original cost, net of contributions in aid of construction. The cost of additions includes direct construction costs, payroll related costs (taxes, pensions and other benefits), administrative and general costs and an allowance for funds used during construction. The allowance for funds used during construction (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.

		2020		2019		2018
Component of AFUDC	Statement of Comprehensive Income Location	(In thousands)
Debt	Interest charges	$	8,436	$	7,643	$	6,810
Equity	Other non-operating income (expense)	23,493		11,165		—
		$	31,929	$	18,808	$	6,810

Major renewals, including replacement pipe, and betterments that are recoverable through our regulatory rate base are capitalized while the costs of maintenance and repairs that are not capitalizable are charged to expense as incurred. The costs of

large projects are accumulated in construction in progress until the project is completed. When the project is completed, tested and placed in service, the balance is transferred to the regulated plant in service account included in the rate base and depreciation begins.

Regulated property, plant and equipment is depreciated at various rates on a straight-line basis. These rates are approved by our regulatory commissions and are comprised of two components: one based on average service life and one based on cost of removal. Accordingly, we recognize our cost of removal expense as a component of depreciation expense. The related cost of removal accrual is reflected as a regulatory liability on the consolidated balance sheet. At the time property, plant and equipment is retired, removal expenses less salvage, are charged to the regulatory cost of removal accrual. The composite depreciation rate was 3.0 percent, 3.1 percent and 3.2 percent for the fiscal years ended September 30, 2020, 2019 and 2018.

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. Accretion of the asset retirement obligation due to the passage of time is recorded as an operating expense.

As of September 30, 2020 and 2019, we had asset retirement obligations of $20.3 million and $17.1 million. Additionally, we had $14.4 million and $11.3 million of asset retirement costs recorded as a component of property, plant and equipment that will be depreciated over the remaining life of the underlying associated assets.

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 2020, we completed our annual goodwill impairment assessment using a qualitative assessment, as permitted under U.S. GAAP. 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 2020 analysis, if the qualitative 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 assets and lease liabilities within the consolidated balance sheet. See Note 6 for further discussion regarding the accounting polices for these leases.

Marketable securities — As of September 30, 2020, we hold marketable securities classified as either equity or debt securities. Beginning on October 1, 2018, 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). During fiscal 2018 and under the previous accounting guidance, all our debt and equity securities were considered available for sale securities.

We regularly evaluate the performance of our available for sale debt securities on an investment by investment basis for impairment, taking into consideration the securities’ purpose, volatility and current returns. If a determination is made that a decline in fair value is other than temporary, 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 14.

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

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

Financial Instruments Associated with Commodity Price Risk

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

Financial Instruments Associated with Interest Rate Risk

In connection with the planned issuance of long-term debt, we may use financial instruments to manage interest rate risk. We currently manage this risk through the use of forward starting interest rate swaps to fix the Treasury yield component of the interest cost associated with anticipated financings. We designate these financial instruments as cash flow hedges at the time the agreements are executed. Unrealized gains and losses associated with the instruments are recorded as a component of accumulated other comprehensive income (loss). When the instruments settle, the realized gain or loss is recorded as a component of accumulated other comprehensive income (loss) and recognized as a component of interest charges over the life of the related financing arrangement. As of September 30, 2020 and 2019, no cash was required to be held in margin accounts.

Fair Value Measurements — We report certain assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We primarily use quoted market prices and other observable market pricing information in valuing our financial assets and liabilities and minimize the use of unobservable pricing inputs in our measurements.

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

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

Authoritative accounting literature establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority given to unobservable inputs (Level 3). The levels of the hierarchy are described below:

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

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

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

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

Pension and other postretirement plans — Pension and other postretirement plan costs and liabilities are determined on an actuarial basis and are affected by numerous assumptions and estimates including the market value of plan assets, estimates of the expected return on plan assets, assumed discount rates and current demographic and actuarial mortality data. Our measurement date is September 30. The assumed discount rate and the expected return are the assumptions that generally have the most significant impact on our pension costs and liabilities. The assumed discount rate, the assumed health care cost trend rate and assumed rates of retirement generally have the most significant impact on our postretirement plan costs and liabilities. For the valuation performed as of September 30, 2020, decreases in the discount rate resulted in actuarial losses that increased our plan obligations.

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

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

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

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

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

On October 1, 2018 we adopted new accounting guidance, which required we present only the current service cost component of the net benefit cost within operations and maintenance expense in the consolidated statements of comprehensive income. The remaining components of net benefit cost are recorded in other non-operating income (expense) in our consolidated statements of comprehensive income. The change in presentation of these costs was implemented on a retrospective basis as required by the guidance. In lieu of determining how each component of the net periodic benefit cost was actually reflected in the fiscal 2018 statement of comprehensive income, we elected to utilize a practical expedient that permits the use of the amounts disclosed for these costs in our pension and post-retirement benefit plans footnote as the basis to retroactively apply this standard.

In addition, only the service cost component of net benefit cost is eligible for capitalization and we continue to capitalize these costs into property, plant and equipment. Additionally, we defer into a regulatory asset the portion of non-service components of net periodic benefit cost that are capitalizable for regulatory purposes.

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

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

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

Contingencies — In the normal course of business, we are confronted with issues or events that may result in a contingent liability. These generally relate to lawsuits, claims made by third parties or the action of various regulatory agencies. For such matters, we record liabilities when they are considered probable and estimable, based on currently available facts and our estimates of the ultimate outcome or resolution of the liability in the future. Actual results may differ from estimates, depending on actual outcomes or changes in the facts or expectations surrounding each potential exposure.

Subsequent events — Except as noted in Note 7 regarding the public offering of senior notes, no events occurred subsequent to the balance sheet date that would require recognition or disclosure in the financial statements.

Recent accounting pronouncements

Accounting pronouncements adopted in fiscal 2020

In February 2016, the Financial Accounting Standards Board (FASB) issued a comprehensive new leasing standard that requires lessees to recognize a lease liability and a right-of-use (ROU) asset for all leases, including operating leases on its balance sheet. The new standard was effective for us beginning on October 1, 2019. See Note 6 to the consolidated financial statements for further details regarding our adoption of the new lease standard and the related disclosures.

Accounting pronouncements that will be effective after fiscal 2020

In March 2020, the 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 relationships 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. We are currently evaluating if we will apply the optional guidance as we assess the impact of the cessation of LIBOR on our current contracts and hedging relationships and the potential impact on our financial position, results of operations and cash flows.

In December 2019, the FASB issued new guidance related to accounting for income taxes which removes certain exceptions for recognizing deferred taxes for investments, performing intraperiod allocations and calculating income taxes in interim periods. The new standard also adds guidance to reduce complexity in certain areas, such as recognizing deferred taxes for tax goodwill and allocating taxes to members of a consolidated group. The new standard will be effective for us beginning on October 1, 2021; early adoption is permitted. We do not believe the new standard will have a material impact on our financial position, results of operations and cash flows. 

In June 2016, the FASB issued new guidance which will require 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, entities will estimate credit losses over the entire contractual term of the instrument from the date of initial recognition of that instrument. In contrast, current U.S. GAAP is based on an incurred loss model that delays recognition of credit losses until it is probable the loss has been incurred. The new guidance also introduces a new impairment recognition model for available-for-sale debt

securities that will require credit losses for available-for-sale debt securities to be recorded through an allowance account. The new standard was effective for us beginning on October 1, 2020. We do not anticipate the adoption of this standard will have a material impact to our financial position, results of operations and cash flows.

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Segment Information

12 Months Ended

Sep. 30, 2020

Segment Reporting [Abstract]

Segment Information

Segment Information

As of September 30, 2020, we manage and review our consolidated operations through the following two reportable segments:

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

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

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

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

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

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

	Year Ended September 30, 2019
	Distribution		Pipeline and Storage			Eliminations			Consolidated
	(In thousands)
Operating revenues from external parties	$	2,742,824	$	159,024		$	—		$	2,901,848
Intersegment revenues	2,637		408,000			(410,637		)	—
Total operating revenues	2,745,461		567,024			(410,637		)	2,901,848
Purchased gas cost	1,268,591		(360		)	(409,394		)	858,837
Operation and maintenance expense	480,222		151,329			(1,243		)	630,308
Depreciation and amortization expense	283,697		107,759			—			391,456
Taxes, other than income	242,179		33,010			—			275,189
Operating income	470,772		275,286			—			746,058
Other non-operating income	6,241		1,163			—			7,404
Interest charges	60,031		43,122			—			103,153
Income before income taxes	416,982		233,327			—			650,309
Income tax expense	88,168		50,735			—			138,903
Net income	$	328,814	$	182,592		$	—		$	511,406
Capital expenditures	$	1,274,613	$	418,864		$	—		$	1,693,477

	Year Ended September 30, 2018
	Distribution			Pipeline and Storage			Eliminations			Consolidated
	(In thousands)
Operating revenues from external parties	$	3,000,404		$	115,142		$	—		$	3,115,546
Intersegment revenues	2,643			392,571			(395,214		)	—
Total operating revenues	3,003,047			507,713			(395,214		)	3,115,546
Purchased gas cost	1,559,836			1,978			(393,966		)	1,167,848
Operation and maintenance expense	461,048			134,995			(1,248		)	594,795
Depreciation and amortization expense	264,930			96,153			—			361,083
Taxes, other than income	231,566			32,320			—			263,886
Operating income	485,667			242,267			—			727,934
Other non-operating expense	(6,649		)	(3,495		)	—			(10,144		)
Interest charges	65,850			40,796			—			106,646
Income before income taxes	413,168			197,976			—			611,144
Income tax expense (benefit)	(29,798		)	37,878			—			8,080
Net income	$	442,966		$	160,098		$	—		$	603,064
Capital expenditures	$	1,025,800		$	441,791		$	—		$	1,467,591

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

	2020		2019		2018
	(In thousands)
Distribution revenues:
Gas sales revenues:
Residential	$	1,717,070	$	1,733,548	$	1,916,101
Commercial	654,963		711,284		797,073
Industrial	89,641		118,046		131,267
Public authority and other	42,007		42,613		47,714
Total gas sales revenues	2,503,681		2,605,491		2,892,155
Transportation revenues	97,441		95,629		99,250
Other gas revenues	23,129		41,704		8,999
Total distribution revenues	2,624,251		2,742,824		3,000,404
Pipeline and storage revenues	196,886		159,024		115,142
Total operating revenues	$	2,821,137	$	2,901,848	$	3,115,546

Balance sheet information at September 30, 2020 and 2019 by segment is presented in the following tables.

	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

	September 30, 2019
	Distribution		Pipeline and Storage		Eliminations			Consolidated
	(In thousands)
Property, plant and equipment, net	$	8,737,590	$	3,050,079	$	—		$	11,787,669
Total assets	$	12,579,741	$	3,279,323	$	(2,491,445	)	$	13,367,619

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Earnings Per Share

12 Months Ended

Sep. 30, 2020

Earnings Per Share [Abstract]

Earnings Per Share

Earnings Per Share

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

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

	2020		2019		2018
	(In thousands, except per share data)
Basic Earnings Per Share
Net Income	$	601,443	$	511,406	$	603,064
Less: Income allocated to participating securities	444		416		580
Net Income available to common shareholders	$	600,999	$	510,990	$	602,484
Basic weighted average shares outstanding	122,788		117,200		111,012
Net Income per share — Basic	$	4.89	$	4.36	$	5.43
Diluted Earnings Per Share
Net Income available to common shareholders	$	600,999	$	510,990	$	602,484
Effect of dilutive shares	—		—		—
Net Income available to common shareholders	$	600,999	$	510,990	$	602,484
Basic weighted average shares outstanding	122,788		117,200		111,012
Dilutive shares	84		261		—
Diluted weighted average shares outstanding	122,872		117,461		111,012
Net Income per share — Diluted	$	4.89	$	4.35	$	5.43

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Revenue Revenue

12 Months Ended

Sep. 30, 2020

Revenue [Abstract]

Revenue

Revenue

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

	Year Ended September 30, 2020					Year Ended September 30, 2019
	Distribution		Pipeline and Storage			Distribution			Pipeline and Storage
	(In thousands)
Gas sales revenues:
Residential	$	1,704,444	$	—		$	1,755,229		$	—
Commercial	650,396		—			716,757			—
Industrial	89,467		—			118,060			—
Public authority and other	41,339		—			42,796			—
Total gas sales revenues	2,485,646		—			2,632,842			—
Transportation revenues	99,435		636,819			97,495			623,808
Miscellaneous revenues	19,085		9,754			26,050			8,060
Revenues from contracts with customers	2,604,166		646,573			2,756,387			631,868
Alternative revenue program revenues(1)	20,856		(37,234		)	(12,958		)	(64,844		)
Other revenues	1,971		—			2,032			—
Total operating revenues	$	2,626,993	$	609,339		$	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.

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Leases

12 Months Ended

Sep. 30, 2020

Leases [Abstract]

Leases

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 standard.

The new guidance included several practical expedients to facilitate the implementation of the new standard. The following summarizes the practical expedients we used to implement the standard.

•We elected to bundle our lease and non-lease components as a single component for all asset classes.

•We elected not to perform the following:

◦Evaluate existing or expired land easements prior to October 1, 2019 to determine if they are leases.

◦Include short-term leases in the calculation of our lease liability.

◦Evaluate existing or expired contracts to determine if they are leases.

◦Assess lease classification for existing or expired leases.

◦Review initial direct costs for existing leases.

◦Use hindsight in order to determine the lease term or impairment of our ROU assets.

Upon adoption of this new guidance, we recorded ROU assets and lease liabilities of $231.3 million. Additionally, we reclassified a net $6.5 million of accrued and prepaid lease costs to the ROU asset and $2.5 million related to an existing finance lease from deferred credits and other liabilities to long-term debt.

Implementation of the new lease accounting guidance had no material impact on our consolidated statements of comprehensive income or our consolidated statements of cash flows. Additionally, we did not record a cumulative-effect adjustment to retained earnings on the opening balance sheet.

New Lease Accounting Policy

We determine if an arrangement is a lease at the inception of the agreement based on the terms and conditions in the contract. A contract contains a lease if there is an identified asset and we have the right to control the asset. We are the lessee for substantially all of our leasing 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.

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

	September 30, 2020
Weighted average remaining lease term (years)
Finance leases	19.1
Operating leases	10.6

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

The following table represents our weighted average discount rate:

	September 30, 2020
Weighted average discount rate
Finance leases	8.0	%
Operating leases	2.9	%

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.

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.

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

	September 30, 2020
	(In thousands)
Finance lease cost	$	622
Operating lease cost	40,887
Total lease cost	$	41,509

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

	Balance Sheet Classification	September 30, 2020
		(In thousands)
Assets
Finance leases	Net Property, Plant and Equipment	$	8,480
Operating leases	Deferred charges and other assets	227,146
Total right-of-use assets		$	235,626
Liabilities
Current
Finance leases	Current maturities of long-term debt	$	165
Operating leases	Other current liabilities	35,716
Noncurrent
Finance leases	Long-term debt	8,466
Operating leases	Deferred credits and other liabilities	201,071
Total lease liabilities		$	245,418

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

	September 30, 2020
	(In thousands)
Cash paid amounts included in the measurement of lease liabilities
Operating cash flows used for operating leases	$	37,758
Right-of-use assets obtained in exchange for lease obligations
Finance leases	$	6,083
Operating leases	$	34,169

Maturities of our lease liabilities as of September 30, 2020 were as follows:

	Total		Finance Leases		Operating Leases
	(In thousands)
2021	$	40,790	$	741	$	40,049
2022	38,423		751		37,672
2023	33,266		762		32,504
2024	25,464		773		24,691
2025	17,666		784		16,882
Thereafter	139,049		12,666		126,383
Total lease payments	294,658		16,477		278,181
Less: Imputed interest	49,240		7,846		41,394
Total	$	245,418	$	8,631	$	236,787
Reported as of September 30, 2020
Short-term lease liabilities	$	35,881	$	165	$	35,716
Long-term lease liabilities	209,537		8,466		201,071
Total lease liabilities	$	245,418	$	8,631	$	236,787

Disclosures Related to Prior Periods

The future minimum lease payments as of September 30, 2019 were as follows:

	Operating Leases(1)		Capital Lease
	(In thousands)
2020	$	21,017	$	243
2021	20,416		248
2022	19,370		253
2023	18,071		258
2024	15,718		263
Thereafter	105,544		4,343
Total minimum lease payments	$	200,136	5,608
Less amount representing interest			3,018
Present value of net minimum lease payments			$	2,590

(1) Future minimum lease payments do not include amounts for fleet leases and other de minimis items that can be renewed beyond the initial lease term. The Company anticipates renewing the leases beyond the initial term, but the anticipated payments associated with the renewals do not meet the definition of expected minimum lease payments and therefore are not included above. Expected payments are $17.6 million in 2020, $18.0 million in 2021, $11.8 million in 2022, $8.5 million in 2023, $5.4 million in 2024 and $2.7 million thereafter.

Consolidated lease and rental expense amounted to $40.4 million and $33.8 million for fiscal 2019 and 2018.

Leases

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 standard.

The new guidance included several practical expedients to facilitate the implementation of the new standard. The following summarizes the practical expedients we used to implement the standard.

•We elected to bundle our lease and non-lease components as a single component for all asset classes.

•We elected not to perform the following:

◦Evaluate existing or expired land easements prior to October 1, 2019 to determine if they are leases.

◦Include short-term leases in the calculation of our lease liability.

◦Evaluate existing or expired contracts to determine if they are leases.

◦Assess lease classification for existing or expired leases.

◦Review initial direct costs for existing leases.

◦Use hindsight in order to determine the lease term or impairment of our ROU assets.

Upon adoption of this new guidance, we recorded ROU assets and lease liabilities of $231.3 million. Additionally, we reclassified a net $6.5 million of accrued and prepaid lease costs to the ROU asset and $2.5 million related to an existing finance lease from deferred credits and other liabilities to long-term debt.

Implementation of the new lease accounting guidance had no material impact on our consolidated statements of comprehensive income or our consolidated statements of cash flows. Additionally, we did not record a cumulative-effect adjustment to retained earnings on the opening balance sheet.

New Lease Accounting Policy

We determine if an arrangement is a lease at the inception of the agreement based on the terms and conditions in the contract. A contract contains a lease if there is an identified asset and we have the right to control the asset. We are the lessee for substantially all of our leasing 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.

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

	September 30, 2020
Weighted average remaining lease term (years)
Finance leases	19.1
Operating leases	10.6

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

The following table represents our weighted average discount rate:

	September 30, 2020
Weighted average discount rate
Finance leases	8.0	%
Operating leases	2.9	%

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.

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.

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

	September 30, 2020
	(In thousands)
Finance lease cost	$	622
Operating lease cost	40,887
Total lease cost	$	41,509

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

	Balance Sheet Classification	September 30, 2020
		(In thousands)
Assets
Finance leases	Net Property, Plant and Equipment	$	8,480
Operating leases	Deferred charges and other assets	227,146
Total right-of-use assets		$	235,626
Liabilities
Current
Finance leases	Current maturities of long-term debt	$	165
Operating leases	Other current liabilities	35,716
Noncurrent
Finance leases	Long-term debt	8,466
Operating leases	Deferred credits and other liabilities	201,071
Total lease liabilities		$	245,418

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

	September 30, 2020
	(In thousands)
Cash paid amounts included in the measurement of lease liabilities
Operating cash flows used for operating leases	$	37,758
Right-of-use assets obtained in exchange for lease obligations
Finance leases	$	6,083
Operating leases	$	34,169

Maturities of our lease liabilities as of September 30, 2020 were as follows:

	Total		Finance Leases		Operating Leases
	(In thousands)
2021	$	40,790	$	741	$	40,049
2022	38,423		751		37,672
2023	33,266		762		32,504
2024	25,464		773		24,691
2025	17,666		784		16,882
Thereafter	139,049		12,666		126,383
Total lease payments	294,658		16,477		278,181
Less: Imputed interest	49,240		7,846		41,394
Total	$	245,418	$	8,631	$	236,787
Reported as of September 30, 2020
Short-term lease liabilities	$	35,881	$	165	$	35,716
Long-term lease liabilities	209,537		8,466		201,071
Total lease liabilities	$	245,418	$	8,631	$	236,787

Disclosures Related to Prior Periods

The future minimum lease payments as of September 30, 2019 were as follows:

	Operating Leases(1)		Capital Lease
	(In thousands)
2020	$	21,017	$	243
2021	20,416		248
2022	19,370		253
2023	18,071		258
2024	15,718		263
Thereafter	105,544		4,343
Total minimum lease payments	$	200,136	5,608
Less amount representing interest			3,018
Present value of net minimum lease payments			$	2,590

(1) Future minimum lease payments do not include amounts for fleet leases and other de minimis items that can be renewed beyond the initial lease term. The Company anticipates renewing the leases beyond the initial term, but the anticipated payments associated with the renewals do not meet the definition of expected minimum lease payments and therefore are not included above. Expected payments are $17.6 million in 2020, $18.0 million in 2021, $11.8 million in 2022, $8.5 million in 2023, $5.4 million in 2024 and $2.7 million thereafter.

Consolidated lease and rental expense amounted to $40.4 million and $33.8 million for fiscal 2019 and 2018.

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Debt

12 Months Ended

Sep. 30, 2020

Debt Disclosure [Abstract]

Debt

Debt

Long-term debt

Long-term debt at September 30, 2020 and 2019 consisted of the following:

	2020		2019
	(In thousands)
Unsecured 3.00% Senior Notes, due 2027	$	500,000	$	500,000
Unsecured 2.625% Senior Notes, due 2029	300,000		—
Unsecured 5.95% Senior Notes, due 2034	200,000		200,000
Unsecured 5.50% Senior Notes, due 2041	400,000		400,000
Unsecured 4.15% Senior Notes, due 2043	500,000		500,000
Unsecured 4.125% Senior Notes, due 2044	750,000		750,000
Unsecured 4.30% Senior Notes, due 2048	600,000		600,000
Unsecured 4.125% Senior Notes, due 2049	450,000		450,000
Unsecured 3.375% Senior Notes, due 2049	500,000		—
Floating-rate term loan, due 2022	200,000		—
Medium term Series A notes, 1995-1, 6.67%, due 2025	10,000		10,000
Unsecured 6.75% Debentures, due 2028	150,000		150,000
Finance lease obligations (see Note 6)	8,631		—
Total long-term debt	4,568,631		3,560,000
Less:
Net original issue (premium) / discount on unsecured senior notes and debentures	583		193
Debt issuance cost	36,104		30,355
Current maturities	165		—
	$	4,531,779	$	3,529,452

    

Maturities of long-term debt, excluding our finance lease obligations, at September 30, 2020 were as follows (in thousands):

2021	$	—
2022	200,000
2023	—
2024	—
2025	10,000
Thereafter	4,350,000
	$	4,560,000

On October 1, 2020, we completed a public offering of $600 million of 1.50% senior notes due 2031. The net proceeds from the offering, after the underwriting discount and estimated offering expenses, of $592.5 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. The effective interest rate on these notes is 1.71%, after giving effect to the offering costs.

On April 9, 2020, we entered into a two year, $200 million term loan agreement that bears interest at a rate of LIBOR plus 1.25 percent. The term loan was used to pay down borrowings pursuant to our commercial paper program.

On October 2, 2019, 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. We received net proceeds from the offering, after the underwriting discount and offering expenses, of $791.7 million, that were used for general corporate purposes, including the repayment of working capital

borrowings pursuant to our commercial paper program. The effective interest rate on these notes was 2.72% and 3.42%, after giving effect to the offering costs.

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-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. Changes in the price of natural gas and the amount of natural gas we need to supply our customers’ needs could significantly affect our borrowing requirements. Our short-term borrowings typically reach their highest levels in the winter months.

As of September 30, 2020, our short-term borrowing requirements were satisfied through a combination of a $1.5 billion commercial paper program and four committed revolving credit facilities with third-party lenders that provide $2.2 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 expires on September 25, 2023. The 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 1.25 percent, 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, 2020, there were no amounts outstanding under our commercial paper program. At September 30, 2019, a total of $464.9 million was outstanding with weighted average interest rates of 2.24% and weighted average maturities of less than one month.

Additionally, we had a $25 million 364-day unsecured facility that was renewed on April 1, 2020 and increased to $50 million, which is used to provide working capital funding. There were no borrowings outstanding under this facility as of September 30, 2020.

Finally, we had a $10 million 364-day unsecured revolving credit facility, which was replaced on April 30, 2020, with a new $50 million 364-day unsecured revolving credit facility, which is used to issue letters of credit and to provide working capital funding. At September 30, 2020, there were no borrowings outstanding under the new facility; however, outstanding letters of credit reduced the total amount available to us under our $50 million unsecured revolving facility to $44.4 million.

On April 23, 2020, we executed a new $600 million 364-day unsecured revolving credit facility to provide additional working capital funding. The 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 1.25 percent, based on the Company's credit ratings. At September 30, 2020, there were no borrowings outstanding under this facility.

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, 2020, our total-debt-to-total-capitalization ratio, as defined, was 42 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, 2020. 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.

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Shareholders' Equity

12 Months Ended

Sep. 30, 2020

Equity [Abstract]

Shareholders' Equity

Shareholders' Equity

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

On February 11, 2020, we filed a shelf registration statement with the Securities and Exchange Commission (SEC) that allows us to issue up to $4.0 billion in common stock and/or debt securities, which expires February 11, 2023. This shelf registration statement replaced our previous shelf registration statement which was filed on November 13, 2018 (2018 Registration Statement). At September 30, 2020, approximately $3.0 billion of securities remained available for issuance under

the shelf registration statement. Following the completion of the $600 million senior unsecured note offering on October 1, 2020 (see Note 7), approximately $2.4 billion of securities remained available for issuance under the shelf registration statement.

On February 12, 2020, we filed a prospectus supplement under the shelf registration statement relating to an at-the-market (ATM) equity sales program (February 2020 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 November 19, 2018 (November 2018 ATM), which was exhausted during the second quarter of fiscal 2020.

During the year ended September 30, 2020, we executed forward sales under the February 2020 ATM and the November 2018 ATM equity sales programs with various forward sellers who borrowed and sold 4,808,051 shares of our common stock for $523.2 million. Additionally, during the year ended September 30, 2020, we settled forward sale agreements with respect to 5,616,727 shares that had been borrowed and sold by various forward sellers under the November 2018 ATM and the February 2020 ATM for net proceeds of $581.5 million. As of September 30, 2020, the February 2020 ATM program had approximately $552 million of equity available for issuance.

On November 30, 2018, we filed a prospectus supplement under the registration statement relating to an underwriting agreement to sell 5,390,836 shares of our common stock for $500 million. After expenses, net proceeds from the offering were $494.1 million. Concurrently, we entered into separate forward sale agreements with two forward sellers who borrowed and sold 2,668,464 shares of our common stock for $247.5 million. During the year ended September 30, 2019, we settled forward sale agreements with respect to 2,183,275 of the shares that had been borrowed and sold for net proceeds of $200.0 million. During the year ended September 30, 2020, we settled the remaining 485,189 shares for net proceeds of $44.4 million.

During the year ended September 30, 2019, we executed forward sales under the November 2018 ATM with various forward sellers who borrowed and sold 4,144,671 shares of our common stock at an aggregate price of $425.0 million.

If we had settled all shares that remain available under our outstanding forward sale agreements as of September 30, 2020, we would have received proceeds of $345.2 million, based on a net price of $103.48 per share. Additional details are presented below.

Maturity	Shares Available	Net Proceeds Available (In Thousands)		Forward Price
March 31, 2021	1,281,578	$	134,660	$	105.07
June 30, 2021	1,394,423	142,388		$	102.11
September 30, 2021	659,994	68,158		$	103.27
Total	3,335,995	$	345,206

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).

	Available- for-Sale Securities			Interest Rate Agreement Cash Flow Hedges			Total
	(In thousands)
September 30, 2019	$	132		$	(114,715	)	$	(114,583	)
Other comprehensive income before reclassifications	108			53,241			53,349
Amounts reclassified from accumulated other comprehensive income	(2		)	3,647			3,645
Net current-period other comprehensive income	106			56,888			56,994
September 30, 2020	$	238		$	(57,827	)	$	(57,589	)

	Available- for-Sale Securities			Interest Rate Agreement Cash Flow Hedges			Total
	(In thousands)
September 30, 2018	$	8,124		$	(91,771	)	$	(83,647	)
Other comprehensive income (loss) before reclassifications	219			(25,966		)	(25,747		)
Amounts reclassified from accumulated other comprehensive income	(1		)	3,022			3,021
Net current-period other comprehensive income (loss)	218			(22,944		)	(22,726		)
Cumulative effect of accounting change	(8,210		)	—			(8,210		)
September 30, 2019	$	132		$	(114,715	)	$	(114,583	)

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Retirement and Post-Retirement Employee Benefit Plans

12 Months Ended

Sep. 30, 2020

Retirement Benefits [Abstract]

Retirement and Post-Retirement Employee Benefit Plans

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 recoverable through our rates over a period of up to 15 years. A portion of these costs is capitalized into our rate base or deferred as a regulatory asset or liability. The remaining costs are recorded as a component of operation and maintenance expense or other non-operating expense. Additionally, the amounts that have not yet been recognized in net periodic pension cost that have been recorded as regulatory assets or liabilities are as follows:

	Defined Benefit Plan			Supplemental Executive Retirement Plans		Postretirement Plans			Total
	(In thousands)
September 30, 2020
Unrecognized prior service (credit) cost	$	(584	)	$	—	$	951		$	367
Unrecognized actuarial loss	78,082			51,045		9,110			138,237
	$	77,498		$	51,045	$	10,061		$	138,604
September 30, 2019
Unrecognized prior service (credit) cost	$	(815	)	$	—	$	1,125		$	310
Unrecognized actuarial (gain) loss	67,191			56,784		(43,782		)	80,193
	$	66,376		$	56,784	$	(42,657	)	$	80,503

Defined Benefit Plans

Employee Pension Plan

As of September 30, 2020, we maintained one cash balance defined benefit plan, the Atmos Energy Corporation 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 2020, we did not make a contribution to the Plan. During fiscal 2019 we contributed $8.5 million in cash to the Plan to achieve a desired level of funding while maximizing the tax deductibility of this payment. Based upon market conditions at September 30, 2020, the current funded position of the Plan and the funding requirements under the PPA, we do not anticipate a minimum required contribution for fiscal 2021. However, we may consider whether a voluntary contribution is prudent to maintain certain funding levels.

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

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

The following table presents asset allocation information for the Master Trust as of September 30, 2020 and 2019.

	Targeted Allocation  Range	Actual Allocation September 30
Security Class		2020	2019
Domestic equities	35%-55%	45.3%	40.6%
International equities	10%-20%	15.6%	14.5%
Fixed income	5%-30%	17.0%	18.8%
Company stock	0%-15%	13.0%	15.4%
Other assets	0%-20%	9.1%	10.7%

At September 30, 2020 and 2019, the Plan held 716,700 shares of our common stock which represented 13.0 percent and 15.4 percent of total Plan assets. These shares generated dividend income for the Plan of approximately $1.6 million and $1.5 million during fiscal 2020 and 2019.

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 development of our assumptions is fully described in our significant accounting policies in Note 2. The actuarial assumptions used to determine the pension liability for the Plan was determined as of September 30, 2020 and 2019 and the actuarial assumptions used to determine the net periodic pension cost for the Plan was determined as of September 30, 2019, 2018 and 2017. On October 21, 2020, 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, 2020, we updated our assumed mortality rates to incorporate the updated mortality table.

Additional assumptions are presented in the following table:

	Pension Liability				Pension Cost
	2020		2019		2020		2019		2018
Discount rate	2.80	%	3.29	%	3.29	%	4.38	%	3.89	%
Rate of compensation increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%
Expected return on plan assets	6.25	%	6.50	%	6.50	%	6.75	%	6.75	%
Interest crediting rate	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, 2020 and 2019:

	2020			2019
	(In thousands)
Accumulated benefit obligation	$	565,755		$	541,287
Change in projected benefit obligation:
Benefit obligation at beginning of year	$	577,270		$	504,719
Service cost	17,551			15,311
Interest cost	19,028			22,071
Actuarial (gain) loss	22,898			71,139
Benefits paid	(32,526		)	(35,970		)
Benefit obligation at end of year	604,221			577,270
Change in plan assets:
Fair value of plan assets at beginning of year	530,109			531,691
Actual return on plan assets	31,298			25,888
Employer contributions	—			8,500
Benefits paid	(32,526		)	(35,970		)
Fair value of plan assets at end of year	528,881			530,109
Reconciliation:
Funded status	(75,340		)	(47,161		)
Unrecognized prior service cost	—			—
Unrecognized net loss	—			—
Net amount recognized	$	(75,340	)	$	(47,161	)

Net periodic pension cost for the Plan for fiscal 2020, 2019 and 2018 is presented in the following table.

	Fiscal Year Ended September 30
	2020			2019			2018
	(In thousands)
Components of net periodic pension cost:
Service cost	$	17,551		$	15,311		$	17,264
Interest cost(1)	19,028			22,071			20,803
Expected return on assets(1)	(28,316		)	(28,451		)	(27,666		)
Amortization of prior service credit(1)	(231		)	(232		)	(231		)
Recognized actuarial loss(1)	9,025			4,201			9,114
Net periodic pension cost	$	17,057		$	12,900		$	19,284

(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.

The following tables set forth by level, within the fair value hierarchy, the Plan's assets at fair value as of September 30, 2020 and 2019. 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. 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 $0.7 million and $1.3 million at September 30, 2020 and 2019, which materially approximates fair value due to the short-term nature of these assets.

	Assets at Fair Value as of September 30, 2020
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Common stocks	$	211,244	$	—	$	—	$	211,244
Money market funds	—		6,096		—		6,096
Registered investment companies	29,762		—		—		29,762
Government securities:
Mortgage-backed securities	—		15,230		—		15,230
U.S. treasuries	21,755		36		—		21,791
Corporate bonds	—		52,648		—		52,648
Total investments measured at fair value	$	262,761	$	74,010	$	—	336,771
Investments measured at net asset value:
Common/collective trusts (1)							122,207
Limited partnerships (1)							69,176
Total investments							$	528,154

	Assets at Fair Value as of September 30, 2019
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Common stocks	$	212,785	$	—	$	—	$	212,785
Money market funds	—		16,419		—		16,419
Registered investment companies	26,326		—		—		26,326
Government securities:
Mortgage-backed securities	—		19,986		—		19,986
U.S. treasuries	22,930		885		—		23,815
Corporate bonds	—		55,774		—		55,774
Total investments measured at fair value	$	262,041	$	93,064	$	—	355,105
Investments measured at net asset value:
Common/collective trusts (1)							108,975
Limited partnerships (1)							64,718
Total investments							$	528,798

(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 benefits 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 underlying qualified defined benefit plan are an offset to the benefits under the SERP.

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

Due to the retirement of an executive of the company during fiscal 2020, we recognized a one-time settlement charge of $9.2 million and paid a $22.7 million lump sum in relation to the retirement.

Similar to our employee pension plans, we review the estimates and assumptions underlying our supplemental 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, 2020 and 2019 and the actuarial assumptions used to determine the net periodic pension cost for the supplemental plans were determined as of September 30, 2019, 2018 and 2017. These assumptions are presented in the following table:

	Pension Liability				Pension Cost
	2020		2019		2020		2019		2018
Discount rate(1)	2.80	%	3.29	%	3.19	%	4.38	%	4.08	%
Rate of compensation increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%
Interest crediting rate	4.69	%	4.69	%	4.69	%	4.69	%	4.69	%

 (1) Reflects a weighted average discount rate for pension cost for fiscal 2020 and 2018 due to the settlements during the year.

The following table presents the supplemental plans’ accumulated benefit obligation, projected benefit obligation and funded status as of September 30, 2020 and 2019:

	2020			2019
	(In thousands)
Accumulated benefit obligation	$	122,207		$	138,772
Change in projected benefit obligation:
Benefit obligation at beginning of year	$	143,987		$	121,370
Service cost	1,074			869
Interest cost	4,188			5,127
Actuarial (gain) loss	7,386			25,099
Benefits paid	(4,766		)	(8,478		)
Settlements	(22,729		)	—
Benefit obligation at end of year	129,140			143,987
Change in plan assets:
Fair value of plan assets at beginning of year	—			—
Employer contribution	27,495			8,478
Benefits paid	(4,766		)	(8,478		)
Settlements	(22,729		)	—
Fair value of plan assets at end of year	—			—
Reconciliation:
Funded status	(129,140		)	(143,987		)
Unrecognized prior service cost	—			—
Unrecognized net loss	—			—
Accrued pension cost	$	(129,140	)	$	(143,987	)

Assets for the supplemental plans are held in separate rabbi trusts. At September 30, 2020 and 2019, assets held in the rabbi trusts consisted of equity securities of $41.9 million and $44.0 million, which are included in our fair value disclosures in Note 15.

Net periodic pension cost for the supplemental plans for fiscal 2020, 2019 and 2018 is presented in the following table.

	Fiscal Year Ended September 30
	2020		2019		2018
	(In thousands)
Components of net periodic pension cost:
Service cost	$	1,074	$	869	$	1,332
Interest cost(1)	4,188		5,127		4,988
Recognized actuarial loss(1)	3,945		2,227		3,079
Settlements(1)	9,180		—		4,159
Net periodic pension cost	$	18,387	$	8,223	$	13,558

(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.

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)
2021	$	37,523	$	30,021
2022	37,804		17,117
2023	39,053		5,124
2024	40,036		4,472
2025	41,016		32,550
2026-2030	204,582		22,308

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 benefits depending on the level of coverage chosen by the participants and the terms of predecessor plans; however, we generally pay 80 percent of the projected net claims and administrative costs and participants pay the remaining 20 percent. Effective January 1, 2015, for employees who had not met the participation requirements by September 30, 2009, the contribution rates for the Company 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 2021.

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 regarding the postretirement benefits plan.

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, 2020 and 2019.

	Actual Allocation September 30
Security Class	2020	2019
Diversified investment funds	97.4%	97.1%
Cash and cash equivalents	2.6%	2.9%

Similar to our employee pension and supplemental plans, we review the estimates and assumptions underlying 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, 2020 and 2019 and the actuarial assumptions used to determine the net periodic pension cost for the postretirement plan were determined as of September 30, 2019, 2018 and 2017.

The assumptions are presented in the following table:

	Postretirement Liability				Postretirement Cost
	2020		2019		2020		2019		2018
Discount rate	2.80	%	3.29	%	3.29	%	4.38	%	3.89	%
Expected return on plan assets	4.94	%	5.14	%	5.14	%	5.33	%	4.29	%
Initial trend rate	6.25	%	6.25	%	6.25	%	6.50	%	7.00	%
Ultimate trend rate	5.00	%	5.00	%	5.00	%	5.00	%	5.00	%
Ultimate trend reached in	2026		2025		2025		2022		2022

The following table presents the postretirement plan’s benefit obligation and funded status as of September 30, 2020 and 2019:

	2020			2019
	(In thousands)
Change in benefit obligation:
Benefit obligation at beginning of year	$	316,033		$	265,986
Service cost	13,466			10,810
Interest cost	10,612			11,839
Plan participants’ contributions	5,849			5,901
Actuarial (gain) loss	43,412			39,472
Benefits paid	(18,694		)	(17,975		)
Benefit obligation at end of year	370,678			316,033
Change in plan assets:
Fair value of plan assets at beginning of year	201,901			199,361
Actual return on plan assets	2,356			1,125
Employer contributions	16,833			13,489
Plan participants’ contributions	5,849			5,901
Benefits paid	(18,694		)	(17,975		)
Fair value of plan assets at end of year	208,245			201,901
Reconciliation:
Funded status	(162,433		)	(114,132		)
Unrecognized transition obligation	—			—
Unrecognized prior service cost	—			—
Unrecognized net loss	—			—
Accrued postretirement cost	$	(162,433	)	$	(114,132	)

Net periodic postretirement cost for fiscal 2020, 2019 and 2018 is presented in the following table.

	Fiscal Year Ended September 30
	2020			2019			2018
	(In thousands)
Components of net periodic postretirement cost:
Service cost	$	13,466		$	10,810		$	12,078
Interest cost(1)	10,612			11,839			10,907
Expected return on assets(1)	(10,499		)	(10,659		)	(8,006		)
Amortization of transition obligation(1)	—			—			—
Amortization of prior service cost (credit)(1)	173			173			11
Recognized actuarial gain(1)	(1,337		)	(8,178		)	(6,473		)
Net periodic postretirement cost	$	12,415		$	3,985		$	8,517

(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.

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

The following tables set forth by level, within the fair value hierarchy, the Retiree Medical Plan’s assets at fair value as of September 30, 2020 and 2019. The methods used to determine fair value for the assets held by the Retiree Medical Plan are fully described in Note 2.

	Assets at Fair Value as of September 30, 2020
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Money market funds	$	—	$	5,525	$	—	$	5,525
Registered investment companies	202,720		—		—		202,720
Total investments measured at fair value	$	202,720	$	5,525	$	—	$	208,245

	Assets at Fair Value as of September 30, 2019
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Money market funds	$	—	$	5,972	$	—	$	5,972
Registered investment companies	195,929		—		—		195,929
Total investments measured at fair value	$	195,929	$	5,972	$	—	$	201,901

Estimated Future Benefit Payments

The following benefit payments paid by us, retirees and prescription drug subsidy payments for our postretirement benefit plans, which reflect expected future service, as appropriate, are expected to be paid in the following fiscal years. Company payments for fiscal 2020 include contributions to our postretirement plan trusts.

	Company Payments		Retiree Payments		Subsidy Payments		Total Postretirement Benefits
	(In thousands)
2021	$	22,632	$	4,368	$	—	$	27,000
2022	16,263		4,772		—		21,035
2023	16,590		5,144		—		21,734
2024	17,517		5,651		—		23,168
2025	18,353		6,104		—		24,457
2026-2030	101,158		35,039		—		136,197

Defined Contribution Plan

The Atmos Energy Corporation Retirement Savings Plan and Trust (the Retirement Savings Plan) covers substantially all employees and is subject to the provisions of Section 401(k) of the Internal Revenue Code. Effective January 1, 2007, employees automatically become participants of the Retirement Savings Plan on the date of employment. Participants may elect a salary reduction up to a maximum of 65 percent of eligible compensation, as defined by the 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. Participants are eligible to receive matching contributions after completing one year of service, in which they are immediately vested. Effective January 1, 2021, participants are eligible to receive matching contributions immediately upon enrollment in the Retirement Savings Plan. This matching contribution vests after completing one year of service. Participants are also permitted to take out a loan against their accounts subject to certain restrictions. Employees hired on or after October 1, 2010 participate in the enhanced plan in which participants receive a fixed annual contribution of four percent of eligible earnings to their Retirement Savings Plan account. Participants will continue to be eligible for company matching contributions of up to four percent of their eligible earnings and will be fully vested in the fixed annual contribution after three years of service.

Matching and fixed annual contributions to the Retirement Savings Plan are expensed as incurred and amounted to $17.9 million, $16.7 million and $16.2 million for fiscal years 2020, 2019 and 2018. At September 30, 2020 and 2019, the Retirement Savings Plan held 2.2 percent and 2.6 percent of our outstanding common stock.

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Stock and Other Compensation Plans

12 Months Ended

Sep. 30, 2020

Share-based Payment Arrangement [Abstract]

Stock and Other Compensation Plans

Stock and Other Compensation Plans

Stock-Based Compensation Plans

Total stock-based compensation cost was $21.1 million, $23.9 million and $23.9 million for the fiscal years ended September 30, 2020, 2019 and 2018. Of this amount, $11.6 million, $12.8 million and $11.1 million was capitalized.

1998 Long-Term Incentive Plan

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

We were originally 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, 2020, 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 1.3 million shares are available for future issuance through September 30, 2021.

Restricted Stock Units Award Grants

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

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

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

The following summarizes information regarding the restricted stock units granted under the plan during the fiscal years ended September 30, 2020, 2019 and 2018:

	2020				2019				2018
	Number of Restricted Units		Weighted Average Grant-Date Fair Value		Number of Restricted Units		Weighted Average Grant-Date Fair Value		Number of Restricted Units		Weighted Average Grant-Date Fair Value
Nonvested at beginning of year	503,072		$	91.66	538,592		$	80.91	570,814		$	69.45
Granted	199,985		102.34		241,472		98.25		248,710		85.62
Vested	(242,975	)	85.66		(269,347	)	76.71		(274,392	)	64.43
Forfeited	(16,803	)	96.87		(7,645	)	86.37		(6,540	)	74.87
Nonvested at end of year	443,279		$	99.28	503,072		$	91.66	538,592		$	80.91

As of September 30, 2020, there was $13.0 million of total unrecognized compensation cost related to nonvested restricted stock units granted under the LTIP. That cost is expected to be recognized over a weighted average period of 1.5 years. The fair value of restricted stock vested during the fiscal years ended September 30, 2020, 2019 and 2018 was $20.7 million, $20.5 million and $17.2 million.

Other Plans

Direct Stock Purchase Plan

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

Equity Incentive and Deferred Compensation Plan for Non-Employee Directors

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

Other Discretionary Compensation Plans

We have an annual incentive program covering substantially all employees to give each employee an opportunity to share in our financial success based on the achievement of key performance measures considered critical to achieving business

objectives for a given year with minimum and maximum thresholds. The Company must meet the minimum threshold for the plan to be funded and distributed to employees. These performance measures may include earnings growth objectives, improved cash flow objectives or crucial customer satisfaction and safety results. We monitor progress towards the achievement of the performance measures throughout the year and record accruals based upon the expected payout using the best estimates available at the time the accrual is recorded. During the last several fiscal years, we have used earnings per share as our sole performance measure.

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Details of Selected Consolidated Balance Sheet Captions

12 Months Ended

Sep. 30, 2020

Balance Sheet Related Disclosures [Abstract]

Details of Selected Consolidated Balance Sheet Captions

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, 2020 and 2019:

	September 30
	2020			2019
	(In thousands)
Billed accounts receivable	$	140,259		$	126,984
Unbilled revenue	80,699			78,986
Contributions in aid of construction receivable	19,821			22,378
Other accounts receivable	19,765			18,122
Total accounts receivable	260,544			246,470
Less: allowance for doubtful accounts	(29,949		)	(15,899		)
Net accounts receivable	$	230,595		$	230,571

Other current assets

Other current assets as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Deferred gas costs	$	40,593	$	23,766
Prepaid expenses	40,340		38,895
Materials and supplies	6,829		5,916
Assets from risk management activities	5,687		1,586
Other	14,456		2,609
Total	$	107,905	$	72,772

Property, plant and equipment

Property, plant and equipment was comprised of the following as of September 30, 2020 and 2019:

	September 30
	2020			2019
	(In thousands)
Storage plant	$	530,985		$	431,286
Transmission plant	3,459,765			3,157,316
Distribution plant	10,680,495			9,333,011
General plant	829,624			799,095
Intangible plant	38,297			38,191
	15,539,166			13,758,899
Construction in progress	418,055			421,694
	15,957,221			14,180,593
Less: accumulated depreciation and amortization	(2,601,874		)	(2,392,924		)
Net property, plant and equipment(1)	$	13,355,347		$	11,787,669

(1) Net property, plant and equipment includes plant acquisition adjustments of $(37.8) million and $(46.7) million at September 30, 2020 and 2019.

Goodwill

The following presents our goodwill balance allocated by segment and changes in the balance for the fiscal year ended September 30, 2020:

	Distribution			Pipeline and Storage		Total
	(In thousands)
Balance as of September 30, 2019	$	587,604		$	143,102	$	730,706
Deferred tax adjustments on prior acquisitions(1)	(768		)	1,319		551
Balance as of September 30, 2020	$	586,836		$	144,421	$	731,257

(1) We annually adjust certain deferred taxes recorded in connection with an acquisition completed in fiscal 2005, which resulted in an increase to goodwill and net deferred tax liabilities of $0.6 million for fiscal 2020.

Deferred charges and other assets

Deferred charges and other assets as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Marketable securities	$	103,952	$	101,883
Regulatory assets (See Note 2)	371,707		260,220
Operating lease right of use assets (See Note 6)	227,146		—
Assets from risk management activities	74,991		225
Tax receivable	—		10,099
Other	23,374		18,786
Total	$	801,170	$	391,213

Accounts payable and accrued liabilities

Accounts payable and accrued liabilities as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Trade accounts payable	$	141,075	$	176,581
Accrued gas payable	42,054		36,817
Accrued liabilities	52,646		51,626
Total	$	235,775	$	265,024

Other current liabilities

Other current liabilities as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Customer credit balances and deposits	$	56,485	$	54,617
Accrued employee costs	57,057		55,216
Deferred gas costs	19,985		14,112
Operating lease liabilities (See Note 6)	35,716		—
Accrued interest	53,554		51,381
Liabilities from risk management activities	2,015		4,552
Taxes payable	148,292		135,597
Pension and postretirement liabilities	29,609		26,197
Regulatory cost of service reserve	1,716		4,209
Regulatory cost of removal obligation	73,908		55,721
APT annual adjustment mechanism	43,893		52,856
Regulatory excess deferred taxes (See Note 13)	20,887		21,206
Other	3,344		3,837
Total	$	546,461	$	479,501

Deferred credits and other liabilities

Deferred credits and other liabilities as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Pension and post retirement liabilities	$	337,303	$	279,083
Operating lease liabilities (See Note 6)	201,071		—
Customer advances for construction	10,060		12,566
Other regulatory liabilities (See Note 2)	17,838		16,120
Asset retirement obligation	20,348		17,054
Liabilities from risk management activities	—		1,249
APT annual adjustment mechanism	13,486		25,545
Unrecognized tax benefits	30,921		27,716
Other	11,101		20,883
Total	$	642,128	$	400,216

Statement of Comprehensive Income

Other non-operating income (expense)

Other non-operating income (expense) for the fiscal years ended September 30, 2020, 2019 and 2018 were comprised of the following accounts.

	Year Ended September 30
	2020			2019			2018
	(In thousands)
Equity component of AFUDC	$	23,493		$	11,165		$	—
Performance-based rate program	6,771			6,737			6,745
Pension and other postretirement non-service credit (cost)	(3,189		)	3,016			(5,770		)
Interest income	2,932			4,160			1,450
Community support spending	(11,728		)	(4,771		)	(6,053		)
Miscellaneous	(11,108		)	(12,903		)	(6,516		)
Total	$	7,171		$	7,404		$	(10,144	)

Statement of Cash Flows

Supplemental disclosures of cash flow information for the fiscal years ended September 30, 2020, 2019 and 2018 were as follows:

	Year Ended September 30
	2020			2019		2018
	(In thousands)
Cash Paid (Received) During The Period For:
Interest(1)	$	194,993		$	184,852	$	169,987
Income taxes	$	(3,071	)	$	11,467	$	6,102
Non-Cash Transactions:
Capital expenditures included in current liabilities	$	113,365		$	149,993	$	112,211

(1) Cash paid during the period for interest, net of amounts capitalized was $82.3 million, $91.3 million and $106.8 million for the fiscal years ended September 30, 2020, 2019 and 2018.

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Commitments and Contingencies

12 Months Ended

Sep. 30, 2020

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Litigation and Environmental Matters

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

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.

The National Transportation Safety Board (NTSB) is investigating an incident that occurred at a Dallas, Texas residence on February 23, 2018 that resulted in one fatality and injuries to four other residents. Together with the Railroad Commission of Texas (RRC) and the Pipeline and Hazardous Materials Safety Administration (PHMSA), Atmos Energy is a party to the investigation and in that capacity is working closely with the NTSB to help determine the cause of this incident.

We are a party to various other litigation and environmental-related matters or claims that have arisen in the ordinary course of our business. While the results of such litigation and response actions to such environmental-related matters or claims

cannot be predicted with certainty, we continue to believe the final outcome of such litigation and matters or claims will not have a material adverse effect on our financial condition, results of operations or cash flows.

Purchase Commitments

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

Our Mid-Tex Division also maintains a limited number of long-term supply contracts to ensure a reliable source of gas for our customers in its service area, which obligate it to purchase specified volumes at prices indexed to natural gas trading hubs. At September 30, 2020, we were committed to purchase 59.3 Bcf within one year, 57.0 Bcf within two to three years and 0.1 Bcf beyond three years under indexed contracts. Purchases under these contracts totaled $58.5 million, $50.8 million and $57.2 million for 2020, 2019 and 2018.

Rate Regulatory Proceedings

As of September 30, 2020, 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.

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Income Taxes

12 Months Ended

Sep. 30, 2020

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

Income Tax Expense

The components of income tax expense from continuing operations for 2020, 2019 and 2018 were as follows:

	2020			2019		2018
	(In thousands)
Current
Federal	$	—		$	—	$	(10,099	)
State	14,193			8,412		11,075
Deferred
Federal	143,039			113,331		150,556
State (1)	(11,879		)	17,160		15,330
TCJA Impact	—			—		(158,782		)
Income tax expense	$	145,353		$	138,903	$	8,080

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

Reconciliations of the provision for income taxes computed at the statutory rate to the reported provisions for income taxes from continuing operations for 2020, 2019 and 2018 are set forth below:

	2020			2019			2018
	(In thousands)
Tax at statutory rate(1)	$	156,827		$	136,565		$	149,730
Common stock dividends deductible for tax reporting	(1,419		)	(1,460		)	(1,745		)
State taxes (net of federal benefit)	22,791			20,202			19,826
Amortization of excess deferred taxes	(16,125		)	(14,085		)	(1,219		)
Remeasurement due to TCJA	—			—			(158,782		)
Remeasurement due to state deferred tax rate change	(20,962		)	—			—
Other, net	4,241			(2,319		)	270
Income tax expense	$	145,353		$	138,903		$	8,080

(1) Tax expense is calculated at the statutory federal income tax rate of 21.0%, 21.0%, 24.5% for the year ended September 30, 2020, 2019 and 2018.

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, 2020 and 2019 are presented below:

	2020			2019
	(In thousands)
Deferred tax assets:
Employee benefit plans	$	66,991		$	70,929
Interest rate swaps	16,719			33,918
Net operating loss carryforwards	476,507			485,133
Charitable and other credit carryforwards	8,712			8,241
Regulatory excess deferred tax	161,565			165,701
Other	73,542			13,186
Total deferred tax assets	804,036			777,108
Valuation allowance	(1,102		)	(1,894		)
Net deferred tax assets	802,934			775,214
Deferred tax liabilities:
Difference in net book value and net tax value of assets(1)	(2,138,966		)	(2,004,516		)
Pension funding	(484		)	(4,384		)
Gas cost adjustments	(23,209		)	(18,072		)
Other	(96,844		)	(48,257		)
Total deferred tax liabilities	(2,259,503		)	(2,075,229		)
Net deferred tax liabilities	$	(1,456,569	)	$	(1,300,015	)
Deferred credits for rate regulated entities	$	2,537		$	2,582

(1) Includes $129.0 million and $131.0 million of deferred tax liability related to goodwill as of September 30, 2020 and 2019.

At September 30, 2020, we had $446.9 million (tax effected) of federal net operating loss carryforwards. The federal net operating loss carryforwards are available to offset taxable income and will begin to expire in 2029. The Company also had $10.1 million of federal alternative minimum tax credit carryforwards as of September 30, 2019, which did not expire and were fully refunded to us during fiscal 2020. In addition, the Company has $6.9 million in charitable contribution carryforwards to offset future taxable income. The Company’s charitable contribution carryforwards expiration period begins in fiscal 2021.

The Company also has $29.6 million (tax effected) of state net operating loss carryforwards (net of $7.9 million of federal effects) and $1.8 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 2021.

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 $1.1 million was established for the year ended September 30, 2020.

At September 30, 2020, we had recorded liabilities associated with unrecognized tax benefits totaling $30.9 million. The following table reconciles the beginning and ending balance of our unrecognized tax benefits:

	2020			2019			2018
	(In thousands)
Unrecognized tax benefits - beginning balance	$	27,716		$	26,203		$	23,719
Increase (decrease) resulting from prior period tax positions	(26		)	(923		)	22
Increase resulting from current period tax positions	3,231			2,436			2,462
Unrecognized tax benefits - ending balance	30,921			27,716			26,203
Less: deferred federal and state income tax benefits	(6,493		)	(5,820		)	(5,503		)
Total unrecognized tax benefits that, if recognized, would impact the effective income tax rate as of the end of the year	$	24,428		$	21,896		$	20,700

The Company recognizes interest accrued related to unrecognized tax benefits in interest expense and penalties included within interest charges in our consolidated statements of comprehensive income. During the years ended September 30, 2020, 2019 and 2018, the Company recognized approximately $0.7 million, $2.2 million and $1.6 million in interest and penalties. The Company had approximately $8.2 million, $7.9 million and $6.1 million for the payment of interest and penalties accrued at September 30, 2020, 2019 and 2018.

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

On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”) was signed into law. The CARES Act, among other things, includes provisions relating to refundable payroll tax credits, deferment of employer side social security payments, net operating loss carryback periods, alternative minimum tax credit refunds, modifications to the net interest deduction limitations and technical corrections to tax depreciation methods for qualified improvement property. The CARES Act did not have an impact on our consolidated financial statements for the year ended September 30, 2020.

Excess Deferred Taxes

On June 1, 2020, the Kansas legislature passed House Bill 2585 which eliminated the assessment of state income taxes on regulated utilities. This legislation was effective for the Company on October 1, 2020. Due to the change in the Kansas state tax law and the result of a study to estimate the rate at which state deferred taxes will reverse in the future, we reduced our deferred tax liability by $32.5 million during the fiscal third quarter of 2020. We established a $12.1 million regulatory liability for excess deferred taxes that will be returned to Kansas customers. We are currently working with the Kansas Corporation Commission to determine the amortization period for this liability. We recognized a $21.0 million income tax benefit in our consolidated statement of comprehensive income for the year ended September 30, 2020.

On December 22, 2017, the Tax Cuts and Jobs Act of 2017 (the "TCJA") was signed into law. As a result of the implementation of the TCJA, we recognized a $158.8 million income tax benefit in our consolidated statement of comprehensive income for the year ended September 30, 2018 related to a change in deferred taxes that were not related to our cost of service ratemaking. The change in deferred taxes related to our cost of service ratemaking (referred to as excess deferred taxes) was reclassified into a regulatory liability and as approved by our regulators, will be returned to ratepayers on a provisional basis over periods ranging from 15 to 46 years. As of September 30, 2020 and 2019, this liability totaled $706.7 million and $726.3 million.

During fiscal 2019, we received approval from regulators to update our cost of service rates to reflect the decrease in the statutory income tax rate in all of our service areas. Additionally, as of September 30, 2020, we have returned the separate regulatory liability to customers in substantially all of our service areas for the difference in taxes included in our rates that were calculated based on a 35% statutory income tax rate until new rates could be established based on the new 21% statutory income tax rate.

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Financial Instruments

12 Months Ended

Sep. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Financial Instruments

Financial Instruments

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

As discussed in Note 2, we report our financial instruments as risk management assets and liabilities, each of which is classified as current or noncurrent based upon the anticipated settlement date of the underlying financial instrument. The following table shows the fair values of our risk management assets and liabilities at September 30, 2020 and 2019.

	September 30
	2020			2019
	(In thousands)
Assets from risk management activities, current	$	5,687		$	1,586
Assets from risk management activities, noncurrent	74,991			225
Liabilities from risk management activities, current	(2,015		)	(4,552		)
Liabilities from risk management activities, noncurrent	—			(1,249		)
Net assets (liabilities)	$	78,663		$	(3,990	)

Commodity Risk Management Activities

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

In jurisdictions where we are permitted to mitigate commodity price risk through financial instruments, the relevant regulatory authorities may establish the level of heating season gas purchases that can be hedged. Our distribution gas supply department is responsible for executing this segment’s commodity risk management activities in conformity with regulatory requirements. Historically, if the regulatory authority does not establish this level, we seek to hedge between 25 and 50 percent of anticipated heating season gas purchases using financial instruments. For the 2019-2020 heating season (generally October through March), in the jurisdictions where we are permitted to utilize financial instruments, we hedged approximately 49 percent, or approximately 19.9 Bcf of the winter flowing gas requirements at a weighted average cost of approximately $2.84 per Mcf. We have not designated these financial instruments as hedges for accounting purposes.

Interest Rate Risk Management Activities

In fiscal 2020, we entered into forward starting interest rate swaps to effectively fix the Treasury yield component associated with $500 million of a planned issuance of unsecured senior notes in fiscal 2021 at 0.69%; these swaps were settled in September 2020 with a net payment of $4.4 million. On October 1, 2020, the notes were issued as planned.

Additionally, in fiscal 2020, we entered into forward starting interest rate swaps to effectively fix the Treasury yield component associated with $450 million of a planned issuance of unsecured senior notes in fiscal 2022 at 1.33%, $300 million of a planned issuance of unsecured senior notes in fiscal 2023 at 1.36% and $300 million of a planned issuance of unsecured senior notes in fiscal 2025 at 1.35%, which we designated as cash flow hedges at the time the agreements were executed.

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, 2020, 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, 2020, we had 18,191 MMcf of net long commodity contracts outstanding. These contracts have not been designated as hedges.

Financial Instruments on the Balance Sheet

The following tables present the fair value and balance sheet classification of our financial instruments as of September 30, 2020 and 2019. The gross amounts of recognized assets and liabilities are netted within our consolidated balance sheets to the extent that we have netting arrangements with the counterparties. However, as of September 30, 2020 and 2019, no gross amounts and no cash collateral were netted within our consolidated balance sheet.

	Balance Sheet Location	Assets		Liabilities
		(In thousands)
September 30, 2020
Designated As Hedges:
Interest rate contracts	Deferred charges and other assets / Deferred credits and other liabilities	$	73,055	$	—
Total		73,055		—
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	5,687		(2,015		)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	1,936		—
Total		7,623		(2,015		)
Gross / Net Financial Instruments		$	80,678	$	(2,015	)

	Balance Sheet Location	Assets		Liabilities
		(In thousands)
September 30, 2019
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	$	1,586	$	(4,552	)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	225		(1,249		)
Total		1,811		(5,801		)
Gross / Net Financial Instruments		$	1,811	$	(5,801	)

Impact of Financial Instruments on the Statement of Comprehensive Income

Cash Flow Hedges

As discussed above, the interest rate agreements we executed in prior years were designated as cash flow hedges when those 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, 2020, 2019 and 2018 was $5.5 million, $3.9 million and $2.4 million.

The following table summarizes the gains and losses arising from hedging transactions that were recognized as a component of other comprehensive income (loss), for the years ended September 30, 2020 and 2019. The amounts included in the table below exclude gains and losses arising from ineffectiveness because these amounts are immediately recognized in the statement of comprehensive income as incurred.

	Fiscal Year Ended September 30
	2020		2019
	(In thousands)
Increase (decrease) in fair value:
Interest rate agreements	$	53,241	$	(25,966	)
Recognition of losses in earnings due to settlements:
Interest rate agreements	3,647		3,022
Total other comprehensive income (loss) from hedging, net of tax	$	56,888	$	(22,944	)

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, 2020, we had $114.5 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 2049. However, the table below does not include the expected recognition in earnings of our outstanding interest rate agreements as those financial instruments have not yet settled.

	Interest Rate Agreements
	(In thousands)
2021	$	(4,569	)
2022	(4,569		)
2023	(4,569		)
2024	(4,569		)
2025	(4,569		)
Thereafter	(91,657		)
Total	$	(114,502	)

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.

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Fair Value Measurements

12 Months Ended

Sep. 30, 2020

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

We report certain assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We record cash and cash equivalents, accounts receivable and accounts payable at carrying value, which substantially approximates fair value due to the short-term nature of these assets and liabilities. For other financial assets and liabilities, we primarily use quoted market prices and other observable market pricing information to minimize the use of unobservable pricing inputs in our measurements when determining fair value. The methods used to determine fair value for our assets and liabilities are fully described in Note 2.

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 9.

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, 2020 and 2019. 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.

	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)(1)		Significant Other Unobservable Inputs (Level 3)		Netting and Cash Collateral		September 30, 2020
	(In thousands)
Assets:
Financial instruments	$	—	$	80,678	$	—	$	—	$	80,678
Debt and equity securities
Registered investment companies	37,831		—		—		—		37,831
Bond mutual funds	29,166		—		—		—		29,166
Bonds(2)	—		32,900		—		—		32,900
Money market funds	—		4,055		—		—		4,055
Total debt and equity securities	66,997		36,955		—		—		103,952
Total assets	$	66,997	$	117,633	$	—	$	—	$	184,630
Liabilities:
Financial instruments	$	—	$	2,015	$	—	$	—	$	2,015

	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)(1)		Significant Other Unobservable Inputs (Level 3)		Netting and Cash Collateral		September 30, 2019
	(In thousands)
Assets:
Financial instruments	$	—	$	1,811	$	—	$	—	$	1,811
Debt and equity securities
Registered investment companies	41,406		—		—		—		41,406
Bond mutual funds	25,966		—		—		—		25,966
Bonds(2)	—		31,915		—		—		31,915
Money market funds	—		2,596		—		—		2,596
Total debt and equity securities	67,372		34,511		—		—		101,883
Total assets	$	67,372	$	36,322	$	—	$	—	$	103,694
Liabilities:
Financial instruments	$	—	$	5,801	$	—	$	—	$	5,801

(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.

At September 30, 2020 and 2019, the amortized cost of our available-for-sale debt securities was $32.6 million and $31.7 million. At September 30, 2020 we maintained investments in bonds that have contractual maturity dates ranging from October 2020 through May 2023.

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 and debt, which are recorded at carrying value. The nonfinancial assets and liabilities include asset retirement obligations and pension and post-retirement plan assets. For cash and cash equivalents, accounts receivable and accounts payable, 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 carrying value of our finance leases materially approximates fair value. The following table presents the carrying value and fair value of our long-term debt, excluding finances leases, debt issuance costs and original issue premium or discount, as of September 30, 2020:

	September 30, 2020
	(In thousands)
Carrying Amount	$	4,560,000
Fair Value	$	5,597,183

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Concentration of Credit Risk

12 Months Ended

Sep. 30, 2020

Risks and Uncertainties [Abstract]

Concentration of Credit Risk

Concentration of Credit Risk

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

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Selected Quarterly Financial Data

12 Months Ended

Sep. 30, 2020

Quarterly Financial Information Disclosure [Abstract]

Selected Quarterly Financial Data (Unaudited)

Selected Quarterly Financial Data (Unaudited)

Summarized unaudited quarterly financial data is presented below. The sum of net income per share by quarter may not equal the net income per share for the fiscal year due to variations in the weighted average shares outstanding used in computing such amounts. Our businesses are seasonal due to weather conditions in our service areas. For further information on its effects on quarterly results, see the “Results of Operations” discussion included in the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” section herein.

	Quarter Ended
	December 31			March 31			June 30			September 30
	(In thousands, except per share data)
Fiscal year 2020:
Operating revenues
Distribution	$	828,504		$	933,005		$	435,308		$	430,176
Pipeline and storage	148,176			146,237			158,008			156,918
Intersegment eliminations	(101,117		)	(101,577		)	(100,321		)	(112,180		)
Total operating revenues	875,563			977,665			492,995			474,914
Purchased gas cost	296,868			317,883			26,072			18,031
Operating income	252,781			331,438			139,035			100,845
Net Income	178,673			239,646			117,791			65,333
Basic net income per share	$	1.47		$	1.95		$	0.96		$	0.53
Diluted net income per share	$	1.47		$	1.95		$	0.96		$	0.53

	Quarter Ended
	December 31			March 31			June 30			September 30
	(In thousands, except per share data)
Fiscal year 2019:
Operating revenues
Distribution	$	838,835		$	1,057,889		$	444,944		$	403,793
Pipeline and storage	134,470			135,650			149,198			147,706
Intersegment eliminations	(95,523		)	(98,894		)	(108,404		)	(107,816		)
Total operating revenues	877,782			1,094,645			485,738			443,683
Purchased gas cost	342,165			471,676			31,326			13,670
Operating income	236,464			297,677			122,202			89,715
Net Income	157,646			214,888			80,466			58,406
Basic net income per share	$	1.38		$	1.83		$	0.68		$	0.49
Diluted net income per share	$	1.38		$	1.82		$	0.68		$	0.49

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Schedule II - Valuation and Qualifying Accounts

12 Months Ended

Sep. 30, 2020

SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]

Schedule II Valuation and Qualifying Accounts

ATMOS ENERGY CORPORATION

Valuation and Qualifying Accounts

Three Years Ended September 30, 2020

			Additions
	Balance at beginning of period		Charged to cost & expenses		Charged to other accounts		Deductions			Balance at end of period
			(In thousands)
2020
Allowance for doubtful accounts	$	15,899	$	23,837	$	—	$	9,787	(1)	$	29,949
2019
Allowance for doubtful accounts	$	14,795	$	17,633	$	—	$	16,529	(1)	$	15,899
2018
Allowance for doubtful accounts	$	10,865	$	14,894	$	—	$	10,964	(1)	$	14,795

⁽¹⁾ 

Uncollectible accounts written off.

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Summary of Significant Accounting Policies (Policies)

12 Months Ended

Sep. 30, 2020

Accounting Policies [Abstract]

Principles of consolidation

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

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

Regulation

Regulation — Our distribution and pipeline and storage operations are subject to regulation with respect to rates, service, maintenance of accounting records and various other matters by the respective regulatory authorities in the states in which we operate. Our accounting policies recognize the financial effects of the ratemaking and accounting practices and policies of the various regulatory commissions. Accounting principles generally accepted in the United States require cost-based, rate-regulated entities that meet certain criteria to reflect the authorized recovery of costs due to regulatory decisions in their financial statements. As a result, certain costs are permitted to be capitalized rather than expensed because they can be recovered through rates. We record certain costs as regulatory assets when future recovery through customer rates is considered probable. Regulatory liabilities are recorded when it is probable that revenues will be reduced for amounts that will be credited to customers through the ratemaking process. The amounts to be recovered or recognized are based upon historical experience and our understanding of the regulations. Further, regulation may impact the period in which revenues or expenses are recognized.

Substantially all of our regulatory assets are recorded as a component of 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.

Revenue recognition

Revenue recognition

Distribution Revenues

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

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

Pipeline and Storage Revenues

Pipeline and storage revenues primarily represent the transportation and storage of natural gas on our APT system and the transmission of natural gas through our 21-mile pipeline in Louisiana. APT provides transportation and storage services to our Mid-Tex Division, other third party local distribution companies and certain industrial customers under tariff rates approved by

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

Revenue Recognition for Alternative Revenue Programs

Alternative Revenue Program Revenues

In our distribution segment, we have weather-normalization adjustment mechanisms that serve to minimize the effects of weather on our residential and commercial revenues. Additionally, APT has a regulatory mechanism that requires that we share with its tariffed customers 75% of the difference between the total non-tariffed revenues earned during a test period and a revenue benchmark of $69.4 million that was established in its most recent rate case. Differences between actual revenues and revenues calculated under these mechanisms adjust the amount billed to customers. These mechanisms are considered to be alternative revenue programs under accounting standards generally accepted in the United States as they are deemed to be contracts between us and our regulator. Accordingly, revenue under these mechanisms are excluded from revenue from contracts with customers.

Purchased gas costs

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.

Cash and cash equivalents

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 doubtful accounts

Accounts receivable and allowance for doubtful accounts — Accounts receivable arise from natural gas sales to residential, commercial, industrial, public authority and other customers. We establish an allowance for doubtful accounts to reduce the net receivable balance to the amount we reasonably expect to collect based on our collection experience or where we are aware of a specific customer’s inability or reluctance to pay. However, if circumstances change, our estimate of the recoverability of accounts receivable could be affected. Circumstances which could affect our estimates include, but are not limited to, customer credit issues, the level of natural gas prices, customer deposits and general economic conditions. Accounts are written off once they are deemed to be uncollectible.

Gas stored underground

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

Property, plant and equipment

Property, plant and equipment — Regulated property, plant and equipment is stated at original cost, net of contributions in aid of construction. The cost of additions includes direct construction costs, payroll related costs (taxes, pensions and other benefits), administrative and general costs and an allowance for funds used during construction. The allowance for funds used during construction (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.

		2020		2019		2018
Component of AFUDC	Statement of Comprehensive Income Location	(In thousands)
Debt	Interest charges	$	8,436	$	7,643	$	6,810
Equity	Other non-operating income (expense)	23,493		11,165		—
		$	31,929	$	18,808	$	6,810

Major renewals, including replacement pipe, and betterments that are recoverable through our regulatory rate base are capitalized while the costs of maintenance and repairs that are not capitalizable are charged to expense as incurred. The costs of

large projects are accumulated in construction in progress until the project is completed. When the project is completed, tested and placed in service, the balance is transferred to the regulated plant in service account included in the rate base and depreciation begins.

Regulated property, plant and equipment is depreciated at various rates on a straight-line basis. These rates are approved by our regulatory commissions and are comprised of two components: one based on average service life and one based on cost of removal. Accordingly, we recognize our cost of removal expense as a component of depreciation expense. The related cost of removal accrual is reflected as a regulatory liability on the consolidated balance sheet. At the time property, plant and equipment is retired, removal expenses less salvage, are charged to the regulatory cost of removal accrual. The composite depreciation rate was 3.0 percent, 3.1 percent and 3.2 percent for the fiscal years ended September 30, 2020, 2019 and 2018.

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

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. Accretion of the asset retirement obligation due to the passage of time is recorded as an operating expense.

As of September 30, 2020 and 2019, we had asset retirement obligations of $20.3 million and $17.1 million. Additionally, we had $14.4 million and $11.3 million of asset retirement costs recorded as a component of property, plant and equipment that will be depreciated over the remaining life of the underlying associated assets.

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

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

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 2020, we completed our annual goodwill impairment assessment using a qualitative assessment, as permitted under U.S. GAAP. 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 2020 analysis, if the qualitative 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

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 assets and lease liabilities within the consolidated balance sheet. See Note 6 for further discussion regarding the accounting polices for these leases.

New Lease Accounting Policy

We determine if an arrangement is a lease at the inception of the agreement based on the terms and conditions in the contract. A contract contains a lease if there is an identified asset and we have the right to control the asset. We are the lessee for substantially all of our leasing 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.

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 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.

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.

The lease liability represents the present value of all lease payments over the lease term. 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.

Marketable securities

Marketable securities — As of September 30, 2020, we hold marketable securities classified as either equity or debt securities. Beginning on October 1, 2018, 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). During fiscal 2018 and under the previous accounting guidance, all our debt and equity securities were considered available for sale securities.

We regularly evaluate the performance of our available for sale debt securities on an investment by investment basis for impairment, taking into consideration the securities’ purpose, volatility and current returns. If a determination is made that a decline in fair value is other than temporary, the related investment is written down to its estimated fair value.

Financial instruments and hedging activities

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 14.

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

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

Financial Instruments Associated with Commodity Price Risk

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

Financial Instruments Associated with Interest Rate Risk

In connection with the planned issuance of long-term debt, we may use financial instruments to manage interest rate risk. We currently manage this risk through the use of forward starting interest rate swaps to fix the Treasury yield component of the interest cost associated with anticipated financings. We designate these financial instruments as cash flow hedges at the time the agreements are executed. Unrealized gains and losses associated with the instruments are recorded as a component of accumulated other comprehensive income (loss). When the instruments settle, the realized gain or loss is recorded as a component of accumulated other comprehensive income (loss) and recognized as a component of interest charges over the life of the related financing arrangement. As of September 30, 2020 and 2019, no cash was required to be held in margin accounts.

Fair Value Measurements

Fair Value Measurements — We report certain assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). We primarily use quoted market prices and other observable market pricing information in valuing our financial assets and liabilities and minimize the use of unobservable pricing inputs in our measurements.

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

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

Authoritative accounting literature establishes a fair value hierarchy that prioritizes the inputs used to measure fair value based on observable and unobservable data. The hierarchy categorizes the inputs into three levels, with the highest priority given to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority given to unobservable inputs (Level 3). The levels of the hierarchy are described below:

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

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

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

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

Pension and other postretirement plans

Pension and other postretirement plans — Pension and other postretirement plan costs and liabilities are determined on an actuarial basis and are affected by numerous assumptions and estimates including the market value of plan assets, estimates of the expected return on plan assets, assumed discount rates and current demographic and actuarial mortality data. Our measurement date is September 30. The assumed discount rate and the expected return are the assumptions that generally have the most significant impact on our pension costs and liabilities. The assumed discount rate, the assumed health care cost trend rate and assumed rates of retirement generally have the most significant impact on our postretirement plan costs and liabilities. For the valuation performed as of September 30, 2020, decreases in the discount rate resulted in actuarial losses that increased our plan obligations.

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

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

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

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

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

On October 1, 2018 we adopted new accounting guidance, which required we present only the current service cost component of the net benefit cost within operations and maintenance expense in the consolidated statements of comprehensive income. The remaining components of net benefit cost are recorded in other non-operating income (expense) in our consolidated statements of comprehensive income. The change in presentation of these costs was implemented on a retrospective basis as required by the guidance. In lieu of determining how each component of the net periodic benefit cost was actually reflected in the fiscal 2018 statement of comprehensive income, we elected to utilize a practical expedient that permits the use of the amounts disclosed for these costs in our pension and post-retirement benefit plans footnote as the basis to retroactively apply this standard.

In addition, only the service cost component of net benefit cost is eligible for capitalization and we continue to capitalize these costs into property, plant and equipment. Additionally, we defer into a regulatory asset the portion of non-service components of net periodic benefit cost that are capitalizable for regulatory purposes.

Income taxes

Income taxes — 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

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

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. Actual results may differ from estimates, depending on actual outcomes or changes in the facts or expectations surrounding each potential exposure.

Recent accounting pronouncements

Recent accounting pronouncements

Accounting pronouncements adopted in fiscal 2020

In February 2016, the Financial Accounting Standards Board (FASB) issued a comprehensive new leasing standard that requires lessees to recognize a lease liability and a right-of-use (ROU) asset for all leases, including operating leases on its balance sheet. The new standard was effective for us beginning on October 1, 2019. See Note 6 to the consolidated financial statements for further details regarding our adoption of the new lease standard and the related disclosures.

Accounting pronouncements that will be effective after fiscal 2020

In March 2020, the 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 relationships 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. We are currently evaluating if we will apply the optional guidance as we assess the impact of the cessation of LIBOR on our current contracts and hedging relationships and the potential impact on our financial position, results of operations and cash flows.

In December 2019, the FASB issued new guidance related to accounting for income taxes which removes certain exceptions for recognizing deferred taxes for investments, performing intraperiod allocations and calculating income taxes in interim periods. The new standard also adds guidance to reduce complexity in certain areas, such as recognizing deferred taxes for tax goodwill and allocating taxes to members of a consolidated group. The new standard will be effective for us beginning on October 1, 2021; early adoption is permitted. We do not believe the new standard will have a material impact on our financial position, results of operations and cash flows. 

In June 2016, the FASB issued new guidance which will require 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, entities will estimate credit losses over the entire contractual term of the instrument from the date of initial recognition of that instrument. In contrast, current U.S. GAAP is based on an incurred loss model that delays recognition of credit losses until it is probable the loss has been incurred. The new guidance also introduces a new impairment recognition model for available-for-sale debt

securities that will require credit losses for available-for-sale debt securities to be recorded through an allowance account. The new standard was effective for us beginning on October 1, 2020. We do not anticipate the adoption of this standard will have a material impact to our financial position, results of operations and cash flows.

Segment information

As of September 30, 2020, we manage and review our consolidated operations through the following two reportable segments:

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

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

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

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

Earnings per share

We use the two-class method of computing earnings per share because we have participating securities in the form of non-vested restricted stock units with a nonforfeitable right to dividend equivalents, for which vesting is predicated solely on the passage of time. The calculation of earnings per share using the two-class method excludes income attributable to these participating securities from the numerator and excludes the dilutive impact of those shares from the denominator.

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Nature of Business (Table)

12 Months Ended

Sep. 30, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of divisions and service areas

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 metropolitan area
Atmos Energy Mississippi Division	Mississippi
Atmos Energy West Texas Division	West Texas

 

(1)

Denotes location where we have more limited service areas.

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Summary of Significant Accounting Policies (Table)

12 Months Ended

Sep. 30, 2020

Accounting Policies [Abstract]

Schedule of Regulatory Assets

Significant regulatory assets and liabilities as of September 30, 2020 and 2019 included the following:

	September 30
	2020		2019
	(In thousands)
Regulatory assets:
Pension and postretirement benefit costs	$	149,089	$	86,089
Infrastructure mechanisms(1)	183,943		131,894
Deferred gas costs	40,593		23,766
Recoverable loss on reacquired debt	4,894		6,551
Deferred pipeline record collection costs	29,839		26,418
Other	6,283		9,829
	$	414,641	$	284,547
Regulatory liabilities:
Regulatory excess deferred taxes(2)	$	718,651	$	726,307
Regulatory cost of service reserve	1,716		5,238
Regulatory cost of removal obligation	531,096		528,893
Deferred gas costs	19,985		14,112
Asset retirement obligation	20,348		17,054
APT annual adjustment mechanism	57,379		78,402
Other	17,838		16,120
	$	1,367,013	$	1,386,126

(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)

Due to the passage of the Kansas House Bill 2585, on June 1, 2020, we remeasured our deferred tax liability and updated our state deferred tax rate resulting in a $12.1 million regulatory liability as of September 30, 2020. The remaining amount reflects the remeasurement of the net deferred tax liability included in our rate base as a result of the Tax Cuts and Jobs Act of 2017 (the TCJA). Of this amount, $20.9 million as of September 30, 2020 and $21.2 million as of September 30, 2019 is recorded in other current liabilities. See Note 13 for further information.

Schedule of Regulatory Liabilities

Significant regulatory assets and liabilities as of September 30, 2020 and 2019 included the following:

	September 30
	2020		2019
	(In thousands)
Regulatory assets:
Pension and postretirement benefit costs	$	149,089	$	86,089
Infrastructure mechanisms(1)	183,943		131,894
Deferred gas costs	40,593		23,766
Recoverable loss on reacquired debt	4,894		6,551
Deferred pipeline record collection costs	29,839		26,418
Other	6,283		9,829
	$	414,641	$	284,547
Regulatory liabilities:
Regulatory excess deferred taxes(2)	$	718,651	$	726,307
Regulatory cost of service reserve	1,716		5,238
Regulatory cost of removal obligation	531,096		528,893
Deferred gas costs	19,985		14,112
Asset retirement obligation	20,348		17,054
APT annual adjustment mechanism	57,379		78,402
Other	17,838		16,120
	$	1,367,013	$	1,386,126

(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)

Due to the passage of the Kansas House Bill 2585, on June 1, 2020, we remeasured our deferred tax liability and updated our state deferred tax rate resulting in a $12.1 million regulatory liability as of September 30, 2020. The remaining amount reflects the remeasurement of the net deferred tax liability included in our rate base as a result of the Tax Cuts and Jobs Act of 2017 (the TCJA). Of this amount, $20.9 million as of September 30, 2020 and $21.2 million as of September 30, 2019 is recorded in other current liabilities. See Note 13 for further information.

Schedule of Capitalization

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

		2020		2019		2018
Component of AFUDC	Statement of Comprehensive Income Location	(In thousands)
Debt	Interest charges	$	8,436	$	7,643	$	6,810
Equity	Other non-operating income (expense)	23,493		11,165		—
		$	31,929	$	18,808	$	6,810

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Segment Information (Table)

12 Months Ended

Sep. 30, 2020

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

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

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

	Year Ended September 30, 2019
	Distribution		Pipeline and Storage			Eliminations			Consolidated
	(In thousands)
Operating revenues from external parties	$	2,742,824	$	159,024		$	—		$	2,901,848
Intersegment revenues	2,637		408,000			(410,637		)	—
Total operating revenues	2,745,461		567,024			(410,637		)	2,901,848
Purchased gas cost	1,268,591		(360		)	(409,394		)	858,837
Operation and maintenance expense	480,222		151,329			(1,243		)	630,308
Depreciation and amortization expense	283,697		107,759			—			391,456
Taxes, other than income	242,179		33,010			—			275,189
Operating income	470,772		275,286			—			746,058
Other non-operating income	6,241		1,163			—			7,404
Interest charges	60,031		43,122			—			103,153
Income before income taxes	416,982		233,327			—			650,309
Income tax expense	88,168		50,735			—			138,903
Net income	$	328,814	$	182,592		$	—		$	511,406
Capital expenditures	$	1,274,613	$	418,864		$	—		$	1,693,477

	Year Ended September 30, 2018
	Distribution			Pipeline and Storage			Eliminations			Consolidated
	(In thousands)
Operating revenues from external parties	$	3,000,404		$	115,142		$	—		$	3,115,546
Intersegment revenues	2,643			392,571			(395,214		)	—
Total operating revenues	3,003,047			507,713			(395,214		)	3,115,546
Purchased gas cost	1,559,836			1,978			(393,966		)	1,167,848
Operation and maintenance expense	461,048			134,995			(1,248		)	594,795
Depreciation and amortization expense	264,930			96,153			—			361,083
Taxes, other than income	231,566			32,320			—			263,886
Operating income	485,667			242,267			—			727,934
Other non-operating expense	(6,649		)	(3,495		)	—			(10,144		)
Interest charges	65,850			40,796			—			106,646
Income before income taxes	413,168			197,976			—			611,144
Income tax expense (benefit)	(29,798		)	37,878			—			8,080
Net income	$	442,966		$	160,098		$	—		$	603,064
Capital expenditures	$	1,025,800		$	441,791		$	—		$	1,467,591

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

	2020		2019		2018
	(In thousands)
Distribution revenues:
Gas sales revenues:
Residential	$	1,717,070	$	1,733,548	$	1,916,101
Commercial	654,963		711,284		797,073
Industrial	89,641		118,046		131,267
Public authority and other	42,007		42,613		47,714
Total gas sales revenues	2,503,681		2,605,491		2,892,155
Transportation revenues	97,441		95,629		99,250
Other gas revenues	23,129		41,704		8,999
Total distribution revenues	2,624,251		2,742,824		3,000,404
Pipeline and storage revenues	196,886		159,024		115,142
Total operating revenues	$	2,821,137	$	2,901,848	$	3,115,546

Balance sheet information at September 30, 2020 and 2019 by segment is presented in the following tables.

	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

	September 30, 2019
	Distribution		Pipeline and Storage		Eliminations			Consolidated
	(In thousands)
Property, plant and equipment, net	$	8,737,590	$	3,050,079	$	—		$	11,787,669
Total assets	$	12,579,741	$	3,279,323	$	(2,491,445	)	$	13,367,619

Revenue from External Customers by Products and Services

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

	2020		2019		2018
	(In thousands)
Distribution revenues:
Gas sales revenues:
Residential	$	1,717,070	$	1,733,548	$	1,916,101
Commercial	654,963		711,284		797,073
Industrial	89,641		118,046		131,267
Public authority and other	42,007		42,613		47,714
Total gas sales revenues	2,503,681		2,605,491		2,892,155
Transportation revenues	97,441		95,629		99,250
Other gas revenues	23,129		41,704		8,999
Total distribution revenues	2,624,251		2,742,824		3,000,404
Pipeline and storage revenues	196,886		159,024		115,142
Total operating revenues	$	2,821,137	$	2,901,848	$	3,115,546

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Earnings Per Share (Table)

12 Months Ended

Sep. 30, 2020

Earnings Per Share [Abstract]

Earnings per share table

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

	2020		2019		2018
	(In thousands, except per share data)
Basic Earnings Per Share
Net Income	$	601,443	$	511,406	$	603,064
Less: Income allocated to participating securities	444		416		580
Net Income available to common shareholders	$	600,999	$	510,990	$	602,484
Basic weighted average shares outstanding	122,788		117,200		111,012
Net Income per share — Basic	$	4.89	$	4.36	$	5.43
Diluted Earnings Per Share
Net Income available to common shareholders	$	600,999	$	510,990	$	602,484
Effect of dilutive shares	—		—		—
Net Income available to common shareholders	$	600,999	$	510,990	$	602,484
Basic weighted average shares outstanding	122,788		117,200		111,012
Dilutive shares	84		261		—
Diluted weighted average shares outstanding	122,872		117,461		111,012
Net Income per share — Diluted	$	4.89	$	4.35	$	5.43

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Revenue (Table)

12 Months Ended

Sep. 30, 2020

Revenue [Abstract]

Disaggregation of Revenue

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

	Year Ended September 30, 2020					Year Ended September 30, 2019
	Distribution		Pipeline and Storage			Distribution			Pipeline and Storage
	(In thousands)
Gas sales revenues:
Residential	$	1,704,444	$	—		$	1,755,229		$	—
Commercial	650,396		—			716,757			—
Industrial	89,467		—			118,060			—
Public authority and other	41,339		—			42,796			—
Total gas sales revenues	2,485,646		—			2,632,842			—
Transportation revenues	99,435		636,819			97,495			623,808
Miscellaneous revenues	19,085		9,754			26,050			8,060
Revenues from contracts with customers	2,604,166		646,573			2,756,387			631,868
Alternative revenue program revenues(1)	20,856		(37,234		)	(12,958		)	(64,844		)
Other revenues	1,971		—			2,032			—
Total operating revenues	$	2,626,993	$	609,339		$	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.

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Leases (Tables)

12 Months Ended

Sep. 30, 2020

Leases [Abstract]

Other Pertinent Information Related to Leases

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

	Balance Sheet Classification	September 30, 2020
		(In thousands)
Assets
Finance leases	Net Property, Plant and Equipment	$	8,480
Operating leases	Deferred charges and other assets	227,146
Total right-of-use assets		$	235,626
Liabilities
Current
Finance leases	Current maturities of long-term debt	$	165
Operating leases	Other current liabilities	35,716
Noncurrent
Finance leases	Long-term debt	8,466
Operating leases	Deferred credits and other liabilities	201,071
Total lease liabilities		$	245,418

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

	September 30, 2020
	(In thousands)
Cash paid amounts included in the measurement of lease liabilities
Operating cash flows used for operating leases	$	37,758
Right-of-use assets obtained in exchange for lease obligations
Finance leases	$	6,083
Operating leases	$	34,169

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

	September 30, 2020
	(In thousands)
Finance lease cost	$	622
Operating lease cost	40,887
Total lease cost	$	41,509

The following table represents our weighted average discount rate:

	September 30, 2020
Weighted average discount rate
Finance leases	8.0	%
Operating leases	2.9	%

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

	September 30, 2020
Weighted average remaining lease term (years)
Finance leases	19.1
Operating leases	10.6

Schedule of Finance Lease Liability Maturities

Maturities of our lease liabilities as of September 30, 2020 were as follows:

	Total		Finance Leases		Operating Leases
	(In thousands)
2021	$	40,790	$	741	$	40,049
2022	38,423		751		37,672
2023	33,266		762		32,504
2024	25,464		773		24,691
2025	17,666		784		16,882
Thereafter	139,049		12,666		126,383
Total lease payments	294,658		16,477		278,181
Less: Imputed interest	49,240		7,846		41,394
Total	$	245,418	$	8,631	$	236,787
Reported as of September 30, 2020
Short-term lease liabilities	$	35,881	$	165	$	35,716
Long-term lease liabilities	209,537		8,466		201,071
Total lease liabilities	$	245,418	$	8,631	$	236,787

Schedule of Operating Lease Liability Maturities

Maturities of our lease liabilities as of September 30, 2020 were as follows:

	Total		Finance Leases		Operating Leases
	(In thousands)
2021	$	40,790	$	741	$	40,049
2022	38,423		751		37,672
2023	33,266		762		32,504
2024	25,464		773		24,691
2025	17,666		784		16,882
Thereafter	139,049		12,666		126,383
Total lease payments	294,658		16,477		278,181
Less: Imputed interest	49,240		7,846		41,394
Total	$	245,418	$	8,631	$	236,787
Reported as of September 30, 2020
Short-term lease liabilities	$	35,881	$	165	$	35,716
Long-term lease liabilities	209,537		8,466		201,071
Total lease liabilities	$	245,418	$	8,631	$	236,787

Schedule of Future Minimum Lease Payments for Capital Leases

The future minimum lease payments as of September 30, 2019 were as follows:

	Operating Leases(1)		Capital Lease
	(In thousands)
2020	$	21,017	$	243
2021	20,416		248
2022	19,370		253
2023	18,071		258
2024	15,718		263
Thereafter	105,544		4,343
Total minimum lease payments	$	200,136	5,608
Less amount representing interest			3,018
Present value of net minimum lease payments			$	2,590

(1)

Future minimum lease payments do not include amounts for fleet leases and other de minimis items that can be renewed beyond the initial lease term. The Company anticipates renewing the leases beyond the initial term, but the anticipated payments associated with the renewals do not meet the definition of expected minimum lease payments and therefore are not included above. Expected payments are $17.6 million in 2020, $18.0 million in 2021, $11.8 million in 2022, $8.5 million in 2023, $5.4 million in 2024 and $2.7 million thereafter.

Schedule of Future Minimum Rental Payments for Operating Leases

The future minimum lease payments as of September 30, 2019 were as follows:

	Operating Leases(1)		Capital Lease
	(In thousands)
2020	$	21,017	$	243
2021	20,416		248
2022	19,370		253
2023	18,071		258
2024	15,718		263
Thereafter	105,544		4,343
Total minimum lease payments	$	200,136	5,608
Less amount representing interest			3,018
Present value of net minimum lease payments			$	2,590

(1)

Future minimum lease payments do not include amounts for fleet leases and other de minimis items that can be renewed beyond the initial lease term. The Company anticipates renewing the leases beyond the initial term, but the anticipated payments associated with the renewals do not meet the definition of expected minimum lease payments and therefore are not included above. Expected payments are $17.6 million in 2020, $18.0 million in 2021, $11.8 million in 2022, $8.5 million in 2023, $5.4 million in 2024 and $2.7 million thereafter.

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Debt (Table)

12 Months Ended

Sep. 30, 2020

Debt Disclosure [Abstract]

Schedule of Long-term Debt Instruments

Long-term debt at September 30, 2020 and 2019 consisted of the following:

	2020		2019
	(In thousands)
Unsecured 3.00% Senior Notes, due 2027	$	500,000	$	500,000
Unsecured 2.625% Senior Notes, due 2029	300,000		—
Unsecured 5.95% Senior Notes, due 2034	200,000		200,000
Unsecured 5.50% Senior Notes, due 2041	400,000		400,000
Unsecured 4.15% Senior Notes, due 2043	500,000		500,000
Unsecured 4.125% Senior Notes, due 2044	750,000		750,000
Unsecured 4.30% Senior Notes, due 2048	600,000		600,000
Unsecured 4.125% Senior Notes, due 2049	450,000		450,000
Unsecured 3.375% Senior Notes, due 2049	500,000		—
Floating-rate term loan, due 2022	200,000		—
Medium term Series A notes, 1995-1, 6.67%, due 2025	10,000		10,000
Unsecured 6.75% Debentures, due 2028	150,000		150,000
Finance lease obligations (see Note 6)	8,631		—
Total long-term debt	4,568,631		3,560,000
Less:
Net original issue (premium) / discount on unsecured senior notes and debentures	583		193
Debt issuance cost	36,104		30,355
Current maturities	165		—
	$	4,531,779	$	3,529,452

Schedule of Maturities of Long-term Debt

Maturities of long-term debt, excluding our finance lease obligations, at September 30, 2020 were as follows (in thousands):

2021	$	—
2022	200,000
2023	—
2024	—
2025	10,000
Thereafter	4,350,000
	$	4,560,000

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Shareholders' Equity (Table)

12 Months Ended

Sep. 30, 2020

Equity [Abstract]

Forward Sales Equity Agreement

Maturity	Shares Available	Net Proceeds Available (In Thousands)		Forward Price
March 31, 2021	1,281,578	$	134,660	$	105.07
June 30, 2021	1,394,423	142,388		$	102.11
September 30, 2021	659,994	68,158		$	103.27
Total	3,335,995	$	345,206

Schedule of Accumulated Other Comprehensive Income (Loss)

The following tables provide the components of our accumulated other comprehensive income (loss) balances, net of the related tax effects allocated to each component of other comprehensive income (loss).

	Available- for-Sale Securities			Interest Rate Agreement Cash Flow Hedges			Total
	(In thousands)
September 30, 2019	$	132		$	(114,715	)	$	(114,583	)
Other comprehensive income before reclassifications	108			53,241			53,349
Amounts reclassified from accumulated other comprehensive income	(2		)	3,647			3,645
Net current-period other comprehensive income	106			56,888			56,994
September 30, 2020	$	238		$	(57,827	)	$	(57,589	)

	Available- for-Sale Securities			Interest Rate Agreement Cash Flow Hedges			Total
	(In thousands)
September 30, 2018	$	8,124		$	(91,771	)	$	(83,647	)
Other comprehensive income (loss) before reclassifications	219			(25,966		)	(25,747		)
Amounts reclassified from accumulated other comprehensive income	(1		)	3,022			3,021
Net current-period other comprehensive income (loss)	218			(22,944		)	(22,726		)
Cumulative effect of accounting change	(8,210		)	—			(8,210		)
September 30, 2019	$	132		$	(114,715	)	$	(114,583	)

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Retirement and Post-Retirement Employee Benefit Plans (Tables)

12 Months Ended

Sep. 30, 2020

Retirement Benefits [Abstract]

Schedule of Net Periodic Benefit Cost Not yet Recognized

Additionally, the amounts that have not yet been recognized in net periodic pension cost that have been recorded as regulatory assets or liabilities are as follows:

	Defined Benefit Plan			Supplemental Executive Retirement Plans		Postretirement Plans			Total
	(In thousands)
September 30, 2020
Unrecognized prior service (credit) cost	$	(584	)	$	—	$	951		$	367
Unrecognized actuarial loss	78,082			51,045		9,110			138,237
	$	77,498		$	51,045	$	10,061		$	138,604
September 30, 2019
Unrecognized prior service (credit) cost	$	(815	)	$	—	$	1,125		$	310
Unrecognized actuarial (gain) loss	67,191			56,784		(43,782		)	80,193
	$	66,376		$	56,784	$	(42,657	)	$	80,503

Schedule of Allocation of Plan Assets

The following table presents asset allocation information for the Master Trust as of September 30, 2020 and 2019.

	Targeted Allocation  Range	Actual Allocation September 30
Security Class		2020	2019
Domestic equities	35%-55%	45.3%	40.6%
International equities	10%-20%	15.6%	14.5%
Fixed income	5%-30%	17.0%	18.8%
Company stock	0%-15%	13.0%	15.4%
Other assets	0%-20%	9.1%	10.7%

The following table presents asset allocation information for the postretirement benefit plan assets as of September 30, 2020 and 2019.

	Actual Allocation September 30
Security Class	2020	2019
Diversified investment funds	97.4%	97.1%
Cash and cash equivalents	2.6%	2.9%

Schedule of Assumptions Used

The actuarial assumptions used to determine the pension liability for the supplemental plans were determined as of September 30, 2020 and 2019 and the actuarial assumptions used to determine the net periodic pension cost for the supplemental plans were determined as of September 30, 2019, 2018 and 2017. These assumptions are presented in the following table:

	Pension Liability				Pension Cost
	2020		2019		2020		2019		2018
Discount rate(1)	2.80	%	3.29	%	3.19	%	4.38	%	4.08	%
Rate of compensation increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%
Interest crediting rate	4.69	%	4.69	%	4.69	%	4.69	%	4.69	%

 (1)

Reflects a weighted average discount rate for pension cost for fiscal 2020 and 2018 due to the settlements during the year.

The actuarial assumptions used to determine the pension liability for our postretirement plan were determined as of September 30, 2020 and 2019 and the actuarial assumptions used to determine the net periodic pension cost for the postretirement plan were determined as of September 30, 2019, 2018 and 2017.

The assumptions are presented in the following table:

	Postretirement Liability				Postretirement Cost
	2020		2019		2020		2019		2018
Discount rate	2.80	%	3.29	%	3.29	%	4.38	%	3.89	%
Expected return on plan assets	4.94	%	5.14	%	5.14	%	5.33	%	4.29	%
Initial trend rate	6.25	%	6.25	%	6.25	%	6.50	%	7.00	%
Ultimate trend rate	5.00	%	5.00	%	5.00	%	5.00	%	5.00	%
Ultimate trend reached in	2026		2025		2025		2022		2022

The actuarial assumptions used to determine the pension liability for the Plan was determined as of September 30, 2020 and 2019 and the actuarial assumptions used to determine the net periodic pension cost for the Plan was determined as of September 30, 2019, 2018 and 2017. On October 21, 2020, 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, 2020, we updated our assumed mortality rates to incorporate the updated mortality table.

Additional assumptions are presented in the following table:

	Pension Liability				Pension Cost
	2020		2019		2020		2019		2018
Discount rate	2.80	%	3.29	%	3.29	%	4.38	%	3.89	%
Rate of compensation increase	3.50	%	3.50	%	3.50	%	3.50	%	3.50	%
Expected return on plan assets	6.25	%	6.50	%	6.50	%	6.75	%	6.75	%
Interest crediting rate	4.69	%	4.69	%	4.69	%	4.69	%	4.69	%

Changes in Projected Benefit Obligations, Fair Value of Plan Assets, and Funded Status of Plan

The following table presents the Plan’s accumulated benefit obligation, projected benefit obligation and funded status as of September 30, 2020 and 2019:

	2020			2019
	(In thousands)
Accumulated benefit obligation	$	565,755		$	541,287
Change in projected benefit obligation:
Benefit obligation at beginning of year	$	577,270		$	504,719
Service cost	17,551			15,311
Interest cost	19,028			22,071
Actuarial (gain) loss	22,898			71,139
Benefits paid	(32,526		)	(35,970		)
Benefit obligation at end of year	604,221			577,270
Change in plan assets:
Fair value of plan assets at beginning of year	530,109			531,691
Actual return on plan assets	31,298			25,888
Employer contributions	—			8,500
Benefits paid	(32,526		)	(35,970		)
Fair value of plan assets at end of year	528,881			530,109
Reconciliation:
Funded status	(75,340		)	(47,161		)
Unrecognized prior service cost	—			—
Unrecognized net loss	—			—
Net amount recognized	$	(75,340	)	$	(47,161	)

The following table presents the postretirement plan’s benefit obligation and funded status as of September 30, 2020 and 2019:

	2020			2019
	(In thousands)
Change in benefit obligation:
Benefit obligation at beginning of year	$	316,033		$	265,986
Service cost	13,466			10,810
Interest cost	10,612			11,839
Plan participants’ contributions	5,849			5,901
Actuarial (gain) loss	43,412			39,472
Benefits paid	(18,694		)	(17,975		)
Benefit obligation at end of year	370,678			316,033
Change in plan assets:
Fair value of plan assets at beginning of year	201,901			199,361
Actual return on plan assets	2,356			1,125
Employer contributions	16,833			13,489
Plan participants’ contributions	5,849			5,901
Benefits paid	(18,694		)	(17,975		)
Fair value of plan assets at end of year	208,245			201,901
Reconciliation:
Funded status	(162,433		)	(114,132		)
Unrecognized transition obligation	—			—
Unrecognized prior service cost	—			—
Unrecognized net loss	—			—
Accrued postretirement cost	$	(162,433	)	$	(114,132	)

The following table presents the supplemental plans’ accumulated benefit obligation, projected benefit obligation and funded status as of September 30, 2020 and 2019:

	2020			2019
	(In thousands)
Accumulated benefit obligation	$	122,207		$	138,772
Change in projected benefit obligation:
Benefit obligation at beginning of year	$	143,987		$	121,370
Service cost	1,074			869
Interest cost	4,188			5,127
Actuarial (gain) loss	7,386			25,099
Benefits paid	(4,766		)	(8,478		)
Settlements	(22,729		)	—
Benefit obligation at end of year	129,140			143,987
Change in plan assets:
Fair value of plan assets at beginning of year	—			—
Employer contribution	27,495			8,478
Benefits paid	(4,766		)	(8,478		)
Settlements	(22,729		)	—
Fair value of plan assets at end of year	—			—
Reconciliation:
Funded status	(129,140		)	(143,987		)
Unrecognized prior service cost	—			—
Unrecognized net loss	—			—
Accrued pension cost	$	(129,140	)	$	(143,987	)

Schedule of Net Benefit Costs Supplemental Plan

Net periodic pension cost for the Plan for fiscal 2020, 2019 and 2018 is presented in the following table.

	Fiscal Year Ended September 30
	2020			2019			2018
	(In thousands)
Components of net periodic pension cost:
Service cost	$	17,551		$	15,311		$	17,264
Interest cost(1)	19,028			22,071			20,803
Expected return on assets(1)	(28,316		)	(28,451		)	(27,666		)
Amortization of prior service credit(1)	(231		)	(232		)	(231		)
Recognized actuarial loss(1)	9,025			4,201			9,114
Net periodic pension cost	$	17,057		$	12,900		$	19,284

(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.

Net periodic pension cost for the supplemental plans for fiscal 2020, 2019 and 2018 is presented in the following table.

	Fiscal Year Ended September 30
	2020		2019		2018
	(In thousands)
Components of net periodic pension cost:
Service cost	$	1,074	$	869	$	1,332
Interest cost(1)	4,188		5,127		4,988
Recognized actuarial loss(1)	3,945		2,227		3,079
Settlements(1)	9,180		—		4,159
Net periodic pension cost	$	18,387	$	8,223	$	13,558

(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.

Net periodic postretirement cost for fiscal 2020, 2019 and 2018 is presented in the following table.

	Fiscal Year Ended September 30
	2020			2019			2018
	(In thousands)
Components of net periodic postretirement cost:
Service cost	$	13,466		$	10,810		$	12,078
Interest cost(1)	10,612			11,839			10,907
Expected return on assets(1)	(10,499		)	(10,659		)	(8,006		)
Amortization of transition obligation(1)	—			—			—
Amortization of prior service cost (credit)(1)	173			173			11
Recognized actuarial gain(1)	(1,337		)	(8,178		)	(6,473		)
Net periodic postretirement cost	$	12,415		$	3,985		$	8,517

(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.

Schedule of Employee Pension Plans Investments at Fair Value

In addition to the assets shown below, the Plan had net accounts receivable of $0.7 million and $1.3 million at September 30, 2020 and 2019, which materially approximates fair value due to the short-term nature of these assets.

	Assets at Fair Value as of September 30, 2020
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Common stocks	$	211,244	$	—	$	—	$	211,244
Money market funds	—		6,096		—		6,096
Registered investment companies	29,762		—		—		29,762
Government securities:
Mortgage-backed securities	—		15,230		—		15,230
U.S. treasuries	21,755		36		—		21,791
Corporate bonds	—		52,648		—		52,648
Total investments measured at fair value	$	262,761	$	74,010	$	—	336,771
Investments measured at net asset value:
Common/collective trusts (1)							122,207
Limited partnerships (1)							69,176
Total investments							$	528,154

	Assets at Fair Value as of September 30, 2019
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Common stocks	$	212,785	$	—	$	—	$	212,785
Money market funds	—		16,419		—		16,419
Registered investment companies	26,326		—		—		26,326
Government securities:
Mortgage-backed securities	—		19,986		—		19,986
U.S. treasuries	22,930		885		—		23,815
Corporate bonds	—		55,774		—		55,774
Total investments measured at fair value	$	262,041	$	93,064	$	—	355,105
Investments measured at net asset value:
Common/collective trusts (1)							108,975
Limited partnerships (1)							64,718
Total investments							$	528,798

(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.

Schedule of Expected 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)
2021	$	37,523	$	30,021
2022	37,804		17,117
2023	39,053		5,124
2024	40,036		4,472
2025	41,016		32,550
2026-2030	204,582		22,308

The following benefit payments paid by us, retirees and prescription drug subsidy payments for our postretirement benefit plans, which reflect expected future service, as appropriate, are expected to be paid in the following fiscal years. Company payments for fiscal 2020 include contributions to our postretirement plan trusts.

	Company Payments		Retiree Payments		Subsidy Payments		Total Postretirement Benefits
	(In thousands)
2021	$	22,632	$	4,368	$	—	$	27,000
2022	16,263		4,772		—		21,035
2023	16,590		5,144		—		21,734
2024	17,517		5,651		—		23,168
2025	18,353		6,104		—		24,457
2026-2030	101,158		35,039		—		136,197

Schedule of Postretirement Benefit Plans Investments at Fair Value

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, 2020 and 2019. The methods used to determine fair value for the assets held by the Retiree Medical Plan are fully described in Note 2.

	Assets at Fair Value as of September 30, 2020
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Money market funds	$	—	$	5,525	$	—	$	5,525
Registered investment companies	202,720		—		—		202,720
Total investments measured at fair value	$	202,720	$	5,525	$	—	$	208,245

	Assets at Fair Value as of September 30, 2019
	Level 1		Level 2		Level 3		Total
	(In thousands)
Investments:
Money market funds	$	—	$	5,972	$	—	$	5,972
Registered investment companies	195,929		—		—		195,929
Total investments measured at fair value	$	195,929	$	5,972	$	—	$	201,901

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Stock and Other Compensation Plans (Table)

12 Months Ended

Sep. 30, 2020

Share-based Payment Arrangement [Abstract]

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity

The following summarizes information regarding the restricted stock units granted under the plan during the fiscal years ended September 30, 2020, 2019 and 2018:

	2020				2019				2018
	Number of Restricted Units		Weighted Average Grant-Date Fair Value		Number of Restricted Units		Weighted Average Grant-Date Fair Value		Number of Restricted Units		Weighted Average Grant-Date Fair Value
Nonvested at beginning of year	503,072		$	91.66	538,592		$	80.91	570,814		$	69.45
Granted	199,985		102.34		241,472		98.25		248,710		85.62
Vested	(242,975	)	85.66		(269,347	)	76.71		(274,392	)	64.43
Forfeited	(16,803	)	96.87		(7,645	)	86.37		(6,540	)	74.87
Nonvested at end of year	443,279		$	99.28	503,072		$	91.66	538,592		$	80.91

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Details of Selected Consolidated Balance Sheet Captions (Table)

12 Months Ended

Sep. 30, 2020

Balance Sheet Related Disclosures [Abstract]

Accounts Receivables Detail Table

Accounts receivable was comprised of the following at September 30, 2020 and 2019:

	September 30
	2020			2019
	(In thousands)
Billed accounts receivable	$	140,259		$	126,984
Unbilled revenue	80,699			78,986
Contributions in aid of construction receivable	19,821			22,378
Other accounts receivable	19,765			18,122
Total accounts receivable	260,544			246,470
Less: allowance for doubtful accounts	(29,949		)	(15,899		)
Net accounts receivable	$	230,595		$	230,571

Other Current Assets Detail Table

Other current assets as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Deferred gas costs	$	40,593	$	23,766
Prepaid expenses	40,340		38,895
Materials and supplies	6,829		5,916
Assets from risk management activities	5,687		1,586
Other	14,456		2,609
Total	$	107,905	$	72,772

Property, Plant and Equipment Detail Table

Property, plant and equipment was comprised of the following as of September 30, 2020 and 2019:

	September 30
	2020			2019
	(In thousands)
Storage plant	$	530,985		$	431,286
Transmission plant	3,459,765			3,157,316
Distribution plant	10,680,495			9,333,011
General plant	829,624			799,095
Intangible plant	38,297			38,191
	15,539,166			13,758,899
Construction in progress	418,055			421,694
	15,957,221			14,180,593
Less: accumulated depreciation and amortization	(2,601,874		)	(2,392,924		)
Net property, plant and equipment(1)	$	13,355,347		$	11,787,669

(1)

Net property, plant and equipment includes plant acquisition adjustments of $(37.8) million and $(46.7) million at September 30, 2020 and 2019.

Goodwill Detail Table

The following presents our goodwill balance allocated by segment and changes in the balance for the fiscal year ended September 30, 2020:

	Distribution			Pipeline and Storage		Total
	(In thousands)
Balance as of September 30, 2019	$	587,604		$	143,102	$	730,706
Deferred tax adjustments on prior acquisitions(1)	(768		)	1,319		551
Balance as of September 30, 2020	$	586,836		$	144,421	$	731,257

(1)

We annually adjust certain deferred taxes recorded in connection with an acquisition completed in fiscal 2005, which resulted in an increase to goodwill and net deferred tax liabilities of $0.6 million for fiscal 2020.

Deferred Charges and Other Assets Detail Table

Deferred charges and other assets as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Marketable securities	$	103,952	$	101,883
Regulatory assets (See Note 2)	371,707		260,220
Operating lease right of use assets (See Note 6)	227,146		—
Assets from risk management activities	74,991		225
Tax receivable	—		10,099
Other	23,374		18,786
Total	$	801,170	$	391,213

Accounts Payable and Accrued Liabilities

Accounts payable and accrued liabilities as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Trade accounts payable	$	141,075	$	176,581
Accrued gas payable	42,054		36,817
Accrued liabilities	52,646		51,626
Total	$	235,775	$	265,024

Other Current Liabilities Detail Table

Other current liabilities as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Customer credit balances and deposits	$	56,485	$	54,617
Accrued employee costs	57,057		55,216
Deferred gas costs	19,985		14,112
Operating lease liabilities (See Note 6)	35,716		—
Accrued interest	53,554		51,381
Liabilities from risk management activities	2,015		4,552
Taxes payable	148,292		135,597
Pension and postretirement liabilities	29,609		26,197
Regulatory cost of service reserve	1,716		4,209
Regulatory cost of removal obligation	73,908		55,721
APT annual adjustment mechanism	43,893		52,856
Regulatory excess deferred taxes (See Note 13)	20,887		21,206
Other	3,344		3,837
Total	$	546,461	$	479,501

Deferred Credits and Other Liabilities Detail Table

Deferred credits and other liabilities as of September 30, 2020 and 2019 were comprised of the following accounts.

	September 30
	2020		2019
	(In thousands)
Pension and post retirement liabilities	$	337,303	$	279,083
Operating lease liabilities (See Note 6)	201,071		—
Customer advances for construction	10,060		12,566
Other regulatory liabilities (See Note 2)	17,838		16,120
Asset retirement obligation	20,348		17,054
Liabilities from risk management activities	—		1,249
APT annual adjustment mechanism	13,486		25,545
Unrecognized tax benefits	30,921		27,716
Other	11,101		20,883
Total	$	642,128	$	400,216

Other Non-Operating Income (Expense) Table

Other non-operating income (expense) for the fiscal years ended September 30, 2020, 2019 and 2018 were comprised of the following accounts.

	Year Ended September 30
	2020			2019			2018
	(In thousands)
Equity component of AFUDC	$	23,493		$	11,165		$	—
Performance-based rate program	6,771			6,737			6,745
Pension and other postretirement non-service credit (cost)	(3,189		)	3,016			(5,770		)
Interest income	2,932			4,160			1,450
Community support spending	(11,728		)	(4,771		)	(6,053		)
Miscellaneous	(11,108		)	(12,903		)	(6,516		)
Total	$	7,171		$	7,404		$	(10,144	)

Supplemental Cash Flow Disclosures

Supplemental disclosures of cash flow information for the fiscal years ended September 30, 2020, 2019 and 2018 were as follows:

	Year Ended September 30
	2020			2019		2018
	(In thousands)
Cash Paid (Received) During The Period For:
Interest(1)	$	194,993		$	184,852	$	169,987
Income taxes	$	(3,071	)	$	11,467	$	6,102
Non-Cash Transactions:
Capital expenditures included in current liabilities	$	113,365		$	149,993	$	112,211

(1) Cash paid during the period for interest, net of amounts capitalized was $82.3 million, $91.3 million and $106.8 million for the fiscal years ended September 30, 2020, 2019 and 2018.

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Income Taxes (Table)

12 Months Ended

Sep. 30, 2020

Income Tax Disclosure [Abstract]

Schedule of Components of Income Tax Expense (Benefit)

The components of income tax expense from continuing operations for 2020, 2019 and 2018 were as follows:

	2020			2019		2018
	(In thousands)
Current
Federal	$	—		$	—	$	(10,099	)
State	14,193			8,412		11,075
Deferred
Federal	143,039			113,331		150,556
State (1)	(11,879		)	17,160		15,330
TCJA Impact	—			—		(158,782		)
Income tax expense	$	145,353		$	138,903	$	8,080

(1)

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

Schedule of Effective Income Tax Rate Reconciliation

Reconciliations of the provision for income taxes computed at the statutory rate to the reported provisions for income taxes from continuing operations for 2020, 2019 and 2018 are set forth below:

	2020			2019			2018
	(In thousands)
Tax at statutory rate(1)	$	156,827		$	136,565		$	149,730
Common stock dividends deductible for tax reporting	(1,419		)	(1,460		)	(1,745		)
State taxes (net of federal benefit)	22,791			20,202			19,826
Amortization of excess deferred taxes	(16,125		)	(14,085		)	(1,219		)
Remeasurement due to TCJA	—			—			(158,782		)
Remeasurement due to state deferred tax rate change	(20,962		)	—			—
Other, net	4,241			(2,319		)	270
Income tax expense	$	145,353		$	138,903		$	8,080

(1) Tax expense is calculated at the statutory federal income tax rate of 21.0%, 21.0%, 24.5% for the year ended September 30, 2020, 2019 and 2018.

Schedule of Deferred Tax Assets and Liabilities

The tax effect of temporary differences that gave rise to significant components of the deferred tax liabilities and deferred tax assets at September 30, 2020 and 2019 are presented below:

	2020			2019
	(In thousands)
Deferred tax assets:
Employee benefit plans	$	66,991		$	70,929
Interest rate swaps	16,719			33,918
Net operating loss carryforwards	476,507			485,133
Charitable and other credit carryforwards	8,712			8,241
Regulatory excess deferred tax	161,565			165,701
Other	73,542			13,186
Total deferred tax assets	804,036			777,108
Valuation allowance	(1,102		)	(1,894		)
Net deferred tax assets	802,934			775,214
Deferred tax liabilities:
Difference in net book value and net tax value of assets(1)	(2,138,966		)	(2,004,516		)
Pension funding	(484		)	(4,384		)
Gas cost adjustments	(23,209		)	(18,072		)
Other	(96,844		)	(48,257		)
Total deferred tax liabilities	(2,259,503		)	(2,075,229		)
Net deferred tax liabilities	$	(1,456,569	)	$	(1,300,015	)
Deferred credits for rate regulated entities	$	2,537		$	2,582

(1) Includes $129.0 million and $131.0 million of deferred tax liability related to goodwill as of September 30, 2020 and 2019.

Schedule of Unrecognized Tax Benefits Roll Forward

The following table reconciles the beginning and ending balance of our unrecognized tax benefits:

	2020			2019			2018
	(In thousands)
Unrecognized tax benefits - beginning balance	$	27,716		$	26,203		$	23,719
Increase (decrease) resulting from prior period tax positions	(26		)	(923		)	22
Increase resulting from current period tax positions	3,231			2,436			2,462
Unrecognized tax benefits - ending balance	30,921			27,716			26,203
Less: deferred federal and state income tax benefits	(6,493		)	(5,820		)	(5,503		)
Total unrecognized tax benefits that, if recognized, would impact the effective income tax rate as of the end of the year	$	24,428		$	21,896		$	20,700

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Financial Instruments (Table)

12 Months Ended

Sep. 30, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of financial instrument assets and liabilities at fair value

The following table shows the fair values of our risk management assets and liabilities at September 30, 2020 and 2019.

	September 30
	2020			2019
	(In thousands)
Assets from risk management activities, current	$	5,687		$	1,586
Assets from risk management activities, noncurrent	74,991			225
Liabilities from risk management activities, current	(2,015		)	(4,552		)
Liabilities from risk management activities, noncurrent	—			(1,249		)
Net assets (liabilities)	$	78,663		$	(3,990	)

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, 2020 and 2019. The gross amounts of recognized assets and liabilities are netted within our consolidated balance sheets to the extent that we have netting arrangements with the counterparties. However, as of September 30, 2020 and 2019, no gross amounts and no cash collateral were netted within our consolidated balance sheet.

	Balance Sheet Location	Assets		Liabilities
		(In thousands)
September 30, 2020
Designated As Hedges:
Interest rate contracts	Deferred charges and other assets / Deferred credits and other liabilities	$	73,055	$	—
Total		73,055		—
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	5,687		(2,015		)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	1,936		—
Total		7,623		(2,015		)
Gross / Net Financial Instruments		$	80,678	$	(2,015	)

	Balance Sheet Location	Assets		Liabilities
		(In thousands)
September 30, 2019
Not Designated As Hedges:
Commodity contracts	Other current assets / Other current liabilities	$	1,586	$	(4,552	)
Commodity contracts	Deferred charges and other assets / Deferred credits and other liabilities	225		(1,249		)
Total		1,811		(5,801		)
Gross / Net Financial Instruments		$	1,811	$	(5,801	)

Other comprehensive income from hedging table

The following table summarizes the gains and losses arising from hedging transactions that were recognized as a component of other comprehensive income (loss), for the years ended September 30, 2020 and 2019. The amounts included in the table below exclude gains and losses arising from ineffectiveness because these amounts are immediately recognized in the statement of comprehensive income as incurred.

	Fiscal Year Ended September 30
	2020		2019
	(In thousands)
Increase (decrease) in fair value:
Interest rate agreements	$	53,241	$	(25,966	)
Recognition of losses in earnings due to settlements:
Interest rate agreements	3,647		3,022
Total other comprehensive income (loss) from hedging, net of tax	$	56,888	$	(22,944	)

Expected recognition in earnings of deferred losses in AOCI table

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 2049. However, the table below does not include the expected recognition in earnings of our outstanding interest rate agreements as those financial instruments have not yet settled.

	Interest Rate Agreements
	(In thousands)
2021	$	(4,569	)
2022	(4,569		)
2023	(4,569		)
2024	(4,569		)
2025	(4,569		)
Thereafter	(91,657		)
Total	$	(114,502	)

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Fair Value Measurements (Table)

12 Months Ended

Sep. 30, 2020

Fair Value Disclosures [Abstract]

Fair value measurements table

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, 2020 and 2019. 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.

	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)(1)		Significant Other Unobservable Inputs (Level 3)		Netting and Cash Collateral		September 30, 2020
	(In thousands)
Assets:
Financial instruments	$	—	$	80,678	$	—	$	—	$	80,678
Debt and equity securities
Registered investment companies	37,831		—		—		—		37,831
Bond mutual funds	29,166		—		—		—		29,166
Bonds(2)	—		32,900		—		—		32,900
Money market funds	—		4,055		—		—		4,055
Total debt and equity securities	66,997		36,955		—		—		103,952
Total assets	$	66,997	$	117,633	$	—	$	—	$	184,630
Liabilities:
Financial instruments	$	—	$	2,015	$	—	$	—	$	2,015

	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)(1)		Significant Other Unobservable Inputs (Level 3)		Netting and Cash Collateral		September 30, 2019
	(In thousands)
Assets:
Financial instruments	$	—	$	1,811	$	—	$	—	$	1,811
Debt and equity securities
Registered investment companies	41,406		—		—		—		41,406
Bond mutual funds	25,966		—		—		—		25,966
Bonds(2)	—		31,915		—		—		31,915
Money market funds	—		2,596		—		—		2,596
Total debt and equity securities	67,372		34,511		—		—		101,883
Total assets	$	67,372	$	36,322	$	—	$	—	$	103,694
Liabilities:
Financial instruments	$	—	$	5,801	$	—	$	—	$	5,801

(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

Other fair value measurements table

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, 2020:

	September 30, 2020
	(In thousands)
Carrying Amount	$	4,560,000
Fair Value	$	5,597,183

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Selected Quarterly Financial Data (Table)

12 Months Ended

Sep. 30, 2020

Quarterly Financial Information Disclosure [Abstract]

Schedule of Quarterly Financial Information

Summarized unaudited quarterly financial data is presented below. The sum of net income per share by quarter may not equal the net income per share for the fiscal year due to variations in the weighted average shares outstanding used in computing such amounts. Our businesses are seasonal due to weather conditions in our service areas. For further information on its effects on quarterly results, see the “Results of Operations” discussion included in the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” section herein.

	Quarter Ended
	December 31			March 31			June 30			September 30
	(In thousands, except per share data)
Fiscal year 2020:
Operating revenues
Distribution	$	828,504		$	933,005		$	435,308		$	430,176
Pipeline and storage	148,176			146,237			158,008			156,918
Intersegment eliminations	(101,117		)	(101,577		)	(100,321		)	(112,180		)
Total operating revenues	875,563			977,665			492,995			474,914
Purchased gas cost	296,868			317,883			26,072			18,031
Operating income	252,781			331,438			139,035			100,845
Net Income	178,673			239,646			117,791			65,333
Basic net income per share	$	1.47		$	1.95		$	0.96		$	0.53
Diluted net income per share	$	1.47		$	1.95		$	0.96		$	0.53

	Quarter Ended
	December 31			March 31			June 30			September 30
	(In thousands, except per share data)
Fiscal year 2019:
Operating revenues
Distribution	$	838,835		$	1,057,889		$	444,944		$	403,793
Pipeline and storage	134,470			135,650			149,198			147,706
Intersegment eliminations	(95,523		)	(98,894		)	(108,404		)	(107,816		)
Total operating revenues	877,782			1,094,645			485,738			443,683
Purchased gas cost	342,165			471,676			31,326			13,670
Operating income	236,464			297,677			122,202			89,715
Net Income	157,646			214,888			80,466			58,406
Basic net income per share	$	1.38		$	1.83		$	0.68		$	0.49
Diluted net income per share	$	1.38		$	1.82		$	0.68		$	0.49

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Nature of Business (Details) customer in Millions	Sep. 30, 2020 customer regulated_distribution_division
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of customers serviced | customer	3,000,000
Number of regulated distribution divisions | regulated_distribution_division	6

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Summary of Significant Accounting Policies - Schedule of Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Regulatory Liabilities [Line Items]
Regulatory Liabilities	$ 1,367,013	$ 1,386,126
Regulatory Assets [Line Items]
Regulatory Assets	414,641	284,547
Regulatory excess deferred taxes
Regulatory Liabilities [Line Items]
Regulatory Liabilities	718,651	726,307
Regulatory Cost of Service Reserve
Regulatory Liabilities [Line Items]
Regulatory Liabilities	1,716	5,238
Regulatory cost of removal obligation
Regulatory Liabilities [Line Items]
Regulatory Liabilities	531,096	528,893
Deferred gas costs
Regulatory Liabilities [Line Items]
Regulatory Liabilities	19,985	14,112
Asset retirement obligation
Regulatory Liabilities [Line Items]
Regulatory Liabilities	20,348	17,054
APT annual adjustment mechanism
Regulatory Liabilities [Line Items]
Regulatory Liabilities	57,379	78,402
Other
Regulatory Liabilities [Line Items]
Regulatory Liabilities	17,838	16,120
Other Current Liabilities | Regulatory excess deferred taxes
Regulatory Liabilities [Line Items]
Regulatory Liabilities	20,900	21,200
Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory Assets	149,089	86,089
Infrastructure mechanisms
Regulatory Assets [Line Items]
Regulatory Assets	183,943	131,894
Deferred gas costs
Regulatory Assets [Line Items]
Regulatory Assets	40,593	23,766
Recoverable loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory Assets	4,894	6,551
Deferred pipeline record collection costs
Regulatory Assets [Line Items]
Regulatory Assets	29,839	26,418
Other
Regulatory Assets [Line Items]
Regulatory Assets	6,283	$ 9,829
State and Local Jurisdiction | Regulatory excess deferred taxes
Regulatory Liabilities [Line Items]
Regulatory Liabilities	$ 12,100

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Summary of Significant Accounting Policies - Narrative (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Alternative Revenue Program [Line Items]
Composite depreciation rate for regulated property, plant and equipment	3.00%	3.10%	3.20%
Asset retirement obligations	$ 20,300,000	$ 17,100,000
Asset retirement costs	14,400,000	11,300,000
Cash held in margin accounts	$ 0	$ 0
Pipeline and Storage
Alternative Revenue Program [Line Items]
Regulatory mechanism threshold	75.00%
Rate Case Revenue Benchmark	$ 69,400,000

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Summary of Significant Accounting Policies Allowance for Funds Used During Construction (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Accounting Policies [Abstract]
AFUDC Debt	$ 8,436	$ 7,643	$ 6,810
Equity component of AFUDC	23,493	11,165	0
AFUDC, Additions	$ 31,929	$ 18,808	$ 6,810

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Segment Information - Narrative (Details)	12 Months Ended
	Sep. 30, 2020 segment state
Segment Reporting [Abstract]
Reportable segments | segment	2
Number of states with operations | state	8

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Segment Information - Income Statements and Capital Expenditures By Segment (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Total operating revenues									$ 2,821,137	$ 2,901,848	$ 3,115,546
Total purchased gas cost									658,854	858,837	1,167,848
Operation and maintenance expense									629,601	630,308	594,795
Depreciation and amortization expense									429,828	391,456	361,083
Taxes, other than income									278,755	275,189	263,886
Operating income	$ 100,845	$ 139,035	$ 331,438	$ 252,781	$ 89,715	$ 122,202	$ 297,677	$ 236,464	824,099	746,058	727,934
Miscellaneous expense (benefit)									7,171	7,404	(10,144)
Interest charges									84,474	103,153	106,646
Income from continuing operations before income taxes									746,796	650,309	611,144
Income tax (benefit) expense									145,353	138,903	8,080
Net Income									601,443	511,406	603,064
Capital expenditures									1,935,676	1,693,477	1,467,591
Distribution
Segment Reporting Information [Line Items]
Total operating revenues									2,624,251	2,742,824	3,000,404
Pipeline and Storage
Segment Reporting Information [Line Items]
Total operating revenues									196,886	159,024	115,142
Operating Segments | Distribution
Segment Reporting Information [Line Items]
Total operating revenues									2,626,993	2,745,461	3,003,047
Total purchased gas cost									1,071,227	1,268,591	1,559,836
Operation and maintenance expense									472,760	480,222	461,048
Depreciation and amortization expense									309,582	283,697	264,930
Taxes, other than income									245,181	242,179	231,566
Operating income									528,243	470,772	485,667
Miscellaneous expense (benefit)									(1,265)	6,241	(6,649)
Interest charges									39,634	60,031	65,850
Income from continuing operations before income taxes									487,344	416,982	413,168
Income tax (benefit) expense									91,680	88,168	(29,798)
Net Income									395,664	328,814	442,966
Capital expenditures									1,466,631	1,274,613	1,025,800
Operating Segments | Pipeline and Storage
Segment Reporting Information [Line Items]
Total operating revenues									609,339	567,024	507,713
Total purchased gas cost									1,548	(360)	1,978
Operation and maintenance expense									158,115	151,329	134,995
Depreciation and amortization expense									120,246	107,759	96,153
Taxes, other than income									33,574	33,010	32,320
Operating income									295,856	275,286	242,267
Miscellaneous expense (benefit)									8,436	1,163	(3,495)
Interest charges									44,840	43,122	40,796
Income from continuing operations before income taxes									259,452	233,327	197,976
Income tax (benefit) expense									53,673	50,735	37,878
Net Income									205,779	182,592	160,098
Capital expenditures									469,045	418,864	441,791
Eliminations
Segment Reporting Information [Line Items]
Total operating revenues									(415,195)	(410,637)	(395,214)
Total purchased gas cost									(413,921)	(409,394)	(393,966)
Operation and maintenance expense									(1,274)	(1,243)	(1,248)
Depreciation and amortization expense									0	0	0
Taxes, other than income									0	0	0
Operating income									0	0	0
Miscellaneous expense (benefit)									0	0	0
Interest charges									0	0	0
Income from continuing operations before income taxes									0	0	0
Income tax (benefit) expense									0	0	0
Net Income									0	0	0
Capital expenditures									0	0	0
Eliminations | Distribution
Segment Reporting Information [Line Items]
Total operating revenues									2,742	2,637	2,643
Eliminations | Pipeline and Storage
Segment Reporting Information [Line Items]
Total operating revenues									$ 412,453	$ 408,000	$ 392,571

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Segment Information - Revenue from External Customers by Products and Services (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Revenues from External Customers and Long-Lived Assets [Line Items]
Total operating revenues	$ 2,821,137	$ 2,901,848	$ 3,115,546
Distribution
Revenues from External Customers and Long-Lived Assets [Line Items]
Other gas revenues	23,129	41,704	8,999
Total distribution revenues	2,624,251	2,742,824	3,000,404
Distribution | Natural Gas, US Regulated
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenue	2,503,681	2,605,491	2,892,155
Distribution | Natural Gas, Gathering, Transportation, Marketing and Processing
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenue	97,441	95,629	99,250
Distribution | Residential | Natural Gas, US Regulated
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenue	1,717,070	1,733,548	1,916,101
Distribution | Commercial | Natural Gas, US Regulated
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenue	654,963	711,284	797,073
Distribution | Industrial | Natural Gas, US Regulated
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenue	89,641	118,046	131,267
Distribution | Public authority and other | Natural Gas, US Regulated
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenue	42,007	42,613	47,714
Pipeline and Storage
Revenues from External Customers and Long-Lived Assets [Line Items]
Pipeline and storage revenues	$ 196,886	$ 159,024	$ 115,142

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Segment Information - Balance Sheet Information by Segment (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Segment Reporting Information [Line Items]
Property, plant and equipment, net	$ 13,355,347	$ 11,787,669
Total assets	15,359,032	13,367,619
Operating Segments | Distribution
Segment Reporting Information [Line Items]
Property, plant and equipment, net	9,944,978	8,737,590
Total assets	14,578,176	12,579,741
Operating Segments | Pipeline and Storage
Segment Reporting Information [Line Items]
Property, plant and equipment, net	3,410,369	3,050,079
Total assets	3,647,907	3,279,323
Eliminations
Segment Reporting Information [Line Items]
Property, plant and equipment, net	0	0
Total assets	$ (2,867,051)	$ (2,491,445)

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Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Basic Earnings Per Share
Net Income	$ 65,333	$ 117,791	$ 239,646	$ 178,673	$ 58,406	$ 80,466	$ 214,888	$ 157,646	$ 601,443	$ 511,406	$ 603,064
Less: Income allocated to participating securities									444	416	580
Net Income available to common shareholders									$ 600,999	$ 510,990	$ 602,484
Basic weighted average shares outstanding									122,788	117,200	111,012
Net Income per share — Basic	$ 0.53	$ 0.96	$ 1.95	$ 1.47	$ 0.49	$ 0.68	$ 1.83	$ 1.38	$ 4.89	$ 4.36	$ 5.43
Earnings Per Share, Diluted [Abstract]
Net Income available to common shareholders									$ 600,999	$ 510,990	$ 602,484
Effect of dilutive shares									0	0	0
Net Income available to common shareholders									$ 600,999	$ 510,990	$ 602,484
Basic weighted average shares outstanding									122,788	117,200	111,012
Dilutive shares									84	261	0
Diluted weighted average shares outstanding									122,872	117,461	111,012
Net Income per share — Diluted	$ 0.53	$ 0.96	$ 1.95	$ 1.47	$ 0.49	$ 0.68	$ 1.82	$ 1.38	$ 4.89	$ 4.35	$ 5.43

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Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 2,821,137	$ 2,901,848	$ 3,115,546
Distribution
Disaggregation of Revenue [Line Items]
Total operating revenues	2,624,251	2,742,824	3,000,404
Pipeline and Storage
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 196,886	159,024	115,142
Regulatory mechanism threshold	75.00%
Operating Segments | Distribution
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 2,604,166	2,756,387
Alternative revenue program revenues	20,856	(12,958)
Other revenues	1,971	2,032
Total operating revenues	2,626,993	2,745,461	3,003,047
Operating Segments | Pipeline and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	646,573	631,868
Alternative revenue program revenues	(37,234)	(64,844)
Other revenues	0	0
Total operating revenues	609,339	567,024	$ 507,713
Operating Segments | Gas sales revenue [Member] | Distribution
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	2,485,646	2,632,842
Operating Segments | Gas sales revenue [Member] | Pipeline and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Operating Segments | Gas sales revenue [Member] | Residential | Distribution
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1,704,444	1,755,229
Operating Segments | Gas sales revenue [Member] | Residential | Pipeline and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Operating Segments | Gas sales revenue [Member] | Commercial | Distribution
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	650,396	716,757
Operating Segments | Gas sales revenue [Member] | Commercial | Pipeline and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Operating Segments | Gas sales revenue [Member] | Industrial | Distribution
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	89,467	118,060
Operating Segments | Gas sales revenue [Member] | Industrial | Pipeline and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Operating Segments | Gas sales revenue [Member] | Public authority and other | Distribution
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	41,339	42,796
Operating Segments | Gas sales revenue [Member] | Public authority and other | Pipeline and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0	0
Operating Segments | Transportation revenue [Member] | Distribution
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	99,435	97,495
Operating Segments | Transportation revenue [Member] | Pipeline and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	636,819	623,808
Operating Segments | Miscellaneous revenue [Member] | Distribution
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	19,085	26,050
Operating Segments | Miscellaneous revenue [Member] | Pipeline and Storage
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 9,754	$ 8,060

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Leases - Narrative (Details) - USD ($) $ in Thousands		12 Months Ended
	Oct. 01, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2020	Oct. 01, 2019
Lessee, Lease, Description [Line Items]
Operating lease right-of-use assets				$ 227,146
Operating lease liabilities				$ 236,787
Lease and rental expense		$ 40,400	$ 33,800
Accounting Standards Update [Extensible List]	us-gaap:AccountingStandardsUpdate201602Member
Cumulative effect of accounting change
Lessee, Lease, Description [Line Items]
Operating lease right-of-use assets					$ 231,300
Operating lease liabilities					231,300
Accrued and prepaid rent reclassified					6,500
Deferred rent credits and other liabilities reclassified					$ 2,500

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Leases - Weighted Averages (Details)	Sep. 30, 2020
Leases [Abstract]
Finance lease, weighted average remaining lease term	19 years 1 month 6 days
Operating lease, weighted average remaining lease term	10 years 7 months 6 days
Finance lease, weighted average discount rate (in percent)	8.00%
Operating lease, weighted average discount rate (in percent)	2.90%

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Leases - Income statement presentation (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($)
Lessee, Finance Lease, Description [Abstract]
Finance lease cost	$ 622
Operating lease cost	40,887
Total lease cost	$ 41,509

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Leases - Balance sheet presentation (Details) $ in Thousands	Sep. 30, 2020 USD ($)
Assets
Finance leases	$ 8,480
Operating leases	227,146
Total right-of-use assets	235,626
Current
Finance leases	165
Operating leases	35,716
Noncurrent
Finance leases	8,466
Operating leases	201,071
Total lease liabilities	$ 245,418
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	us-gaap:PublicUtilitiesPropertyPlantAndEquipmentNet
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	us-gaap:OtherAssetsNoncurrent
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:LongTermDebtAndCapitalLeaseObligationsCurrent
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilitiesCurrent
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	us-gaap:LongTermDebtAndCapitalLeaseObligations
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilitiesNoncurrent

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Leases - Other pertinent information (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($)
Leases [Abstract]
Operating cash flows used for operating leases	$ 37,758
Right-of-use assets obtained in exchange for lease obligations, Finance leases	6,083
Right-of-use assets obtained in exchange for lease obligations, Operating leases	$ 34,169

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Leases - Maturities of lease liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Leases [Abstract]
2021	$ 40,790
2022	38,423
2023	33,266
2024	25,464
2025	17,666
Thereafter	139,049
Total lease payments	294,658
Less: Imputed interest	49,240
Total lease liabilities	245,418
Short-term lease liabilities	35,881
Long-term lease liabilities	209,537
Finance Leases
2021	741
2022	751
2023	762
2024	773
2025	784
Thereafter	12,666
Total lease payments	16,477
Less: Imputed interest	7,846
Total	8,631	$ 0
Short-term lease liabilities	165
Long-term lease liabilities	8,466
Operating Leases
2021	40,049
2022	37,672
2023	32,504
2024	24,691
2025	16,882
Thereafter	126,383
Total lease payments	278,181
Less: Imputed interest	41,394
Total	236,787
Short-term lease liabilities	35,716
Long-term lease liabilities	$ 201,071

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Leases - Future minimum lease payments (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Lessee, Lease, Description [Line Items]
2021		$ 21,017
2022		20,416
2023		19,370
2024		18,071
2025		15,718
Thereafter		105,544
Total minimum lease payments		200,136
2021		243
2022		248
2023		253
2024		258
2025		263
Thereafter		4,343
Total minimum lease payments		5,608
Less amount representing interest		$ 3,018
Present value of net minimum lease payments	$ 2,590
Vehicles
Lessee, Lease, Description [Line Items]
2020	17,600
2021	18,000
2022	11,800
2023	8,500
2024	5,400
Thereafter	$ 2,700

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Debt - Schedule of Long-term Debt Instruments (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Debt Instrument [Line Items]
Long Term Debt	$ 4,560,000
Finance lease obligation	8,631	$ 0
Total long-term debt	4,568,631	3,560,000
Less:
Net original issue (premium) / discount on unsecured senior notes and debentures	583	193
Debt issuance cost	36,104	30,355
Current maturities	165	0
Long-term debt	4,531,779	3,529,452
Unsecured 3.00% Senior Notes, due 2027
Debt Instrument [Line Items]
Long Term Debt	$ 500,000	500,000
Less:
Interest rate	3.00%
Unsecured 2.625% Senior Notes, due 2029
Debt Instrument [Line Items]
Long Term Debt	$ 300,000	0
Less:
Interest rate	2.625%
Unsecured 5.95% Senior Notes, due 2034
Debt Instrument [Line Items]
Long Term Debt	$ 200,000	200,000
Less:
Interest rate	5.95%
Unsecured 5.50% Senior Notes, due 2041
Debt Instrument [Line Items]
Long Term Debt	$ 400,000	400,000
Less:
Interest rate	5.50%
Unsecured 4.15% Senior Notes, due 2043
Debt Instrument [Line Items]
Long Term Debt	$ 500,000	500,000
Less:
Interest rate	4.15%
Unsecured 4.125% Senior Notes, due 2044
Debt Instrument [Line Items]
Long Term Debt	$ 750,000	750,000
Less:
Interest rate	4.125%
Unsecured 4.30% Senior Notes, due 2048
Debt Instrument [Line Items]
Long Term Debt	$ 600,000	600,000
Less:
Interest rate	4.30%
Unsecured 4.125% Senior Notes, due 2049
Debt Instrument [Line Items]
Long Term Debt	$ 450,000	450,000
Less:
Interest rate	4.125%
Unsecured 3.375% Senior Notes, due 2049
Debt Instrument [Line Items]
Long Term Debt	$ 500,000	0
Less:
Interest rate	3.375%
Floating-rate term loan, due 2022
Debt Instrument [Line Items]
Long Term Debt	$ 200,000	0
Medium term Series A notes, 1995-1, 6.67%, due 2025
Debt Instrument [Line Items]
Long Term Debt	$ 10,000	10,000
Less:
Interest rate	6.67%
Unsecured 6.75% Debentures, due 2028
Debt Instrument [Line Items]
Long Term Debt	$ 150,000	$ 150,000
Less:
Interest rate	6.75%

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Debt - Schedule of Maturities of Long-term Debt (Details) $ in Thousands	Sep. 30, 2020 USD ($)
Debt Disclosure [Abstract]
2021	$ 0
2022	200,000
2023	0
2024	0
2025	10,000
Thereafter	4,350,000
Total long-term debt	$ 4,560,000

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Debt - Narrative (Details)						12 Months Ended
	Oct. 01, 2020 USD ($)	Apr. 30, 2020 USD ($)	Apr. 23, 2020 USD ($)	Apr. 09, 2020 USD ($)	Oct. 02, 2019 USD ($)	Sep. 30, 2020 USD ($) credit_facilities	Apr. 01, 2020 USD ($)	Sep. 30, 2019 USD ($)
Debt Instrument [Line Items]
Maximum borrowing capacity						$ 2,200,000,000
Ratio of total debt to total capitalization maximum						70.00%
Total-debt-to-total-capitalization ratio						42.00%
Unsecured 2.625% Senior Notes, due 2029
Debt Instrument [Line Items]
Interest rate						2.625%
Unsecured 3.375% Senior Notes, due 2049
Debt Instrument [Line Items]
Interest rate						3.375%
Five Year Unsecured Revolving Credit Agreement
Debt Instrument [Line Items]
Commercial paper						$ 0		$ 464,900,000
Weighted average interest rate								2.24%
Senior Notes
Debt Instrument [Line Items]
Proceeds from issuance of debt					$ 791,700,000
Senior Notes | Unsecured 2.625% Senior Notes, due 2029
Debt Instrument [Line Items]
Debt face amount					$ 300,000,000
Interest rate					2.625%
Effective rate					2.72%
Senior Notes | Unsecured 3.375% Senior Notes, due 2049
Debt Instrument [Line Items]
Debt face amount					$ 500,000,000
Interest rate					3.375%
Effective rate					3.42%
Term Loan Agreement | $200 Million Term Loan Agreement
Debt Instrument [Line Items]
Debt face amount				$ 200,000,000
Minimum
Debt Instrument [Line Items]
Equity-to-capitalization ratio						50.00%
Outstanding indebtedness						$ 15,000,000
Maximum
Debt Instrument [Line Items]
Equity-to-capitalization ratio						60.00%
Outstanding indebtedness						$ 100,000,000
Revolving Credit Facility
Debt Instrument [Line Items]
Number of credit facilities | credit_facilities						4
Revolving Credit Facility | $10 Million Revolving Credit Note
Debt Instrument [Line Items]
Maximum borrowing capacity						$ 10,000,000
Debt term						364 days
Revolving Credit Facility | $50 Million Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 50,000,000				$ 50,000,000
Debt term		364 days
Remaining borrowing capacity						44,400,000
Revolving Credit Facility | $600 Million Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 600,000,000
Debt term			364 days
Line of credit borrowings outstanding						0
Line of Credit | $25 Million Bank Loan Agreement
Debt Instrument [Line Items]
Maximum borrowing capacity						$ 25,000,000
Debt term						364 days
Line of Credit | $50 Million Bank Loan Agreement [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity							$ 50,000,000
Line of credit borrowings outstanding						$ 0
Line of Credit | $50 Million Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit borrowings outstanding						0
Commercial Paper | Five Year Unsecured Revolving Credit Agreement
Debt Instrument [Line Items]
Maximum borrowing capacity						$ 1,500,000,000
Debt term						5 years
Accordion feature						$ 250,000,000
Loan increase potential						$ 1,750,000,000
London Interbank Offered Rate (LIBOR) | Term Loan Agreement | $200 Million Term Loan Agreement
Debt Instrument [Line Items]
Basis spread percent				125.00%
London Interbank Offered Rate (LIBOR) | Revolving Credit Facility | Minimum | $600 Million Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Basis spread percent			0.00%
London Interbank Offered Rate (LIBOR) | Revolving Credit Facility | Maximum | $600 Million Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Basis spread percent			125.00%
London Interbank Offered Rate (LIBOR) | Commercial Paper | Minimum | Five Year Unsecured Revolving Credit Agreement
Debt Instrument [Line Items]
Basis spread percent						0.00%
London Interbank Offered Rate (LIBOR) | Commercial Paper | Maximum | Five Year Unsecured Revolving Credit Agreement
Debt Instrument [Line Items]
Basis spread percent						1.25%
Subsequent Event | Senior Notes
Debt Instrument [Line Items]
Proceeds from issuance of debt	$ 592,500,000
Subsequent Event | Senior Notes | Unsecured 1.50% Senior Notes, Due 2031
Debt Instrument [Line Items]
Debt face amount	$ 600,000,000
Interest rate	1.50%
Effective rate	1.71%

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Shareholders' Equity - Narrative (Details) - USD ($)		12 Months Ended
	Nov. 30, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Oct. 01, 2020	Feb. 12, 2020	Feb. 11, 2020
Class of Stock [Line Items]
Net proceeds from equity offering		$ 624,302,000	$ 694,103,000	$ 395,092,000
Forward sales equity agreement, settlement in cash		345,206,000
Shelf Registration Statement
Class of Stock [Line Items]
Debt and equity securities authorized for issuance							$ 4,000,000,000.0
Debt and equity securities authorized for issuance value remaining		3,000,000,000.0			$ 2,400,000,000
At-The-Market
Class of Stock [Line Items]
Value of shares authorized for issuance						$ 1,000,000,000.0
Value of shares available for issuance		$ 552,000,000
Shares issued		5,616,727	2,183,275
Net proceeds from equity offering		$ 581,500,000	$ 200,000,000.0
Forward sales equity agreement, settlement in cash		$ 523,200,000
Forward sales equity agreement, shares		4,808,051	4,144,671
Common Stock Block Trade
Class of Stock [Line Items]
Shares issued	5,390,836
Proceeds from issuance of common stock gross	$ 500,000,000
Net proceeds from equity offering	494,100,000
Forward sales equity agreement, settlement in cash	$ 247,500,000
Forward sales equity agreement, shares	2,668,464
Forward Sales Equity Agreements
Class of Stock [Line Items]
Shares issued		485,189
Net proceeds from equity offering		$ 44,400,000
Forward sales equity agreement, settlement in cash		$ 345,200,000	$ 425,000,000.0
Forward sales equity agreement, forward rate per share		$ 103.48
Senior Notes | Unsecured 1.50% Senior Notes, Due 2031 | Subsequent Event
Class of Stock [Line Items]
Debt face amount					$ 600,000,000

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Shareholders' Equity Shareholders' Equity - Schedule of Forward Sales Executed (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares Available	3,335,995
Net Proceeds Available	$ 345,206
Forward Sales Equity Agreement, Maturing Quarter ended March 31, 2021
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares Available	1,281,578
Net Proceeds Available	$ 134,660
Forward Price	$ 105.07
Forward Sales Equity Agreement, Maturing Quarter ended June 30, 2021
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares Available		1,394,423
Net Proceeds Available	$ 142,388
Forward Price	$ 102.11
Forward Sales Equity Agreement, Maturing Quarter ended September 30, 2021
Forward Contract Indexed to Issuer's Equity [Line Items]
Shares Available	659,994
Net Proceeds Available	$ 68,158
Forward Price	$ 103.27

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Shareholders' Equity - Schedule of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Shareholders' equity, beginning balance	$ 5,750,223	$ 4,769,951	$ 3,898,666
Other comprehensive income before reclassifications	53,349	(25,747)
Amounts reclassified from accumulated other comprehensive income	3,645	3,021
Net current-period other comprehensive income	56,994	(22,726)	44,541
Shareholders' equity, ending balance	6,791,203	5,750,223	4,769,951
Available- for-Sale Securities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Shareholders' equity, beginning balance	132	8,124
Other comprehensive income before reclassifications	108	219
Amounts reclassified from accumulated other comprehensive income	(2)	(1)
Net current-period other comprehensive income	106	218
Shareholders' equity, ending balance	238	132	8,124
Interest Rate Agreement Cash Flow Hedges
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Shareholders' equity, beginning balance	(114,715)	(91,771)
Other comprehensive income before reclassifications	53,241	(25,966)
Amounts reclassified from accumulated other comprehensive income	3,647	3,022
Net current-period other comprehensive income	56,888	(22,944)
Shareholders' equity, ending balance	(57,827)	(114,715)	(91,771)
Accumulated Other Comprehensive Income (Loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Shareholders' equity, beginning balance	(114,583)	(83,647)	(105,254)
Net current-period other comprehensive income	56,994	(22,726)	44,541
Shareholders' equity, ending balance	(57,589)	(114,583)	(83,647)
Cumulative effect of accounting change | Available- for-Sale Securities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Shareholders' equity, beginning balance	(8,210)
Shareholders' equity, ending balance		(8,210)
Cumulative effect of accounting change | Interest Rate Agreement Cash Flow Hedges
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Shareholders' equity, beginning balance	0
Shareholders' equity, ending balance		0
Cumulative effect of accounting change | Accumulated Other Comprehensive Income (Loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Shareholders' equity, beginning balance	$ (8,210)	(8,210)	(22,934)
Shareholders' equity, ending balance		$ (8,210)	$ (8,210)

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Retirement and Post-Retirement Employee Benefit Plans - Schedule of Net Periodic Benefit Cost Not yet Recognized (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Unrecognized prior service (credit) cost
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	$ 367	$ 310
Unrecognized prior service (credit) cost | Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	(584)	(815)
Unrecognized prior service (credit) cost | Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	0	0
Unrecognized prior service (credit) cost | Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	951	1,125
Unrecognized actuarial loss
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	138,237	80,193
Unrecognized actuarial loss | Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	78,082	67,191
Unrecognized actuarial loss | Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	51,045	56,784
Unrecognized actuarial loss | Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	9,110	(43,782)
Total Unrecognized in Net Periodic Pension Cost | Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	77,498	66,376
Total Unrecognized in Net Periodic Pension Cost | Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	51,045	56,784
Total Unrecognized in Net Periodic Pension Cost | Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	10,061	(42,657)
Total Unrecognized in Net Periodic Pension Cost | Pension and postretirement benefit costs
Defined Benefit Plan Disclosure [Line Items]
Net Regulatory Assets	$ 138,604	$ 80,503

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Retirement and Post-Retirement Employee Benefit Plans - Schedule of Allocation of Plan Assets (Details) - Defined Benefit Plan	Sep. 30, 2020	Sep. 30, 2019
Domestic equities
Defined Benefit Plan Disclosure [Line Items]
Actual Allocation	45.30%	40.60%
International equities
Defined Benefit Plan Disclosure [Line Items]
Actual Allocation	15.60%	14.50%
Fixed income
Defined Benefit Plan Disclosure [Line Items]
Actual Allocation	17.00%	18.80%
Company stock
Defined Benefit Plan Disclosure [Line Items]
Actual Allocation	13.00%	15.40%
Other assets
Defined Benefit Plan Disclosure [Line Items]
Actual Allocation	9.10%	10.70%
Minimum | Domestic equities
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	35.00%
Minimum | International equities
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	10.00%
Minimum | Fixed income
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	5.00%
Minimum | Company stock
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	0.00%
Minimum | Other assets
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	0.00%
Maximum | Domestic equities
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	55.00%
Maximum | International equities
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	20.00%
Maximum | Fixed income
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	30.00%
Maximum | Company stock
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	15.00%
Maximum | Other assets
Defined Benefit Plan Disclosure [Line Items]
Targeted Allocation Range	20.00%

XML

Retirement and Post-Retirement Employee Benefit Plans - Schedule of Assumptions Used (Details)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Discount rate Pension Liability	2.80%	3.29%
Discount rate Pension Cost	3.29%	4.38%	3.89%
Rate of compensation increase Pension Liability	3.50%	3.50%
Rate of compensation increase Pension Cost	3.50%	3.50%	3.50%
Expected return on plan assets Pension Liability	6.25%	6.50%
Expected return on plan assets Pension Cost	6.50%	6.75%	6.75%
Interest crediting rate increase Pension Liability	4.69%	4.69%
Interest crediting rate increase Pension Cost	4.69%	4.69%	4.69%
Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Discount rate Pension Liability	2.80%	3.29%
Discount rate Pension Cost	3.19%	4.38%	4.08%
Rate of compensation increase Pension Liability	3.50%	3.50%
Rate of compensation increase Pension Cost	3.50%	3.50%	3.50%
Interest crediting rate increase Pension Liability	4.69%	4.69%
Interest crediting rate increase Pension Cost	4.69%	4.69%	4.69%

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Retirement and Post-Retirement Employee Benefit Plans - Plans’ Accumulated Benefit Obligation, Projected Benefit Obligation and Funded Status (Details) - Defined Benefit Plan - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 565,755	$ 541,287
Change in projected benefit obligation:
Benefit obligation at beginning of year	577,270	504,719
Service cost	17,551	15,311	$ 17,264
Interest cost	19,028	22,071	20,803
Actuarial (gain) loss	22,898	71,139
Benefits paid	(32,526)	(35,970)
Benefit obligation at end of year	604,221	577,270	504,719
Change in plan assets:
Fair value of plan assets at beginning of year	530,109	531,691
Actual return on plan assets	31,298	25,888
Employer contribution	0	8,500
Benefits paid	(32,526)	(35,970)
Fair value of plan assets at end of year	528,881	530,109	$ 531,691
Reconciliation:
Funded status	(75,340)	(47,161)
Unrecognized prior service cost	0	0
Unrecognized net loss	0	0
Net amount recognized	$ (75,340)	$ (47,161)

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Retirement and Post-Retirement Employee Benefit Plans - Supplemental Plans’ Accumulated Benefit Obligation, Projected Benefit Obligation and Funded Status (Details) - Supplemental Executive Retirement Plans - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 122,207	$ 138,772
Change in projected benefit obligation:
Benefit obligation at beginning of year	143,987	121,370
Service cost	1,074	869	$ 1,332
Interest cost	4,188	5,127	4,988
Actuarial (gain) loss	7,386	25,099
Benefits paid	(4,766)	(8,478)
Settlements	(22,729)	0
Benefit obligation at end of year	129,140	143,987	121,370
Change in plan assets:
Fair value of plan assets at beginning of year	0	0
Employer contribution	27,495	8,478
Benefits paid	(4,766)	(8,478)
Settlements	(22,729)	0
Fair value of plan assets at end of year	0	0	$ 0
Reconciliation:
Funded status	(129,140)	(143,987)
Unrecognized prior service cost	0	0
Unrecognized net loss	0	0
Net amount recognized	$ (129,140)	$ (143,987)

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Retirement and Post-Retirement Employee Benefit Plans - Schedule of Net Benefit Costs (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Supplemental Executive Retirement Plans
Components of net periodic postretirement cost:
Service cost	$ 1,074	$ 869	$ 1,332
Interest cost	4,188	5,127	4,988
Recognized actuarial loss	3,945	2,227	3,079
Settlements	9,180	0	4,159
Net periodic pension cost	18,387	8,223	13,558
Defined Benefit Plan
Components of net periodic postretirement cost:
Service cost	17,551	15,311	17,264
Interest cost	19,028	22,071	20,803
Expected return on assets	(28,316)	(28,451)	(27,666)
Amortization of prior service cost	(231)	(232)	(231)
Recognized actuarial loss	9,025	4,201	9,114
Net periodic pension cost	$ 17,057	$ 12,900	$ 19,284

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Retirement and Post-Retirement Employee Benefit Plans - Schedule of Employee Pension Plans Investments at Fair Value (Details) - Defined Benefit Plan - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Derivatives, Fair Value [Line Items]
Total investments	$ 528,881	$ 530,109	$ 531,691
Fair Value, Recurring
Derivatives, Fair Value [Line Items]
Total investments	528,154	528,798
Fair Value, Recurring | Fair Value, Inputs, Level 1, 2 and 3
Derivatives, Fair Value [Line Items]
Total investments	336,771	355,105
Fair Value, Recurring | Fair Value, Inputs, Level 1, 2 and 3 | Common stocks
Derivatives, Fair Value [Line Items]
Total investments	211,244	212,785
Fair Value, Recurring | Fair Value, Inputs, Level 1, 2 and 3 | Money market funds
Derivatives, Fair Value [Line Items]
Total investments	6,096	16,419
Fair Value, Recurring | Fair Value, Inputs, Level 1, 2 and 3 | Registered investment companies
Derivatives, Fair Value [Line Items]
Total investments	29,762	26,326
Fair Value, Recurring | Fair Value, Inputs, Level 1, 2 and 3 | Mortgage-backed securities
Derivatives, Fair Value [Line Items]
Total investments	15,230	19,986
Fair Value, Recurring | Fair Value, Inputs, Level 1, 2 and 3 | U.S. treasuries
Derivatives, Fair Value [Line Items]
Total investments	21,791	23,815
Fair Value, Recurring | Fair Value, Inputs, Level 1, 2 and 3 | Corporate bonds
Derivatives, Fair Value [Line Items]
Total investments	52,648	55,774
Fair Value, Recurring | Level 1
Derivatives, Fair Value [Line Items]
Total investments	262,761	262,041
Fair Value, Recurring | Level 1 | Common stocks
Derivatives, Fair Value [Line Items]
Total investments	211,244	212,785
Fair Value, Recurring | Level 1 | Money market funds
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 1 | Registered investment companies
Derivatives, Fair Value [Line Items]
Total investments	29,762	26,326
Fair Value, Recurring | Level 1 | Mortgage-backed securities
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 1 | U.S. treasuries
Derivatives, Fair Value [Line Items]
Total investments	21,755	22,930
Fair Value, Recurring | Level 1 | Corporate bonds
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 2
Derivatives, Fair Value [Line Items]
Total investments	74,010	93,064
Fair Value, Recurring | Level 2 | Common stocks
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 2 | Money market funds
Derivatives, Fair Value [Line Items]
Total investments	6,096	16,419
Fair Value, Recurring | Level 2 | Registered investment companies
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 2 | Mortgage-backed securities
Derivatives, Fair Value [Line Items]
Total investments	15,230	19,986
Fair Value, Recurring | Level 2 | U.S. treasuries
Derivatives, Fair Value [Line Items]
Total investments	36	885
Fair Value, Recurring | Level 2 | Corporate bonds
Derivatives, Fair Value [Line Items]
Total investments	52,648	55,774
Fair Value, Recurring | Level 3
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 3 | Common stocks
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 3 | Money market funds
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 3 | Registered investment companies
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 3 | Mortgage-backed securities
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 3 | U.S. treasuries
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Level 3 | Corporate bonds
Derivatives, Fair Value [Line Items]
Total investments	0	0
Fair Value, Recurring | Fair Value Measured at Net Asset Value Per Share | Common/collective trusts
Derivatives, Fair Value [Line Items]
Total investments	122,207	108,975
Fair Value, Recurring | Fair Value Measured at Net Asset Value Per Share | Limited partnerships
Derivatives, Fair Value [Line Items]
Total investments	$ 69,176	$ 64,718

XML

Retirement and Post-Retirement Employee Benefit Plans - Schedule of Expected Benefit Payments Defined Benefit Plan (Details) $ in Thousands	Sep. 30, 2020 USD ($)
Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
2021	$ 37,523
2022	37,804
2023	39,053
2024	40,036
2025	41,016
2026-2030	204,582
Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
2021	30,021
2022	17,117
2023	5,124
2024	4,472
2025	32,550
2026-2030	$ 22,308

XML

Retirement and Post-Retirement Employee Benefit Plans - Asset Allocation Postretirement Benefit Plan (Details) - Postretirement Plans	Sep. 30, 2020	Sep. 30, 2019
Diversified investment funds
Defined Benefit Plan Disclosure [Line Items]
Asset Allocation	97.40%	97.10%
Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Asset Allocation	2.60%	2.90%

XML

Retirement and Post-Retirement Employee Benefit Plans - Actuarial Assumptions For Net Periodic Pension Cost (Details) - Postretirement Plans	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Discount rate Pension Liability	2.80%	3.29%
Discount rate Postretirement Cost	3.29%	4.38%	3.89%
Expected return on plan assets Pension Liability	4.94%	5.14%
Expected return on plan assets Postretirement Cost	5.14%	5.33%	4.29%
Initial trend rate Pension Liability	6.25%	6.25%
Initial trend rate Postretirement Cost	6.25%	6.50%	7.00%
Ultimate trend rate Pension Liability	5.00%	5.00%
Ultimate trend rate Postretirement Cost	5.00%	5.00%	5.00%

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Retirement and Post-Retirement Employee Benefit Plans - Postretirement Plans’ Accumulated Benefit Obligation, Projected Benefit Obligation and Funded Status (Details) - Postretirement Plans - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Change in projected benefit obligation:
Benefit obligation at beginning of year	$ 316,033	$ 265,986
Service cost	13,466	10,810	$ 12,078
Interest cost	10,612	11,839	10,907
Plan participants’ contributions	5,849	5,901
Actuarial (gain) loss	43,412	39,472
Benefits paid	(18,694)	(17,975)
Benefit obligation at end of year	370,678	316,033	265,986
Change in plan assets:
Fair value of plan assets at beginning of year	201,901	199,361
Actual return on plan assets	2,356	1,125
Employer contribution	16,833	13,489
Plan participants’ contributions	5,849	5,901
Benefits paid	(18,694)	(17,975)
Fair value of plan assets at end of year	208,245	201,901	$ 199,361
Reconciliation:
Funded status	(162,433)	(114,132)
Unrecognized prior service cost	0	0
Unrecognized prior service cost	0	0
Unrecognized net loss	0	0
Net amount recognized	$ (162,433)	$ (114,132)

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Retirement and Post-Retirement Employee Benefit Plans - Schedule of Net Benefit Costs Postretirement (Details) - Postretirement Plans - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Components of net periodic postretirement cost:
Service cost	$ 13,466	$ 10,810	$ 12,078
Interest cost	10,612	11,839	10,907
Expected return on assets	(10,499)	(10,659)	(8,006)
Amortization of transition obligation	0	0	0
Amortization of prior service cost	173	173	11
Recognized actuarial loss	(1,337)	(8,178)	(6,473)
Net periodic pension cost	$ 12,415	$ 3,985	$ 8,517

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Retirement and Post-Retirement Employee Benefit Plans - Schedule of Postretirement Benefit Plans Investments at Fair Value (Details) - Postretirement Plans - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	$ 208,245	$ 201,901	$ 199,361
Fair Value, Recurring
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	208,245	201,901
Fair Value, Recurring | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	202,720	195,929
Fair Value, Recurring | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	5,525	5,972
Fair Value, Recurring | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	0	0
Fair Value, Recurring | Money market funds
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	5,525	5,972
Fair Value, Recurring | Money market funds | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	0	0
Fair Value, Recurring | Money market funds | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	5,525	5,972
Fair Value, Recurring | Money market funds | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	0	0
Fair Value, Recurring | Registered investment companies
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	202,720	195,929
Fair Value, Recurring | Registered investment companies | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	202,720	195,929
Fair Value, Recurring | Registered investment companies | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	0	0
Fair Value, Recurring | Registered investment companies | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total investments	$ 0	$ 0

XML

Retirement and Post-Retirement Employee Benefit Plans - Schedule of Expected Benefit Payments Post Retirement Benefit Plan (Details) - Postretirement Plans $ in Thousands	Sep. 30, 2020 USD ($)
Company Payments
2021	$ 22,632
2022	16,263
2023	16,590
2024	17,517
2025	18,353
2026-2030	101,158
Retiree Payments
2021	4,368
2022	4,772
2023	5,144
2024	5,651
2025	6,104
2026-2030	35,039
Subsidy Payments
2021	0
2022	0
2023	0
2024	0
2025	0
2026-2030	0
Total Postretirement Benefits
2021	27,000
2022	21,035
2023	21,734
2024	23,168
2025	24,457
2026-2030	$ 136,197

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Retirement and Post-Retirement Employee Benefit Plans - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Recovery period	15 years
Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Vesting period	3 years
Employer contribution	$ 0	$ 8,500
Accounts receivable	$ 700	1,300
Defined Benefit Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Medium-term horizon	3 years
Defined Benefit Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Medium-term horizon	5 years
Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Employer contribution	$ 27,495	8,478
Assets held-in-trust	41,900	44,000
Settlement charge	(9,180)	0	$ (4,159)
Lump sum settlement	22,729	0
Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Employer contribution	$ 16,833	$ 13,489
Percent of projected claims paid	80.00%
Remaining percent of claims paid by participant	20.00%
Defined Benefit Plan, employer contribution limit	3.00%
Postretirement Plans | Minimum
Defined Benefit Plan Disclosure [Line Items]
Expected contribution amount	$ 15,000
Postretirement Plans | Maximum
Defined Benefit Plan Disclosure [Line Items]
Expected contribution amount	$ 25,000
Company stock | Defined Benefit Plan
Defined Benefit Plan Disclosure [Line Items]
Shares held by Plan (in shares)	716,700	716,700
Percent of plan assets	13.00%	15.40%
Dividend income	$ 1,600	$ 1,500
Diversified investment funds | Postretirement Plans
Defined Benefit Plan Disclosure [Line Items]
Percent of plan assets	97.40%	97.10%
Maximum investment percent	75.00%
Supplemental Executive Benefit Plan | Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Percent of covered compensation	75.00%
1998 Supplemental Executive Retirement Plan, Defined Benefit | Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Percent of covered compensation	60.00%
2009 Supplemental Executive Retirement Plan, Defined Benefit | Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Vesting period	3 years
Contribution percent	10.00%
Contribution percent for members	25.00%
Attainment age	55 years
Retirement Savings Plan
Defined Benefit Plan Disclosure [Line Items]
Maximum of eligible compensation	65.00%
New employee contribution percentage	4.00%
Percent of employee contribution	100.00%
Employer Matching, Percent of employee salary	4.00%
Years of service	1 year
Fixed annual contribution percent	4.00%
Years of service vesting period	3 years
Contribution plan cost	$ 17,900	$ 16,700	$ 16,200
Percent of common stock outstanding	2.20%	2.60%
Executive Officer | Supplemental Executive Retirement Plans
Defined Benefit Plan Disclosure [Line Items]
Settlement charge	$ 9,200
Lump sum settlement	$ 22,700

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Stock and Other Compensation Plans - Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity (Details) - $ / shares	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Number of Restricted Units
Nonvested at beginning of year (in shares)	503,072	538,592	570,814
Granted (in shares)	199,985	241,472	248,710
Vested (in shares)	(242,975)	(269,347)	(274,392)
Forfeited (in shares)	(16,803)	(7,645)	(6,540)
Nonvested at end of year (in shares)	443,279	503,072	538,592
Weighted Average Grant-Date Fair Value
Nonvested at beginning of year (in dollars per share)	$ 91.66	$ 80.91	$ 69.45
Granted (in dollars per share)	102.34	98.25	85.62
Vested (in dollars per share)	85.66	76.71	64.43
Forfeited (in dollars per share)	96.87	86.37	74.87
Nonvested at end of year (in dollars per share)	$ 99.28	$ 91.66	$ 80.91

XML

Stock and Other Compensation Plans - Narrative (Details) - USD ($)	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Share-based Payment Arrangement [Abstract]
Stock-based compensation cost	$ 21,100,000	$ 23,900,000	$ 23,900,000
Capitalized stock-based compensation cost	$ 11,600,000	12,800,000	11,100,000
Maximum shares authorized (in shares)	11,200,000
Shares available for future issuance	1,300,000
Service period	3 years
Unrecognized compensation cost	$ 13,000,000.0
Cost recognition period	1 year 6 months
Fair value of restricted stock vested	$ 20,700,000	$ 20,500,000	$ 17,200,000
Minimum initial investment	1,250
Minimum cash payments	25
Maximum annual cash payments	$ 100,000

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Details of Selected Consolidated Balance Sheet Captions - Accounts Receivables Detail Table (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Condensed Balance Sheet Statements, Captions [Line Items]
Total accounts receivable	$ 260,544	$ 246,470
Less: allowance for doubtful accounts	(29,949)	(15,899)
Net accounts receivable	230,595	230,571
Billed and Unbilled Receivables | Billed accounts receivable
Condensed Balance Sheet Statements, Captions [Line Items]
Total accounts receivable	140,259	126,984
Billed and Unbilled Receivables | Unbilled revenue
Condensed Balance Sheet Statements, Captions [Line Items]
Total accounts receivable	80,699	78,986
Contributions in aid of construction receivable
Condensed Balance Sheet Statements, Captions [Line Items]
Total accounts receivable	19,821	22,378
Other accounts receivable
Condensed Balance Sheet Statements, Captions [Line Items]
Total accounts receivable	$ 19,765	$ 18,122

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Details of Selected Consolidated Balance Sheet Captions - Other Current Assets Detail Table (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Balance Sheet Related Disclosures [Abstract]
Deferred gas costs	$ 40,593	$ 23,766
Prepaid expenses	40,340	38,895
Materials and supplies	6,829	5,916
Assets from risk management activities	5,687	1,586
Other	14,456	2,609
Total	$ 107,905	$ 72,772

XML

Details of Selected Consolidated Balance Sheet Captions - Property, Plant and Equipment Detail Table (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Balance Sheet Related Disclosures [Abstract]
Storage plant	$ 530,985	$ 431,286
Transmission plant	3,459,765	3,157,316
Distribution plant	10,680,495	9,333,011
General plant	829,624	799,095
Intangible plant	38,297	38,191
Property, plant and equipment	15,539,166	13,758,899
Construction in progress	418,055	421,694
Total property, plant and equipment and construction in progress	15,957,221	14,180,593
Less: accumulated depreciation and amortization	(2,601,874)	(2,392,924)
Net property, plant and equipment	13,355,347	11,787,669
Plant acquisition adjustments	$ (37,800)	$ (46,700)

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Details of Selected Consolidated Balance Sheet Captions - Goodwill Detail Table (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2020 USD ($)
Goodwill [Roll Forward]
Goodwill beginning balance	$ 730,706
Deferred tax adjustments on prior acquisitions	551
Goodwill ending balance	731,257
Goodwill, Period Increase (Decrease)	600
Distribution
Goodwill [Roll Forward]
Goodwill beginning balance	587,604
Deferred tax adjustments on prior acquisitions	(768)
Goodwill ending balance	586,836
Pipeline and Storage
Goodwill [Roll Forward]
Goodwill beginning balance	143,102
Deferred tax adjustments on prior acquisitions	1,319
Goodwill ending balance	$ 144,421

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Details of Selected Consolidated Balance Sheet Captions - Deferred Charges and Other Assets Detail Table (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Operating lease right-of-use assets	$ 227,146
Assets from risk management activities	74,991	$ 225
Total	801,170	391,213
Other Assets
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Marketable securities	103,952	101,883
Regulatory assets (See Note 2)	371,707	260,220
Operating lease right-of-use assets	227,146
Assets from risk management activities	74,991	225
Taxes receivable	0	10,099
Other	23,374	18,786
Total	$ 801,170	$ 391,213

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Details of Selected Consolidated Balance Sheet Captions - Accounts Payable and Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Balance Sheet Related Disclosures [Abstract]
Trade accounts payable	$ 141,075	$ 176,581
Accrued gas payable	42,054	36,817
Accrued liabilities	52,646	51,626
Total	$ 235,775	$ 265,024

XML

Details of Selected Consolidated Balance Sheet Captions - Other Current Liabilities Detail Table (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Balance Sheet Related Disclosures [Abstract]
Customer credit balances and deposits	$ 56,485	$ 54,617
Accrued employee costs	57,057	55,216
Deferred gas costs	19,985	14,112
Operating leases	35,716
Accrued interest	53,554	51,381
Liabilities from risk management activities	2,015	4,552
Taxes payable	148,292	135,597
Pension and postretirement liabilities	29,609	26,197
Regulatory cost of service reserve	1,716	4,209
Regulatory cost of removal obligation	73,908	55,721
APT annual adjustment mechanism, current	43,893	52,856
Regulatory excess deferred taxes	20,887	21,206
Other	3,344	3,837
Total	$ 546,461	$ 479,501

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Details of Selected Consolidated Balance Sheet Captions - Deferred Credits and Other Liabilities Detail Table (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2017
Balance Sheet Related Disclosures [Abstract]
Pension and post retirement liabilities	$ 337,303	$ 279,083
Operating leases	201,071
Customer advances for construction	10,060	12,566
Other regulatory liabilities	17,838	16,120
Asset retirement obligation	20,348	17,054
Liabilities from risk management activities	0	1,249
APT annual adjustment mechanism	13,486	25,545
Unrecognized Tax Benefits	30,921	27,716	$ 26,203	$ 23,719
Other	11,101	20,883
Total	$ 642,128	$ 400,216

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Details of Selected Consolidated Balance Sheet Captions - Other Non-Operating Income (Expense) (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Balance Sheet Related Disclosures [Abstract]
Equity component of AFUDC	$ 23,493	$ 11,165	$ 0
Performance-based rate program	6,771	6,737	6,745
Pension and other postretirement non-service credit (cost)	(3,189)	3,016	(5,770)
Interest income	2,932	4,160	1,450
Community support spending	(11,728)	(4,771)	(6,053)
Miscellaneous	(11,108)	(12,903)	(6,516)
Other non-operating income (expense)	$ 7,171	$ 7,404	$ (10,144)

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Details of Selected Consolidated Balance Sheet Captions - Supplemental Disclosures of Cash Flow Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Balance Sheet Related Disclosures [Abstract]
Interest	$ 194,993	$ 184,852	$ 169,987
Income taxes	(3,071)	11,467	6,102
Capital expenditures included in current liabilities	113,365	149,993	112,211
Interest paid, net of amount capitalized	$ 82,300	$ 91,300	$ 106,800

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Commitments and Contingencies (Details) $ in Millions	12 Months Ended
	Sep. 30, 2020 USD ($) Bcf	Sep. 30, 2019 USD ($)	Sep. 30, 2018 USD ($)
Long Term Purchase Commitment [Line Items]
Self-insured retention | $	$ 1.0
Purchases under contract | $	$ 58.5	$ 50.8	$ 57.2
Supply Commitment
Long Term Purchase Commitment [Line Items]
Contract term	1 year
Supply Commitment | Short-term Contract with Customer
Long Term Purchase Commitment [Line Items]
Purchase commitment volume	59,300
Contract term	1 year
Supply Commitment | Long-term Contract with Customer Within Two To Three Years
Long Term Purchase Commitment [Line Items]
Purchase commitment volume	57,000.0
Supply Commitment | Long-term Contract With Customer Beyond Three Years
Long Term Purchase Commitment [Line Items]
Purchase commitment volume	0.1
Minimum | Supply Commitment | Long-term Contract with Customer Within Two To Three Years
Long Term Purchase Commitment [Line Items]
Contract term	2 years
Maximum | Supply Commitment | Long-term Contract with Customer Within Two To Three Years
Long Term Purchase Commitment [Line Items]
Contract term	3 years

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Income Taxes - Schedule of Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Current
Federal	$ 0	$ 0	$ (10,099)
State	14,193	8,412	11,075
Deferred
Federal	143,039	113,331	150,556
State (1)	(11,879)	17,160	15,330
TCJA Impact	0	0	(158,782)
Income tax expense (benefit)	145,353	138,903	8,080
Remeasurement due to state deferred tax rate change	$ 20,962	$ 0	$ 0

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Income Taxes - Schedule of Effective Income Tax Rate Reconciliation (Details) - USD ($) $ in Thousands		12 Months Ended
	Sep. 30, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Tax at statutory rate		$ 156,827	$ 136,565	$ 149,730
Common stock dividends deductible for tax reporting		(1,419)	(1,460)	(1,745)
State taxes (net of federal benefit)		22,791	20,202	19,826
Amortization of excess deferred taxes		(16,125)	(14,085)	(1,219)
One-time income tax benefit		0	0	(158,782)
Remeasurement due to state deferred tax rate change		20,962	0	0
Other, net		4,241	(2,319)	270
Income tax expense (benefit)		$ 145,353	$ 138,903	$ 8,080
Statutory federal income tax rate	35.00%	21.00%	21.00%	24.50%

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Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Deferred tax assets:
Employee benefit plans	$ 66,991	$ 70,929
Interest rate swaps	16,719	33,918
Net operating loss carryforwards	476,507	485,133
Charitable and other credit carryforwards	8,712	8,241
Regulatory excess deferred tax	161,565	165,701
Other	73,542	13,186
Total deferred tax assets	804,036	777,108
Valuation allowance	(1,102)	(1,894)
Net deferred tax assets	802,934	775,214
Deferred tax liabilities:
Difference in net book value and net tax value of assets	(2,138,966)	(2,004,516)
Pension funding	(484)	(4,384)
Gas cost adjustments	(23,209)	(18,072)
Other	(96,844)	(48,257)
Total deferred tax liabilities	(2,259,503)	(2,075,229)
Net deferred tax liabilities	(1,456,569)	(1,300,015)
Deferred credits for rate regulated entities	2,537	2,582
Deferred tax liabilities related to goodwill	$ 129,000	$ 131,000

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Income Taxes - Schedule of Unrecognized Tax Benefits Roll Forward (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Reconciliation of Unrecognized Tax Benefits [Roll Forward]
Unrecognized Tax Benefits - beginning balance	$ 27,716	$ 26,203	$ 23,719
Decrease resulting from prior period tax positions	(26)	(923)
Increase resulting from prior period tax positions			22
Increase resulting from current period tax positions	3,231	2,436	2,462
Unrecognized tax benefits - ending balance	30,921	27,716	26,203
Unrecognized tax benefits, period increase	30,900
Less: deferred federal and state income tax benefits	(6,493)	(5,820)	(5,503)
Total unrecognized tax benefits that, if recognized, would impact the effective income tax rate as of the end of the year	$ 24,428	$ 21,896	$ 20,700

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Income Taxes - Narrative (Details) - USD ($) $ in Thousands		3 Months Ended	12 Months Ended
	Sep. 30, 2018	Jun. 30, 2020	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Income Tax Contingency [Line Items]
Charitable contribution carryforwards			$ 6,900
Remeasured federal effects			500
Unrecognized tax benefits, period increase			30,900
Interest and penalties			700	$ 2,200	$ 1,600
Payment of interest and penalties accrued	$ 6,100		8,200	7,900	6,100
Reduction in deferred tax liabilities		$ 32,500
Regulatory liability			1,367,013	1,386,126
Income tax benefit			20,962	0	0
One-time income tax benefit			0	0	$ 158,782
Deferred tax liability, regulated operations			$ 706,700	$ 726,300
Statutory federal income tax rate	35.00%		21.00%	21.00%	24.50%
Domestic Tax Authority
Income Tax Contingency [Line Items]
Federal net operating loss carryforwards			$ 446,900
Federal alternative minimum tax credit carryforwards			10,100
State and Local Jurisdiction
Income Tax Contingency [Line Items]
Federal net operating loss carryforwards			29,600
Federal alternative minimum tax credit carryforwards			1,800
Federal effects			7,900
Valuation Allowance, Tax Credit Carryforward
Income Tax Contingency [Line Items]
Valuation allowance			$ 1,100
Minimum
Income Tax Contingency [Line Items]
Recognition period			15 years
Maximum
Income Tax Contingency [Line Items]
Recognition period			46 years
Deferred Income Tax Charge - Remeasurement Due to Law Change under the Reg Liability [Member]
Income Tax Contingency [Line Items]
Regulatory liability		$ 12,100

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Financial Instruments Financial Instruments at Fair Value (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Assets from risk management activities	$ 5,687	$ 1,586
Assets from risk management activities	74,991	225
Liabilities from risk management activities, current	(2,015)	(4,552)
Liabilities from risk management activities, noncurrent	0	(1,249)
Net assets (liabilities)	$ 78,663	$ (3,990)

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Financial Instruments Balance Sheet Location (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
ASSETS
Net Financial Instruments	$ 80,678	$ 1,811
Liabilities
Net Financial Instruments	(2,015)	(5,801)
Designated as Hedging Instrument
ASSETS
Gross / Net Financial Instruments	73,055
Liabilities
Gross / Net Financial Instruments	0
Designated as Hedging Instrument | Deferred Charges And Other Assets | Interest rate agreements
ASSETS
Gross / Net Financial Instruments	73,055
Designated as Hedging Instrument | Deferred Credits And Other Liabilities | Interest rate agreements
Liabilities
Gross / Net Financial Instruments	0
Not Designated as Hedging Instrument
ASSETS
Gross / Net Financial Instruments	7,623	1,811
Liabilities
Gross / Net Financial Instruments	(2,015)	(5,801)
Not Designated as Hedging Instrument | Other Current Assets | Commodity contracts
ASSETS
Gross / Net Financial Instruments	5,687	1,586
Not Designated as Hedging Instrument | Deferred Charges And Other Assets | Commodity contracts
ASSETS
Gross / Net Financial Instruments	1,936	225
Not Designated as Hedging Instrument | Other Current Liabilities | Commodity contracts
Liabilities
Gross / Net Financial Instruments	(2,015)	(4,552)
Not Designated as Hedging Instrument | Deferred Credits And Other Liabilities | Commodity contracts
Liabilities
Gross / Net Financial Instruments	$ 0	$ (1,249)

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Financial Instruments Other Comprehensive Income (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Other Comprehensive Income [Abstract]
Total other comprehensive income (loss) from hedging, net of tax	$ 56,888	$ (22,944)
Expected Earnings [Line Items]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	3,647	3,022
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	53,241	$ (25,966)
Interest rate agreements
Expected Earnings [Line Items]
FY2021	(4,569)
FY2022	(4,569)
FY2023	(4,569)
FY2024	(4,569)
FY2025	(4,569)
Thereafter	(91,657)
Total	$ (114,502)

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Financial Instruments - Narrative (Details) $ / Bcf in Thousands	1 Months Ended	3 Months Ended	12 Months Ended
	Sep. 30, 2020 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2020 USD ($) $ / Bcf Bcf	Sep. 30, 2019 USD ($)	Sep. 30, 2018 USD ($)	Sep. 30, 2025	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2021
Derivative [Line Items]
Net loss on settled Treasury lock agreements reclassified from AOCI into interest expense		$ 5,500,000		$ 3,900,000	$ 2,400,000
AOCI impact from settlement of financial instruments	$ (114,500,000)	$ (114,500,000)	$ (114,500,000)
Not Designated as Hedging Instrument | Gas Purchases | Commodity contracts
Derivative [Line Items]
Hedging percent	49.00%	49.00%	49.00%
Purchase commitment volume | Bcf			19,900
Weighted average cost | $ / Bcf			2,840
Not Designated as Hedging Instrument | Gas Purchases | Commodity contracts | Minimum
Derivative [Line Items]
Hedging percent	25.00%	25.00%	25.00%
Not Designated as Hedging Instrument | Gas Purchases | Commodity contracts | Maximum
Derivative [Line Items]
Hedging percent	50.00%	50.00%	50.00%
Designated as Hedging Instrument | Forward Interest Rate Swap 1
Derivative [Line Items]
Derivative notional amount	$ 500,000,000	$ 500,000,000	$ 500,000,000
Settlement of interest rate swaps	4,400,000
Designated as Hedging Instrument | Forward Interest Rate Swap 2
Derivative [Line Items]
Derivative notional amount	450,000,000	450,000,000	450,000,000
Designated as Hedging Instrument | Forward Interest Rate Swap 3
Derivative [Line Items]
Derivative notional amount	300,000,000	300,000,000	300,000,000
Designated as Hedging Instrument | Forward Interest Rate Swap 4
Derivative [Line Items]
Derivative notional amount	$ 300,000,000	$ 300,000,000	$ 300,000,000
Long | Not Designated as Hedging Instrument | Gas Purchases | Commodity contracts
Derivative [Line Items]
Purchase commitment volume | Bcf			18.191
Unsecured Senior Notes In Fiscal 2021 | Forecast
Derivative [Line Items]
Interest rate									0.69%
Unsecured Senior Notes In Fiscal 2023 | Forecast
Derivative [Line Items]
Interest rate							1.36%	1.33%
Unsecured Senior Notes In Fiscal 2025 | Forecast
Derivative [Line Items]
Interest rate						1.35%

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- Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Sep. 30, 2019
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Netting and Cash Collateral	$ 0	$ 0
Financial instruments net assets	80,678	1,811
Total debt and equity securities	103,952	101,883
Total assets	184,630	103,694
Netting and Cash Collateral	0	0
Financial instruments net liability	2,015	5,801
Registered investment companies
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	37,831	41,406
Bond mutual funds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	29,166	25,966
Bonds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Debt securities	32,900	31,915
Money market funds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	4,055	2,596
Level 1
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Financial instruments	0	0
Total debt and equity securities	66,997	67,372
Total assets	66,997	67,372
Financial instruments	0	0
Level 1 | Registered investment companies
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	37,831	41,406
Level 1 | Bond mutual funds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	29,166	25,966
Level 1 | Bonds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Debt securities	0	0
Level 1 | Money market funds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	0	0
Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Financial instruments	80,678	1,811
Total debt and equity securities	36,955	34,511
Total assets	117,633	36,322
Financial instruments	2,015	5,801
Level 2 | Registered investment companies
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	0	0
Level 2 | Bond mutual funds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	0	0
Level 2 | Bonds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Debt securities	32,900	31,915
Level 2 | Money market funds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	4,055	2,596
Level 3
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Financial instruments	0	0
Total debt and equity securities	0	0
Total assets	0	0
Financial instruments	0	0
Level 3 | Registered investment companies
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	0	0
Level 3 | Bond mutual funds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	0	0
Level 3 | Bonds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Debt securities	0	0
Level 3 | Money market funds
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Equity Securities	$ 0	$ 0

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Fair Value Measurements - Narrative (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019
Fair Value Disclosures [Abstract]
Amortized cost	$ 32.6	$ 31.7

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Fair Value Measurements - Other Fair Value MeasurementS (Details) $ in Thousands	Sep. 30, 2020 USD ($)
Fair Value Disclosures [Abstract]
Carrying Amount	$ 4,560,000
Fair Value of Debt	$ 5,597,183

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Selected Quarterly Financial Data (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
Operating Revenues by Segment [Line Items]
Operating revenues	$ 474,914	$ 492,995	$ 977,665	$ 875,563	$ 443,683	$ 485,738	$ 1,094,645	$ 877,782
Total purchased gas cost									$ 658,854	$ 858,837	$ 1,167,848
Operating income	100,845	139,035	331,438	252,781	89,715	122,202	297,677	236,464	824,099	746,058	727,934
Net Income	$ 65,333	$ 117,791	$ 239,646	$ 178,673	$ 58,406	$ 80,466	$ 214,888	$ 157,646	$ 601,443	$ 511,406	$ 603,064
Basic and diluted earnings per share
Basic net income per share	$ 0.53	$ 0.96	$ 1.95	$ 1.47	$ 0.49	$ 0.68	$ 1.83	$ 1.38	$ 4.89	$ 4.36	$ 5.43
Diluted net income per share	$ 0.53	$ 0.96	$ 1.95	$ 1.47	$ 0.49	$ 0.68	$ 1.82	$ 1.38	$ 4.89	$ 4.35	$ 5.43
Distribution
Operating Revenues by Segment [Line Items]
Operating revenues	$ 430,176	$ 435,308	$ 933,005	$ 828,504	$ 403,793	$ 444,944	$ 1,057,889	$ 838,835
Pipeline and Storage
Operating Revenues by Segment [Line Items]
Operating revenues	156,918	158,008	146,237	148,176	147,706	149,198	135,650	134,470
Natural Gas, US Regulated
Operating Revenues by Segment [Line Items]
Total purchased gas cost	18,031	26,072	317,883	296,868	13,670	31,326	471,676	342,165	$ 658,854	$ 858,837	$ 1,167,848
Eliminations
Operating Revenues by Segment [Line Items]
Operating revenues	$ (112,180)	$ (100,321)	$ (101,577)	$ (101,117)	$ (107,816)	$ (108,404)	$ (98,894)	$ (95,523)
Total purchased gas cost									(413,921)	(409,394)	(393,966)
Operating income									0	0	0
Eliminations | Natural Gas, US Regulated
Operating Revenues by Segment [Line Items]
Total purchased gas cost									$ (413,921)	$ (409,394)	$ (393,966)

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Valuation and Qualifying Accounts (Details) - Allowance For Doubtful Accounts Member - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2018
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at beginning of period	$ 15,899	$ 14,795	$ 10,865
Charged to cost & expenses	23,837	17,633	14,894
Charged to other accounts	0	0	0
Deductions	9,787	16,529	10,964
Balance at end of period	$ 29,949	$ 15,899	$ 14,795