National Fuel Gas (NFG) 10-Q 30 Jan 25 2025 Q1 Quarterly report Financial data

Document And Entity Information

Document And Entity Information	3 Months Ended
	Dec. 31, 2024 $ / shares shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Dec. 31, 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 | $ / shares	$ 1
Entity Common Stock, Shares Outstanding | shares	90,612,955
Entity Central Index Key	0000070145
Current Fiscal Year End Date	--09-30
Document Fiscal Year Focus	2025
Document Fiscal Period Focus	Q1

Consolidated Statements Of Inco

Consolidated Statements Of Income And Earnings Reinvested In The Business (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
INCOME
Operating Revenues	$ 549,482	$ 525,361
Operating Expenses:
Purchased Gas	65,337	56,552
Property, Franchise and Other Taxes	22,056	22,416
Depreciation, Depletion and Amortization	109,370	115,790
Impairment of Assets	141,802	0
Total Operating Expenses	463,291	318,251
Operating Income	86,191	207,110
Other Income (Expense):
Other Income (Deductions)	7,720	3,732
Interest Expense on Long-Term Debt	(33,362)	(28,462)
Other Interest Expense	(4,381)	(6,273)
Income Before Income Taxes	56,168	176,107
Income Tax Expense	11,182	43,087
Net Income Available for Common Stock	44,986	133,020
EARNINGS REINVESTED IN THE BUSINESS
Balance at Beginning of Period	1,727,326	1,885,856
Beginning Retained Earnings Unappropriated And Current Period Net Income	1,772,312	2,018,876
Dividends on Common Stock	(46,671)	(45,597)
Balance at December 31	$ 1,698,648	$ 1,973,279
Basic:
Net Income Available for Common Stock (in dollars per share)	$ 0.50	$ 1.45
Diluted:
Net Income Available for Common Stock (in dollars per share)	$ 0.49	$ 1.44
Weighted Average Common Shares Outstanding:
Used in Basic Calculation (shares)	90,777,446	91,910,244
Used in Diluted Calculation (shares)	91,434,741	92,442,145
Dividends Per Common Share:
Dividends Declared (in dollars per share)	$ 0.515	$ 0.495
Earnings Reinvested in The Business
Other Income (Expense):
Net Income Available for Common Stock	$ 44,986	$ 133,020
EARNINGS REINVESTED IN THE BUSINESS
Share Repurchases	(26,993)	0
Dividends on Common Stock	(46,671)	(45,597)
Utility
INCOME
Operating Revenues	228,424	201,920
Operating Expenses:
Operation and Maintenance	55,244	53,705
Exploration and Production and Other Revenues
INCOME
Operating Revenues	248,860	254,019
Operating Expenses:
Operation and Maintenance	33,541	34,826
Pipeline and Storage and Gathering Revenues
INCOME
Operating Revenues	72,198	69,422
Operating Expenses:
Operation and Maintenance	$ 35,941	$ 34,962

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Statement of Comprehensive Income [Abstract]
Net Income Available for Common Stock	$ 44,986	$ 133,020
Other Comprehensive Income (Loss), Before Tax:
Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	(53,516)	189,167
Reclassification Adjustment for Realized (Gains) Losses on Derivative Financial Instruments in Net Income	(29,504)	(19,708)
Other Comprehensive Income (Loss), Before Tax	(83,020)	169,459
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	(14,403)	52,486
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Derivative Financial Instruments in Net Income	(7,940)	(5,468)
Income Taxes – Net	(22,343)	47,018
Other Comprehensive Income (Loss)	(60,677)	122,441
Comprehensive Income (Loss)	$ (15,691)	$ 255,461

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Dec. 31, 2024	Sep. 30, 2024
ASSETS
Property, Plant and Equipment	$ 14,675,281	$ 14,524,798
Less - Accumulated Depreciation, Depletion and Amortization	7,393,477	7,185,593
Property, Plant and Equipment, Net, Total	7,281,804	7,339,205
Current Assets
Cash and Temporary Cash Investments	48,694	38,222
Receivables – Net of Allowance for Uncollectible Accounts of $28,384 and $26,194, Respectively	202,821	127,222
Unbilled Revenue	57,117	15,521
Gas Stored Underground	24,725	35,055
Materials and Supplies - at average cost	47,820	47,670
Other Current Assets	83,435	92,229
Total Current Assets	464,612	355,919
Other Assets
Recoverable Future Taxes	83,740	80,084
Unamortized Debt Expense	5,206	5,604
Other Regulatory Assets	106,386	108,022
Deferred Charges	68,952	69,662
Other Investments	71,493	81,705
Goodwill	5,476	5,476
Prepaid Pension and Post-Retirement Benefit Costs	185,224	180,230
Fair Value of Derivative Financial Instruments	20,695	87,905
Other	7,860	5,958
Total Other Assets	555,032	624,646
Total Assets	8,301,448	8,319,770
Capitalization:
Common Stock, $1 Par Value; Authorized - 200,000,000 Shares; Issued and Outstanding - 90,612,955 Shares and 91,005,993 Shares, Respectively	90,613	91,006
Paid in Capital	1,039,705	1,045,487
Earnings Reinvested in the Business	1,698,648	1,727,326
Accumulated Other Comprehensive Loss	(76,153)	(15,476)
Total Comprehensive Shareholders’ Equity	2,752,813	2,848,343
Long-Term Debt, Net of Current Portion and Unamortized Discount and Debt Issuance Costs	2,189,421	2,188,243
Total Capitalization	4,942,234	5,036,586
Current and Accrued Liabilities
Notes Payable to Banks and Commercial Paper	200,000	90,700
Current Portion of Long-Term Debt	500,000	500,000
Accounts Payable	120,991	165,068
Amounts Payable to Customers	42,587	42,720
Dividends Payable	46,671	46,872
Interest Payable on Long-Term Debt	44,376	27,247
Customer Advances	15,295	19,373
Customer Security Deposits	36,091	36,265
Other Accruals and Current Liabilities	172,409	162,903
Fair Value of Derivative Financial Instruments	20,893	4,744
Total Current and Accrued Liabilities	1,199,313	1,095,892
Other Liabilities
Deferred Income Taxes	1,089,394	1,111,165
Taxes Refundable to Customers	303,344	305,645
Cost of Removal Regulatory Liability	296,660	292,477
Other Regulatory Liabilities	147,561	151,452
Other Post-Retirement Liabilities	3,476	3,511
Asset Retirement Obligations	199,310	203,006
Other Liabilities	120,156	120,036
Total Other Liabilities	2,159,901	2,187,292
Commitments and Contingencies (Note 7)	0	0
Total Capitalization and Liabilities	$ 8,301,448	$ 8,319,770

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2024	Sep. 30, 2024
Statement of Financial Position [Abstract]
Receivables, allowance for uncollectible accounts	$ 28,384	$ 26,194
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)	90,612,955	91,005,993
Common stock, shares outstanding (in shares)	90,612,955	91,005,993

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
OPERATING ACTIVITIES
Net Income Available for Common Stock	$ 44,986	$ 133,020
Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities:
Impairment of Assets	141,802	0
Depreciation, Depletion and Amortization	109,370	115,790
Deferred Income Taxes	(5,385)	38,362
Stock-Based Compensation	4,705	4,660
Other	7,146	8,041
Change in:
Receivables and Unbilled Revenue	(115,165)	(58,459)
Gas Stored Underground and Materials and Supplies	10,180	6,915
Other Current Assets	8,814	892
Accounts Payable	9,703	(3,355)
Amounts Payable to Customers	(133)	1,013
Customer Advances	(4,078)	2,083
Customer Security Deposits	(174)	2,079
Other Accruals and Current Liabilities	21,266	28,612
Other Assets	(3,892)	(6,306)
Other Liabilities	(9,057)	(2,403)
Net Cash Provided by Operating Activities	220,088	270,944
INVESTING ACTIVITIES
Capital Expenditures	(240,427)	(246,938)
Other	5,878	(920)
Net Cash Used in Investing Activities	(234,549)	(247,858)
FINANCING ACTIVITIES
Changes in Notes Payable to Banks and Commercial Paper	109,300	12,500
Shares Repurchased Under Repurchase Plan	(33,524)	0
Dividends Paid on Common Stock	(46,872)	(45,451)
Net Repurchases of Common Stock Under Stock and Benefit Plans	(3,971)	(3,897)
Net Cash Provided by (Used in) Financing Activities	24,933	(36,848)
Net Increase (Decrease) in Cash and Cash Equivalents	10,472	(13,762)
Cash and Cash Equivalents at October 1	38,222	55,447
Cash and Cash Equivalents at December 31	48,694	41,685
Supplemental Disclosure of Cash Flow Information
Non-Cash Capital Expenditures	$ 71,616	$ 97,922

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	3 Months Ended
	Dec. 31, 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, 2024, 2023 and 2022 that are included in the Company's 2024 Form 10-K. The consolidated financial statements for the year ended September 30, 2025 will be audited by the Company's independent registered public accounting firm after the end of the fiscal year. The earnings for the three months ended December 31, 2024 should not be taken as a prediction of earnings for the entire fiscal year ending September 30, 2025. 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 8 – Business Segment Information. Consolidated Statements of Cash Flows. The Statement of Cash Flows for the three months ended December 31, 2024 and the three months ended December 31, 2023 reconciles the net increase (decrease) in cash and cash equivalents, which consists solely of cash and temporary cash investments for the periods presented. The Company did not have any restricted cash at December 31, 2024, October 1, 2024, December 31, 2023 or October 1, 2023. The Company considers all highly liquid debt instruments purchased with a maturity date of generally three months or less to be cash equivalents. 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 charged 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. Starting in the quarter ended March 31, 2025, account balances will be charged off against the allowance approximately three months after the account is final billed or when it is anticipated that the receivable will not be recovered. Activity in the allowance for uncollectible accounts for the three months ended December 31, 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 Three Months Ended December 31, 2024 Allowance for Uncollectible Accounts $ 26,194 $ 4,605 $ 107 $ (2,522) $ 28,384 Three Months Ended December 31, 2023 Allowance for Uncollectible Accounts $ 36,295 $ 4,157 $ 119 $ (3,455) $ 37,116 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 as storage quantities are withdrawn and increases in the third and fourth quarters as storage quantities are replenished. 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 $1.3 million at December 31, 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 $2.2 billion and $2.3 billion at December 31, 2024 and September 30, 2024, 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 $133.3 million and $201.0 million at December 31, 2024 and September 30, 2024, 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 December 31, 2024. As such, the Company recognized a non-cash, pre-tax ceiling test impairment charge in the Exploration and Production segment of $108.3 million for the quarter ended December 31, 2024. A deferred income tax benefit of $29.2 million related to the non-cash impairment charge was also recognized for the quarter ended December 31, 2024. In adjusting estimated future cash flows for hedging under the ceiling test at December 31, 2024, estimated future net cash flows were increased by $495.3 million. The Exploration and Production segment also has items of property, plant and equipment that are accounted for outside of the provisions of the full cost method of accounting. As discussed in Note 3 – Fair Value Measurements, an impairment charge related to certain water disposal assets was recorded at December 31, 2024. 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 December 31, 2024. Accumulated Other Comprehensive Income (Loss). The components of Accumulated Other Comprehensive Income (Loss) and changes for the three months ended December 31, 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 December 31, 2024 Balance at October 1, 2024 $ 55,799 $ (71,275) $ (15,476) Other Comprehensive Gains and Losses Before Reclassifications (39,113) — (39,113) Amounts Reclassified From Other Comprehensive Loss (21,564) — (21,564) Balance at December 31, 2024 $ (4,878) $ (71,275) $ (76,153) Three Months Ended December 31, 2023 Balance at October 1, 2023 $ 4,623 $ (59,683) $ (55,060) Other Comprehensive Gains and Losses Before Reclassifications 136,681 — 136,681 Amounts Reclassified From Other Comprehensive Income (14,240) — (14,240) Balance at December 31, 2023 $ 127,064 $ (59,683) $ 67,381 Reclassifications Out of Accumulated Other Comprehensive Income (Loss). The details about the reclassification adjustments out of accumulated other comprehensive income (loss) for the three months ended December 31, 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 2024 2023 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $29,729 $19,755 Operating Revenues Foreign Currency Contracts (225) (47) Operating Revenues 29,504 19,708 Total Before Income Tax (7,940) (5,468) Income Tax Expense $21,564 $14,240 Net of Tax Other Current Assets . The components of the Company’s Other Current Assets are as follows (in thousands): At December 31, 2024 At September 30, 2024 Prepayments $ 13,890 $ 18,463 Prepaid Property and Other Taxes 14,301 14,187 Federal Income Taxes Receivable — 8,154 State Income Taxes Receivable 6,911 13,161 Regulatory Assets 48,333 38,264 $ 83,435 $ 92,229 Other Accruals and Current Liabilities . The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At December 31, 2024 At September 30, 2024 Accrued Capital Expenditures $ 52,852 $ 47,344 Regulatory Liabilities 24,235 29,352 Reserve for Gas Replacement 1,316 — Liability for Royalty and Working Interests 23,673 15,007 Federal Income Taxes Payable 5,249 — Non-Qualified Benefit Plan Liability 14,135 14,135 Other 50,949 57,065 $ 172,409 $ 162,903 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. For the quarter ended December 31, 2024, 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 four securities excluded as being antidilutive for the quarter ended December 31, 2024. For the quarter ended December 31, 2023, there were no securities excluded as being antidilutive. 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 6 – Capitalization for further discussion of the Company's share repurchase program. Stock-Based Compensation. The Company granted 239,042 performance shares during the quarter ended December 31, 2024. The weighted average fair value of such performance shares was $55.43 per share for the quarter ended December 31, 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 quarter ended December 31, 2024 include awards that must meet a performance goal related to either relative total return on capital over a three-year performance cycle ("ROC Performance Shares"), methane intensity and greenhouse gas emissions reductions over a three-year performance cycle ("Emissions Performance Shares") or relative total shareholder return over a three-year performance cycle ("TSR Performance Shares"). The performance goal related to the ROC Performance Shares over the three-year performance cycle 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 Emissions 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 or exceeding the Company's 2030 goals. The number of these Emissions 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 Emissions 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 three-year performance cycle is the Company’s three-year total shareholder return relative to the three-year total shareholder return of the other companies in the Report Group. Three-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 130,252 restricted stock units during the quarter ended December 31, 2024. The weighted average fair value of such restricted stock units was $58.48 per share for the quarter ended December 31, 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.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	3 Months Ended
	Dec. 31, 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 three months ended December 31, 2024 and 2023, presented by type of service from each reportable segment. Quarter Ended December 31, 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 $ 217,458 $ — $ — $ — $ — $ — $ 217,458 Production of Crude Oil 515 — — — — — 515 Natural Gas Processing 275 — — — — — 275 Natural Gas Gathering Service — — 61,131 — — (57,683) 3,448 Natural Gas Transportation Service — 81,204 — 26,921 — (27,181) 80,944 Natural Gas Storage Service — 24,993 — — — (10,504) 14,489 Natural Gas Residential Sales — — — 156,350 — — 156,350 Natural Gas Commercial Sales — — — 22,243 — — 22,243 Natural Gas Industrial Sales — — — 1,338 — (1) 1,337 Other 883 415 — 15,740 — (261) 16,777 Total Revenues from Contracts with Customers 219,131 106,612 61,131 222,592 — (95,630) 513,836 Alternative Revenue Programs — — — 5,917 — — 5,917 Derivative Financial Instruments 29,729 — — — — — 29,729 Total Revenues $ 248,860 $ 106,612 $ 61,131 $ 228,509 $ — $ (95,630) $ 549,482 Quarter Ended December 31, 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 $ 232,661 $ — $ — $ — $ — $ — $ 232,661 Production of Crude Oil 687 — — — — — 687 Natural Gas Processing 267 — — — — — 267 Natural Gas Gathering Service — — 62,588 — — (57,992) 4,596 Natural Gas Transportation Service — 71,618 — 29,285 — (20,362) 80,541 Natural Gas Storage Service — 21,292 — — — (9,059) 12,233 Natural Gas Residential Sales — — — 146,546 — — 146,546 Natural Gas Commercial Sales — — — 20,281 — — 20,281 Natural Gas Industrial Sales — — — 906 — (2) 904 Other 649 1,503 — (567) — (251) 1,334 Total Revenues from Contracts with Customers 234,264 94,413 62,588 196,451 — (87,666) 500,050 Alternative Revenue Programs — — — 5,556 — — 5,556 Derivative Financial Instruments 19,755 — — — — — 19,755 Total Revenues $ 254,019 $ 94,413 $ 62,588 $ 202,007 $ — $ (87,666) $ 525,361 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: $175.5 million for the remainder of fiscal 2025; $196.7 million for fiscal 2026; $155.0 million for fiscal 2027; $135.4 million for fiscal 2028; $121.0 million for fiscal 2029; and $648.5 million thereafter.

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Dec. 31, 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 December 31, 2024 and September 30, 2024. 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 December 31, 2024 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 41,745 $ — $ — $ — $ 41,745 Derivative Financial Instruments: Over the Counter Swaps – Gas — 43,937 — (31,220) 12,717 Over the Counter No Cost Collars – Gas — 18,426 — (10,380) 8,046 Contingent Consideration for Asset Sale — 380 — — 380 Foreign Currency Contracts — 52 — (500) (448) Other Investments: Balanced Equity Mutual Fund 12,241 — — — 12,241 Fixed Income Mutual Fund 16,281 — — — 16,281 Total $ 70,267 $ 62,795 $ — $ (42,100) $ 90,962 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 41,848 $ — $ (31,220) $ 10,628 Over the Counter No Cost Collars – Gas — 19,266 — (10,380) 8,886 Foreign Currency Contracts — 1,879 — (500) 1,379 Total $ — $ 62,993 $ — $ (42,100) $ 20,893 Total Net Assets/(Liabilities) $ 70,267 $ (198) $ — $ — $ 70,069 Recurring Fair Value Measures At fair value as of September 30, 2024 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 29,238 $ — $ — $ — $ 29,238 Derivative Financial Instruments: Over the Counter Swaps – Gas — 76,009 — (17,198) 58,811 Over the Counter No Cost Collars – Gas — 32,584 — (3,774) 28,810 Contingent Consideration for Asset Sale — 729 — — 729 Foreign Currency Contracts — 281 — (726) (445) Other Investments: Balanced Equity Mutual Fund 19,523 — — — 19,523 Fixed Income Mutual Fund 17,374 — — — 17,374 Total $ 66,135 $ 109,603 $ — $ (21,698) $ 154,040 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 22,206 $ — $ (17,198) $ 5,008 Over the Counter No Cost Collars – Gas — 3,501 — (3,774) (273) Foreign Currency Contracts — 726 — (726) — Total $ — $ 26,433 $ — $ (21,698) $ 4,735 Total Net Assets/(Liabilities) $ 66,135 $ 83,170 $ — $ — $ 149,305 (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. The following table presents impairments of assets associated with certain nonrecurring fair value measurements within Level 3 of the fair value hierarchy as of December 31, 2024 and 2023 (in thousands): Impairments Nonrecurring Fair Value Measures Quarter Ended December 31, Segment Date of Measurement Fair Value 2024 2023 Impairment of Assets: Water Disposal Assets Exploration and Production December 31, 2024 $ 12,880 $ 33,453 $ — In exploring the potential sale of certain water disposal assets during the quarter ended December 31, 2024, the Company determined that the fair market value of such assets was less than the recorded net book value resulting in an impairment charge that reduced the net book value to fair market value. These assets are used to dispose of water from operations in the Exploration and Production segment. Derivative Financial Instruments The derivative financial instruments reported in Level 2 at December 31, 2024 and September 30, 2024 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 December 31, 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 December 31, 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 and 2024 contingency periods expired with the ICE Brent Average falling below $95 per barrel each calendar year. 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	3 Months Ended
	Dec. 31, 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): December 31, 2024 September 30, 2024 Carrying Fair Value Carrying Fair Value Long-Term Debt $ 2,689,421 $ 2,618,660 $ 2,688,243 $ 2,656,888 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 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 December 31, 2024 At September 30, 2024 Life Insurance Contracts $ 42,971 $ 44,808 Equity Mutual Fund 12,241 19,523 Fixed Income Mutual Fund 16,281 17,374 $ 71,493 $ 81,705 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 6 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 and 2024 contingency periods expired with the ICE Brent Average falling below $95 per barrel each calendar year. 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 $0.4 million and $0.7 million at December 31, 2024 and September 30, 2024, respectively. A $0.3 million mark-to-market adjustment to reduce the fair value of the contingent consideration was recorded during the quarter ended December 31, 2024. The Company has presented its net derivative assets and liabilities as “Fair Value of Derivative Financial Instruments” on its Consolidated Balance Sheets at December 31, 2024 and September 30, 2024. 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 December 31, 2024, the Company had 388.2 Bcf of natural gas commodity derivative contracts (swaps and no cost collars) outstanding. As of December 31, 2024, the Company was hedging a total of $51.2 million of forecasted transportation costs denominated in Canadian dollars with foreign currency forward contracts. As of December 31, 2024, the Company had $4.9 million of net hedging losses after taxes included in the accumulated other comprehensive income (loss) balance. Of this amount, it is expected that $1.9 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 December 31, 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 $ (51,909) $ 187,989 Operating Revenue $ 29,729 $ 19,755 Foreign Currency Contracts (1,607) 1,178 Operating Revenue (225) (47) Total $ (53,516) $ 189,167 $ 29,504 $ 19,708 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 eighteen counterparties of which eight are in a net gain position. On average, the Company had $2.5 million of credit exposure per counterparty in a gain position at December 31, 2024. The maximum credit exposure per counterparty in a gain position at December 31, 2024 was $9.3 million. As of December 31, 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 December 31, 2024, twelve of the eighteen 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 December 31, 2024, the fair market value of the derivative financial instrument liabilities with a credit-risk related contingency feature was $5.9 million according to the Company's internal model (discussed in Note 3 – Fair Value Measurements), and no hedging collateral deposits were required to be posted by the Company at December 31, 2024. Depending on the movement of commodity prices in the future, it is possible that these liability positions could swing into asset positions, at which point the Company would be exposed to credit risk on its derivative financial instruments. In that case, the Company's counterparties could be required to post hedging collateral deposits.

Income Taxes

Income Taxes	3 Months Ended
	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The effective tax rates for the quarters ended December 31, 2024 and December 31, 2023 were 19.9% and 24.5%, respectively. The change in the quarterly effective income tax rate was primarily driven by the impact of the impairments of the exploration and production properties under the ceiling test and other operational assets, which resulted in a smaller income tax expense on income before income taxes to be recorded during the quarter ended December 31, 2024.

Capitalization

Capitalization	3 Months Ended
	Dec. 31, 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 October 1, 2024 91,006 $ 91,006 $ 1,045,487 $ 1,727,326 $ (15,476) Net Income Available for Common Stock 44,986 Dividends Declared on Common Stock ($0.515 Per Share) (46,671) Other Comprehensive Loss, Net of Tax (60,677) Share-Based Payment Expense (1) 4,090 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 156 156 (3,511) Share Repurchases Under Repurchase Plan (549) (549) (6,361) (26,993) Balance at December 31, 2024 90,613 $ 90,613 $ 1,039,705 $ 1,698,648 $ (76,153) Balance at October 1, 2023 91,819 $ 91,819 $ 1,040,761 $ 1,885,856 $ (55,060) Net Income Available for Common Stock 133,020 Dividends Declared on Common Stock ($0.495 Per Share) (45,597) Other Comprehensive Income, Net of Tax 122,441 Share-Based Payment Expense (1) 4,135 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 297 297 (3,670) Balance at December 31, 2023 92,116 $ 92,116 $ 1,041,226 $ 1,973,279 $ 67,381 (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. Common stock share activity during the three months ended December 31, 2024 consisted of the following items: Three Months Ended December 31, 2024 Vesting of Restricted Stock Units 119,177 Vesting of Performance Shares 89,843 Issuance of Common Stock Pursuant to the Company's Non-Employee Director Equity Compensation Plan and Deferred Compensation Plan for Directors and Officers 10,169 Shares Tendered to Pay Withholding Taxes on Stock-Based Compensation Awards (1) (63,631) Common Stock Issued Under Stock and Benefit Plans 155,558 Share Repurchases Under Repurchase Plan (548,596) Total Net Shares Repurchased During the Three Months Ended December 31, 2024 (393,038) (1) 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 three months ended December 31, 2024, the Company executed transactions to repurchase 548,596 shares at an average price of $61.27 per share. With broker fees and excise taxes, the total cost of these repurchases amounted to $33.9 million. Share repurchases that settled during the three months ended December 31, 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 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 a one-year 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. In January 2025, the Company and the eleven banks in the syndicate consented to a second one-year extension of the maturity date, from February 25, 2028 to February 23, 2029, such that the Company has aggregate commitments available under the Credit Agreement in the full amount of $1.0 billion through February 23, 2029. Current Portion of Long-Term Debt. The Current Portion of Long-Term Debt at December 31, 2024 and September 30, 2024 consisted of $50.0 million of 7.38% notes that mature in June 2025 and $450.0 million of 5.20% notes that mature in July 2025. Delayed Draw Term Loan.

Commitments And Contingencies

Commitments And Contingencies	3 Months Ended
	Dec. 31, 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 December 31, 2024, the Company has estimated its remaining clean-up costs related to former manufactured gas plant sites will be approximately $4.0 million. The Company's liability for such clean-up costs has been recorded in Other Liabilities on the Consolidated Balance Sheet at December 31, 2024. The Company has a regulatory liability of $3.3 million related to environmental clean-up costs at December 31, 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. 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	3 Months Ended
	Dec. 31, 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 2024 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 2024 Form 10-K. A listing of segment assets at December 31, 2024 and September 30, 2024 is shown in the tables below. Quarter Ended December 31, 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 $248,860 $68,750 $3,448 $228,424 $549,482 $— $— $549,482 Intersegment Revenues $— $37,862 $57,683 $85 $95,630 $— $(95,630) $— Segment Profit: Net Income (Loss) $(46,777) $32,454 $27,145 $32,499 $45,321 $(193) $(142) $44,986 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Segment Assets: At December 31, 2024 $2,533,521 $2,475,767 $1,039,149 $2,454,198 $8,502,635 $7,931 $(209,118) $8,301,448 At September 30, 2024 $2,644,820 $2,446,243 $987,103 $2,398,709 $8,476,875 $6,227 $(163,332) $8,319,770 Quarter Ended December 31, 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 $254,019 $64,826 $4,596 $201,920 $525,361 $— $— $525,361 Intersegment Revenues $— $29,587 $57,992 $87 $87,666 $— $(87,666) $— Segment Profit: Net Income (Loss) $52,483 $24,055 $28,825 $26,551 $131,914 $(121) $1,227 $133,020

Retirement Plan And Other Post-

Retirement Plan And Other Post-Retirement Benefits	3 Months Ended
	Dec. 31, 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 December 31, 2024 2023 2024 2023 Service Cost $ 1,023 $ 1,049 $ 130 $ 109 Interest Cost 9,223 10,890 3,625 3,890 Expected Return on Plan Assets (14,647) (17,086) (6,536) (6,660) Amortization of Prior Service Cost (Credit) 76 91 (107) (107) Amortization of (Gains) Losses 1,620 (335) 9 (567) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) (165) 4,057 (727) 2,238 Net Periodic Benefit Cost (Income) $ (2,870) $ (1,334) $ (3,606) $ (1,097) (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 three months ended December 31, 2024, and does not anticipate making any such contributions during the remainder of fiscal 2025. The Company also did not make any contributions to its VEBA trusts for its other post-retirement benefits during the three months ended December 31, 2024, and does not anticipate making any such contributions during the remainder of fiscal 2025.

Regulatory Matters

Regulatory Matters	3 Months Ended
	Dec. 31, 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 December 19, 2024 with rates effective January 1, 2025 (“2024 Rate Order”). The 2024 Rate Order authorizes a three-year rate plan effective October 1, 2024, with a make-whole provision allowing full recovery of revenues that would have been billed at the new rates between October 1, 2024 and December 31, 2024. It also reflects a return on equity of 9.7% and authorizes a revenue requirement increase of $57.3 million in fiscal 2025, an additional revenue requirement increase of $15.8 million in fiscal 2026, and an additional revenue requirement increase of $12.7 million in fiscal 2027. The revenue requirement for each year of the three-year plan has been reduced by $14 million for actuarial projections of income that is expected to be recognized for qualified pension and other post-retirement benefits. Qualified pension and other post-retirement benefit income or costs are matched with amounts included in revenue resulting in zero impact to earnings. The 2024 Rate Order approves the continuation of several ratemaking mechanisms, including revenue decoupling and WNA, and establishes a number of new cost trackers and regulatory deferrals. It also includes an earnings sharing mechanism, gas safety and customer service performance metrics (including maintaining the Company’s leak prone pipe replacement program), and provisions that will facilitate achievement of the emissions reduction goals of the CLCPA. Pennsylvania Jurisdiction Distribution Corporation’s current delivery rates in its Pennsylvania jurisdiction were approved by the PaPUC in an order issued on June 15, 2023 with rates effective August 1, 2023 (“2023 Rate Order”). The 2023 Rate Order provided for, among other things, an increase in Distribution Corporation’s annual base rate operating revenues of $23 million and authorized a new weather normalization adjustment mechanism. 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. The DSIC petition was approved by the PaPUC on December 5, 2024, and on January 1, 2025, the Company initiated recovery of eligible costs on incremental rate base added after September 30, 2024. FERC Jurisdiction Supply Corporation’s rate settlement, approved June 11, 2024, provides that 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. Supply Corporation has no rate case currently on file. Empire's 2019 rate settlement requires a Section 4 rate case filing no later than May 1, 2025. Empire is not barred from filing a Section 4 rate case before the May 1, 2025 date. Empire has no rate case currently on file.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Pay vs Performance Disclosure
Net Income Available for Common Stock	$ 44,986	$ 133,020

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Dec. 31, 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)	3 Months Ended
	Dec. 31, 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, 2024, 2023 and 2022 that are included in the Company's 2024 Form 10-K. The consolidated financial statements for the year ended September 30, 2025 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 Statement of Cash Flows for the three months ended December 31, 2024 and the three months ended December 31, 2023 reconciles the net increase (decrease) in cash and cash equivalents, which consists solely of cash and temporary cash investments for the periods presented. The Company did not have any restricted cash at December 31, 2024, October 1, 2024, December 31, 2023 or October 1, 2023. The Company considers all highly liquid debt instruments purchased with a maturity date of generally three months or less to be cash equivalents.
Allowance for Uncollectible Accounts	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 charged 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. Starting in the quarter ended March 31, 2025, account balances will be charged off against the allowance approximately three months after the account is final billed or when it is anticipated that the receivable will not be recovered.
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 as storage quantities are withdrawn and increases in the third and fourth quarters as storage quantities are replenished. 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 $1.3 million at December 31, 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 $2.2 billion and $2.3 billion at December 31, 2024 and September 30, 2024, 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 $133.3 million and $201.0 million at December 31, 2024 and September 30, 2024, 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 December 31, 2024. As such, the Company recognized a non-cash, pre-tax ceiling test impairment charge in the Exploration and Production segment of $108.3 million for the quarter ended December 31, 2024. A deferred income tax benefit of $29.2 million related to the non-cash impairment charge was also recognized for the quarter ended December 31, 2024. In adjusting estimated future cash flows for hedging under the ceiling test at December 31, 2024, estimated future net cash flows were increased by $495.3 million. The Exploration and Production segment also has items of property, plant and equipment that are accounted for outside of the provisions of the full cost method of accounting. As discussed in Note 3 – Fair Value Measurements, an impairment charge related to certain water disposal assets was recorded at December 31, 2024.
Earnings Per Common Share	Earnings Per Common Share.
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 6 – Capitalization for further discussion of the Company's share repurchase program.
Stock-Based Compensation	Stock-Based Compensation. The Company granted 239,042 performance shares during the quarter ended December 31, 2024. The weighted average fair value of such performance shares was $55.43 per share for the quarter ended December 31, 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 quarter ended December 31, 2024 include awards that must meet a performance goal related to either relative total return on capital over a three-year performance cycle ("ROC Performance Shares"), methane intensity and greenhouse gas emissions reductions over a three-year performance cycle ("Emissions Performance Shares") or relative total shareholder return over a three-year performance cycle ("TSR Performance Shares"). The performance goal related to the ROC Performance Shares over the three-year performance cycle 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 Emissions 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 or exceeding the Company's 2030 goals. The number of these Emissions 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 Emissions 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 three-year performance cycle is the Company’s three-year total shareholder return relative to the three-year total shareholder return of the other companies in the Report Group. Three-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 130,252 restricted stock units during the quarter ended December 31, 2024. The weighted average fair value of such restricted stock units was $58.48 per share for the quarter ended December 31, 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.

Summary Of Significant Accoun_3

Summary Of Significant Accounting Policies (Tables)	3 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Schedule of Allowance for Uncollectible Accounts	Activity in the allowance for uncollectible accounts for the three months ended December 31, 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 Three Months Ended December 31, 2024 Allowance for Uncollectible Accounts $ 26,194 $ 4,605 $ 107 $ (2,522) $ 28,384 Three Months Ended December 31, 2023 Allowance for Uncollectible Accounts $ 36,295 $ 4,157 $ 119 $ (3,455) $ 37,116
Components of Accumulated Other Comprehensive Income (Loss)	The components of Accumulated Other Comprehensive Income (Loss) and changes for the three months ended December 31, 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 December 31, 2024 Balance at October 1, 2024 $ 55,799 $ (71,275) $ (15,476) Other Comprehensive Gains and Losses Before Reclassifications (39,113) — (39,113) Amounts Reclassified From Other Comprehensive Loss (21,564) — (21,564) Balance at December 31, 2024 $ (4,878) $ (71,275) $ (76,153) Three Months Ended December 31, 2023 Balance at October 1, 2023 $ 4,623 $ (59,683) $ (55,060) Other Comprehensive Gains and Losses Before Reclassifications 136,681 — 136,681 Amounts Reclassified From Other Comprehensive Income (14,240) — (14,240) Balance at December 31, 2023 $ 127,064 $ (59,683) $ 67,381
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 three months ended December 31, 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 2024 2023 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $29,729 $19,755 Operating Revenues Foreign Currency Contracts (225) (47) Operating Revenues 29,504 19,708 Total Before Income Tax (7,940) (5,468) Income Tax Expense $21,564 $14,240 Net of Tax
Schedule of Other Current Assets	The components of the Company’s Other Current Assets are as follows (in thousands): At December 31, 2024 At September 30, 2024 Prepayments $ 13,890 $ 18,463 Prepaid Property and Other Taxes 14,301 14,187 Federal Income Taxes Receivable — 8,154 State Income Taxes Receivable 6,911 13,161 Regulatory Assets 48,333 38,264 $ 83,435 $ 92,229
Schedule of Other Accruals and Current Liabilities	The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At December 31, 2024 At September 30, 2024 Accrued Capital Expenditures $ 52,852 $ 47,344 Regulatory Liabilities 24,235 29,352 Reserve for Gas Replacement 1,316 — Liability for Royalty and Working Interests 23,673 15,007 Federal Income Taxes Payable 5,249 — Non-Qualified Benefit Plan Liability 14,135 14,135 Other 50,949 57,065 $ 172,409 $ 162,903

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	3 Months Ended
	Dec. 31, 2024
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following tables provide a disaggregation of the Company's revenues for the three months ended December 31, 2024 and 2023, presented by type of service from each reportable segment. Quarter Ended December 31, 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 $ 217,458 $ — $ — $ — $ — $ — $ 217,458 Production of Crude Oil 515 — — — — — 515 Natural Gas Processing 275 — — — — — 275 Natural Gas Gathering Service — — 61,131 — — (57,683) 3,448 Natural Gas Transportation Service — 81,204 — 26,921 — (27,181) 80,944 Natural Gas Storage Service — 24,993 — — — (10,504) 14,489 Natural Gas Residential Sales — — — 156,350 — — 156,350 Natural Gas Commercial Sales — — — 22,243 — — 22,243 Natural Gas Industrial Sales — — — 1,338 — (1) 1,337 Other 883 415 — 15,740 — (261) 16,777 Total Revenues from Contracts with Customers 219,131 106,612 61,131 222,592 — (95,630) 513,836 Alternative Revenue Programs — — — 5,917 — — 5,917 Derivative Financial Instruments 29,729 — — — — — 29,729 Total Revenues $ 248,860 $ 106,612 $ 61,131 $ 228,509 $ — $ (95,630) $ 549,482 Quarter Ended December 31, 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 $ 232,661 $ — $ — $ — $ — $ — $ 232,661 Production of Crude Oil 687 — — — — — 687 Natural Gas Processing 267 — — — — — 267 Natural Gas Gathering Service — — 62,588 — — (57,992) 4,596 Natural Gas Transportation Service — 71,618 — 29,285 — (20,362) 80,541 Natural Gas Storage Service — 21,292 — — — (9,059) 12,233 Natural Gas Residential Sales — — — 146,546 — — 146,546 Natural Gas Commercial Sales — — — 20,281 — — 20,281 Natural Gas Industrial Sales — — — 906 — (2) 904 Other 649 1,503 — (567) — (251) 1,334 Total Revenues from Contracts with Customers 234,264 94,413 62,588 196,451 — (87,666) 500,050 Alternative Revenue Programs — — — 5,556 — — 5,556 Derivative Financial Instruments 19,755 — — — — — 19,755 Total Revenues $ 254,019 $ 94,413 $ 62,588 $ 202,007 $ — $ (87,666) $ 525,361

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Dec. 31, 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 December 31, 2024 and September 30, 2024. 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 December 31, 2024 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 41,745 $ — $ — $ — $ 41,745 Derivative Financial Instruments: Over the Counter Swaps – Gas — 43,937 — (31,220) 12,717 Over the Counter No Cost Collars – Gas — 18,426 — (10,380) 8,046 Contingent Consideration for Asset Sale — 380 — — 380 Foreign Currency Contracts — 52 — (500) (448) Other Investments: Balanced Equity Mutual Fund 12,241 — — — 12,241 Fixed Income Mutual Fund 16,281 — — — 16,281 Total $ 70,267 $ 62,795 $ — $ (42,100) $ 90,962 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 41,848 $ — $ (31,220) $ 10,628 Over the Counter No Cost Collars – Gas — 19,266 — (10,380) 8,886 Foreign Currency Contracts — 1,879 — (500) 1,379 Total $ — $ 62,993 $ — $ (42,100) $ 20,893 Total Net Assets/(Liabilities) $ 70,267 $ (198) $ — $ — $ 70,069 Recurring Fair Value Measures At fair value as of September 30, 2024 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 29,238 $ — $ — $ — $ 29,238 Derivative Financial Instruments: Over the Counter Swaps – Gas — 76,009 — (17,198) 58,811 Over the Counter No Cost Collars – Gas — 32,584 — (3,774) 28,810 Contingent Consideration for Asset Sale — 729 — — 729 Foreign Currency Contracts — 281 — (726) (445) Other Investments: Balanced Equity Mutual Fund 19,523 — — — 19,523 Fixed Income Mutual Fund 17,374 — — — 17,374 Total $ 66,135 $ 109,603 $ — $ (21,698) $ 154,040 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 22,206 $ — $ (17,198) $ 5,008 Over the Counter No Cost Collars – Gas — 3,501 — (3,774) (273) Foreign Currency Contracts — 726 — (726) — Total $ — $ 26,433 $ — $ (21,698) $ 4,735 Total Net Assets/(Liabilities) $ 66,135 $ 83,170 $ — $ — $ 149,305 (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, Nonrecurring	The following table presents impairments of assets associated with certain nonrecurring fair value measurements within Level 3 of the fair value hierarchy as of December 31, 2024 and 2023 (in thousands): Impairments Nonrecurring Fair Value Measures Quarter Ended December 31, Segment Date of Measurement Fair Value 2024 2023 Impairment of Assets: Water Disposal Assets Exploration and Production December 31, 2024 $ 12,880 $ 33,453 $ —

Financial Instruments (Tables)

Financial Instruments (Tables)	3 Months Ended
	Dec. 31, 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): December 31, 2024 September 30, 2024 Carrying Fair Value Carrying Fair Value Long-Term Debt $ 2,689,421 $ 2,618,660 $ 2,688,243 $ 2,656,888
Schedule Of Other Investments	The components of the Company's Other Investments are as follows (in thousands): At December 31, 2024 At September 30, 2024 Life Insurance Contracts $ 42,971 $ 44,808 Equity Mutual Fund 12,241 19,523 Fixed Income Mutual Fund 16,281 17,374 $ 71,493 $ 81,705
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 December 31, 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 $ (51,909) $ 187,989 Operating Revenue $ 29,729 $ 19,755 Foreign Currency Contracts (1,607) 1,178 Operating Revenue (225) (47) Total $ (53,516) $ 189,167 $ 29,504 $ 19,708

Capitalization (Tables)

Capitalization (Tables)	3 Months Ended
	Dec. 31, 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 October 1, 2024 91,006 $ 91,006 $ 1,045,487 $ 1,727,326 $ (15,476) Net Income Available for Common Stock 44,986 Dividends Declared on Common Stock ($0.515 Per Share) (46,671) Other Comprehensive Loss, Net of Tax (60,677) Share-Based Payment Expense (1) 4,090 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 156 156 (3,511) Share Repurchases Under Repurchase Plan (549) (549) (6,361) (26,993) Balance at December 31, 2024 90,613 $ 90,613 $ 1,039,705 $ 1,698,648 $ (76,153) Balance at October 1, 2023 91,819 $ 91,819 $ 1,040,761 $ 1,885,856 $ (55,060) Net Income Available for Common Stock 133,020 Dividends Declared on Common Stock ($0.495 Per Share) (45,597) Other Comprehensive Income, Net of Tax 122,441 Share-Based Payment Expense (1) 4,135 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 297 297 (3,670) Balance at December 31, 2023 92,116 $ 92,116 $ 1,041,226 $ 1,973,279 $ 67,381 (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.
Summary of Common Stock Share Activity	Common stock share activity during the three months ended December 31, 2024 consisted of the following items: Three Months Ended December 31, 2024 Vesting of Restricted Stock Units 119,177 Vesting of Performance Shares 89,843 Issuance of Common Stock Pursuant to the Company's Non-Employee Director Equity Compensation Plan and Deferred Compensation Plan for Directors and Officers 10,169 Shares Tendered to Pay Withholding Taxes on Stock-Based Compensation Awards (1) (63,631) Common Stock Issued Under Stock and Benefit Plans 155,558 Share Repurchases Under Repurchase Plan (548,596) Total Net Shares Repurchased During the Three Months Ended December 31, 2024 (393,038) (1) The Company considers all shares tendered as cancelled shares restored to the status of authorized but unissued shares, in accordance with New Jersey law.

Business Segment Information (T

Business Segment Information (Tables)	3 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
Financial Segment Information By Segment	A listing of segment assets at December 31, 2024 and September 30, 2024 is shown in the tables below. Quarter Ended December 31, 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 $248,860 $68,750 $3,448 $228,424 $549,482 $— $— $549,482 Intersegment Revenues $— $37,862 $57,683 $85 $95,630 $— $(95,630) $— Segment Profit: Net Income (Loss) $(46,777) $32,454 $27,145 $32,499 $45,321 $(193) $(142) $44,986 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Segment Assets: At December 31, 2024 $2,533,521 $2,475,767 $1,039,149 $2,454,198 $8,502,635 $7,931 $(209,118) $8,301,448 At September 30, 2024 $2,644,820 $2,446,243 $987,103 $2,398,709 $8,476,875 $6,227 $(163,332) $8,319,770 Quarter Ended December 31, 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 $254,019 $64,826 $4,596 $201,920 $525,361 $— $— $525,361 Intersegment Revenues $— $29,587 $57,992 $87 $87,666 $— $(87,666) $— Segment Profit: Net Income (Loss) $52,483 $24,055 $28,825 $26,551 $131,914 $(121) $1,227 $133,020

Retirement Plan And Other Pos_2

Retirement Plan And Other Post-Retirement Benefits (Tables)	3 Months Ended
	Dec. 31, 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 December 31, 2024 2023 2024 2023 Service Cost $ 1,023 $ 1,049 $ 130 $ 109 Interest Cost 9,223 10,890 3,625 3,890 Expected Return on Plan Assets (14,647) (17,086) (6,536) (6,660) Amortization of Prior Service Cost (Credit) 76 91 (107) (107) Amortization of (Gains) Losses 1,620 (335) 9 (567) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) (165) 4,057 (727) 2,238 Net Periodic Benefit Cost (Income) $ (2,870) $ (1,334) $ (3,606) $ (1,097) (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 (Allowance for Uncollectible Accounts) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Allowance for Uncollectible Accounts [Roll Forward]
Balance at Beginning of Period	$ 26,194	$ 36,295
Additions Charged to Costs and Expenses	4,605	4,157
Discounts on Purchased Receivables	107	119
Net Accounts Receivable Written-Off	(2,522)	(3,455)
Balance at End of Period	$ 28,384	$ 37,116

Summary Of Significant Accoun_5

Summary Of Significant Accounting Policies (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Sep. 30, 2024	Sep. 30, 2025
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground	$ 24,725		$ 35,055
Capitalized Costs Exploration and Production Activities Net	2,200,000		2,300,000
Capitalized costs of unproved properties excluded from amortization	$ 133,300		$ 201,000
Full cost ceiling test discount factor (as a percent)	10%
Impairment of exploration and production properties	$ 108,300
Increase estimated future net cash flows	$ 495,300
Antidilutive securities (in shares)	4	0
Impairment of Exploration and Production Properties
Summary Of Significant Accounting Policies [Line Items]
Deferred income tax benefit	$ 29,200
Reserve For Gas Replacement
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground	$ 1,300
Reserve For Gas Replacement | Forecast
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground				$ 0
Restricted Stock Units
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period (in shares)	130,252
Granted in fiscal year, weighted average grant date fair value (in USD per share)	$ 58.48
Performance Shares
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period (in shares)	239,042
Granted in fiscal year, weighted average grant date fair value (in USD per share)	$ 55.43
Return on capital, performance cycle (in years)	3 years
Greenhouse gas emissions reductions, performance cycle	3 years
Relative shareholder return, performance cycle	3 years

Summary Of Significant Accoun_6

Summary Of Significant Accounting Policies (Components Of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	$ (15,476)	$ (55,060)
Other Comprehensive Gains and Losses Before Reclassifications	(39,113)	136,681
Amounts Reclassified From Other Comprehensive Income (Loss)	(21,564)	(14,240)
Ending balance	(76,153)	67,381
Gains and Losses on Derivative Financial Instruments
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	55,799	4,623
Other Comprehensive Gains and Losses Before Reclassifications	(39,113)	136,681
Amounts Reclassified From Other Comprehensive Income (Loss)	(21,564)	(14,240)
Ending balance	(4,878)	127,064
Funded Status of the Pension and Other Post-Retirement Benefit Plans
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(71,275)	(59,683)
Other Comprehensive Gains and Losses Before Reclassifications	0	0
Amounts Reclassified From Other Comprehensive Income (Loss)	0	0
Ending balance	$ (71,275)	$ (59,683)

Summary Of Significant Accoun_7

Summary Of Significant Accounting Policies (Reclassification Out Of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Reclassification Adjustments out of Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating Revenues	$ 549,482	$ 525,361
Total Before Income Tax	56,168	176,107
Income Tax Expense	(11,182)	(43,087)
Net Income Available for Common Stock	44,986	133,020
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	29,504	19,708
Income Tax Expense	(7,940)	(5,468)
Net Income Available for Common Stock	21,564	14,240
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	29,729	19,755
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	$ (225)	$ (47)

Summary Of Significant Accoun_8

Summary Of Significant Accounting Policies (Components Of Other Current Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Sep. 30, 2024
Summary Of Significant Accounting Policies [Line Items]
Prepayments	$ 13,890	$ 18,463
Prepaid Property and Other Taxes	14,301	14,187
Regulatory Assets	48,333	38,264
Other Current Assets	83,435	92,229
Federal
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	0	8,154
State
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	$ 6,911	$ 13,161

Summary Of Significant Accoun_9

Summary Of Significant Accounting Policies (Schedule Of Other Accruals And Current Liabilities) (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Sep. 30, 2024
Summary Of Significant Accounting Policies [Line Items]
Accrued Capital Expenditures	$ 52,852	$ 47,344
Regulatory Liabilities	24,235	29,352
Reserve for Gas Replacement	1,316	0
Liability for Royalty and Working Interests	23,673	15,007
Non-Qualified Benefit Plan Liability	14,135	14,135
Other	50,949	57,065
Other Accruals and Current Liabilities	172,409	162,903
Federal
Summary Of Significant Accounting Policies [Line Items]
Federal Income Taxes Payable	$ 5,249	$ 0

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	$ 513,836	$ 500,050
Alternative Revenue Programs	5,917	5,556
Derivative Financial Instruments	29,729	19,755
Total Revenues	549,482	525,361
All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Alternative Revenue Programs	0	0
Derivative Financial Instruments	0	0
Total Revenues	0	0
Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(95,630)	(87,666)
Alternative Revenue Programs	0	0
Derivative Financial Instruments	0	0
Total Revenues	(95,630)	(87,666)
Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	219,131	234,264
Alternative Revenue Programs	0	0
Derivative Financial Instruments	29,729	19,755
Total Revenues	248,860	254,019
Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	106,612	94,413
Alternative Revenue Programs	0	0
Derivative Financial Instruments	0	0
Total Revenues	106,612	94,413
Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	61,131	62,588
Alternative Revenue Programs	0	0
Derivative Financial Instruments	0	0
Total Revenues	61,131	62,588
Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	222,592	196,451
Alternative Revenue Programs	5,917	5,556
Derivative Financial Instruments	0	0
Total Revenues	228,509	202,007
Production of Natural Gas
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	217,458	232,661
Production of Natural Gas | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Production of Natural Gas | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Production of Natural Gas | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	217,458	232,661
Production of Natural Gas | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Production of Natural Gas | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Production of Natural Gas | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Production of Crude Oil
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	515	687
Production of Crude Oil | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Production of Crude Oil | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Production of Crude Oil | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	515	687
Production of Crude Oil | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Production of Crude Oil | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Production of Crude Oil | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Processing
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	275	267
Natural Gas Processing | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Processing | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Processing | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	275	267
Natural Gas Processing | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Processing | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Processing | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Gathering Service
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	3,448	4,596
Natural Gas Gathering Service | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Gathering Service | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(57,683)	(57,992)
Natural Gas Gathering Service | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	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
Natural Gas Gathering Service | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	61,131	62,588
Natural Gas Gathering Service | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Transportation Service
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	80,944	80,541
Natural Gas Transportation Service | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Transportation Service | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(27,181)	(20,362)
Natural Gas Transportation Service | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Transportation Service | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	81,204	71,618
Natural Gas Transportation Service | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Transportation Service | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	26,921	29,285
Natural Gas Storage Service
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	14,489	12,233
Natural Gas Storage Service | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Storage Service | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(10,504)	(9,059)
Natural Gas Storage Service | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Storage Service | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	24,993	21,292
Natural Gas Storage Service | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Storage Service | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Residential Sales
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	156,350	146,546
Natural Gas Residential Sales | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Residential Sales | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	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
Natural Gas Residential Sales | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Residential Sales | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Residential Sales | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	156,350	146,546
Natural Gas Commercial Sales
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	22,243	20,281
Natural Gas Commercial Sales | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Commercial Sales | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	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
Natural Gas Commercial Sales | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Commercial Sales | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Commercial Sales | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	22,243	20,281
Natural Gas Industrial Sales
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,337	904
Natural Gas Industrial Sales | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Industrial Sales | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(1)	(2)
Natural Gas Industrial Sales | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	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
Natural Gas Industrial Sales | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Natural Gas Industrial Sales | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,338	906
Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	16,777	1,334
Other | All Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Other | Corporate and Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(261)	(251)
Other | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	883	649
Other | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	415	1,503
Other | Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0
Other | Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	$ 15,740	$ (567)

Revenue from Contracts with C_4

Revenue from Contracts with Customers (Narrative) (Details) $ in Millions	Dec. 31, 2024 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 175.5
Remaining performance obligation, period	9 months
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	$ 196.7
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	$ 155
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	$ 135.4
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	$ 121
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 648.5
Remaining performance obligation, period

Fair Value Measurements - Recur

Fair Value Measurements - Recurring Fair Value Measures Of Assets And Liabilities (Details) - USD ($) $ in Thousands		Dec. 31, 2024	Sep. 30, 2024
Assets:
Cash Equivalents – Money Market Mutual Funds	[1]	$ 41,745	$ 29,238
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]	$ 90,962	$ 154,040
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]	$ 20,893	$ 4,735
Total Net Assets/(Liabilities)	[1]	70,069	149,305
Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset	[1]	12,717	58,811
Derivative Financial Instruments:
Derivative Liability	[1]	10,628	5,008
Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset	[1]	8,046	28,810
Derivative Financial Instruments:
Derivative Liability	[1]	8,886	(273)
Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset	[1]	380	729
Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset	[1]	(448)	(445)
Derivative Financial Instruments:
Derivative Liability	[1]	1,379	0
Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	12,241	19,523
Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	16,281	17,374
Level 1
Assets:
Cash Equivalents – Money Market Mutual Funds		41,745	29,238
Derivative Financial Instruments:
Total Assets		70,267	66,135
Derivative Financial Instruments:
Total Liabilities		0	0
Total Net Assets/(Liabilities)		70,267	66,135
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	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		12,241	19,523
Level 1 | Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments		16,281	17,374
Level 2
Assets:
Cash Equivalents – Money Market Mutual Funds		0	0
Derivative Financial Instruments:
Total Assets		62,795	109,603
Derivative Financial Instruments:
Total Liabilities		62,993	26,433
Total Net Assets/(Liabilities)		(198)	83,170
Level 2 | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset		43,937	76,009
Derivative Financial Instruments:
Derivative Liability		41,848	22,206
Level 2 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		18,426	32,584
Derivative Financial Instruments:
Derivative Liability		19,266	3,501
Level 2 | Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset		380	729
Level 2 | Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset		52	281
Derivative Financial Instruments:
Derivative Liability		1,879	726
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 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	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
Netting Adjustments
Assets:
Cash Equivalents – Money Market Mutual Funds	[1]	0	0
Derivative Financial Instruments:
Total Assets	[1]	(42,100)	(21,698)
Derivative Financial Instruments:
Total Liabilities	[1]	(42,100)	(21,698)
Total Net Assets/(Liabilities)	[1]	0	0
Netting Adjustments | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset	[1]	(31,220)	(17,198)
Derivative Financial Instruments:
Derivative Liability	[1]	(31,220)	(17,198)
Netting Adjustments | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset	[1]	(10,380)	(3,774)
Derivative Financial Instruments:
Derivative Liability	[1]	(10,380)	(3,774)
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]	(500)	(726)
Derivative Financial Instruments:
Derivative Liability	[1]	(500)	(726)
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
[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 Measures and Disclos

Fair Value Measures and Disclosures - Nonrecurring Fair Value Measures Within Level 3 (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Impairment of Assets	$ 141,802	$ 0
Level 3 | Fair Value, Nonrecurring | Exploration and Production
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Impairment of Assets	33,453	$ 0
Property, plant, and equipment, fair value	$ 12,880

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - California Asset Sale	12 Months Ended	36 Months Ended
	Dec. 31, 2023 USD ($)	Dec. 31, 2025 USD ($) payment
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
Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
ICE Brent Average (in dollars per barrel)	$ 95
Minimum | Forecast
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
ICE Brent Average (in dollars per barrel)		$ 95
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

Financial Instruments (Long-Ter

Financial Instruments (Long-Term Debt) (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Sep. 30, 2024
Financial Instruments, Owned, at Fair Value, by Type, Alternative [Abstract]
Carrying Amount	$ 2,689,421	$ 2,688,243
Fair Value	$ 2,618,660	$ 2,656,888

Financial Instruments (Other In

Financial Instruments (Other Investments) (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Sep. 30, 2024
Investment Holdings [Line Items]
Life Insurance Contracts	$ 42,971	$ 44,808
Other Investments	71,493	81,705
Equity Mutual Fund
Investment Holdings [Line Items]
Mutual Funds	12,241	19,523
Fixed Income Mutual Fund
Investment Holdings [Line Items]
Mutual Funds	$ 16,281	$ 17,374

Financial Instruments (Narrativ

Financial Instruments (Narrative) (Details) Bcf in Billions	3 Months Ended	12 Months Ended	36 Months Ended
	Dec. 31, 2024 USD ($) counterparty Bcf	Dec. 31, 2023 USD ($)	Dec. 31, 2025 USD ($) payment	Sep. 30, 2024 USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Foreign Currency Forward Contract Hedge Duration	6 years
After tax net hedging losses in accumulated other comprehensive income (loss)	$ (4,900,000)
After Tax Net Hedging Gains Reclassified Within Twelve Months	1,900,000
Fair market value of derivative liability with a credit-risk related contingency	5,900,000
Hedging Collateral Deposits	$ 0
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	18
Number of counterparties in net gain position | counterparty	8
Credit risk exposure per counterparty	$ 2,500,000
Maximum Credit Risk Exposure Per Counterparty	9,300,000
Collateral Received by the Company	$ 0
Number of counterparties with a common credit-risk related contingency | counterparty	12
Foreign Currency Contracts
Derivative Instruments, Gain (Loss) [Line Items]
Hedging Notional Amount of Forecasted Transportation Costs	$ 51,200,000
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 | 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
California Asset Sale | Present Value of Contingent Consideration
Derivative Instruments, Gain (Loss) [Line Items]
Value of Contingent Consideration Received from Sale of Assets	400,000			$ 700,000
California Asset Sale | Mark to Market of Contingent Consideration
Derivative Instruments, Gain (Loss) [Line Items]
Mark-to-Market Adjustment for Contingent Consideration	$ (300,000)
Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Hedge Duration	5 years
Cash Flow Hedges | Natural Gas Bcf
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk cash flow hedge derivatives, natural gas | Bcf	388.2

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
	Dec. 31, 2024	Dec. 31, 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)	$ (53,516)	$ 189,167
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	29,504	19,708
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)	(51,909)	187,989
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	29,729	19,755
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)	(1,607)	1,178
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	$ (225)	$ (47)

Income Taxes (Details)

Income Taxes (Details)	3 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Effective Tax Rate	19.90%	24.50%

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
		Dec. 31, 2024	Dec. 31, 2023
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)		91,005,993
Beginning balance		$ 2,848,343
Net Income Available for Common Stock		44,986	$ 133,020
Dividends Declared on Common Stock		(46,671)	(45,597)
Other Comprehensive Income (Loss), Net of Tax		$ (60,677)	$ 122,441
Share Repurchases (in shares)		(393,038)
Ending balance (in shares)		90,612,955
Ending balance		$ 2,752,813
Dividends per share (in dollars per share)		$ 0.515	$ 0.495
Share Repurchase Plan
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases (in shares)		(548,596)
Share Repurchases		$ (33,900)
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)		91,006,000	91,819,000
Beginning balance		$ 91,006	$ 91,819
Common stock issued under stock and benefit plans (in shares)		156,000	297,000
Common Stock Issued Under Stock and Benefit Plans		$ 156	$ 297
Ending balance (in shares)		90,613,000	92,116,000
Ending balance		$ 90,613	$ 92,116
Common Stock | Share Repurchase Plan
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases (in shares)		(549,000)
Share Repurchases		$ (549)
Paid In Capital
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance		1,045,487	1,040,761
Share-Based Payment Expense	[1]	4,090	4,135
Ending balance		1,039,705	1,041,226
Paid In Capital | Stock and Benefit Plans
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases		(3,511)	3,670
Paid In Capital | Share Repurchase Plan
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases		(6,361)
Earnings Reinvested in the Business
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance		1,727,326	1,885,856
Net Income Available for Common Stock		44,986	133,020
Dividends Declared on Common Stock		(46,671)	(45,597)
Share Repurchases		(26,993)	0
Ending balance		1,698,648	1,973,279
Earnings Reinvested in the Business | Share Repurchase Plan
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share Repurchases		(26,993)
Accumulated Other Comprehensive Income (Loss)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance		(15,476)	(55,060)
Other Comprehensive Income (Loss), Net of Tax		(60,677)	122,441
Ending balance		$ (76,153)	$ 67,381
[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 - Summary of Com

Capitalization - Summary of Common Stock Share Activity (Details)	3 Months Ended
	Dec. 31, 2024 shares
Schedule of Capitalization, Equity [Line Items]
Share Repurchases (in shares)	(393,038)
Director Equity Compensation Plan and Director and Officer DCP Plan
Schedule of Capitalization, Equity [Line Items]
Common stock issued (in shares)	10,169
Stock-Based Compensation Awards
Schedule of Capitalization, Equity [Line Items]
Share Repurchases (in shares)	(63,631)	[1]
Stock and Benefit Plans
Schedule of Capitalization, Equity [Line Items]
Common stock issued (in shares)	155,558
Share Repurchase Plan
Schedule of Capitalization, Equity [Line Items]
Share Repurchases (in shares)	(548,596)
Restricted Stock Units
Schedule of Capitalization, Equity [Line Items]
Common stock issued (in shares)	119,177
Performance Shares
Schedule of Capitalization, Equity [Line Items]
Common stock issued (in shares)	89,843
[1] The Company considers all shares tendered as cancelled shares restored to the status of authorized but unissued shares, in accordance with New Jersey law.

Capitalization (Narrative) (Det

Capitalization (Narrative) (Details) $ / shares in Units, $ in Thousands	3 Months Ended
	Dec. 31, 2024 USD ($) $ / shares shares	Jan. 30, 2025 bank	Sep. 30, 2024 USD ($)	May 31, 2024 USD ($) bank	Apr. 01, 2024 USD ($)	Mar. 08, 2024 USD ($)	Feb. 29, 2024 bank	Feb. 14, 2024 USD ($) lender	Feb. 28, 2022 USD ($) bank
Debt Instrument [Line Items]
Stock repurchase program, authorized amount						$ 200,000
Share Repurchases (in shares) | shares	393,038
Current Portion of Long-Term Debt	$ 500,000		$ 500,000
Share Repurchase Plan
Debt Instrument [Line Items]
Share Repurchases (in shares) | shares	548,596
Share repurchase program, average cost per share (in dollars per share) | $ / shares	$ 61.27
Share Repurchases	$ 33,900
Credit Agreement
Debt Instrument [Line Items]
Number of banks In syndicate | bank				3			11		12
Maximum borrowing capacity				$ 1,000,000					$ 1,000,000
Extended term of credit agreement							1 year
Credit Agreement | Subsequent Event
Debt Instrument [Line Items]
Number of banks In syndicate | bank		11
Extended term of credit agreement		1 year
7.38% Notes Due June 2025
Debt Instrument [Line Items]
Current Portion of Long-Term Debt	$ 50,000		$ 50,000
Long-term debt, interest rate	7.38%		7.38%
5.20% Notes Due July 2025
Debt Instrument [Line Items]
Current Portion of Long-Term Debt	$ 450,000		$ 450,000
Long-term debt, interest rate	5.20%		5.20%
Term Loan Agreement
Debt Instrument [Line Items]
Maximum borrowing capacity								$ 300,000
Number of lenders | lender								6
Long-term debt, face amount					$ 300,000
Proceeds from debt, net of issuance costs	$ 299,400
Rate adjustment to SOFR	0.0010
Spread on variable rate	1.375%
Term Loan Agreement | 5.78% Through February 2025
Debt Instrument [Line Items]
Long-term debt, variable interest rate	5.78%

Commitments And Contingencies (

Commitments And Contingencies (Details) - USD ($) $ in Thousands	Dec. 31, 2024	Sep. 30, 2024
Other Commitments [Line Items]
Estimated minimum liability for environmental remediation	$ 4,000
Other Regulatory Liabilities	147,561	$ 151,452
Environmental Site Remediation Costs
Other Commitments [Line Items]
Other Regulatory Liabilities	$ 3,300

Business Segment Information (N

Business Segment Information (Narrative) (Details)	3 Months Ended
	Dec. 31, 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
	Dec. 31, 2024	Dec. 31, 2023	Sep. 30, 2024
Segment Reporting Information [Line Items]
Revenue from External Customers	$ 549,482	$ 525,361
Intersegment Revenues	0	0
Segment Profit: Net Income (Loss)	44,986	133,020
Segment Assets:	8,301,448		$ 8,319,770
Total Reportable Segments | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	549,482	525,361
Intersegment Revenues	95,630	87,666
Segment Profit: Net Income (Loss)	45,321	131,914
Segment Assets:	8,502,635		8,476,875
Exploration and Production | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	248,860	254,019
Intersegment Revenues	0	0
Segment Profit: Net Income (Loss)	(46,777)	52,483
Segment Assets:	2,533,521		2,644,820
Pipeline and Storage | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	68,750	64,826
Intersegment Revenues	37,862	29,587
Segment Profit: Net Income (Loss)	32,454	24,055
Segment Assets:	2,475,767		2,446,243
Gathering | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	3,448	4,596
Intersegment Revenues	57,683	57,992
Segment Profit: Net Income (Loss)	27,145	28,825
Segment Assets:	1,039,149		987,103
Utility | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	228,424	201,920
Intersegment Revenues	85	87
Segment Profit: Net Income (Loss)	32,499	26,551
Segment Assets:	2,454,198		2,398,709
All Other | All Other
Segment Reporting Information [Line Items]
Revenue from External Customers	0	0
Intersegment Revenues	0	0
Segment Profit: Net Income (Loss)	(193)	(121)
Segment Assets:	7,931		6,227
Corporate and Intersegment Eliminations | Corporate
Segment Reporting Information [Line Items]
Revenue from External Customers	0	0
Corporate and Intersegment Eliminations | Corporate and Intersegment Eliminations
Segment Reporting Information [Line Items]
Intersegment Revenues	(95,630)	(87,666)
Segment Profit: Net Income (Loss)	(142)	$ 1,227
Segment Assets:	$ (209,118)		$ (163,332)

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
		Dec. 31, 2024	Dec. 31, 2023
Retirement Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost		$ 1,023	$ 1,049
Interest Cost		9,223	10,890
Expected Return on Plan Assets		(14,647)	(17,086)
Amortization of Prior Service Cost (Credit)		76	91
Amortization of (Gains) Losses		1,620	(335)
Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments)	[1]	(165)	4,057
Net Periodic Benefit Cost (Income)		(2,870)	(1,334)
Other Post-Retirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service Cost		130	109
Interest Cost		3,625	3,890
Expected Return on Plan Assets		(6,536)	(6,660)
Amortization of Prior Service Cost (Credit)		(107)	(107)
Amortization of (Gains) Losses		9	(567)
Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments)	[1]	(727)	2,238
Net Periodic Benefit Cost (Income)		$ (3,606)	$ (1,097)
[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)	3 Months Ended
	Dec. 31, 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		12 Months Ended			36 Months Ended
	Aug. 01, 2023	Sep. 30, 2027	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2027
NEW YORK | Forecast
Regulatory Matters [Line Items]
Rate plan period					3 years
Approved Return on Equity (as a percent)					9.70%
Increase in annual revenue requirement in first year				$ 57.3
Additional increase in annual revenue requirement in second year			$ 15.8
Additional increase in annual revenue requirement in third year		$ 12.7
Reduction to annual revenue requirement for actuarial projections of pension and other-post retirement benefit income expected to be recognized		$ 14	$ 14	$ 14
PENNSYLVANIA
Regulatory Matters [Line Items]
Public utilities authorized rate increase, amount	$ 23