National Fuel Gas (NFG) 10-Q 1 Aug 24 2024 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - $ / shares	9 Months Ended
	Jun. 30, 2024	Jul. 31, 2024
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2024
Document Transition Report	false
Entity File Number	1-3880
Amendment Flag	false
Entity Registrant Name	NATIONAL FUEL GAS COMPANY
Entity Incorporation, State or Country Code	NJ
Entity Tax Identification Number	13-1086010
Entity Address, Address Line One	6363 Main Street
Entity Address, City or Town	Williamsville,
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	14221
City Area Code	716
Local Phone Number	857-7000
Title of 12(b) Security	Common Stock, par value $1.00 per share
Trading Symbol	NFG
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Listing, Par Value Per Share	$ 1
Entity Common Stock, Shares Outstanding		91,356,883
Entity Central Index Key	0000070145
Current Fiscal Year End Date	--09-30
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q3

Consolidated Statements Of Inco

Consolidated Statements Of Income And Earnings Reinvested In The Business (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
INCOME
Operating Revenues	$ 417,442	$ 428,704	$ 1,572,742	$ 1,804,824
Operating Expenses:
Purchased Gas	4,952	35,425	167,444	450,461
Property, Franchise and Other Taxes	21,201	20,427	66,635	71,999
Depreciation, Depletion and Amortization	113,454	102,410	348,179	299,973
Impairment of Exploration and Production Properties	200,696	0	200,696	0
Total Operating Expenses	468,882	274,608	1,166,448	1,174,980
Operating Income (Loss)	(51,440)	154,096	406,294	629,844
Other Income (Expense):
Other Income (Deductions)	3,188	3,551	12,989	12,754
Interest Expense on Long-Term Debt	(32,876)	(26,311)	(89,791)	(83,499)
Other Interest Expense	(1,341)	(5,781)	(14,250)	(15,485)
Income (Loss) Before Income Taxes	(82,469)	125,555	315,242	543,614
Income Tax Expense (Benefit)	(28,311)	32,935	70,108	140,425
Net Income (Loss) Available for Common Stock	(54,158)	92,620	245,134	403,189
EARNINGS REINVESTED IN THE BUSINESS
Balance at Beginning of Period	2,090,172	1,810,454	1,885,856	1,587,085
Beginning Retained Earnings Unappropriated And Current Period Net Income	2,036,014	1,903,074	2,130,990	1,990,274
Dividends on Common Stock	(47,195)	(45,444)	(138,354)	(132,644)
Balance at June 30	$ 1,970,384	$ 1,857,630	$ 1,970,384	$ 1,857,630
Basic:
Net Income Available for Common Stock (in dollars per share)	$ (0.59)	$ 1.01	$ 2.67	$ 4.40
Diluted:
Net Income Available for Common Stock (in dollars per share)	$ (0.59)	$ 1	$ 2.65	$ 4.37
Weighted Average Common Shares Outstanding:
Used in Basic Calculation (shares)	91,874,049	91,803,638	91,966,034	91,725,286
Used in Diluted Calculation (shares)	91,874,049	92,294,666	92,467,787	92,268,904
Dividends Per Common Share:
Dividends Declared (in dollars per share)	$ 0.515	$ 0.495	$ 1.505	$ 1.445
Earnings Reinvested in The Business
Other Income (Expense):
Net Income (Loss) Available for Common Stock	$ (54,158)	$ 92,620	$ 245,134	$ 403,189
EARNINGS REINVESTED IN THE BUSINESS
Share Repurchases	(18,435)	0	(22,252)	0
Dividends on Common Stock	(47,195)	(45,444)	(138,354)	(132,644)
Utility
INCOME
Operating Revenues	124,858	144,538	616,977	862,914
Operating Expenses:
Operation and Maintenance	53,412	50,080	166,405	156,885
Exploration and Production and Other Revenues
INCOME
Operating Revenues	220,905	216,581	739,537	738,107
Operating Expenses:
Operation and Maintenance	35,148	27,659	102,768	86,315
Pipeline and Storage and Gathering Revenues
INCOME
Operating Revenues	71,679	67,585	216,228	203,803
Operating Expenses:
Operation and Maintenance	$ 40,019	$ 38,607	$ 114,321	$ 109,347

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Statement of Comprehensive Income [Abstract]
Net Income (Loss) Available for Common Stock	$ (54,158)	$ 92,620	$ 245,134	$ 403,189
Other Comprehensive Income (Loss), Before Tax:
Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	(21,936)	65,244	238,395	673,381
Reclassification Adjustment for Realized (Gains) Losses on Derivative Financial Instruments in Net Income	(75,346)	(57,692)	(155,203)	120,590
Other Comprehensive Income (Loss), Before Tax	(97,282)	7,552	83,192	793,971
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	(6,086)	17,885	66,146	184,655
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Derivative Financial Instruments in Net Income	(20,906)	(15,813)	(43,064)	32,967
Income Taxes (Benefits) – Net	(26,992)	2,072	23,082	217,622
Other Comprehensive Income (Loss)	(70,290)	5,480	60,110	576,349
Comprehensive Income (Loss)	$ (124,448)	$ 98,100	$ 305,244	$ 979,538

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2024	Sep. 30, 2023
ASSETS
Property, Plant and Equipment	$ 14,245,690	$ 13,635,303
Less - Accumulated Depreciation, Depletion and Amortization	6,834,824	6,335,441
Property, Plant and Equipment, Net, Total	7,410,866	7,299,862
Current Assets
Cash and Temporary Cash Investments	81,414	55,447
Receivables – Net of Allowance for Uncollectible Accounts of $32,622 and $36,295, Respectively	156,846	160,601
Unbilled Revenue	15,032	16,622
Gas Stored Underground	14,186	32,509
Materials and Supplies - at average cost	48,331	48,989
Other Current Assets	82,923	100,260
Total Current Assets	398,732	414,428
Other Assets
Recoverable Future Taxes	80,820	69,045
Unamortized Debt Expense	6,007	7,240
Other Regulatory Assets	73,934	72,138
Deferred Charges	89,740	82,416
Other Investments	79,547	73,976
Goodwill	5,476	5,476
Prepaid Pension and Post-Retirement Benefit Costs	230,591	200,301
Fair Value of Derivative Financial Instruments	100,317	50,487
Other	5,007	4,891
Total Other Assets	671,439	565,970
Total Assets	8,481,037	8,280,260
Capitalization:
Common Stock, $1 Par Value	91,612	91,819
Paid in Capital	1,046,479	1,040,761
Earnings Reinvested in the Business	1,970,384	1,885,856
Accumulated Other Comprehensive Income (Loss)	5,050	(55,060)
Total Comprehensive Shareholders’ Equity	3,113,525	2,963,376
Long-Term Debt, Net of Current Portion and Unamortized Discount and Debt Issuance Costs	2,637,115	2,384,485
Total Capitalization	5,750,640	5,347,861
Current and Accrued Liabilities
Notes Payable to Banks and Commercial Paper	0	287,500
Current Portion of Long-Term Debt	50,000	0
Accounts Payable	101,200	152,193
Amounts Payable to Customers	62,569	59,019
Dividends Payable	47,195	45,451
Interest Payable on Long-Term Debt	46,926	20,399
Customer Advances	0	21,003
Customer Security Deposits	36,674	28,764
Other Accruals and Current Liabilities	169,133	160,974
Fair Value of Derivative Financial Instruments	2,941	31,009
Total Current and Accrued Liabilities	516,638	806,312
Other Liabilities
Deferred Income Taxes	1,172,068	1,124,170
Taxes Refundable to Customers	302,733	268,562
Cost of Removal Regulatory Liability	289,356	277,694
Other Regulatory Liabilities	164,390	165,441
Other Post-Retirement Liabilities	2,741	2,915
Asset Retirement Obligations	157,653	165,492
Other Liabilities	124,818	121,813
Total Other Liabilities	2,213,759	2,126,087
Commitments and Contingencies (Note 8)	0	0
Total Capitalization and Liabilities	$ 8,481,037	$ 8,280,260

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2024	Sep. 30, 2023
Statement of Financial Position [Abstract]
Receivables, allowance for uncollectible accounts	$ 32,622	$ 36,295
Common stock, par value (in dollars per share)	$ 1	$ 1
Common stock, shares authorized (in shares)	200,000,000	200,000,000
Common stock, shares issued (in shares)	91,612,488	91,819,405
Common stock, shares outstanding (in shares)	91,612,488	91,819,405

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
OPERATING ACTIVITIES
Net Income Available for Common Stock	$ 245,134	$ 403,189
Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities:
Impairment of Exploration and Production Properties	200,696	0
Depreciation, Depletion and Amortization	348,179	299,973
Deferred Income Taxes	47,212	101,096
Stock-Based Compensation	15,984	15,807
Other	18,542	16,640
Change in:
Receivables and Unbilled Revenue	5,253	192,324
Gas Stored Underground and Materials and Supplies	18,981	11,757
Unrecovered Purchased Gas Costs	0	75,244
Other Current Assets	17,431	(12,230)
Accounts Payable	(13,705)	(52,340)
Amounts Payable to Customers	3,550	21,972
Customer Advances	(21,003)	(26,108)
Customer Security Deposits	7,910	9,741
Other Accruals and Current Liabilities	23,846	45,363
Other Assets	(35,346)	(39,367)
Other Liabilities	(14,649)	(7,949)
Net Cash Provided by Operating Activities	868,015	1,055,112
INVESTING ACTIVITIES
Capital Expenditures	(684,200)	(727,738)
Acquisition of Upstream Assets	0	(124,758)
Sale of Fixed Income Mutual Fund Shares in Grantor Trust	0	10,000
Other	(1,371)	13,397
Net Cash Used in Investing Activities	(685,571)	(829,099)
FINANCING ACTIVITIES
Proceeds from Issuance of Short-Term Note Payable to Bank	0	250,000
Repayment of Short-Term Note Payable to Bank	0	(250,000)
Net Change in Other Short-Term Notes Payable to Banks and Commercial Paper	(287,500)	78,500
Net Proceeds from Issuance of Long-Term Debt	299,396	297,533
Shares Repurchased Under Repurchase Plan	(27,847)	0
Reduction of Long-Term Debt	0	(549,000)
Dividends Paid on Common Stock	(136,610)	(130,653)
Net Repurchases of Common Stock Under Stock and Benefit Plans	(3,916)	(6,696)
Net Cash Used in Financing Activities	(156,477)	(310,316)
Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash	25,967	(84,303)
Cash, Cash Equivalents, and Restricted Cash at October 1	55,447	137,718
Cash, Cash Equivalents, and Restricted Cash at June 30	81,414	53,415
Supplemental Disclosure of Cash Flow Information
Non-Cash Capital Expenditures	$ 80,468	$ 71,823

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	9 Months Ended
	Jun. 30, 2024
Accounting Policies [Abstract]
Summary Of Significant Accounting Policies	Summary of Significant Accounting Policies Principles of Consolidation. The Company consolidates all entities in which it has a controlling financial interest. All significant intercompany balances and transactions are eliminated. The Company uses proportionate consolidation when accounting for drilling arrangements related to exploration and production properties accounted for under the full cost method of accounting. The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Earnings for Interim Periods. The Company, in its opinion, has included all adjustments (which consist of only normally recurring adjustments, unless otherwise disclosed in this Quarterly Report on Form 10-Q) that are necessary for a fair statement of the results of operations for the reported periods. The consolidated financial statements and notes thereto, included herein, should be read in conjunction with the financial statements and notes for the years ended September 30, 2023, 2022 and 2021 that are included in the Company's 2023 Form 10-K. The consolidated financial statements for the year ended September 30, 2024 will be audited by the Company's independent registered public accounting firm after the end of the fiscal year. The earnings for the nine months ended June 30, 2024 should not be taken as a prediction of earnings for the entire fiscal year ending September 30, 2024. Most of the business of the Utility segment is seasonal in nature and is influenced by weather conditions. Due to the seasonal nature of the heating business in the Utility segment, earnings during the winter months normally represent a substantial part of the earnings that this business is expected to achieve for the entire fiscal year. The Company’s business segments are discussed more fully in Note 9 – Business Segment Information. Consolidated Statements of Cash Flows. The components, as reported on the Company’s Consolidated Balance Sheets, of the total cash, cash equivalents, and restricted cash presented on the Statement of Cash Flows are as follows (in thousands): Nine Months Ended Nine Months Ended Balance at Balance at October 1, 2023 Balance at Balance at October 1, 2022 Cash and Temporary Cash Investments $ 81,414 $ 55,447 $ 53,415 $ 46,048 Hedging Collateral Deposits — — — 91,670 Cash, Cash Equivalents, and Restricted Cash $ 81,414 $ 55,447 $ 53,415 $ 137,718 The Company considers all highly liquid debt instruments purchased with a maturity date of generally three months or less to be cash equivalents. The Company’s restricted cash is composed entirely of amounts reported as Hedging Collateral Deposits on the Consolidated Balance Sheets. Hedging Collateral Deposits is an account title for cash held in margin accounts funded by the Company to serve as collateral for derivative financial instruments in an unrealized loss position. In accordance with its accounting policy, the Company does not offset hedging collateral deposits paid or received against related derivative financial instruments liability or asset balances. Allowance for Uncollectible Accounts. The allowance for uncollectible accounts is the Company’s best estimate of the amount of probable credit losses in the existing accounts receivable. The allowance, the majority of which is in the Utility segment, is determined based on historical experience, the age of customer accounts, other specific information about customer accounts, and the economic and regulatory environment. Account balances have historically been written off against the allowance approximately twelve months after the account is final billed or when it is anticipated that the receivable will not be recovered. During 2022 and 2021, final billings were suppressed in the Utility segment as a result of state shut-off moratoriums arising from the COVID-19 pandemic. Those moratoriums were lifted in 2022 which allowed for the resumption of final billings during 2022, thereby resulting in higher amounts being written off in 2023 and 2024. Activity in the allowance for uncollectible accounts for the nine months ended June 30, 2024 and 2023 are as follows (in thousands): Balance at Beginning of Period Additions Charged to Costs and Expenses Discounts on Purchased Receivables Net Accounts Receivable Written-Off Balance at End of Period Nine Months Ended June 30, 2024 Allowance for Uncollectible Accounts $ 36,295 $ 11,774 $ 698 $ (16,145) $ 32,622 Nine Months Ended June 30, 2023 Allowance for Uncollectible Accounts $ 40,228 $ 13,142 $ 1,316 $ (11,578) $ 43,108 Gas Stored Underground. In the Utility segment, gas stored underground is carried at lower of cost or net realizable value, on a LIFO method. Gas stored underground normally declines during the first and second quarters of the year and is replenished during the third and fourth quarters. In the Utility segment, the current cost of replacing gas withdrawn from storage is recorded in the Consolidated Statements of Income and a reserve for gas replacement is recorded in the Consolidated Balance Sheets under the caption “Other Accruals and Current Liabilities.” Such reserve, which amounted to $6.7 million at June 30, 2024, is reduced to zero by September 30 of each year as the inventory is replenished. Property, Plant and Equipment. In the Company’s Exploration and Production segment, property acquisition, exploration and development costs are capitalized under the full cost method of accounting. Under this methodology, all costs associated with property acquisition, exploration and development activities are capitalized, including internal costs directly identified with acquisition, exploration and development activities. The internal costs that are capitalized do not include any costs related to production, general corporate overhead, or similar activities. The Company does not recognize any gain or loss on the sale or other disposition of properties unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves attributable to a cost center. The Company's capitalized costs relating to exploration and production activities, net of accumulated depreciation, depletion and amortization, were $2.6 billion and $2.4 billion at June 30, 2024 and September 30, 2023, respectively. Capitalized costs include costs related to unproved properties, which are excluded from amortization until proved reserves are found or it is determined that the unproved properties are impaired. Such costs amounted to $202.2 million and $161.1 million at June 30, 2024 and September 30, 2023, respectively. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. The amount of any impairment is transferred to the pool of capitalized costs being amortized. Capitalized costs are subject to the SEC full cost ceiling test. The ceiling test, which is performed each quarter, determines a limit, or ceiling, on the amount of property acquisition, exploration and development costs that can be capitalized. The ceiling under this test represents (a) the present value of estimated future net cash flows, excluding future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet, using a discount factor of 10%, which is computed by applying commodity pricing (as adjusted for hedging) to estimated future production of proved reserves as of the date of the latest balance sheet, less estimated future expenditures, plus (b) the cost of unproved properties not being depleted, less (c) income tax effects related to the differences between the book and tax basis of the properties. The commodity prices used to calculate the full cost ceiling are based on an unweighted arithmetic average of first day of the month commodity price for each month within the twelve-month period prior to the end of the reporting period. If capitalized costs, net of accumulated depreciation, depletion and amortization and related deferred income taxes, exceed the ceiling at the end of any quarter, a permanent non-cash impairment is required to be charged to earnings in that quarter. The book value of the exploration and production properties exceeded the ceiling at June 30, 2024. As such, the Company recognized a non-cash, pre-tax impairment charge of $200.7 million for the quarter ended June 30, 2024. A deferred income tax benefit of $55.7 million related to the non-cash impairment charge was also recognized for the quarter ended June 30, 2024. In adjusting estimated future cash flows for hedging under the ceiling test at June 30, 2024, estimated future net cash flows were increased by $375.8 million. The principal assets of the Utility, Pipeline and Storage and Gathering segments, consisting primarily of gas distribution pipelines, transmission pipelines, storage facilities, gathering lines and compressor stations, are recorded at historical cost. There were no indications of any impairments to property, plant and equipment in the Utility, Pipeline and Storage and Gathering segments at June 30, 2024. Accumulated Other Comprehensive Income (Loss). The components of Accumulated Other Comprehensive Income (Loss) and changes for the nine months ended June 30, 2024 and 2023, net of related tax effect, are as follows (amounts in parentheses indicate debits) (in thousands): Gains and Losses on Derivative Financial Instruments Funded Status of the Pension and Other Post-Retirement Benefit Plans Total Three Months Ended June 30, 2024 Balance at April 1, 2024 $ 135,023 $ (59,683) $ 75,340 Other Comprehensive Gains and Losses Before Reclassifications (15,850) — (15,850) Amounts Reclassified From Other Comprehensive Loss (54,440) — (54,440) Balance at June 30, 2024 $ 64,733 $ (59,683) $ 5,050 Nine Months Ended June 30, 2024 Balance at October 1, 2023 $ 4,623 $ (59,683) $ (55,060) Other Comprehensive Gains and Losses Before Reclassifications 172,249 — 172,249 Amounts Reclassified From Other Comprehensive Income (112,139) — (112,139) Balance at June 30, 2024 $ 64,733 $ (59,683) $ 5,050 Three Months Ended June 30, 2023 Balance at April 1, 2023 $ (1,294) $ (53,570) $ (54,864) Other Comprehensive Gains and Losses Before Reclassifications 47,359 — 47,359 Amounts Reclassified From Other Comprehensive Income (41,879) — (41,879) Balance at June 30, 2023 $ 4,186 $ (53,570) $ (49,384) Nine Months Ended June 30, 2023 Balance at October 1, 2022 $ (572,163) $ (53,570) $ (625,733) Other Comprehensive Gains and Losses Before Reclassifications 488,726 — 488,726 Amounts Reclassified From Other Comprehensive Income 87,623 — 87,623 Balance at June 30, 2023 $ 4,186 $ (53,570) $ (49,384) Reclassifications Out of Accumulated Other Comprehensive Income (Loss). The details about the reclassification adjustments out of accumulated other comprehensive income (loss) for the nine months ended June 30, 2024 and 2023 are as follows (amounts in parentheses indicate debits to the income statement) (in thousands): Details About Accumulated Other Comprehensive Income (Loss) Components Amount of Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) Affected Line Item in the Statement Where Net Income is Presented Three Months Ended Nine Months Ended 2024 2023 2024 2023 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $75,462 $57,842 $155,401 ($120,088) Operating Revenues Foreign Currency Contracts (116) (150) (198) (502) Operating Revenues 75,346 57,692 155,203 (120,590) Total Before Income Tax (20,906) (15,813) (43,064) 32,967 Income Tax Expense $54,440 $41,879 $112,139 ($87,623) Net of Tax Other Current Assets . The components of the Company’s Other Current Assets are as follows (in thousands): At June 30, 2024 At September 30, 2023 Prepayments $ 23,972 $ 18,966 Prepaid Property and Other Taxes 11,462 14,186 Federal Income Taxes Receivable — 14,602 State Income Taxes Receivable 12,298 16,133 Regulatory Assets 35,191 36,373 $ 82,923 $ 100,260 Other Accruals and Current Liabilities . The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At June 30, 2024 At September 30, 2023 Accrued Capital Expenditures $ 52,620 $ 43,323 Regulatory Liabilities 27,538 38,105 Reserve for Gas Replacement 6,657 — Liability for Royalty and Working Interests 17,670 17,679 Federal Income Taxes Payable 1,027 — Non-Qualified Benefit Plan Liability 13,052 13,052 Other 50,569 48,815 $ 169,133 $ 160,974 Earnings Per Common Share. Basic earnings per common share is computed by dividing income or loss by the weighted average number of common shares outstanding for the period. Diluted earnings per common share reflects the potential dilution that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. For purposes of determining earnings per common share, the potentially dilutive securities the Company had outstanding were restricted stock units and performance shares. As the Company recognized a net loss for the quarter ended June 30, 2024, in accordance with accounting guidance, all dilution associated with restricted stock units and performance shares in the amount of 567,681 shares, was excluded from the earnings per share calculation for the quarter ended June 30, 2024. For the nine months ended June 30, 2024 and for the quarter and nine months ended June 30, 2023, the diluted weighted average shares outstanding shown on the Consolidated Statements of Income reflects the potential dilution as a result of these securities as determined using the Treasury Stock Method. Restricted stock units and performance shares that are antidilutive are excluded from the calculation of diluted earnings per common share. There were 335 securities excluded as being antidilutive for the nine months ended June 30, 2024. There were 8,322 securities and 4,526 securities excluded as being antidilutive for the quarter and nine months ended June 30, 2023, respectively. Share Repurchases. The Company considers all shares repurchased as cancelled shares restored to the status of authorized but unissued shares, in accordance with New Jersey law. The repurchases are accounted for on the date the share repurchase is traded as an adjustment to common stock (at par value) with the excess repurchase price allocated between paid in capital and retained earnings. Refer to Note 7 – Capitalization for further discussion of the Company's share repurchase program. Stock-Based Compensation. The Company granted 361,729 performance shares during the nine months ended June 30, 2024. The weighted average fair value of such performance shares was $44.23 per share for the nine months ended June 30, 2024. Performance shares are an award constituting units denominated in common stock of the Company, the number of which may be adjusted over a performance cycle based upon the extent to which performance goals have been satisfied. Earned performance shares may be distributed in the form of shares of common stock of the Company, an equivalent value in cash or a combination of cash and shares of common stock of the Company, as determined by the Company. The performance shares do not entitle the participant to receive dividends during the vesting period. The performance shares granted during the nine months ended June 30, 2024 include awards that must meet a performance goal related to either relative return on capital over a three-year or five-year performance cycle ("ROC performance shares"), methane intensity and greenhouse gas emissions reductions over a three-year performance cycle ("ESG performance shares") or relative shareholder return over a three-year or five-year performance cycle ("TSR performance shares"). The performance goal related to the ROC performance shares over the respective performance cycles is the Company’s total return on capital relative to the total return on capital of other companies in a group selected by the Compensation Committee (“Report Group”). Total return on capital for a given company means the average of the Report Group companies’ returns on capital for each twelve-month period corresponding to each of the Company’s fiscal years during the performance cycle, based on data reported for the Report Group companies in the Bloomberg database. The number of these ROC performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value of the ROC performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the ESG performance shares over the three-year performance cycle consists of two parts: reductions in the rates of intensity of methane emissions for each of the Company's operating segments, and reduction of the consolidated Company's total greenhouse gas emissions. The Company's Compensation Committee set specific target levels for methane intensity rates and total greenhouse gas emissions, and the performance goal is intended to incentivize and reward performance to the extent management achieves methane intensity and greenhouse gas reduction targets making progress towards the Company's 2030 goals. The number of these ESG performance shares that will vest and be paid out will depend upon the number of methane intensity segment targets achieved and whether the Company meets the total greenhouse gas emissions target. The fair value of these ESG performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the TSR performance shares over the respective performance cycles is the Company’s three-year (or five-year) total shareholder return relative to the three-year (or five-year) total shareholder return of the other companies in the Report Group. Three-year (or five-year) total shareholder return for a given company will be based on the data reported for that company (with the starting and ending stock prices over the performance cycle calculated as the average closing stock price for the prior calendar month and with dividends reinvested in that company’s securities at each ex-dividend date) in the Bloomberg database. The number of these TSR performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value price at the date of grant for the TSR performance shares is determined using a Monte Carlo simulation technique, which includes a reduction in value for the present value of forgone dividends over the vesting term of the award. This price is multiplied by the number of TSR performance shares awarded, the result of which is recorded as compensation expense over the vesting term of the award. The Company granted 220,778 restricted stock units during the nine months ended June 30, 2024. The weighted average fair value of such restricted stock units was $42.44 per share for the nine months ended June 30, 2024. Restricted stock units represent the right to receive shares of common stock of the Company (or the equivalent value in cash or a combination of cash and shares of common stock of the Company, as determined by the Company) at the end of a specified time period. These restricted stock units do not entitle the participant to receive dividends during the vesting period. The fair value at the date of grant of the restricted stock units (represented by the market value of Company common stock on the date of the award) must be reduced by the present value of forgone dividends over the vesting term of the award. The fair value of restricted stock units on the date of award is recorded as compensation expense over the vesting period. Pursuant to registration statements for the Company's stock award plans, there were 3,890,301 shares available for future grant at June 30, 2024. These shares include shares available for future options, SARs, restricted stock and performance share grants.

Asset Acquisitions

Asset Acquisitions	9 Months Ended
	Jun. 30, 2024
Asset Acquisition [Abstract]
Asset Acquisitions	Asset Acquisition On June 1, 2023, the Company completed its acquisition of certain upstream assets located primarily in Tioga County, Pennsylvania from SWN Production Company, LLC ("SWN") for total consideration of $124.8 million. The purchase price, which reflects an effective date of January 1, 2023, was reduced for production revenues less expenses that were retained by SWN from the effective date to the closing date. As part of the transaction, the Company acquired approximately 34,000 net acres in an area that is contiguous with existing Company-owned upstream assets. This transaction was accounted for as an asset acquisition, and, as such, the purchase price was allocated to property, plant and equipment. The following is a summary of the asset acquisition in thousands: Purchase Price $ 124,178 Transaction Costs 580 Total Consideration $ 124,758

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
	Jun. 30, 2024
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	Revenue from Contracts with Customers The following tables provide a disaggregation of the Company's revenues for the quarter and nine months ended June 30, 2024 and 2023, presented by type of service from each reportable segment. Quarter Ended June 30, 2024 (Thousands) Revenues By Type of Service Exploration and Production Pipeline and Storage Gathering Utility All Other Corporate and Intersegment Eliminations Total Consolidated Production of Natural Gas $ 144,374 $ — $ — $ — $ — $ — $ 144,374 Production of Crude Oil 511 — — — — — 511 Natural Gas Processing 195 — — — — — 195 Natural Gas Gathering Service — — 60,120 — — (56,476) 3,644 Natural Gas Transportation Service — 79,640 — 21,690 — (26,826) 74,504 Natural Gas Storage Service — 24,612 — — — (10,436) 14,176 Natural Gas Residential Sales — — — 89,034 — — 89,034 Natural Gas Commercial Sales — — — 11,022 — — 11,022 Natural Gas Industrial Sales — — — 480 — (1) 479 Other 363 1,167 — (618) — (207) 705 Total Revenues from Contracts with Customers 145,443 105,419 60,120 121,608 — (93,946) 338,644 Alternative Revenue Programs — — — 3,336 — — 3,336 Derivative Financial Instruments 75,462 — — — — — 75,462 Total Revenues $ 220,905 $ 105,419 $ 60,120 $ 124,944 $ — $ (93,946) $ 417,442 Nine Months Ended June 30, 2024 (Thousands) Revenues By Type of Service Exploration and Production Pipeline and Storage Gathering Utility All Other Corporate and Intersegment Eliminations Total Consolidated Production of Natural Gas $ 580,233 $ — $ — $ — $ — $ — $ 580,233 Production of Crude Oil 1,722 — — — — — 1,722 Natural Gas Processing 765 — — — — — 765 Natural Gas Gathering Service — — 186,701 — — (174,544) 12,157 Natural Gas Transportation Service — 232,532 — 88,817 — (73,040) 248,309 Natural Gas Storage Service — 71,247 — — — (30,520) 40,727 Natural Gas Residential Sales — — — 445,971 — — 445,971 Natural Gas Commercial Sales — — — 62,117 — — 62,117 Natural Gas Industrial Sales — — — 2,668 — (5) 2,663 Other 1,416 4,073 — (2,066) — (695) 2,728 Total Revenues from Contracts with Customers 584,136 307,852 186,701 597,507 — (278,804) 1,397,392 Alternative Revenue Programs — — — 19,949 — — 19,949 Derivative Financial Instruments 155,401 — — — — — 155,401 Total Revenues $ 739,537 $ 307,852 $ 186,701 $ 617,456 $ — $ (278,804) $ 1,572,742 Quarter Ended June 30, 2023 (Thousands) Revenues By Type of Service Exploration and Production Pipeline and Storage Gathering Utility All Other Corporate and Intersegment Eliminations Total Consolidated Production of Natural Gas $ 157,682 $ — $ — $ — $ — $ — $ 157,682 Production of Crude Oil 483 — — — — — 483 Natural Gas Processing 284 — — — — — 284 Natural Gas Gathering Service — — 58,906 — — (54,277) 4,629 Natural Gas Transportation Service — 70,424 — 19,905 — (20,311) 70,018 Natural Gas Storage Service — 21,147 — — — (9,006) 12,141 Natural Gas Residential Sales — — — 108,398 — — 108,398 Natural Gas Commercial Sales — — — 13,971 — — 13,971 Natural Gas Industrial Sales — — — 866 — (2) 864 Other 290 824 — 406 — (199) 1,321 Total Revenues from Contracts with Customers 158,739 92,395 58,906 143,546 — (83,795) 369,791 Alternative Revenue Programs — — — 1,071 — — 1,071 Derivative Financial Instruments 57,842 — — — — — 57,842 Total Revenues $ 216,581 $ 92,395 $ 58,906 $ 144,617 $ — $ (83,795) $ 428,704 Nine Months Ended June 30, 2023 (Thousands) Revenues By Type of Service Exploration and Production Pipeline and Storage Gathering Utility All Other Corporate and Intersegment Eliminations Total Consolidated Production of Natural Gas $ 849,811 $ — $ — $ — $ — $ — $ 849,811 Production of Crude Oil 1,637 — — — — — 1,637 Natural Gas Processing 867 — — — — — 867 Natural Gas Gathering Service — — 172,300 — — (163,297) 9,003 Natural Gas Transportation Service — 220,420 — 84,079 — (62,880) 241,619 Natural Gas Storage Service — 63,903 — — — (27,221) 36,682 Natural Gas Residential Sales — — — 671,352 — — 671,352 Natural Gas Commercial Sales — — — 97,432 — — 97,432 Natural Gas Industrial Sales — — — 5,273 — (6) 5,267 Other 5,880 831 — (1,717) — (747) 4,247 Total Revenues from Contracts with Customers 858,195 285,154 172,300 856,419 — (254,151) 1,917,917 Alternative Revenue Programs — — — 6,995 — — 6,995 Derivative Financial Instruments (120,088) — — — — — (120,088) Total Revenues $ 738,107 $ 285,154 $ 172,300 $ 863,414 $ — $ (254,151) $ 1,804,824 The Company records revenue related to its derivative financial instruments in the Exploration and Production segment. The Company also records revenue related to alternative revenue programs in its Utility segment. Revenue related to derivative financial instruments and alternative revenue programs are excluded from the scope of the authoritative guidance regarding revenue recognition since they are accounted for under other existing accounting guidance. The Company’s Pipeline and Storage segment expects to recognize the following revenue amounts in future periods related to “fixed” charges associated with remaining performance obligations for transportation and storage contracts: $58.9 million for the remainder of fiscal 2024; $224.8 million for fiscal 2025; $174.5 million for fiscal 2026; $136.4 million for fiscal 2027; $117.2 million for fiscal 2028; and $612.0 million thereafter.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Jun. 30, 2024
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The FASB authoritative guidance regarding fair value measurements establishes a fair-value hierarchy and prioritizes the inputs used in valuation techniques that measure fair value. Those inputs are prioritized into three levels. Level 1 inputs are unadjusted quoted prices in active markets for assets or liabilities that the Company can access at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly at the measurement date. Level 3 inputs are unobservable inputs for the asset or liability at the measurement date. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The following table sets forth, by level within the fair value hierarchy, the Company's financial assets and liabilities (as applicable) that were accounted for at fair value on a recurring basis as of June 30, 2024 and September 30, 2023. Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Recurring Fair Value Measures At fair value as of June 30, 2024 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 72,625 $ — $ — $ — $ 72,625 Derivative Financial Instruments: Over the Counter Swaps – Gas — 85,623 — (17,654) 67,969 Over the Counter No Cost Collars – Gas — 33,876 — (3,060) 30,816 Contingent Consideration for Asset Sale — 2,429 — — 2,429 Foreign Currency Contracts — 185 — (1,082) (897) Other Investments: Balanced Equity Mutual Fund 18,464 — — — 18,464 Fixed Income Mutual Fund 16,745 — — — 16,745 Total $ 107,834 $ 122,113 $ — $ (21,796) $ 208,151 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 21,018 $ — $ (17,654) $ 3,364 Over the Counter No Cost Collars – Gas — 2,190 — (3,060) (870) Foreign Currency Contracts — 1,082 — (1,082) — Total $ — $ 24,290 $ — $ (21,796) $ 2,494 Total Net Assets/(Liabilities) $ 107,834 $ 97,823 $ — $ — $ 205,657 Recurring Fair Value Measures At fair value as of September 30, 2023 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 39,332 $ — $ — $ — $ 39,332 Derivative Financial Instruments: Over the Counter Swaps – Gas — 65,800 — (37,508) 28,292 Over the Counter No Cost Collars – Gas — 30,966 — (14,745) 16,221 Contingent Consideration for Asset Sale — 7,277 — — 7,277 Foreign Currency Contracts — 150 — (1,453) (1,303) Other Investments: Balanced Equity Mutual Fund 15,837 — — — 15,837 Fixed Income Mutual Fund 15,897 — — — 15,897 Total $ 71,066 $ 104,193 $ — $ (53,706) $ 121,553 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 68,311 $ — $ (37,508) $ 30,803 Over the Counter No Cost Collars – Gas — 14,950 — (14,745) 205 Foreign Currency Contracts — 1,454 — (1,453) 1 Total $ — $ 84,715 $ — $ (53,706) $ 31,009 Total Net Assets/(Liabilities) $ 71,066 $ 19,478 $ — $ — $ 90,544 (1) Netting Adjustments represent the impact of legally-enforceable master netting arrangements that allow the Company to net gain and loss positions held with the same counterparties. The net asset or net liability for each counterparty is recorded as an asset or liability on the Company’s balance sheet. Derivative Financial Instruments The derivative financial instruments reported in Level 2 at June 30, 2024 and September 30, 2023 include natural gas price swap agreements, natural gas no cost collars, and foreign currency contracts, all of which are used in the Company’s Exploration and Production segment. The fair value of the Level 2 price swap agreements and no cost collars is based on an internal cash flow model that uses observable inputs (i.e. SOFR based discount rates for the price swap agreements and basis differential information, if applicable, at active natural gas trading markets). The fair value of the Level 2 foreign currency contracts is determined using the market approach based on observable market transactions of forward Canadian currency rates. The authoritative guidance for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At June 30, 2024, the Company determined that nonperformance risk associated with the price swap agreements, no cost collars and foreign currency contracts would have no material impact on its financial position or results of operation. To assess nonperformance risk, the Company considered information such as any applicable collateral posted, master netting arrangements, and applied a market-based method by using the counterparty's (assuming the derivative is in a gain position) or the Company’s (assuming the derivative is in a loss position) credit default swaps rates. Derivative financial instruments reported in Level 2 at June 30, 2024 also includes the contingent consideration associated with the sale of the Exploration and Production segment's California assets on June 30, 2022. The terms of the purchase and sale agreement specified that the Company could receive up to three annual contingent payments between calendar year 2023 and calendar year 2025, not to exceed $10 million per year, with the amount of each annual payment calculated at $1.0 million for each $1 per barrel that the ICE Brent Average for each calendar year exceeds $95 per barrel up to $105 per barrel. The calendar 2023 contingency period expired with the ICE Brent Average falling below $95 per barrel. The fair value of the contingent consideration was calculated using a Monte Carlo simulation model that uses observable inputs, including the ICE Brent closing price as of the valuation date, initial and max trigger price, volatility, risk-free rate, time of maturity and counterparty risk.

Financial Instruments

Financial Instruments	9 Months Ended
	Jun. 30, 2024
Financial Instruments, Owned, at Fair Value, by Type, Alternative [Abstract]
Financial Instruments	Financial Instruments Long-Term Debt. The fair market value of the Company’s debt, as presented in the table below, was determined using a discounted cash flow model, which incorporates the Company’s credit ratings and current market conditions in determining the yield, and subsequently, the fair market value of the debt. Based on these criteria, the fair market value of long-term debt, including current portion, was as follows (in thousands): June 30, 2024 September 30, 2023 Carrying Fair Value Carrying Fair Value Long-Term Debt $ 2,687,115 $ 2,598,784 $ 2,384,485 $ 2,210,478 The fair value amounts are not intended to reflect principal amounts that the Company will ultimately be required to pay. Carrying amounts for other financial instruments recorded on the Company’s Consolidated Balance Sheets approximate fair value. The fair value of long-term debt was calculated using observable inputs (U.S. Treasuries or Secured Overnight Financing Rates (SOFR) for the risk-free component and company specific credit spread information – generally obtained from recent trade activity in the debt). As such, the Company considers the debt to be Level 2. Any temporary cash investments, notes payable to banks and commercial paper are stated at cost. Temporary cash investments are considered Level 1, while notes payable to banks and commercial paper are considered to be Level 2. Given the short-term nature of the notes payable to banks and commercial paper, the Company believes cost is a reasonable approximation of fair value. Other Investments. The components of the Company's Other Investments are as follows (in thousands): At June 30, 2024 At September 30, 2023 Life Insurance Contracts $ 44,338 $ 42,242 Equity Mutual Fund 18,464 15,837 Fixed Income Mutual Fund 16,745 15,897 $ 79,547 $ 73,976 Investments in life insurance contracts are stated at their cash surrender values or net present value. Investments in an equity mutual fund and a fixed income mutual fund are stated at fair value based on quoted market prices with changes in fair value recognized in net income. The insurance contracts and equity mutual fund are primarily informal funding mechanisms for various benefit obligations the Company has to certain employees. The fixed income mutual fund is primarily an informal funding mechanism for certain regulatory obligations that the Company has to Utility segment customers in its Pennsylvania jurisdiction and for various benefit obligations the Company has to certain employees. Derivative Financial Instruments. The Company uses derivative financial instruments to manage commodity price risk in the Exploration and Production segment. The Company enters into over-the-counter no cost collar and swap agreements for natural gas to manage the price risk associated with forecasted sales of natural gas. In addition, the Company also enters into foreign exchange forward contracts to manage the risk of currency fluctuations associated with transportation costs denominated in Canadian currency in the Exploration and Production segment. These instruments are accounted for as cash flow hedges. The duration of the Company’s cash flow hedges does not typically exceed 5 years while the foreign currency forward contracts do not exceed 7 years. On June 30, 2022, the Company completed the sale of Seneca’s California assets. The terms of the purchase and sale agreement specified that the Company could receive up to three annual contingent payments between calendar year 2023 and calendar year 2025, not to exceed $10 million per year, with the amount of each annual payment calculated as $1.0 million for each $1 per barrel that the ICE Brent Average for each calendar year exceeds $95 per barrel up to $105 per barrel. The calendar 2023 contingency period expired with the ICE Brent Average falling below $95 per barrel. The Company has determined that this contingent consideration meets the definition of a derivative under the authoritative accounting guidance. Changes in the fair value of this contingent consideration are marked-to-market each reporting period, with changes in fair value recognized in Other Income (Deductions) on the Consolidated Statement of Income. The fair value of this contingent consideration was estimated to be $2.4 million and $7.3 million at June 30, 2024 and September 30, 2023, respectively. A $1.2 million mark-to-market adjustment to reduce the fair value of the contingent consideration was recorded during the quarter ended June 30, 2024. A $4.9 million mark-to-market adjustment to reduce the fair value of the contingent consideration was recorded during the nine months ended June 30, 2024. The Company has presented its net derivative assets and liabilities as “Fair Value of Derivative Financial Instruments” on its Consolidated Balance Sheets at June 30, 2024 and September 30, 2023. Cash Flow Hedges For derivative financial instruments that are designated and qualify as a cash flow hedge, the gain or loss on the derivative is reported as a component of other comprehensive income (loss) and reclassified into earnings in the period or periods during which the hedged transaction affects earnings. As of June 30, 2024, the Company had 334.0 Bcf of natural gas commodity derivative contracts (swaps and no cost collars) outstanding. As of June 30, 2024, the Company was hedging a total of $54.4 million of forecasted transportation costs denominated in Canadian dollars with foreign currency forward contracts. As of June 30, 2024, the Company had $64.7 million of net hedging gains after taxes included in the accumulated other comprehensive income (loss) balance. Of this amount, it is expected that $43.1 million of unrealized gains after taxes will be reclassified into the Consolidated Statement of Income within the next 12 months as the underlying hedged transactions are recorded in earnings. The Effect of Derivative Financial Instruments on the Statement of Financial Performance for the Three Months Ended June 30, 2024 and 2023 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on Location of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income for the 2024 2023 2024 2023 Commodity Contracts $ (21,682) $ 64,653 Operating Revenue $ 75,462 $ 57,842 Foreign Currency Contracts (254) 591 Operating Revenue (116) (150) Total $ (21,936) $ 65,244 $ 75,346 $ 57,692 The Effect of Derivative Financial Instruments on the Statement of Financial Performance for the Nine Months Ended June 30, 2024 and 2023 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or Location of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income Amount of Derivative Gain or 2024 2023 2024 2023 Commodity Contracts $ 238,184 $ 672,396 Operating Revenue $ 155,401 $ (120,088) Foreign Currency Contracts 211 985 Operating Revenue (198) (502) Total $ 238,395 $ 673,381 $ 155,203 $ (120,590) Credit Risk The Company may be exposed to credit risk on any of the derivative financial instruments that are in a gain position. Credit risk relates to the risk of loss that the Company would incur as a result of nonperformance by counterparties pursuant to the terms of their contractual obligations. To mitigate such credit risk, management performs a credit check, and then on a quarterly basis monitors counterparty credit exposure. The majority of the Company’s counterparties are financial institutions and energy traders. The Company has over-the-counter swap positions, no cost collars and applicable foreign currency forward contracts with nineteen counterparties of which eighteen are in a net gain position. On average, the Company had $5.4 million of credit exposure per counterparty in a gain position at June 30, 2024. The maximum credit exposure per counterparty in a gain position at June 30, 2024 was $21.2 million. As of June 30, 2024, no collateral was received from the counterparties by the Company. The Company's gain position on such derivative financial instruments had not exceeded the established thresholds at which the counterparties would be required to post collateral, nor had the counterparties' credit ratings declined to levels at which the counterparties were required to post collateral. As of June 30, 2024, sixteen of the nineteen counterparties to the Company’s outstanding derivative financial contracts (specifically the over-the-counter swaps, over-the-counter no cost collars and applicable foreign currency forward contracts) had a common credit-risk related contingency feature. In the event the Company’s credit rating increases or falls below a certain threshold (applicable debt ratings), the available credit that could be extended to the Company when it is in a derivative financial liability position would either increase or decrease. A decline in the Company’s credit rating, in and of itself, would not cause the Company to be required to post or increase the level of its hedging collateral deposits (in the form of cash deposits, letters of credit or treasury debt instruments). If the Company’s outstanding derivative financial instrument contracts with a credit-risk contingency feature were in a liability position (or if the liability were larger) and/or the Company’s credit rating declined, then hedging collateral deposits or an increase to such deposits could be required. At June 30, 2024, the Company did not have any derivative financial instrument liabilities with a credit-risk related contingency feature according to the Company’s internal model (discussed in Note 4 – Fair Value Measurements), and no hedging collateral deposits were required to be posted by the Company at June 30, 2024. Depending on the movement of commodity prices in the future, it is possible that the Company's derivative asset positions could swing into liability positions, at which point the Company could be required to post hedging collateral deposits.

Income Taxes

Income Taxes	9 Months Ended
	Jun. 30, 2024
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The effective tax rates for the quarters ended June 30, 2024 and June 30, 2023 were 34.3% and 26.2%, respectively. The change in the quarterly effective income tax rate was primarily driven by the impact of the impairment of exploration and production properties under the ceiling test and a methodology change for repairs and maintenance tax deductions as a result of updated IRS guidance published in 2023, which resulted in a larger income tax benefit on a loss before income taxes during the quarter ended June 30, 2024. The effective tax rates for the nine months ended June 30, 2024 and June 30, 2023 were 22.2% and 25.8%, respectively. The decrease in the year-to-date effective income tax rate was also primarily due to the impact of the impairment of exploration and production properties under the ceiling test on income before income taxes, and the methodology change for repairs and maintenance tax deductions as a result of updated IRS guidance published in 2023.

Capitalization

Capitalization	9 Months Ended
	Jun. 30, 2024
Capitalization, Long-Term Debt and Equity [Abstract]
Capitalization	Capitalization Summary of Changes in Common Stock Equity Common Stock Paid In Earnings Accumulated Shares Amount (Thousands, except per share amounts) Balance at April 1, 2024 92,032 $ 92,032 $ 1,045,929 $ 2,090,172 $ 75,340 Net Loss Available for Common Stock (54,158) Dividends Declared on Common Stock ($0.515 Per Share) (47,195) Other Comprehensive Loss, Net of Tax (70,290) Share-Based Payment Expense (1) 4,905 Common Stock Issued Under Stock and Benefit Plans 11 11 587 Share Repurchases Under Repurchase Plan (431) (431) (4,942) (18,435) Balance at June 30, 2024 91,612 $ 91,612 $ 1,046,479 $ 1,970,384 $ 5,050 Balance at October 1, 2023 91,819 $ 91,819 $ 1,040,761 $ 1,885,856 $ (55,060) Net Income Available for Common Stock 245,134 Dividends Declared on Common Stock ($1.505 Per Share) (138,354) Other Comprehensive Income, Net of Tax 60,110 Share-Based Payment Expense (1) 14,262 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 320 320 (2,514) Share Repurchases Under Repurchase Plan (527) (527) (6,030) (22,252) Balance at June 30, 2024 91,612 $ 91,612 $ 1,046,479 $ 1,970,384 $ 5,050 Balance at April 1, 2023 91,795 $ 91,795 $ 1,031,341 $ 1,810,454 $ (54,864) Net Income Available for Common Stock 92,620 Dividends Declared on Common Stock ($0.495 Per Share) (45,444) Other Comprehensive Income, Net of Tax 5,480 Share-Based Payment Expense (1) 4,009 Common Stock Issued Under Stock and Benefit Plans 9 9 502 Balance at June 30, 2023 91,804 $ 91,804 $ 1,035,852 $ 1,857,630 $ (49,384) Balance at October 1, 2022 91,478 $ 91,478 $ 1,027,066 $ 1,587,085 $ (625,733) Net Income Available for Common Stock 403,189 Dividends Declared on Common Stock ($1.445 Per Share) (132,644) Other Comprehensive Income, Net of Tax 576,349 Share-Based Payment Expense (1) 14,327 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 326 326 (5,541) Balance at June 30, 2023 91,804 $ 91,804 $ 1,035,852 $ 1,857,630 $ (49,384) (1) Paid in Capital includes compensation costs associated with performance shares and/or restricted stock awards. The expense is included within Net Income Available For Common Stock, net of tax benefits. Common Stock. During the nine months ended June 30, 2024, the Company issued 112,667 original issue shares of common stock for restricted stock units that vested and 251,255 original issue shares of common stock for performance shares that vested. The Company also issued 27,310 original issue shares of common stock to the non-employee directors of the Company who receive compensation under the Company’s 2009 Non-Employee Director Equity Compensation Plan, including the reinvestment of dividends for certain non-employee directors who elected to defer their shares pursuant to the dividend reinvestment feature of the Company's Deferred Compensation Plan for Directors and Officers (the "DCP") during the nine months ended June 30, 2024. In addition, the Company issued 5,964 original issue shares of common stock to officers of the Company who elected to defer their shares pursuant to the dividend reinvestment feature of the Company's DCP Plan during the nine months ended June 30, 2024. Holders of stock-based compensation awards will often tender shares of common stock to the Company for payment of applicable withholding taxes. During the nine months ended June 30, 2024, 77,461 shares of common stock were tendered to the Company for such purposes. The Company considers all shares tendered as cancelled shares restored to the status of authorized but unissued shares, in accordance with New Jersey law. On March 8, 2024, the Company’s Board of Directors authorized the Company to implement a share repurchase program, whereby the Company may repurchase outstanding shares of common stock, up to an aggregate amount of $200 million in the open market or through privately negotiated transactions, including through the use of trading plans intended to qualify under SEC Rule 10b5-1, in accordance with applicable securities laws and other restrictions. During the nine months ended June 30, 2024, the Company executed transactions to repurchase 526,652 shares at an average price of $54.28 per share. With broker fees and excise taxes, the total cost of these repurchases amounted to $28.8 million. Share repurchases that settled during the nine months ended June 30, 2024 were funded with cash provided by operating activities and/or short-term borrowings. In the future, it is expected that this share repurchase program will continue to be funded with cash provided by operating activities and/or through the use of short-term borrowings. Short-Term Borrowings. On February 28, 2022, the Company entered into a Credit Agreement (as amended from time to time, the "Credit Agreement") with a syndicate of twelve banks. The Credit Agreement replaced the previous Fourth Amended and Restated Credit Agreement and a previous 364-Day Credit Agreement. As initially entered, the Credit Agreement provided a $1.0 billion unsecured committed revolving credit facility with a maturity date of February 26, 2027. In February 2024, the Company and eleven of the banks in the syndicate consented to an extension of the maturity date of the Credit Agreement from February 26, 2027 to February 25, 2028. In May 2024, three of the banks in the syndicate assumed the commitments of the sole non-extending lender such that the Company has aggregate commitments available under the Credit Agreement in the full amount of $1.0 billion to February 25, 2028. Current Portion of Long-Term Debt. The Current Portion of Long-Term Debt at June 30, 2024 consisted of $50.0 million of 7.375% notes that mature in June 2025. None of the Company's long-term debt as of September 30, 2023 had a maturity date within the following twelve-month period. Delayed Draw Term Loan. On February 14, 2024, the Company entered into a Term Loan Agreement (the “Term Loan Agreement”) with six lenders, all of which are lenders under the Credit Agreement. The Term Loan Agreement provides a $300.0 million unsecured committed delayed draw term loan facility with a maturity date of February 14, 2026, and the Company has the ability to select interest periods of one, three or six months for borrowings. In April 2024, pursuant to the delayed draw mechanism, the Company elected to draw a total of $300.0 million under the facility. The Company selected an initial six month interest period for these borrowings, locking in a weighted average interest rate of 6.705% through the beginning of October 2024. After deducting debt issuance costs, the net proceeds to the Company amounted to $299.4 million. The Company used the proceeds for general corporate purposes, which included the redemption of outstanding commercial paper.

Commitments And Contingencies

Commitments And Contingencies	9 Months Ended
	Jun. 30, 2024
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	Commitments and Contingencies Environmental Matters. The Company is subject to various federal, state and local laws and regulations relating to the protection of the environment. The Company has established procedures for the ongoing evaluation of its operations to identify potential environmental exposures and to comply with regulatory requirements. It is the Company’s policy to accrue estimated environmental clean-up costs (investigation and remediation) when such amounts can reasonably be estimated and it is probable that the Company will be required to incur such costs. At June 30, 2024, the Company has estimated its remaining clean-up costs related to former manufactured gas plant sites will be approximately $2.5 million. The Company's liability for such clean-up costs has been recorded in Other Liabilities on the Consolidated Balance Sheet at June 30, 2024. The Company has a regulatory liability of $5.2 million related to environmental clean-up costs at June 30, 2024 and is currently not aware of any material additional exposure to environmental liabilities. However, changes in environmental laws and regulations, new information or other factors could have an adverse financial impact on the Company. Northern Access Project. On February 3, 2017, Supply Corporation and Empire received FERC approval of the Northern Access project described herein. Shortly thereafter, the NYDEC issued a Notice of Denial of the federal Clean Water Act Section 401 Water Quality Certification and other state stream and wetland permits for the New York portion of the project (the Water Quality Certification for the Pennsylvania portion of the project was received in January of 2017). Subsequently, FERC issued an Order finding that the NYDEC exceeded the statutory time frame to take action under the Clean Water Act and, therefore, waived its opportunity to approve or deny the Water Quality Certification. FERC denied rehearing requests associated with its Order and FERC's decisions were appealed. The Second Circuit Court of Appeals issued an order upholding the FERC waiver orders. In addition, in the Company's state court litigation challenging the NYDEC's actions with regard to various state permits, the New York State Supreme Court issued a decision finding these permits to be preempted. On June 29, 2022, the Company received an extension of time from FERC, until December 31, 2024, to construct the project, which was affirmed on March 29, 2024 by the U.S. Court of Appeals for the D.C. Circuit. In light of the recent D.C. Circuit decision, the Company is evaluating next steps for the project, including the status of various regulatory approvals, the $500 million preliminary cost estimate, and the potential in-service date. As of June 30, 2024, the Company has spent approximately $55.0 million on the project, all of which is recorded on the balance sheet. Other. The Company is involved in other litigation and regulatory matters arising in the normal course of business. These other matters may include, for example, negligence claims and tax, regulatory or other governmental audits, inspections, investigations and other proceedings. These matters may involve state and federal taxes, safety, compliance with regulations, rate base, cost of service and purchased gas cost issues, among other things. While these other matters arising in the normal course of business could have a material effect on earnings and cash flows in the period in which they are resolved, an estimate of the possible loss or range of loss, if any, cannot be made at this time.

Business Segment Information

Business Segment Information	9 Months Ended
	Jun. 30, 2024
Segment Reporting [Abstract]
Business Segment Information	Business Segment Information The Company reports financial results for four segments: Exploration and Production, Pipeline and Storage, Gathering and Utility. The division of the Company’s operations into reportable segments is based upon a combination of factors including differences in products and services, regulatory environment and geographic factors. The data presented in the tables below reflect financial information for the segments and reconcile to consolidated amounts. As stated in the 2023 Form 10-K, the Company evaluates segment performance based on income before discontinued operations (when applicable). When this is not applicable, the Company evaluates performance based on net income. There have not been any changes in the basis of segmentation nor in the basis of measuring segment profit or loss from those used in the Company’s 2023 Form 10-K. A listing of segment assets at June 30, 2024 and September 30, 2023 is shown in the tables below. Quarter Ended June 30, 2024 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $220,905 $68,035 $3,644 $124,858 $417,442 $— $— $417,442 Intersegment Revenues $— $37,384 $56,476 $86 $93,946 $— $(93,946) $— Segment Profit: Net Income (Loss) $(112,028) $30,690 $24,979 $2,559 $(53,800) $(124) $(234) $(54,158) Nine Months Ended June 30, 2024 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $739,537 $204,071 $12,157 $616,977 $1,572,742 $— $— $1,572,742 Intersegment Revenues $— $103,781 $174,544 $479 $278,804 $— $(278,804) $— Segment Profit: Net Income (Loss) $2,521 $85,482 $82,510 $73,848 $244,361 $(341) $1,114 $245,134 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Segment Assets: At June 30, 2024 $2,815,598 $2,486,740 $998,176 $2,329,894 $8,630,408 $5,067 $(154,438) $8,481,037 At September 30, 2023 $2,814,218 $2,427,214 $912,923 $2,247,743 $8,402,098 $4,795 $(126,633) $8,280,260 Quarter Ended June 30, 2023 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $216,581 $62,956 $4,629 $144,538 $428,704 $— $— $428,704 Intersegment Revenues $— $29,439 $54,277 $79 $83,795 $— $(83,795) $— Segment Profit: Net Income (Loss) $43,329 $23,813 $24,135 $37 $91,314 $(81) $1,387 $92,620 Nine Months Ended June 30, 2023 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $738,107 $194,800 $9,003 $862,914 $1,804,824 $— $— $1,804,824 Intersegment Revenues $— $90,354 $163,297 $500 $254,151 $— $(254,151) $— Segment Profit: Net Income (Loss) $195,503 $77,147 $73,207 $55,574 $401,431 $(430) $2,188 $403,189

Retirement Plan And Other Post-

Retirement Plan And Other Post-Retirement Benefits	9 Months Ended
	Jun. 30, 2024
Retirement Benefits [Abstract]
Retirement Plan and Other Post-Retirement Benefits	Retirement Plan and Other Post-Retirement Benefits Components of Net Periodic Benefit Cost (in thousands): Retirement Plan Other Post-Retirement Benefits Three Months Ended June 30, 2024 2023 2024 2023 Service Cost $ 1,049 $ 1,297 $ 109 $ 147 Interest Cost 10,890 10,629 3,890 3,912 Expected Return on Plan Assets (17,086) (16,648) (6,660) (6,403) Amortization of Prior Service Cost (Credit) 91 109 (107) (107) Amortization of (Gains) Losses (335) (1,920) (567) (2,189) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 4,057 5,378 2,248 3,829 Net Periodic Benefit Cost (Income) $ (1,334) $ (1,155) $ (1,087) $ (811) Retirement Plan Other Post-Retirement Benefits Nine Months Ended June 30, 2024 2023 2024 2023 Service Cost $ 3,148 $ 3,891 $ 326 $ 440 Interest Cost 32,668 31,887 11,671 11,736 Expected Return on Plan Assets (51,257) (49,945) (19,981) (19,210) Amortization of Prior Service Cost (Credit) 271 327 (322) (321) Amortization of (Gains) Losses (1,004) (5,760) (1,700) (6,566) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 12,173 16,134 6,256 11,143 Net Periodic Benefit Cost (Income) $ (4,001) $ (3,466) $ (3,750) $ (2,778) (1) The Company’s policy is to record retirement plan and other post-retirement benefit costs in the Utility segment on a volumetric basis to reflect the fact that the Utility segment experiences higher throughput of natural gas in the winter months and lower throughput of natural gas in the summer months. The components of net periodic benefit cost other than service cost are presented in Other Income (Deductions) on the Consolidated Statements of Income. Employer Contributions. The Company did not make any contributions to its tax-qualified, noncontributory defined benefit retirement plan (Retirement Plan) during the nine months ended June 30, 2024, and does not anticipate making any such contributions during the remainder of fiscal 2024. The Company also did not make any contributions to its VEBA trusts for its other post-retirement benefits during the nine months ended June 30, 2024, and does not anticipate making any such contributions during the remainder of fiscal 2024.

Regulatory Matters

Regulatory Matters	9 Months Ended
	Jun. 30, 2024
Regulatory Assets and Liabilities, Other Disclosure [Abstract]
Regulatory Matters	Regulatory Matters New York Jurisdiction Distribution Corporation's current delivery rates in its New York jurisdiction were approved by the NYPSC in an order issued on April 20, 2017 with rates becoming effective May 1, 2017 ("2017 Rate Order"). The 2017 Rate Order provided for a return on equity of 8.7% and directed the implementation of an earnings sharing mechanism to be in place beginning on April 1, 2018. On October 31, 2023, Distribution Corporation made a filing with the NYPSC seeking an increase of approximately $88 million in its total annual operating revenues for the projected rate year ending September 30, 2025, with a proposed effective date of October 1, 2024 that includes the maximum suspension period permitted under the New York Public Service Law ("2023 Rate Filing"). The Company is also proposing, among other things, to continue its leak prone pipe replacement program and to implement a number of initiatives that will facilitate achievement of the emissions reduction goals of the CLCPA. A Notice of Impending Settlement Negotiations was filed with the NYPSC on March 26, 2024 and settlement discussions with parties are ongoing. To facilitate settlement negotiations, the Company has indicated that it is willing to accept an extension of the suspension period for the effective date of new base delivery rates through and including January 31, 2025. Consistent with normal regulatory practice, the Company’s acceptance is subject to a “make-whole” provision that would permit the Company to recover or refund any revenue under-collections or over-collections, respectively, resulting from the extension period. On August 13, 2021, the NYPSC issued an order extending the date through which qualified pipeline replacement costs incurred by the Company can be recovered using the existing system modernization tracker for two years (until March 31, 2023). On December 9, 2022, the Company filed a petition with the NYPSC to effectuate a system improvement tracker through which qualified pipeline replacement costs through September 30, 2024 would be tracked and recovered, and to recover certain deferred costs associated with the existing system modernization tracker, effective April 1, 2023. The NYPSC approved the petition by order dated March 17, 2023 contingent on the Company not filing a base rate case that would result in new rates becoming effective prior to October 1, 2024. The 2023 Rate Filing proposes to stop accruing and collecting revenues under its current system modernization and system improvement trackers and shift those revenues into the Company’s new base delivery rates. In the absence of a multi-year rate plan settlement, the Company is requesting that it be allowed to reinstate a tracking mechanism similar to the existing system modernization tracker. Pennsylvania Jurisdiction On October 28, 2022, Distribution Corporation made a filing with the PaPUC seeking an increase in its annual base rate operating revenues of $28.1 million. A settlement involving all active parties to the proceeding was reached and filed with the PaPUC on April 13, 2023. The settlement provided for, among other things, an increase in Distribution Corporation’s annual base rate operating revenues of $23 million. The PaPUC approved the settlement in full, without modification or correction, on June 15, 2023 and new rates went into effect on August 1, 2023. On April 10, 2024, Distribution Corporation filed with the PaPUC a petition for approval of a distribution system improvement charge (“DSIC”) to recover, between base rate cases, capital expenses related to eligible property constructed or installed to rehabilitate, improve and replace portions of the Company’s natural gas distribution system. If approved as filed, beginning October 1, 2024, the Company will be able to recover costs associated with plant placed in service on and after August 1, 2024 if it exceeds approximately $781.3 million of plant as of July 31, 2024 and its quarterly rate of return does not exceed the authorized PaPUC rate of return. As of June 30, 2024, plant placed in service for Distribution Corporation’s Pennsylvania division is $763.7 million. The DSIC petition is currently pending before the PaPUC. FERC Jurisdiction Supply Corporation filed an NGA Section 4 rate case on July 31, 2023 proposing rate increases to be effective February 1, 2024. On March 8, 2024, Supply Corporation and the parties in the case reached a settlement in principle (the Settlement) to resolve the rate case. Supply Corporation’s March 11, 2024 motion to put in place Settlement Rates effective February 1, 2024, was approved by FERC’s Chief Administrative Law Judge on March 12, 2024. The Settlement was filed with FERC on March 27, 2024. A letter order approving the Settlement as filed was issued on June 11, 2024. The “black box” settlement provides for new rates and resolves all issues in the proceeding. The Settlement Rates are estimated to increase Supply Corporation’s revenues on a yearly basis by approximately $56 million, assuming current contract levels. The Settlement generally provides for the continuation of current depreciation rates with minimal changes. Under the Settlement, Supply Corporation may make a rate filing for new rates to be effective at any time. As well, any party can make a filing under NGA Section 5. Empire's 2019 rate settlement requires a Section 4 rate case filing no later than May 1, 2025. Empire has no rate case currently on file.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Pay vs Performance Disclosure
Net Income Available for Common Stock	$ (54,158)	$ 92,620	$ 245,134	$ 403,189

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Jun. 30, 2024
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Summary Of Significant Accoun_2

Summary Of Significant Accounting Policies (Policy)	9 Months Ended
	Jun. 30, 2024
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation. The Company consolidates all entities in which it has a controlling financial interest. All significant intercompany balances and transactions are eliminated. The Company uses proportionate consolidation when accounting for drilling arrangements related to exploration and production properties accounted for under the full cost method of accounting. The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Earnings For Interim Periods	Earnings for Interim Periods. The Company, in its opinion, has included all adjustments (which consist of only normally recurring adjustments, unless otherwise disclosed in this Quarterly Report on Form 10-Q) that are necessary for a fair statement of the results of operations for the reported periods. The consolidated financial statements and notes thereto, included herein, should be read in conjunction with the financial statements and notes for the years ended September 30, 2023, 2022 and 2021 that are included in the Company's 2023 Form 10-K. The consolidated financial statements for the year ended September 30, 2024 will be audited by the Company's independent registered public accounting firm after the end of the fiscal year.
Consolidated Statements of Cash Flows	The Company considers all highly liquid debt instruments purchased with a maturity date of generally three months or less to be cash equivalents. The Company’s restricted cash is composed entirely of amounts reported as Hedging Collateral Deposits on the Consolidated Balance Sheets. Hedging Collateral Deposits is an account title for cash held in margin accounts funded by the Company to serve as collateral for derivative financial instruments in an unrealized loss position. In accordance with its accounting policy, the Company does not offset hedging collateral deposits paid or received against related derivative financial instruments liability or asset balances.
Allowance for Uncollectible Accounts	Allowance for Uncollectible Accounts.
Gas Stored Underground	Gas Stored Underground. In the Utility segment, gas stored underground is carried at lower of cost or net realizable value, on a LIFO method. Gas stored underground normally declines during the first and second quarters of the year and is replenished during the third and fourth quarters. In the Utility segment, the current cost of replacing gas withdrawn from storage is recorded in the Consolidated Statements of Income and a reserve for gas replacement is recorded in the Consolidated Balance Sheets under the caption “Other Accruals and Current Liabilities.” Such reserve, which amounted to $6.7 million at June 30, 2024, is reduced to zero by September 30 of each year as the inventory is replenished.
Property, Plant and Equipment	Property, Plant and Equipment. In the Company’s Exploration and Production segment, property acquisition, exploration and development costs are capitalized under the full cost method of accounting. Under this methodology, all costs associated with property acquisition, exploration and development activities are capitalized, including internal costs directly identified with acquisition, exploration and development activities. The internal costs that are capitalized do not include any costs related to production, general corporate overhead, or similar activities. The Company does not recognize any gain or loss on the sale or other disposition of properties unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves attributable to a cost center. The Company's capitalized costs relating to exploration and production activities, net of accumulated depreciation, depletion and amortization, were $2.6 billion and $2.4 billion at June 30, 2024 and September 30, 2023, respectively. Capitalized costs include costs related to unproved properties, which are excluded from amortization until proved reserves are found or it is determined that the unproved properties are impaired. Such costs amounted to $202.2 million and $161.1 million at June 30, 2024 and September 30, 2023, respectively. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. The amount of any impairment is transferred to the pool of capitalized costs being amortized. Capitalized costs are subject to the SEC full cost ceiling test. The ceiling test, which is performed each quarter, determines a limit, or ceiling, on the amount of property acquisition, exploration and development costs that can be capitalized. The ceiling under this test represents (a) the present value of estimated future net cash flows, excluding future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet, using a discount factor of 10%, which is computed by applying commodity pricing (as adjusted for hedging) to estimated future production of proved reserves as of the date of the latest balance sheet, less estimated future expenditures, plus (b) the cost of unproved properties not being depleted, less (c) income tax effects related to the differences between the book and tax basis of the properties. The commodity prices used to calculate the full cost ceiling are based on an unweighted arithmetic average of first day of the month commodity price for each month within the twelve-month period prior to the end of the reporting period. If capitalized costs, net of accumulated depreciation, depletion and amortization and related deferred income taxes, exceed the ceiling at the end of any quarter, a permanent non-cash impairment is required to be charged to earnings in that quarter. The book value of the exploration and production properties exceeded the ceiling at June 30, 2024. As such, the Company recognized a non-cash, pre-tax impairment charge of $200.7 million for the quarter ended June 30, 2024. A deferred income tax benefit of $55.7 million related to the non-cash impairment charge was also recognized for the quarter ended June 30, 2024. In adjusting estimated future cash flows for hedging under the ceiling test at June 30, 2024, estimated future net cash flows were increased by $375.8 million.
Earnings Per Common Share	Earnings Per Common Share. Basic earnings per common share is computed by dividing income or loss by the weighted average number of common shares outstanding for the period. Diluted earnings per common share reflects the potential dilution that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. For purposes of determining earnings per common share, the potentially dilutive securities the Company had outstanding were restricted stock units and performance shares. As the Company recognized a net loss for the quarter ended June 30, 2024, in accordance with accounting guidance, all dilution associated with restricted stock units and performance shares in the amount of 567,681 shares, was excluded from the earnings per share calculation for the quarter ended June 30, 2024. For the nine months ended June 30, 2024 and for the quarter and nine months ended June 30, 2023, the diluted weighted average shares
Share Repurchases	Share Repurchases. The Company considers all shares repurchased as cancelled shares restored to the status of authorized but unissued shares, in accordance with New Jersey law. The repurchases are accounted for on the date the share repurchase is traded as an adjustment to common stock (at par value) with the excess repurchase price allocated between paid in capital and retained earnings. Refer to Note 7 – Capitalization for further discussion of the Company's share repurchase program.
Stock-Based Compensation	Stock-Based Compensation. The Company granted 361,729 performance shares during the nine months ended June 30, 2024. The weighted average fair value of such performance shares was $44.23 per share for the nine months ended June 30, 2024. Performance shares are an award constituting units denominated in common stock of the Company, the number of which may be adjusted over a performance cycle based upon the extent to which performance goals have been satisfied. Earned performance shares may be distributed in the form of shares of common stock of the Company, an equivalent value in cash or a combination of cash and shares of common stock of the Company, as determined by the Company. The performance shares do not entitle the participant to receive dividends during the vesting period. The performance shares granted during the nine months ended June 30, 2024 include awards that must meet a performance goal related to either relative return on capital over a three-year or five-year performance cycle ("ROC performance shares"), methane intensity and greenhouse gas emissions reductions over a three-year performance cycle ("ESG performance shares") or relative shareholder return over a three-year or five-year performance cycle ("TSR performance shares"). The performance goal related to the ROC performance shares over the respective performance cycles is the Company’s total return on capital relative to the total return on capital of other companies in a group selected by the Compensation Committee (“Report Group”). Total return on capital for a given company means the average of the Report Group companies’ returns on capital for each twelve-month period corresponding to each of the Company’s fiscal years during the performance cycle, based on data reported for the Report Group companies in the Bloomberg database. The number of these ROC performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value of the ROC performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the ESG performance shares over the three-year performance cycle consists of two parts: reductions in the rates of intensity of methane emissions for each of the Company's operating segments, and reduction of the consolidated Company's total greenhouse gas emissions. The Company's Compensation Committee set specific target levels for methane intensity rates and total greenhouse gas emissions, and the performance goal is intended to incentivize and reward performance to the extent management achieves methane intensity and greenhouse gas reduction targets making progress towards the Company's 2030 goals. The number of these ESG performance shares that will vest and be paid out will depend upon the number of methane intensity segment targets achieved and whether the Company meets the total greenhouse gas emissions target. The fair value of these ESG performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the TSR performance shares over the respective performance cycles is the Company’s three-year (or five-year) total shareholder return relative to the three-year (or five-year) total shareholder return of the other companies in the Report Group. Three-year (or five-year) total shareholder return for a given company will be based on the data reported for that company (with the starting and ending stock prices over the performance cycle calculated as the average closing stock price for the prior calendar month and with dividends reinvested in that company’s securities at each ex-dividend date) in the Bloomberg database. The number of these TSR performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value price at the date of grant for the TSR performance shares is determined using a Monte Carlo simulation technique, which includes a reduction in value for the present value of forgone dividends over the vesting term of the award. This price is multiplied by the number of TSR performance shares awarded, the result of which is recorded as compensation expense over the vesting term of the award. The Company granted 220,778 restricted stock units during the nine months ended June 30, 2024. The weighted average fair value of such restricted stock units was $42.44 per share for the nine months ended June 30, 2024. Restricted stock units represent the right to receive shares of common stock of the Company (or the equivalent value in cash or a combination of cash and shares of common stock of the Company, as determined by the Company) at the end of a specified time period. These restricted stock units do not entitle the participant to receive dividends during the vesting period. The fair value at the date of grant of the restricted stock units (represented by the market value of Company common stock on the date of the award) must be reduced by the present value of forgone dividends over the vesting term of the award. The fair value of restricted stock units on the date of award is recorded as compensation expense over the vesting period. Pursuant to registration statements for the Company's stock award plans, there were 3,890,301 shares available for future grant at June 30, 2024. These shares include shares available for future options, SARs, restricted stock and performance share grants.

Summary Of Significant Accoun_3

Summary Of Significant Accounting Policies (Tables)	9 Months Ended
	Jun. 30, 2024
Accounting Policies [Abstract]
Schedule of Cash, Cash Equivalents and Restricted Cash	The components, as reported on the Company’s Consolidated Balance Sheets, of the total cash, cash equivalents, and restricted cash presented on the Statement of Cash Flows are as follows (in thousands): Nine Months Ended Nine Months Ended Balance at Balance at October 1, 2023 Balance at Balance at October 1, 2022 Cash and Temporary Cash Investments $ 81,414 $ 55,447 $ 53,415 $ 46,048 Hedging Collateral Deposits — — — 91,670 Cash, Cash Equivalents, and Restricted Cash $ 81,414 $ 55,447 $ 53,415 $ 137,718
Schedule of Allowance for Uncollectible Accounts	Activity in the allowance for uncollectible accounts for the nine months ended June 30, 2024 and 2023 are as follows (in thousands): Balance at Beginning of Period Additions Charged to Costs and Expenses Discounts on Purchased Receivables Net Accounts Receivable Written-Off Balance at End of Period Nine Months Ended June 30, 2024 Allowance for Uncollectible Accounts $ 36,295 $ 11,774 $ 698 $ (16,145) $ 32,622 Nine Months Ended June 30, 2023 Allowance for Uncollectible Accounts $ 40,228 $ 13,142 $ 1,316 $ (11,578) $ 43,108
Components of Accumulated Other Comprehensive Income (Loss)	The components of Accumulated Other Comprehensive Income (Loss) and changes for the nine months ended June 30, 2024 and 2023, net of related tax effect, are as follows (amounts in parentheses indicate debits) (in thousands): Gains and Losses on Derivative Financial Instruments Funded Status of the Pension and Other Post-Retirement Benefit Plans Total Three Months Ended June 30, 2024 Balance at April 1, 2024 $ 135,023 $ (59,683) $ 75,340 Other Comprehensive Gains and Losses Before Reclassifications (15,850) — (15,850) Amounts Reclassified From Other Comprehensive Loss (54,440) — (54,440) Balance at June 30, 2024 $ 64,733 $ (59,683) $ 5,050 Nine Months Ended June 30, 2024 Balance at October 1, 2023 $ 4,623 $ (59,683) $ (55,060) Other Comprehensive Gains and Losses Before Reclassifications 172,249 — 172,249 Amounts Reclassified From Other Comprehensive Income (112,139) — (112,139) Balance at June 30, 2024 $ 64,733 $ (59,683) $ 5,050 Three Months Ended June 30, 2023 Balance at April 1, 2023 $ (1,294) $ (53,570) $ (54,864) Other Comprehensive Gains and Losses Before Reclassifications 47,359 — 47,359 Amounts Reclassified From Other Comprehensive Income (41,879) — (41,879) Balance at June 30, 2023 $ 4,186 $ (53,570) $ (49,384) Nine Months Ended June 30, 2023 Balance at October 1, 2022 $ (572,163) $ (53,570) $ (625,733) Other Comprehensive Gains and Losses Before Reclassifications 488,726 — 488,726 Amounts Reclassified From Other Comprehensive Income 87,623 — 87,623 Balance at June 30, 2023 $ 4,186 $ (53,570) $ (49,384)
Schedule of Reclassifications Out of Accumulated Other Comprehensive Income (Loss)	The details about the reclassification adjustments out of accumulated other comprehensive income (loss) for the nine months ended June 30, 2024 and 2023 are as follows (amounts in parentheses indicate debits to the income statement) (in thousands): Details About Accumulated Other Comprehensive Income (Loss) Components Amount of Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) Affected Line Item in the Statement Where Net Income is Presented Three Months Ended Nine Months Ended 2024 2023 2024 2023 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $75,462 $57,842 $155,401 ($120,088) Operating Revenues Foreign Currency Contracts (116) (150) (198) (502) Operating Revenues 75,346 57,692 155,203 (120,590) Total Before Income Tax (20,906) (15,813) (43,064) 32,967 Income Tax Expense $54,440 $41,879 $112,139 ($87,623) Net of Tax
Schedule of Other Current Assets	The components of the Company’s Other Current Assets are as follows (in thousands): At June 30, 2024 At September 30, 2023 Prepayments $ 23,972 $ 18,966 Prepaid Property and Other Taxes 11,462 14,186 Federal Income Taxes Receivable — 14,602 State Income Taxes Receivable 12,298 16,133 Regulatory Assets 35,191 36,373 $ 82,923 $ 100,260
Schedule of Other Accruals and Current Liabilities	The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At June 30, 2024 At September 30, 2023 Accrued Capital Expenditures $ 52,620 $ 43,323 Regulatory Liabilities 27,538 38,105 Reserve for Gas Replacement 6,657 — Liability for Royalty and Working Interests 17,670 17,679 Federal Income Taxes Payable 1,027 — Non-Qualified Benefit Plan Liability 13,052 13,052 Other 50,569 48,815 $ 169,133 $ 160,974

Asset Acquisitions (Table)

Asset Acquisitions (Table)	9 Months Ended
	Jun. 30, 2024
Asset Acquisition [Abstract]
Summary of Asset Acquisition	The following is a summary of the asset acquisition in thousands: Purchase Price $ 124,178 Transaction Costs 580 Total Consideration $ 124,758

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	9 Months Ended
	Jun. 30, 2024
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following tables provide a disaggregation of the Company's revenues for the quarter and nine months ended June 30, 2024 and 2023, presented by type of service from each reportable segment. Quarter Ended June 30, 2024 (Thousands) Revenues By Type of Service Exploration and Production Pipeline and Storage Gathering Utility All Other Corporate and Intersegment Eliminations Total Consolidated Production of Natural Gas $ 144,374 $ — $ — $ — $ — $ — $ 144,374 Production of Crude Oil 511 — — — — — 511 Natural Gas Processing 195 — — — — — 195 Natural Gas Gathering Service — — 60,120 — — (56,476) 3,644 Natural Gas Transportation Service — 79,640 — 21,690 — (26,826) 74,504 Natural Gas Storage Service — 24,612 — — — (10,436) 14,176 Natural Gas Residential Sales — — — 89,034 — — 89,034 Natural Gas Commercial Sales — — — 11,022 — — 11,022 Natural Gas Industrial Sales — — — 480 — (1) 479 Other 363 1,167 — (618) — (207) 705 Total Revenues from Contracts with Customers 145,443 105,419 60,120 121,608 — (93,946) 338,644 Alternative Revenue Programs — — — 3,336 — — 3,336 Derivative Financial Instruments 75,462 — — — — — 75,462 Total Revenues $ 220,905 $ 105,419 $ 60,120 $ 124,944 $ — $ (93,946) $ 417,442 Nine Months Ended June 30, 2024 (Thousands) Revenues By Type of Service Exploration and Production Pipeline and Storage Gathering Utility All Other Corporate and Intersegment Eliminations Total Consolidated Production of Natural Gas $ 580,233 $ — $ — $ — $ — $ — $ 580,233 Production of Crude Oil 1,722 — — — — — 1,722 Natural Gas Processing 765 — — — — — 765 Natural Gas Gathering Service — — 186,701 — — (174,544) 12,157 Natural Gas Transportation Service — 232,532 — 88,817 — (73,040) 248,309 Natural Gas Storage Service — 71,247 — — — (30,520) 40,727 Natural Gas Residential Sales — — — 445,971 — — 445,971 Natural Gas Commercial Sales — — — 62,117 — — 62,117 Natural Gas Industrial Sales — — — 2,668 — (5) 2,663 Other 1,416 4,073 — (2,066) — (695) 2,728 Total Revenues from Contracts with Customers 584,136 307,852 186,701 597,507 — (278,804) 1,397,392 Alternative Revenue Programs — — — 19,949 — — 19,949 Derivative Financial Instruments 155,401 — — — — — 155,401 Total Revenues $ 739,537 $ 307,852 $ 186,701 $ 617,456 $ — $ (278,804) $ 1,572,742 Quarter Ended June 30, 2023 (Thousands) Revenues By Type of Service Exploration and Production Pipeline and Storage Gathering Utility All Other Corporate and Intersegment Eliminations Total Consolidated Production of Natural Gas $ 157,682 $ — $ — $ — $ — $ — $ 157,682 Production of Crude Oil 483 — — — — — 483 Natural Gas Processing 284 — — — — — 284 Natural Gas Gathering Service — — 58,906 — — (54,277) 4,629 Natural Gas Transportation Service — 70,424 — 19,905 — (20,311) 70,018 Natural Gas Storage Service — 21,147 — — — (9,006) 12,141 Natural Gas Residential Sales — — — 108,398 — — 108,398 Natural Gas Commercial Sales — — — 13,971 — — 13,971 Natural Gas Industrial Sales — — — 866 — (2) 864 Other 290 824 — 406 — (199) 1,321 Total Revenues from Contracts with Customers 158,739 92,395 58,906 143,546 — (83,795) 369,791 Alternative Revenue Programs — — — 1,071 — — 1,071 Derivative Financial Instruments 57,842 — — — — — 57,842 Total Revenues $ 216,581 $ 92,395 $ 58,906 $ 144,617 $ — $ (83,795) $ 428,704 Nine Months Ended June 30, 2023 (Thousands) Revenues By Type of Service Exploration and Production Pipeline and Storage Gathering Utility All Other Corporate and Intersegment Eliminations Total Consolidated Production of Natural Gas $ 849,811 $ — $ — $ — $ — $ — $ 849,811 Production of Crude Oil 1,637 — — — — — 1,637 Natural Gas Processing 867 — — — — — 867 Natural Gas Gathering Service — — 172,300 — — (163,297) 9,003 Natural Gas Transportation Service — 220,420 — 84,079 — (62,880) 241,619 Natural Gas Storage Service — 63,903 — — — (27,221) 36,682 Natural Gas Residential Sales — — — 671,352 — — 671,352 Natural Gas Commercial Sales — — — 97,432 — — 97,432 Natural Gas Industrial Sales — — — 5,273 — (6) 5,267 Other 5,880 831 — (1,717) — (747) 4,247 Total Revenues from Contracts with Customers 858,195 285,154 172,300 856,419 — (254,151) 1,917,917 Alternative Revenue Programs — — — 6,995 — — 6,995 Derivative Financial Instruments (120,088) — — — — — (120,088) Total Revenues $ 738,107 $ 285,154 $ 172,300 $ 863,414 $ — $ (254,151) $ 1,804,824

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Jun. 30, 2024
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following table sets forth, by level within the fair value hierarchy, the Company's financial assets and liabilities (as applicable) that were accounted for at fair value on a recurring basis as of June 30, 2024 and September 30, 2023. Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Recurring Fair Value Measures At fair value as of June 30, 2024 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 72,625 $ — $ — $ — $ 72,625 Derivative Financial Instruments: Over the Counter Swaps – Gas — 85,623 — (17,654) 67,969 Over the Counter No Cost Collars – Gas — 33,876 — (3,060) 30,816 Contingent Consideration for Asset Sale — 2,429 — — 2,429 Foreign Currency Contracts — 185 — (1,082) (897) Other Investments: Balanced Equity Mutual Fund 18,464 — — — 18,464 Fixed Income Mutual Fund 16,745 — — — 16,745 Total $ 107,834 $ 122,113 $ — $ (21,796) $ 208,151 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 21,018 $ — $ (17,654) $ 3,364 Over the Counter No Cost Collars – Gas — 2,190 — (3,060) (870) Foreign Currency Contracts — 1,082 — (1,082) — Total $ — $ 24,290 $ — $ (21,796) $ 2,494 Total Net Assets/(Liabilities) $ 107,834 $ 97,823 $ — $ — $ 205,657 Recurring Fair Value Measures At fair value as of September 30, 2023 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 39,332 $ — $ — $ — $ 39,332 Derivative Financial Instruments: Over the Counter Swaps – Gas — 65,800 — (37,508) 28,292 Over the Counter No Cost Collars – Gas — 30,966 — (14,745) 16,221 Contingent Consideration for Asset Sale — 7,277 — — 7,277 Foreign Currency Contracts — 150 — (1,453) (1,303) Other Investments: Balanced Equity Mutual Fund 15,837 — — — 15,837 Fixed Income Mutual Fund 15,897 — — — 15,897 Total $ 71,066 $ 104,193 $ — $ (53,706) $ 121,553 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 68,311 $ — $ (37,508) $ 30,803 Over the Counter No Cost Collars – Gas — 14,950 — (14,745) 205 Foreign Currency Contracts — 1,454 — (1,453) 1 Total $ — $ 84,715 $ — $ (53,706) $ 31,009 Total Net Assets/(Liabilities) $ 71,066 $ 19,478 $ — $ — $ 90,544 (1) Netting Adjustments represent the impact of legally-enforceable master netting arrangements that allow the Company to net gain and loss positions held with the same counterparties. The net asset or net liability for each counterparty is recorded as an asset or liability on the Company’s balance sheet.

Financial Instruments (Tables)

Financial Instruments (Tables)	9 Months Ended
	Jun. 30, 2024
Financial Instruments, Owned, at Fair Value, by Type, Alternative [Abstract]
Long-Term Debt	Based on these criteria, the fair market value of long-term debt, including current portion, was as follows (in thousands): June 30, 2024 September 30, 2023 Carrying Fair Value Carrying Fair Value Long-Term Debt $ 2,687,115 $ 2,598,784 $ 2,384,485 $ 2,210,478
Schedule Of Other Investments	The components of the Company's Other Investments are as follows (in thousands): At June 30, 2024 At September 30, 2023 Life Insurance Contracts $ 44,338 $ 42,242 Equity Mutual Fund 18,464 15,837 Fixed Income Mutual Fund 16,745 15,897 $ 79,547 $ 73,976
Schedule of Derivative Financial Instruments Designated And Qualifying As Cash Flow Hedges On The Statement Of Financial Performance	The Effect of Derivative Financial Instruments on the Statement of Financial Performance for the Three Months Ended June 30, 2024 and 2023 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on Location of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income for the 2024 2023 2024 2023 Commodity Contracts $ (21,682) $ 64,653 Operating Revenue $ 75,462 $ 57,842 Foreign Currency Contracts (254) 591 Operating Revenue (116) (150) Total $ (21,936) $ 65,244 $ 75,346 $ 57,692 The Effect of Derivative Financial Instruments on the Statement of Financial Performance for the Nine Months Ended June 30, 2024 and 2023 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or Location of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income Amount of Derivative Gain or 2024 2023 2024 2023 Commodity Contracts $ 238,184 $ 672,396 Operating Revenue $ 155,401 $ (120,088) Foreign Currency Contracts 211 985 Operating Revenue (198) (502) Total $ 238,395 $ 673,381 $ 155,203 $ (120,590)

Capitalization (Tables)

Capitalization (Tables)	9 Months Ended
	Jun. 30, 2024
Capitalization, Long-Term Debt and Equity [Abstract]
Summary of Changes in Common Stock Equity	Summary of Changes in Common Stock Equity Common Stock Paid In Earnings Accumulated Shares Amount (Thousands, except per share amounts) Balance at April 1, 2024 92,032 $ 92,032 $ 1,045,929 $ 2,090,172 $ 75,340 Net Loss Available for Common Stock (54,158) Dividends Declared on Common Stock ($0.515 Per Share) (47,195) Other Comprehensive Loss, Net of Tax (70,290) Share-Based Payment Expense (1) 4,905 Common Stock Issued Under Stock and Benefit Plans 11 11 587 Share Repurchases Under Repurchase Plan (431) (431) (4,942) (18,435) Balance at June 30, 2024 91,612 $ 91,612 $ 1,046,479 $ 1,970,384 $ 5,050 Balance at October 1, 2023 91,819 $ 91,819 $ 1,040,761 $ 1,885,856 $ (55,060) Net Income Available for Common Stock 245,134 Dividends Declared on Common Stock ($1.505 Per Share) (138,354) Other Comprehensive Income, Net of Tax 60,110 Share-Based Payment Expense (1) 14,262 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 320 320 (2,514) Share Repurchases Under Repurchase Plan (527) (527) (6,030) (22,252) Balance at June 30, 2024 91,612 $ 91,612 $ 1,046,479 $ 1,970,384 $ 5,050 Balance at April 1, 2023 91,795 $ 91,795 $ 1,031,341 $ 1,810,454 $ (54,864) Net Income Available for Common Stock 92,620 Dividends Declared on Common Stock ($0.495 Per Share) (45,444) Other Comprehensive Income, Net of Tax 5,480 Share-Based Payment Expense (1) 4,009 Common Stock Issued Under Stock and Benefit Plans 9 9 502 Balance at June 30, 2023 91,804 $ 91,804 $ 1,035,852 $ 1,857,630 $ (49,384) Balance at October 1, 2022 91,478 $ 91,478 $ 1,027,066 $ 1,587,085 $ (625,733) Net Income Available for Common Stock 403,189 Dividends Declared on Common Stock ($1.445 Per Share) (132,644) Other Comprehensive Income, Net of Tax 576,349 Share-Based Payment Expense (1) 14,327 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 326 326 (5,541) Balance at June 30, 2023 91,804 $ 91,804 $ 1,035,852 $ 1,857,630 $ (49,384) (1) Paid in Capital includes compensation costs associated with performance shares and/or restricted stock awards. The expense is included within Net Income Available For Common Stock, net of tax benefits.

Business Segment Information (T

Business Segment Information (Tables)	9 Months Ended
	Jun. 30, 2024
Segment Reporting [Abstract]
Financial Segment Information By Segment	Quarter Ended June 30, 2024 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $220,905 $68,035 $3,644 $124,858 $417,442 $— $— $417,442 Intersegment Revenues $— $37,384 $56,476 $86 $93,946 $— $(93,946) $— Segment Profit: Net Income (Loss) $(112,028) $30,690 $24,979 $2,559 $(53,800) $(124) $(234) $(54,158) Nine Months Ended June 30, 2024 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $739,537 $204,071 $12,157 $616,977 $1,572,742 $— $— $1,572,742 Intersegment Revenues $— $103,781 $174,544 $479 $278,804 $— $(278,804) $— Segment Profit: Net Income (Loss) $2,521 $85,482 $82,510 $73,848 $244,361 $(341) $1,114 $245,134 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Segment Assets: At June 30, 2024 $2,815,598 $2,486,740 $998,176 $2,329,894 $8,630,408 $5,067 $(154,438) $8,481,037 At September 30, 2023 $2,814,218 $2,427,214 $912,923 $2,247,743 $8,402,098 $4,795 $(126,633) $8,280,260 Quarter Ended June 30, 2023 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $216,581 $62,956 $4,629 $144,538 $428,704 $— $— $428,704 Intersegment Revenues $— $29,439 $54,277 $79 $83,795 $— $(83,795) $— Segment Profit: Net Income (Loss) $43,329 $23,813 $24,135 $37 $91,314 $(81) $1,387 $92,620 Nine Months Ended June 30, 2023 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $738,107 $194,800 $9,003 $862,914 $1,804,824 $— $— $1,804,824 Intersegment Revenues $— $90,354 $163,297 $500 $254,151 $— $(254,151) $— Segment Profit: Net Income (Loss) $195,503 $77,147 $73,207 $55,574 $401,431 $(430) $2,188 $403,189

Retirement Plan And Other Pos_2

Retirement Plan And Other Post-Retirement Benefits (Tables)	9 Months Ended
	Jun. 30, 2024
Retirement Benefits [Abstract]
Components of Net Periodic Benefit Cost (Income)	Components of Net Periodic Benefit Cost (in thousands): Retirement Plan Other Post-Retirement Benefits Three Months Ended June 30, 2024 2023 2024 2023 Service Cost $ 1,049 $ 1,297 $ 109 $ 147 Interest Cost 10,890 10,629 3,890 3,912 Expected Return on Plan Assets (17,086) (16,648) (6,660) (6,403) Amortization of Prior Service Cost (Credit) 91 109 (107) (107) Amortization of (Gains) Losses (335) (1,920) (567) (2,189) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 4,057 5,378 2,248 3,829 Net Periodic Benefit Cost (Income) $ (1,334) $ (1,155) $ (1,087) $ (811) Retirement Plan Other Post-Retirement Benefits Nine Months Ended June 30, 2024 2023 2024 2023 Service Cost $ 3,148 $ 3,891 $ 326 $ 440 Interest Cost 32,668 31,887 11,671 11,736 Expected Return on Plan Assets (51,257) (49,945) (19,981) (19,210) Amortization of Prior Service Cost (Credit) 271 327 (322) (321) Amortization of (Gains) Losses (1,004) (5,760) (1,700) (6,566) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 12,173 16,134 6,256 11,143 Net Periodic Benefit Cost (Income) $ (4,001) $ (3,466) $ (3,750) $ (2,778) (1) The Company’s policy is to record retirement plan and other post-retirement benefit costs in the Utility segment on a volumetric basis to reflect the fact that the Utility segment experiences higher throughput of natural gas in the winter months and lower throughput of natural gas in the summer months.

Summary Of Significant Accoun_4

Summary Of Significant Accounting Policies (Consolidated Statements Of Cash Flows) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Sep. 30, 2023	Jun. 30, 2023	Sep. 30, 2022
Accounting Policies [Abstract]
Cash and Temporary Cash Investments	$ 81,414	$ 55,447	$ 53,415	$ 46,048
Hedging Collateral Deposits	0	0	0	91,670
Cash, Cash Equivalents, and Restricted Cash	$ 81,414	$ 55,447	$ 53,415	$ 137,718

Summary Of Significant Accoun_5

Summary Of Significant Accounting Policies (Allowance for Uncollectible Accounts) (Details) - USD ($) $ in Thousands	9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023
Allowance for Uncollectible Accounts [Roll Forward]
Balance at Beginning of Period	$ 36,295	$ 40,228
Additions Charged to Costs and Expenses	11,774	13,142
Discounts on Purchased Receivables	698	1,316
Net Accounts Receivable Written-Off	(16,145)	(11,578)
Balance at End of Period	$ 32,622	$ 43,108

Summary Of Significant Accoun_6

Summary Of Significant Accounting Policies (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Sep. 30, 2023	Sep. 30, 2024
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground	$ 14,186		$ 14,186		$ 32,509
Capitalized Costs Exploration and Production Activities Net	$ 2,600,000		2,600,000		2,400,000
Capitalized costs of unproved properties excluded from amortization			$ 202,200		$ 161,100
Full cost ceiling test discount factor (as a percent)	10%		10%
Impairment of Exploration and Production Properties	$ 200,696	$ 0	$ 200,696	$ 0
Increase estimated future net cash flows	$ 375,800
Antidilutive securities (in shares)	567,681	8,322	335	4,526
Number of shares available for future grant (in shares)	3,890,301		3,890,301
Impairment of Exploration and Production Properties
Summary Of Significant Accounting Policies [Line Items]
Deferred income tax benefit	$ 55,700
Reserve For Gas Replacement
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground	$ 6,700		$ 6,700
Restricted Stock Units
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period (in shares)			220,778
Granted in fiscal year, weighted average grant date fair value (in USD per share)			$ 42.44
Performance Shares
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period (in shares)			361,729
Granted in fiscal year, weighted average grant date fair value (in USD per share)			$ 44.23
Greenhouse gas emissions reductions, performance cycle			3 years
Performance Shares | Minimum
Summary Of Significant Accounting Policies [Line Items]
Return on capital, performance cycle (in years)			3 years
Relative shareholder return, performance cycle			3 years
Performance Shares | Maximum
Summary Of Significant Accounting Policies [Line Items]
Return on capital, performance cycle (in years)			5 years
Relative shareholder return, performance cycle			5 years
Subsequent Event | Reserve For Gas Replacement | Forecast
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground						$ 0

Summary Of Significant Accoun_7

Summary Of Significant Accounting Policies (Components Of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	$ 75,340	$ (54,864)	$ (55,060)	$ (625,733)
Other Comprehensive Gains and Losses Before Reclassifications	(15,850)	47,359	172,249	488,726
Amounts Reclassified From Other Comprehensive Income (Loss)	(54,440)	(41,879)	(112,139)	87,623
Ending balance	5,050	(49,384)	5,050	(49,384)
Gains and Losses on Derivative Financial Instruments
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	135,023	(1,294)	4,623	(572,163)
Other Comprehensive Gains and Losses Before Reclassifications	(15,850)	47,359	172,249	488,726
Amounts Reclassified From Other Comprehensive Income (Loss)	(54,440)	(41,879)	(112,139)	87,623
Ending balance	64,733	4,186	64,733	4,186
Funded Status of the Pension and Other Post-Retirement Benefit Plans
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(59,683)	(53,570)	(59,683)	(53,570)
Other Comprehensive Gains and Losses Before Reclassifications	0	0	0	0
Amounts Reclassified From Other Comprehensive Income (Loss)	0	0	0	0
Ending balance	$ (59,683)	$ (53,570)	$ (59,683)	$ (53,570)

Summary Of Significant Accoun_8

Summary Of Significant Accounting Policies (Reclassification Out Of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Reclassification Adjustments out of Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating Revenues	$ 417,442	$ 428,704	$ 1,572,742	$ 1,804,824
Total Before Income Tax	(82,469)	125,555	315,242	543,614
Income Tax Expense	28,311	(32,935)	(70,108)	(140,425)
Net Income Available for Common Stock	(54,158)	92,620	245,134	403,189
Amount of Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustments out of Accumulated Other Comprehensive Income (Loss) [Line Items]
Total Before Income Tax	75,346	57,692	155,203	(120,590)
Income Tax Expense	(20,906)	(15,813)	(43,064)	32,967
Net Income Available for Common Stock	54,440	41,879	112,139	(87,623)
Amount of Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) | Commodity Contracts | Gains and Losses on Derivative Financial Instruments
Reclassification Adjustments out of Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating Revenues	75,462	57,842	155,401	(120,088)
Amount of Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) | Foreign Currency Contracts | Gains and Losses on Derivative Financial Instruments
Reclassification Adjustments out of Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating Revenues	$ (116)	$ (150)	$ (198)	$ (502)

Summary Of Significant Accoun_9

Summary Of Significant Accounting Policies (Components Of Other Current Assets) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Sep. 30, 2023
Summary Of Significant Accounting Policies [Line Items]
Prepayments	$ 23,972	$ 18,966
Prepaid Property and Other Taxes	11,462	14,186
Regulatory Assets	35,191	36,373
Other Current Assets	82,923	100,260
Federal
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	0	14,602
State
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	$ 12,298	$ 16,133

Summary Of Significant Accou_10

Summary Of Significant Accounting Policies (Schedule Of Other Accruals And Current Liabilities) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Sep. 30, 2023
Summary Of Significant Accounting Policies [Line Items]
Accrued Capital Expenditures	$ 52,620	$ 43,323
Regulatory Liabilities	27,538	38,105
Reserve for Gas Replacement	6,657	0
Liability for Royalty and Working Interests	17,670	17,679
Non-Qualified Benefit Plan Liability	13,052	13,052
Other	50,569	48,815
Other Accruals and Current Liabilities	169,133	160,974
Federal
Summary Of Significant Accounting Policies [Line Items]
Federal Income Taxes Payable	$ 1,027	$ 0

Asset Acquisitions (Narrative)

Asset Acquisitions (Narrative) (Details) - SWN Upstream Asset Acquisition $ in Thousands	Jun. 01, 2023 USD ($) a
Asset Acquisitions and Divestitures [Line Items]
Total Consideration | $	$ 124,758
Net Acres Acquired in Appalachia | a	34,000

Asset Acquisitions (Summary of

Asset Acquisitions (Summary of Asset Acquisition) (Details) - SWN Upstream Asset Acquisition $ in Thousands	Jun. 01, 2023 USD ($)
Asset Acquisitions and Divestitures [Line Items]
Purchase Price	$ 124,178
Transaction Costs	580
Total Consideration	$ 124,758

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	$ 338,644	$ 369,791	$ 1,397,392	$ 1,917,917
Alternative Revenue Programs	3,336	1,071	19,949	6,995
Derivative Financial Instruments	75,462	57,842	155,401	(120,088)
Total Revenues	417,442	428,704	1,572,742	1,804,824
All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Alternative Revenue Programs	0	0	0	0
Derivative Financial Instruments	0	0	0	0
Total Revenues	0	0	0	0
Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(93,946)	(83,795)	(278,804)	(254,151)
Alternative Revenue Programs	0	0	0	0
Derivative Financial Instruments	0	0	0	0
Total Revenues	(93,946)	(83,795)	(278,804)	(254,151)
Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	145,443	158,739	584,136	858,195
Alternative Revenue Programs	0	0	0	0
Derivative Financial Instruments	75,462	57,842	155,401	(120,088)
Total Revenues	220,905	216,581	739,537	738,107
Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	105,419	92,395	307,852	285,154
Alternative Revenue Programs	0	0	0	0
Derivative Financial Instruments	0	0	0	0
Total Revenues	105,419	92,395	307,852	285,154
Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	60,120	58,906	186,701	172,300
Alternative Revenue Programs	0	0	0	0
Derivative Financial Instruments	0	0	0	0
Total Revenues	60,120	58,906	186,701	172,300
Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	121,608	143,546	597,507	856,419
Alternative Revenue Programs	3,336	1,071	19,949	6,995
Derivative Financial Instruments	0	0	0	0
Total Revenues	124,944	144,617	617,456	863,414
Production of Natural Gas
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	144,374	157,682	580,233	849,811
Production of Natural Gas | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Production of Natural Gas | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Production of Natural Gas | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	144,374	157,682	580,233	849,811
Production of Natural Gas | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Production of Natural Gas | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Production of Natural Gas | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Production of Crude Oil
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	511	483	1,722	1,637
Production of Crude Oil | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Production of Crude Oil | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Production of Crude Oil | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	511	483	1,722	1,637
Production of Crude Oil | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Production of Crude Oil | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Production of Crude Oil | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Processing
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	195	284	765	867
Natural Gas Processing | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Processing | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Processing | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	195	284	765	867
Natural Gas Processing | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Processing | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Processing | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Gathering Service
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	3,644	4,629	12,157	9,003
Natural Gas Gathering Service | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Gathering Service | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(56,476)	(54,277)	(174,544)	(163,297)
Natural Gas Gathering Service | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Gathering Service | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Gathering Service | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	60,120	58,906	186,701	172,300
Natural Gas Gathering Service | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Transportation Service
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	74,504	70,018	248,309	241,619
Natural Gas Transportation Service | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Transportation Service | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(26,826)	(20,311)	(73,040)	(62,880)
Natural Gas Transportation Service | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Transportation Service | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	79,640	70,424	232,532	220,420
Natural Gas Transportation Service | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Transportation Service | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	21,690	19,905	88,817	84,079
Natural Gas Storage Service
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	14,176	12,141	40,727	36,682
Natural Gas Storage Service | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Storage Service | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(10,436)	(9,006)	(30,520)	(27,221)
Natural Gas Storage Service | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Storage Service | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	24,612	21,147	71,247	63,903
Natural Gas Storage Service | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Storage Service | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	89,034	108,398	445,971	671,352
Natural Gas Residential Sales | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	89,034	108,398	445,971	671,352
Natural Gas Commercial Sales
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	11,022	13,971	62,117	97,432
Natural Gas Commercial Sales | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	11,022	13,971	62,117	97,432
Natural Gas Industrial Sales
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	479	864	2,663	5,267
Natural Gas Industrial Sales | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Industrial Sales | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(1)	(2)	(5)	(6)
Natural Gas Industrial Sales | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Industrial Sales | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Industrial Sales | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Natural Gas Industrial Sales | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	480	866	2,668	5,273
Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	705	1,321	2,728	4,247
Other | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Other | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(207)	(199)	(695)	(747)
Other | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	363	290	1,416	5,880
Other | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,167	824	4,073	831
Other | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0	0
Other | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	$ (618)	$ 406	$ (2,066)	$ (1,717)

Revenue from Contracts with C_4

Revenue from Contracts with Customers (Narrative) (Details) $ in Millions	Jun. 30, 2024 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 58.9
Remaining performance obligation, period	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 224.8
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 174.5
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 136.4
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 117.2
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 612
Remaining performance obligation, period

Fair Value Measurements (Recurr

Fair Value Measurements (Recurring Fair Value Measures Of Assets And Liabilities) (Details) - USD ($) $ in Thousands		Jun. 30, 2024		Sep. 30, 2023
Assets:
Cash Equivalents – Money Market Mutual Funds	[1]	$ 72,625		$ 39,332
Derivative Financial Instruments:
Derivative Asset, Statement of Financial Position [Extensible Enumeration]		Fair Value of Derivative Financial Instruments		Fair Value of Derivative Financial Instruments
Total Assets	[1]	$ 208,151		$ 121,553
Derivative Financial Instruments:
Derivative Liability, Statement of Financial Position [Extensible Enumeration]		Fair Value of Derivative Financial Instruments		Fair Value of Derivative Financial Instruments
Total Liabilities	[1]	$ 2,494		$ 31,009
Total Net Assets/(Liabilities)	[1]	205,657		90,544
Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset	[1]	67,969		28,292
Derivative Financial Instruments:
Derivative Liability	[1]	3,364		30,803
Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		30,816	[1]	16,221
Derivative Financial Instruments:
Derivative Liability	[1]			205
Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset	[1]	2,429		7,277
Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset	[1]	(897)		(1,303)
Derivative Financial Instruments:
Derivative Liability	[1]	0		1
Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	18,464		15,837
Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	16,745		15,897
Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Liability	[1]	(870)
Level 1
Assets:
Cash Equivalents – Money Market Mutual Funds		72,625		39,332
Derivative Financial Instruments:
Total Assets		107,834		71,066
Derivative Financial Instruments:
Total Liabilities		0		0
Total Net Assets/(Liabilities)		107,834		71,066
Level 1 | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability		0		0
Level 1 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability				0
Level 1 | Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset		0		0
Level 1 | Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability		0		0
Level 1 | Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments		18,464		15,837
Level 1 | Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments		16,745		15,897
Level 1 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Liability		0
Level 2
Assets:
Cash Equivalents – Money Market Mutual Funds		0		0
Derivative Financial Instruments:
Total Assets		122,113		104,193
Derivative Financial Instruments:
Total Liabilities		24,290		84,715
Total Net Assets/(Liabilities)		97,823		19,478
Level 2 | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset		85,623		65,800
Derivative Financial Instruments:
Derivative Liability		21,018		68,311
Level 2 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		33,876		30,966
Derivative Financial Instruments:
Derivative Liability				14,950
Level 2 | Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset		2,429		7,277
Level 2 | Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset		185		150
Derivative Financial Instruments:
Derivative Liability		1,082		1,454
Level 2 | Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments		0		0
Level 2 | Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments		0		0
Level 2 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Liability		2,190
Level 3
Assets:
Cash Equivalents – Money Market Mutual Funds		0		0
Derivative Financial Instruments:
Total Assets		0		0
Derivative Financial Instruments:
Total Liabilities		0		0
Total Net Assets/(Liabilities)		0		0
Level 3 | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability		0		0
Level 3 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability				0
Level 3 | Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset		0		0
Level 3 | Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability		0		0
Level 3 | Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments		0		0
Level 3 | Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments		0		0
Level 3 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Liability		0
Netting Adjustments
Assets:
Cash Equivalents – Money Market Mutual Funds	[1]	0		0
Derivative Financial Instruments:
Total Assets	[1]	(21,796)		(53,706)
Derivative Financial Instruments:
Total Liabilities	[1]	(21,796)		(53,706)
Total Net Assets/(Liabilities)	[1]	0		0
Netting Adjustments | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset	[1]	(17,654)		(37,508)
Derivative Financial Instruments:
Derivative Liability	[1]	(17,654)		(37,508)
Netting Adjustments | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		(3,060)	[1]	(14,745)
Derivative Financial Instruments:
Derivative Liability	[1]			(14,745)
Netting Adjustments | Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset	[1]	0		0
Netting Adjustments | Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset	[1]	(1,082)		(1,453)
Derivative Financial Instruments:
Derivative Liability	[1]	(1,082)		(1,453)
Netting Adjustments | Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	0		0
Netting Adjustments | Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	0		$ 0
Netting Adjustments | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Liability	[1]	$ (3,060)
[1] Netting Adjustments represent the impact of legally-enforceable master netting arrangements that allow the Company to net gain and loss positions held with the same counterparties. The net asset or net liability for each counterparty is recorded as an asset or liability on the Company’s balance sheet.

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details)	12 Months Ended	36 Months Ended
	Dec. 31, 2023 USD ($)	Dec. 31, 2025 USD ($) payment	Jun. 30, 2024 USD ($)	Sep. 30, 2023 USD ($)	Jun. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hedging Collateral Deposits			$ 0	$ 0	$ 0	$ 91,670,000
California Asset Sale | Forecast
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Maximum Annual Contingent Payment		$ 10,000,000
Amount of Each Incremental Contingency Payment		1,000,000
Incremental price, exceeding ICE Brent Average Price (in dollars per barrel)		1
California Asset Sale | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
ICE Brent Average (in dollars per barrel)	$ 95
California Asset Sale | Minimum | Forecast
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
ICE Brent Average (in dollars per barrel)		$ 95
California Asset Sale | Maximum | Forecast
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Number Of Annual Contingent Payments | payment		3
ICE Brent Average (in dollars per barrel)		$ 105
Derivative Financial Instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Level 3 Fair Value			$ 0		$ 0

Financial Instruments (Narrativ

Financial Instruments (Narrative) (Details) Bcf in Billions	3 Months Ended	9 Months Ended	12 Months Ended	36 Months Ended
	Jun. 30, 2024 USD ($) counterparty Bcf	Jun. 30, 2024 USD ($) counterparty Bcf	Dec. 31, 2023 USD ($)	Dec. 31, 2025 USD ($) payment	Sep. 30, 2023 USD ($)	Jun. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Foreign Currency Forward Contract Hedge Duration		7 years
After tax net hedging gains in accumulated other comprehensive income (loss)	$ 64,700,000	$ 64,700,000
After Tax Net Hedging Gains Reclassified Within Twelve Months		43,100,000
Fair market value of derivative liability with a credit-risk related contingency	0	0
Hedging Collateral Deposits	0	0			$ 0	$ 0	$ 91,670,000
California Asset Sale | Forecast
Derivative Instruments, Gain (Loss) [Line Items]
Maximum Annual Contingent Payment				$ 10,000,000
Amount of Each Incremental Contingency Payment				1,000,000
Incremental price, exceeding ICE Brent Average Price (in dollars per barrel)				1
California Asset Sale | Present Value of Contingent Consideration
Derivative Instruments, Gain (Loss) [Line Items]
Value of Contingent Consideration Received from Sale of Assets	2,400,000	2,400,000			$ 7,300,000
California Asset Sale | Mark to Market of Contingent Consideration
Derivative Instruments, Gain (Loss) [Line Items]
Mark-to-Market Adjustment for Contingent Consideration	$ (1,200,000)	$ (4,900,000)
California Asset Sale | Minimum
Derivative Instruments, Gain (Loss) [Line Items]
ICE Brent Average (in dollars per barrel)			$ 95
California Asset Sale | Minimum | Forecast
Derivative Instruments, Gain (Loss) [Line Items]
ICE Brent Average (in dollars per barrel)				$ 95
California Asset Sale | Maximum | Forecast
Derivative Instruments, Gain (Loss) [Line Items]
Number Of Annual Contingent Payments | payment				3
ICE Brent Average (in dollars per barrel)				$ 105
Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Hedge Duration		5 years
Over the Counter Swaps, No Cost Collars and Foreign Currency Forward Contracts
Derivative Instruments, Gain (Loss) [Line Items]
Number of counterparties in which the company holds over-the-counter swap positions | counterparty	19	19
Number of counterparties in net gain position | counterparty	18	18
Credit risk exposure per counterparty	$ 5,400,000	$ 5,400,000
Maximum Credit Risk Exposure Per Counterparty		21,200,000
Collateral Received by the Company	$ 0	$ 0
Number of counterparties with a common credit-risk related contingency | counterparty	16	16
Hedging Collateral Deposits	$ 0	$ 0
Natural Gas Bcf | Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk cash flow hedge derivatives, natural gas | Bcf	334	334
Foreign Currency Contracts
Derivative Instruments, Gain (Loss) [Line Items]
Hedging Notional Amount of Forecasted Transportation Costs	$ 54,400,000	$ 54,400,000

Financial Instruments (Long-Ter

Financial Instruments (Long-Term Debt) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Sep. 30, 2023
Financial Instruments, Owned, at Fair Value, by Type, Alternative [Abstract]
Carrying Amount	$ 2,687,115	$ 2,384,485
Fair Value	$ 2,598,784	$ 2,210,478

Financial Instruments (Other In

Financial Instruments (Other Investments) (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Sep. 30, 2023
Investment Holdings [Line Items]
Life Insurance Contracts	$ 44,338	$ 42,242
Other Investments	79,547	73,976
Equity Mutual Fund
Investment Holdings [Line Items]
Mutual Funds	18,464	15,837
Fixed Income Mutual Fund
Investment Holdings [Line Items]
Mutual Funds	$ 16,745	$ 15,897

Financial Instruments (Schedule

Financial Instruments (Schedule Of Derivative Financial Instruments Designated And Qualifying As Cash Flow Hedges On The Statement Of Financial Performance) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)	$ (21,936)	$ 65,244	$ 238,395	$ 673,381
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	75,346	57,692	155,203	(120,590)
Commodity Contracts | Operating Revenues
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)	(21,682)	64,653	238,184	672,396
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	75,462	57,842	155,401	(120,088)
Foreign Currency Contracts | Operating Revenues
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)	(254)	591	211	985
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	$ (116)	$ (150)	$ (198)	$ (502)

Income Taxes (Details)

Income Taxes (Details)	3 Months Ended		9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Income Tax Disclosure [Abstract]
Effective Tax Rate	34.30%	26.20%	22.20%	25.80%

Capitalization and Short-Term B

Capitalization and Short-Term Borrowings (Summary of Changes in Common Stock Equity) (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended		9 Months Ended
		Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)				91,819,405
Beginning balance				$ 2,963,376
Net Income Available for Common Stock		$ (54,158)	$ 92,620	245,134	$ 403,189
Dividends Declared on Common Stock		(47,195)	(45,444)	(138,354)	(132,644)
Other Comprehensive Income (Loss), Net of Tax		$ (70,290)	$ 5,480	$ 60,110	$ 576,349
Ending balance (in shares)		91,612,488		91,612,488
Ending balance		$ 3,113,525		$ 3,113,525
Dividends per share (in dollars per share)		$ 0.515	$ 0.495	$ 1.505	$ 1.445
Stock and Benefit Plans
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases (in shares)				(77,461)
Share Repurchase Plan
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases (in shares)				(526,652)
Share Repurchases				$ (28,800)
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)		92,032,000	91,795,000	91,819,000	91,478,000
Beginning balance		$ 92,032	$ 91,795	$ 91,819	$ 91,478
Common stock issued under stock and benefit plans (in shares)		11,000	9,000	320,000	326,000
Common Stock Issued Under Stock and Benefit Plans		$ 11	$ 9	$ 320	$ 326
Ending balance (in shares)		91,612,000	91,804,000	91,612,000	91,804,000
Ending balance		$ 91,612	$ 91,804	$ 91,612	$ 91,804
Common Stock | Share Repurchase Plan
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases (in shares)		(431,000)		(527,000)
Share Repurchases		$ (431)		$ (527)
Paid In Capital
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance		1,045,929	1,031,341	1,040,761	1,027,066
Share-Based Payment Expense	[1]	4,905	4,009	14,262	14,327
Common Stock Issued Under Stock and Benefit Plans		587	502
Ending balance		1,046,479	1,035,852	1,046,479	1,035,852
Paid In Capital | Stock and Benefit Plans
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases				(2,514)	(5,541)
Paid In Capital | Share Repurchase Plan
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases		(4,942)		(6,030)
Earnings Reinvested in the Business
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance		2,090,172	1,810,454	1,885,856	1,587,085
Net Income Available for Common Stock		(54,158)	92,620	245,134	403,189
Dividends Declared on Common Stock		(47,195)	(45,444)	(138,354)	(132,644)
Share Repurchases		(18,435)	0	(22,252)	0
Ending balance		1,970,384	1,857,630	1,970,384	1,857,630
Earnings Reinvested in the Business | Share Repurchase Plan
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases		(18,435)		(22,252)
Accumulated Other Comprehensive Income (Loss)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance		75,340	(54,864)	(55,060)	(625,733)
Other Comprehensive Income (Loss), Net of Tax		(70,290)	5,480	60,110	576,349
Ending balance		$ 5,050	$ (49,384)	$ 5,050	$ (49,384)
[1] Paid in Capital includes compensation costs associated with performance shares and/or restricted stock awards. The expense is included within Net Income Available For Common Stock, net of tax benefits.

Capitalization (Narrative) (Det

Capitalization (Narrative) (Details) $ / shares in Units, $ in Thousands		9 Months Ended
	Feb. 28, 2022 USD ($) bank	Jun. 30, 2024 USD ($) $ / shares shares	May 31, 2024 USD ($) bank	Apr. 01, 2024 USD ($)	Mar. 08, 2024 USD ($)	Feb. 29, 2024 bank	Feb. 14, 2024 USD ($) lender	Sep. 30, 2023 USD ($)
Debt Instrument [Line Items]
Stock repurchase program, authorized amount					$ 200,000
Current Portion of Long-Term Debt		$ 50,000						$ 0
Stock and Benefit Plans
Debt Instrument [Line Items]
Share Repurchases (in shares) | shares		77,461
Share Repurchase Plan
Debt Instrument [Line Items]
Share Repurchases (in shares) | shares		526,652
Share repurchase program, average cost per share (in USD per share) | $ / shares		$ 54.28
Share Repurchases		$ 28,800
364-Day Credit Agreement
Debt Instrument [Line Items]
Term	364 days
Credit Agreement
Debt Instrument [Line Items]
Number of banks In syndicate | bank	12		3			11
Maximum borrowing capacity	$ 1,000,000		$ 1,000,000
Term Loan Agreement
Debt Instrument [Line Items]
Maximum borrowing capacity							$ 300,000
Number of lenders | lender							6
Long-term debt, face amount				$ 300,000
Weighted average interest rate (as a percent)		6.705%
Proceeds from debt, net of issuance costs		$ 299,400
7.375% Notes Due June 2025
Debt Instrument [Line Items]
Current Portion of Long-Term Debt		$ 50,000
Long-term debt, interest rate		7.375%
Restricted Stock Units
Debt Instrument [Line Items]
Common stock issued (in shares) | shares		112,667
Performance Shares
Debt Instrument [Line Items]
Common stock issued (in shares) | shares		251,255
Board Of Directors
Debt Instrument [Line Items]
Common stock issued (in shares) | shares		27,310
Officer DCP Plan
Debt Instrument [Line Items]
Common stock issued (in shares) | shares		5,964

Commitments And Contingencies (

Commitments And Contingencies (Details) - USD ($) $ in Thousands	Jun. 30, 2024	Sep. 30, 2023
Other Commitments [Line Items]
Estimated minimum liability for environmental remediation	$ 2,500
Other Regulatory Liabilities	164,390	$ 165,441
Estimated total project costs	500,000
Project costs	55,000
Environmental Site Remediation Costs
Other Commitments [Line Items]
Other Regulatory Liabilities	$ 5,200

Business Segment Information (N

Business Segment Information (Narrative) (Details)	9 Months Ended
	Jun. 30, 2024 segment
Segment Reporting [Abstract]
Number of reportable segments	4

Business Segment Information (F

Business Segment Information (Financial Segment Information By Segment) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023	Sep. 30, 2023
Segment Reporting Information [Line Items]
Revenue from External Customers	$ 417,442	$ 428,704	$ 1,572,742
Intersegment Revenues	0	0	0
Segment Profit: Net Income (Loss)	(54,158)	92,620	245,134	$ 403,189
Segment Assets:	8,481,037		8,481,037		$ 8,280,260
Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers				1,804,824
Corporate and Intersegment Eliminations
Segment Reporting Information [Line Items]
Intersegment Revenues				0
Total Reportable Segments
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)			244,361	401,431
Total Reportable Segments | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	417,442	428,704	1,572,742	1,804,824
Intersegment Revenues	93,946	83,795		254,151
Segment Profit: Net Income (Loss)	(53,800)	91,314
Segment Assets:	8,630,408		8,630,408		8,402,098
Total Reportable Segments | Corporate and Intersegment Eliminations
Segment Reporting Information [Line Items]
Intersegment Revenues			278,804
Exploration and Production
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)			2,521	195,503
Exploration and Production | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	220,905	216,581	739,537	738,107
Intersegment Revenues	0	0		0
Segment Profit: Net Income (Loss)	(112,028)	43,329
Segment Assets:	2,815,598		2,815,598		2,814,218
Exploration and Production | Corporate and Intersegment Eliminations
Segment Reporting Information [Line Items]
Intersegment Revenues			0
Pipeline and Storage
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)			85,482	77,147
Pipeline and Storage | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	68,035	62,956	204,071	194,800
Intersegment Revenues	37,384	29,439		90,354
Segment Profit: Net Income (Loss)	30,690	23,813
Segment Assets:	2,486,740		2,486,740		2,427,214
Pipeline and Storage | Corporate and Intersegment Eliminations
Segment Reporting Information [Line Items]
Intersegment Revenues			103,781
Gathering
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)			82,510	73,207
Gathering | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	3,644	4,629	12,157	9,003
Intersegment Revenues	56,476	54,277		163,297
Segment Profit: Net Income (Loss)	24,979	24,135
Segment Assets:	998,176		998,176		912,923
Gathering | Corporate and Intersegment Eliminations
Segment Reporting Information [Line Items]
Intersegment Revenues			174,544
Utility
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)			73,848	55,574
Utility | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	124,858	144,538	616,977	862,914
Intersegment Revenues	86	79		500
Segment Profit: Net Income (Loss)	2,559	37
Segment Assets:	2,329,894		2,329,894		2,247,743
Utility | Corporate and Intersegment Eliminations
Segment Reporting Information [Line Items]
Intersegment Revenues			479
All Other
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)				(430)
All Other | All Other
Segment Reporting Information [Line Items]
Revenue from External Customers	0	0	0	0
Intersegment Revenues	0	0	0	0
Segment Profit: Net Income (Loss)	(124)	(81)	(341)
Segment Assets:	5,067		5,067		4,795
Corporate and Intersegment Eliminations
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)				2,188
Corporate and Intersegment Eliminations | Corporate
Segment Reporting Information [Line Items]
Revenue from External Customers	0	0	0	0
Corporate and Intersegment Eliminations | Corporate and Intersegment Eliminations
Segment Reporting Information [Line Items]
Intersegment Revenues	(93,946)	(83,795)	(278,804)	$ (254,151)
Segment Profit: Net Income (Loss)	(234)	$ 1,387	1,114
Segment Assets:	$ (154,438)		$ (154,438)		$ (126,633)

Retirement Plan And Other Pos_3

Retirement Plan And Other Post-Retirement Benefits (Components Of Net Periodic Benefit Cost) (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Jun. 30, 2024	Jun. 30, 2023	Jun. 30, 2024	Jun. 30, 2023
Retirement Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost		$ 1,049	$ 1,297	$ 3,148	$ 3,891
Interest Cost		10,890	10,629	32,668	31,887
Expected Return on Plan Assets		(17,086)	(16,648)	(51,257)	(49,945)
Amortization of Prior Service Cost (Credit)		91	109	271	327
Amortization of (Gains) Losses		(335)	(1,920)	(1,004)	(5,760)
Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments)	[1]	4,057	5,378	12,173	16,134
Net Periodic Benefit Cost (Income)		(1,334)	(1,155)	(4,001)	(3,466)
Other Post-Retirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service Cost		109	147	326	440
Interest Cost		3,890	3,912	11,671	11,736
Expected Return on Plan Assets		(6,660)	(6,403)	(19,981)	(19,210)
Amortization of Prior Service Cost (Credit)		(107)	(107)	(322)	(321)
Amortization of (Gains) Losses		(567)	(2,189)	(1,700)	(6,566)
Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments)	[1]	2,248	3,829	6,256	11,143
Net Periodic Benefit Cost (Income)		$ (1,087)	$ (811)	$ (3,750)	$ (2,778)
[1] The Company’s policy is to record retirement plan and other post-retirement benefit costs in the Utility segment on a volumetric basis to reflect the fact that the Utility segment experiences higher throughput of natural gas in the winter months and lower throughput of natural gas in the summer months.

Retirement Plan And Other Pos_4

Retirement Plan And Other Post-Retirement Benefits (Narrative) (Details) $ in Millions	9 Months Ended
	Jun. 30, 2024 USD ($)
Retirement Plan
Defined Benefit Plan Disclosure [Line Items]
Company's contributions	$ 0
Estimated future contributions in remainder of fiscal year	0
VEBA Trusts
Defined Benefit Plan Disclosure [Line Items]
Company's contributions	0
Estimated future contributions in remainder of fiscal year	$ 0

Regulatory Matters (Details)

Regulatory Matters (Details) - USD ($) $ in Millions					86 Months Ended
	Mar. 27, 2024	Oct. 31, 2023	Aug. 01, 2023	Oct. 28, 2022	Jun. 30, 2024	Jul. 31, 2024
Supply Corporation
Regulatory Matters [Line Items]
Estimated Annual Increase to Revenues	$ 56
NEW YORK
Regulatory Matters [Line Items]
Approved Return on Equity (as a percent)					8.70%
Proposed Base Rate Increase		$ 88
PENNSYLVANIA
Regulatory Matters [Line Items]
Proposed Base Rate Increase				$ 28.1
Public Utilities Authorized Rate Increase, Amount			$ 23
Public Utilities, Distribution System Improvement Charge, Plant					$ 763.7
PENNSYLVANIA | Minimum | Subsequent Event
Regulatory Matters [Line Items]
Public Utilities, Distribution System Improvement Charge, Plant						$ 781.3