National Fuel Gas (NFG) 10-Q 8 Feb 24 2024 Q1 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - $ / shares	3 Months Ended
	Dec. 31, 2023	Jan. 31, 2024
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Dec. 31, 2023
Document Transition Report	false
Entity File Number	1-3880
Amendment Flag	false
Entity Registrant Name	NATIONAL FUEL GAS COMPANY
Entity Incorporation, State or Country Code	NJ
Entity Tax Identification Number	13-1086010
Entity Address, Address Line One	6363 Main Street
Entity Address, City or Town	Williamsville,
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	14221
City Area Code	716
Local Phone Number	857-7000
Title of 12(b) Security	Common Stock, par value $1.00 per share
Trading Symbol	NFG
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Listing, Par Value Per Share	$ 1
Entity Common Stock, Shares Outstanding		92,127,623
Entity Central Index Key	0000070145
Current Fiscal Year End Date	--09-30
Document Fiscal Year Focus	2024
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, 2023	Dec. 31, 2022
INCOME
Operating Revenues	$ 525,361	$ 658,859
Operating Expenses:
Purchased Gas	56,552	171,197
Property, Franchise and Other Taxes	22,416	26,205
Depreciation, Depletion and Amortization	115,790	96,600
Total Operating Expenses	318,251	404,489
Operating Income	207,110	254,370
Other Income (Expense):
Other Income (Deductions)	3,732	6,318
Interest Expense on Long-Term Debt	(28,462)	(29,604)
Other Interest Expense	(6,273)	(3,843)
Income Before Income Taxes	176,107	227,241
Income Tax Expense	43,087	57,552
Net Income Available for Common Stock	133,020	169,689
EARNINGS REINVESTED IN THE BUSINESS
Balance at Beginning of Period	1,885,856	1,587,085
Beginning Retained Earnings Unappropriated And Current Period Net Income	2,018,876	1,756,774
Dividends on Common Stock	(45,597)	(43,598)
Balance at December 31	$ 1,973,279	$ 1,713,176
Basic:
Net Income Available for Common Stock (in dollars per share)	$ 1.45	$ 1.85
Diluted:
Net Income Available for Common Stock (in dollars per share)	$ 1.44	$ 1.84
Weighted Average Common Shares Outstanding:
Used in Basic Calculation (shares)	91,910,244	91,579,814
Used in Diluted Calculation (shares)	92,442,145	92,268,210
Dividends Per Common Share:
Dividends Declared (in dollars per share)	$ 0.495	$ 0.475
Utility
INCOME
Operating Revenues	$ 201,920	$ 311,619
Operating Expenses:
Operation and Maintenance	53,705	50,352
Exploration and Production and Other Revenues
INCOME
Operating Revenues	254,019	276,973
Operating Expenses:
Operation and Maintenance	34,826	26,874
Pipeline and Storage and Gathering Revenues
INCOME
Operating Revenues	69,422	70,267
Operating Expenses:
Operation and Maintenance	$ 34,962	$ 33,261

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Statement of Comprehensive Income [Abstract]
Net Income Available for Common Stock	$ 133,020	$ 169,689
Other Comprehensive Income (Loss), Before Tax:
Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	189,167	297,593
Reclassification Adjustment for Realized (Gains) Losses on Derivative Financial Instruments in Net Income	(19,708)	159,342
Other Comprehensive Income (Loss), Before Tax	169,459	456,935
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	52,486	81,377
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Derivative Financial Instruments in Net Income	(5,468)	43,571
Income Taxes – Net	47,018	124,948
Other Comprehensive Income (Loss)	122,441	331,987
Comprehensive Income	$ 255,461	$ 501,676

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Dec. 31, 2023	Sep. 30, 2023
ASSETS
Property, Plant and Equipment	$ 13,857,060	$ 13,635,303
Less - Accumulated Depreciation, Depletion and Amortization	6,435,129	6,335,441
Property, Plant and Equipment, Net, Total	7,421,931	7,299,862
Current Assets
Cash and Temporary Cash Investments	41,685	55,447
Receivables – Net of Allowance for Uncollectible Accounts of $37,116 and $36,295, Respectively	189,669	160,601
Unbilled Revenue	48,265	16,622
Gas Stored Underground	26,891	32,509
Materials and Supplies - at average cost	47,692	48,989
Other Current Assets	99,400	100,260
Total Current Assets	453,602	414,428
Other Assets
Recoverable Future Taxes	73,283	69,045
Unamortized Debt Expense	6,829	7,240
Other Regulatory Assets	72,088	72,138
Deferred Charges	80,347	82,416
Other Investments	76,633	73,976
Goodwill	5,476	5,476
Prepaid Pension and Post-Retirement Benefit Costs	208,015	200,301
Fair Value of Derivative Financial Instruments	184,739	50,487
Other	4,549	4,891
Total Other Assets	711,959	565,970
Total Assets	8,587,492	8,280,260
Capitalization:
Common Stock, $1 Par Value	92,116	91,819
Paid in Capital	1,041,226	1,040,761
Earnings Reinvested in the Business	1,973,279	1,885,856
Accumulated Other Comprehensive Income (Loss)	67,381	(55,060)
Total Comprehensive Shareholders’ Equity	3,174,002	2,963,376
Long-Term Debt, Net of Current Portion and Unamortized Discount and Debt Issuance Costs	2,385,523	2,384,485
Total Capitalization	5,559,525	5,347,861
Current and Accrued Liabilities
Notes Payable to Banks and Commercial Paper	300,000	287,500
Accounts Payable	105,390	152,193
Amounts Payable to Customers	60,032	59,019
Dividends Payable	45,597	45,451
Interest Payable on Long-Term Debt	42,288	20,399
Customer Advances	23,086	21,003
Customer Security Deposits	30,843	28,764
Other Accruals and Current Liabilities	200,009	160,974
Fair Value of Derivative Financial Instruments	0	31,009
Total Current and Accrued Liabilities	807,245	806,312
Other Liabilities
Deferred Income Taxes	1,164,512	1,124,170
Taxes Refundable to Customers	317,838	268,562
Cost of Removal Regulatory Liability	284,687	277,694
Other Regulatory Liabilities	165,988	165,441
Other Post-Retirement Liabilities	2,859	2,915
Asset Retirement Obligations	164,777	165,492
Other Liabilities	120,061	121,813
Total Other Liabilities	2,220,722	2,126,087
Commitments and Contingencies (Note 7)	0	0
Total Capitalization and Liabilities	$ 8,587,492	$ 8,280,260

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2023	Sep. 30, 2023
Statement of Financial Position [Abstract]
Receivables, allowance for uncollectible accounts	$ 37,116	$ 36,295
Common stock, par value (in dollars per share)	$ 1	$ 1
Common stock, shares authorized (in shares)	200,000,000	200,000,000
Common stock, shares issued (in shares)	92,115,581	91,819,405
Common stock, shares outstanding (in shares)	92,115,581	91,819,405

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
OPERATING ACTIVITIES
Net Income Available for Common Stock	$ 133,020	$ 169,689
Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities:
Depreciation, Depletion and Amortization	115,790	96,600
Deferred Income Taxes	38,362	53,457
Stock-Based Compensation	4,660	5,575
Other	8,041	4,078
Change in:
Receivables and Unbilled Revenue	(58,459)	(29,522)
Gas Stored Underground and Materials and Supplies	6,915	5,622
Unrecovered Purchased Gas Costs	0	20,603
Other Current Assets	892	(1,748)
Accounts Payable	(3,355)	6,091
Amounts Payable to Customers	1,013	(265)
Customer Advances	2,083	5,206
Customer Security Deposits	2,079	4,546
Other Accruals and Current Liabilities	28,612	4,523
Other Assets	(6,306)	(20,238)
Other Liabilities	(2,403)	3,122
Net Cash Provided by Operating Activities	270,944	327,339
INVESTING ACTIVITIES
Capital Expenditures	(246,938)	(233,473)
Sale of Fixed Income Mutual Fund Shares in Grantor Trust	0	10,000
Other	(920)	14,637
Net Cash Used in Investing Activities	(247,858)	(208,836)
FINANCING ACTIVITIES
Proceeds from Issuance of Short-Term Note Payable to Bank	0	250,000
Net Change in Other Short-Term Notes Payable to Banks and Commercial Paper	12,500	(60,000)
Reduction of Long-Term Debt	0	(150,000)
Dividends Paid on Common Stock	(45,451)	(43,452)
Net Repurchases of Common Stock	(3,897)	(6,694)
Net Cash Used in Financing Activities	(36,848)	(10,146)
Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash	(13,762)	108,357
Cash, Cash Equivalents, and Restricted Cash at October 1	55,447	137,718
Cash, Cash Equivalents, and Restricted Cash at December 31	41,685	246,075
Supplemental Disclosure of Cash Flow Information
Non-Cash Capital Expenditures	$ 97,922	$ 110,314

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	3 Months Ended
	Dec. 31, 2023
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 oil and gas producing properties accounted for under the full cost method of accounting. The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Earnings for Interim Periods. The Company, in its opinion, has included all adjustments (which consist of only normally recurring adjustments, unless otherwise disclosed in this Quarterly Report on Form 10-Q) that are necessary for a fair statement of the results of operations for the reported periods. The consolidated financial statements and notes thereto, included herein, should be read in conjunction with the financial statements and notes for the years ended September 30, 2023, 2022 and 2021 that are included in the Company's 2023 Form 10-K. The consolidated financial statements for the year ended September 30, 2024 will be audited by the Company's independent registered public accounting firm after the end of the fiscal year. The earnings for the three months ended December 31, 2023 should not be taken as a prediction of earnings for the entire fiscal year ending September 30, 2024. Most of the business of the Utility segment is seasonal in nature and is influenced by weather conditions. Due to the seasonal nature of the heating business in the Utility segment, earnings during the winter months normally represent a substantial part of the earnings that this business is expected to achieve for the entire fiscal year. The Company’s business segments are discussed more fully in Note 8 – Business Segment Information. Consolidated Statements of Cash Flows. The components, as reported on the Company’s Consolidated Balance Sheets, of the total cash, cash equivalents, and restricted cash presented on the Statement of Cash Flows are as follows (in thousands): Three Months Ended Three Months Ended Balance at Balance at October 1, 2023 Balance at Balance at October 1, 2022 Cash and Temporary Cash Investments $ 41,685 $ 55,447 $ 244,475 $ 46,048 Hedging Collateral Deposits — — 1,600 91,670 Cash, Cash Equivalents, and Restricted Cash $ 41,685 $ 55,447 $ 246,075 $ 137,718 The Company considers all highly liquid debt instruments purchased with a maturity date of generally three months or less to be cash equivalents. The Company’s restricted cash is composed entirely of amounts reported as Hedging Collateral Deposits on the Consolidated Balance Sheets. Hedging Collateral Deposits is an account title for cash held in margin accounts funded by the Company to serve as collateral for derivative financial instruments in an unrealized loss position. In accordance with its accounting policy, the Company does not offset hedging collateral deposits paid or received against related derivative financial instruments liability or asset balances. Allowance for Uncollectible Accounts. The allowance for uncollectible accounts is the Company’s best estimate of the amount of probable credit losses in the existing accounts receivable. The allowance, the majority of which is in the Utility segment, is determined based on historical experience, the age of customer accounts, other specific information about customer accounts, and the economic and regulatory environment. Account balances have historically been written off against the allowance approximately twelve months after the account is final billed or when it is anticipated that the receivable will not be recovered. During 2022 and 2021, final billings were suppressed in the Utility segment as a result of state shut-off moratoriums arising from the COVID-19 pandemic. Those moratoriums were lifted in 2022 which allowed for the resumption of final billings during 2022, thereby resulting in higher amounts being written off in 2023 and 2024. Activity in the allowance for uncollectible accounts for the three months ended December 31, 2023 and 2022 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, 2023 Allowance for Uncollectible Accounts $ 36,295 $ 4,157 $ 119 $ (3,455) $ 37,116 Three Months Ended December 31, 2022 Allowance for Uncollectible Accounts $ 40,228 $ 5,035 $ 228 $ (1,566) $ 43,925 Gas Stored Underground. In the Utility segment, gas stored underground is carried at lower of cost or net realizable value, on a LIFO method. Gas stored underground normally declines during the first and second quarters of the year and is replenished during the third and fourth quarters. In the Utility segment, the current cost of replacing gas withdrawn from storage is recorded in the Consolidated Statements of Income and a reserve for gas replacement is recorded in the Consolidated Balance Sheets under the caption “Other Accruals and Current Liabilities.” Such reserve, which amounted to $1.2 million at December 31, 2023, 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, oil and gas 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 oil and gas properties unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves of oil and gas attributable to a cost center. The Company's capitalized costs relating to oil and gas producing activities, net of accumulated depreciation, depletion and amortization, were $2.5 billion and $2.4 billion at December 31, 2023 and September 30, 2023, respectively. Capitalized costs include costs related to unproved properties, which are excluded from amortization until proved reserves are found or it is determined that the unproved properties are impaired. Such costs amounted to $159.1 million and $161.1 million at December 31, 2023 and September 30, 2023, respectively. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. The amount of any impairment is transferred to the pool of capitalized costs being amortized. Capitalized costs are subject to the SEC full cost ceiling test. The ceiling test, which is performed each quarter, determines a limit, or ceiling, on the amount of property acquisition, exploration and development costs that can be capitalized. The ceiling under this test represents (a) the present value of estimated future net cash flows, excluding future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet, using a discount factor of 10%, which is computed by applying prices of oil and gas (as adjusted for hedging) to estimated future production of proved oil and gas 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 gas and oil prices used to calculate the full cost ceiling are based on an unweighted arithmetic average of the first day of the month oil and gas prices 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. At December 31, 2023, the ceiling exceeded the book value of the oil and gas properties by approximately $84.4 million. The estimated future net cash flows were increased by $307.0 million for hedging under the ceiling test at December 31, 2023. 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, 2023. Accumulated Other Comprehensive Income (Loss). The components of Accumulated Other Comprehensive Income (Loss) and changes for the three months ended December 31, 2023 and 2022, 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, 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 Three Months Ended December 31, 2022 Balance at October 1, 2022 $ (572,163) $ (53,570) $ (625,733) Other Comprehensive Gains and Losses Before Reclassifications 216,216 — 216,216 Amounts Reclassified From Other Comprehensive Income 115,771 — 115,771 Balance at December 31, 2022 $ (240,176) $ (53,570) $ (293,746) 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, 2023 and 2022 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 2023 2022 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $19,755 ($159,162) Operating Revenues Foreign Currency Contracts (47) (180) Operating Revenues 19,708 (159,342) Total Before Income Tax (5,468) 43,571 Income Tax Expense $14,240 ($115,771) Net of Tax Other Current Assets . The components of the Company’s Other Current Assets are as follows (in thousands): At December 31, 2023 At September 30, 2023 Prepayments $ 17,993 $ 18,966 Prepaid Property and Other Taxes 14,778 14,186 Federal Income Taxes Receivable 10,799 14,602 State Income Taxes Receivable 18,208 16,133 Regulatory Assets 37,622 36,373 $ 99,400 $ 100,260 Other Accruals and Current Liabilities . The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At December 31, 2023 At September 30, 2023 Accrued Capital Expenditures $ 75,485 $ 43,323 Regulatory Liabilities 35,770 38,105 Reserve for Gas Replacement 1,247 — Liability for Royalty and Working Interests 25,529 17,679 Non-Qualified Benefit Plan Liability 13,052 13,052 Other 48,926 48,815 $ 200,009 $ 160,974 Earnings Per Common Share. Basic earnings per common share is computed by dividing income or loss by the weighted average number of common shares outstanding for the period. Diluted earnings per common share reflects the potential dilution that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. For purposes of determining earnings per common share, the potentially dilutive securities the Company had outstanding were restricted stock units and performance shares. For the quarter ended December 31, 2023, the diluted weighted average shares outstanding shown on the Consolidated Statements of Income reflects the potential dilution as a result of these securities as determined using the Treasury Stock Method. Restricted stock units and performance shares that are antidilutive are excluded from the calculation of diluted earnings per common share. There were no securities excluded as being antidilutive for the quarter ended December 31, 2023. For the quarter ended December 31, 2022, 1,987 securities were excluded as being antidilutive. Stock-Based Compensation. The Company granted 361,729 performance shares during the quarter ended December 31, 2023. The weighted average fair value of such performance shares was $44.23 per share for the quarter ended December 31, 2023. 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, 2023 include awards that must meet a performance goal related to either relative return on capital over a three-year or five-year performance cycle ("ROC performance shares"), methane intensity and greenhouse gas emissions reductions over a three-year performance cycle ("ESG performance shares") or relative shareholder return over a three-year or five-year performance cycle ("TSR performance shares"). The performance goal related to the ROC performance shares over the respective performance cycles is the Company’s total return on capital relative to the total return on capital of other companies in a group selected by the Compensation Committee (“Report Group”). Total return on capital for a given company means the average of the Report Group companies’ returns on capital for each twelve-month period corresponding to each of the Company’s fiscal years during the performance cycle, based on data reported for the Report Group companies in the Bloomberg database. The number of these ROC performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value of the ROC performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the ESG performance shares over the three-year performance cycle consists of two parts: reductions in the rates of intensity of methane emissions for each of the Company's operating segments, and reduction of the consolidated Company's total greenhouse gas emissions. The Company's Compensation Committee set specific target levels for methane intensity rates and total greenhouse gas emissions, and the performance goal is intended to incentivize and reward performance to the extent management achieves methane intensity and greenhouse gas reduction targets making progress towards the Company's 2030 goals. The number of these ESG performance shares that will vest and be paid out will depend upon the number of methane intensity segment targets achieved and whether the Company meets the total greenhouse gas emissions target. The fair value of these ESG performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the TSR performance shares over the respective performance cycles is the Company’s three-year (or five-year) total shareholder return relative to the three-year (or five-year) total shareholder return of the other companies in the Report Group. Three-year (or five-year) total shareholder return for a given company will be based on the data reported for that company (with the starting and ending stock prices over the performance cycle calculated as the average closing stock price for the prior calendar month and with dividends reinvested in that company’s securities at each ex-dividend date) in the Bloomberg database. The number of these TSR performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value price at the date of grant for the TSR performance shares is determined using a Monte Carlo simulation technique, which includes a reduction in value for the present value of forgone dividends over the vesting term of the award. This price is multiplied by the number of TSR performance shares awarded, the result of which is recorded as compensation expense over the vesting term of the award. The Company granted 219,578 restricted stock units during the quarter ended December 31, 2023. The weighted average fair value of such restricted stock units was $42.44 per share for the quarter ended December 31, 2023. 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, 2023
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, 2023 and 2022, presented by type of service from each reportable segment. 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 Quarter Ended December 31, 2022 (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 $ 432,359 $ — $ — $ — $ — $ — $ 432,359 Production of Crude Oil 628 — — — — — 628 Natural Gas Processing 374 — — — — — 374 Natural Gas Gathering Service — — 56,413 — — (53,767) 2,646 Natural Gas Transportation Service — 76,201 — 28,378 — (20,817) 83,762 Natural Gas Storage Service — 21,286 — — — (8,996) 12,290 Natural Gas Residential Sales — — — 244,306 — — 244,306 Natural Gas Commercial Sales — — — 34,495 — — 34,495 Natural Gas Industrial Sales — — — 1,638 — — 1,638 Other 2,774 168 — (259) — (283) 2,400 Total Revenues from Contracts with Customers 436,135 97,655 56,413 308,558 — (83,863) 814,898 Alternative Revenue Programs — — — 3,123 — — 3,123 Derivative Financial Instruments (159,162) — — — — — (159,162) Total Revenues $ 276,973 $ 97,655 $ 56,413 $ 311,681 $ — $ (83,863) $ 658,859 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: $159.1 million for the remainder of fiscal 2024; $191.6 million for fiscal 2025; $149.2 million for fiscal 2026; $123.3 million for fiscal 2027; $107.5 million for fiscal 2028; and $581.0 million thereafter.

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Dec. 31, 2023
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, 2023 and September 30, 2023. Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Recurring Fair Value Measures At fair value as of December 31, 2023 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 32,781 $ — $ — $ — $ 32,781 Derivative Financial Instruments: Over the Counter Swaps – Gas — 140,548 — (16,722) 123,826 Over the Counter No Cost Collars – Gas — 57,917 — — 57,917 Contingent Consideration for Asset Sale — 3,078 — — 3,078 Foreign Currency Contracts — 505 — (587) (82) Other Investments: Balanced Equity Mutual Fund 17,484 — — — 17,484 Fixed Income Mutual Fund 16,510 — — — 16,510 Total $ 66,775 $ 202,048 $ — $ (17,309) $ 251,514 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 16,722 $ — $ (16,722) $ — Foreign Currency Contracts — 587 — (587) — Total $ — $ 17,309 $ — $ (17,309) $ — Total Net Assets/(Liabilities) $ 66,775 $ 184,739 $ — $ — $ 251,514 Recurring Fair Value Measures At fair value as of September 30, 2023 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 39,332 $ — $ — $ — $ 39,332 Derivative Financial Instruments: Over the Counter Swaps – Gas — 65,800 — (37,508) 28,292 Over the Counter No Cost Collars – Gas — 30,966 — (14,745) 16,221 Contingent Consideration for Asset Sale — 7,277 — — 7,277 Foreign Currency Contracts — 150 — (1,453) (1,303) Other Investments: Balanced Equity Mutual Fund 15,837 — — — 15,837 Fixed Income Mutual Fund 15,897 — — — 15,897 Total $ 71,066 $ 104,193 $ — $ (53,706) $ 121,553 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 68,311 $ — $ (37,508) $ 30,803 Over the Counter No Cost Collars – Gas — 14,950 — (14,745) 205 Foreign Currency Contracts — 1,454 — (1,453) 1 Total $ — $ 84,715 $ — $ (53,706) $ 31,009 Total Net Assets/(Liabilities) $ 71,066 $ 19,478 $ — $ — $ 90,544 (1) Netting Adjustments represent the impact of legally-enforceable master netting arrangements that allow the Company to net gain and loss positions held with the same counterparties. The net asset or net liability for each counterparty is recorded as an asset or liability on the Company’s balance sheet. Derivative Financial Instruments The derivative financial instruments reported in Level 2 at December 31, 2023 and September 30, 2023 include natural gas price swap agreements, natural gas no cost collars, and foreign currency contracts, all of which are used in the Company’s Exploration and Production segment. The fair value of the Level 2 price swap agreements and no cost collars is based on an internal cash flow model that uses observable inputs (i.e. SOFR based discount rates for the price swap agreements and basis differential information, if applicable, at active natural gas trading markets). The fair value of the Level 2 foreign currency contracts is determined using the market approach based on observable market transactions of forward Canadian currency rates. The authoritative guidance for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2023, 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, 2023 also includes the contingent consideration associated with the sale of the Exploration and Production segment's California assets on June 30, 2022. The terms of the purchase and sale agreement specified that the Company could receive up to three annual contingent payments between calendar year 2023 and calendar year 2025, not to exceed $10 million per year, with the amount of each annual payment calculated at $1.0 million for each $1 per barrel that the ICE Brent Average for each calendar year exceeds $95 per barrel up to $105 per barrel. The calendar 2023 contingency period expired with the ICE Brent Average falling below $95 per barrel. The fair value of the contingent consideration was calculated using a Monte Carlo simulation model that uses observable inputs, including the ICE Brent closing price as of the valuation date, initial and max trigger price, volatility, risk-free rate, time of maturity and counterparty risk.

Financial Instruments

Financial Instruments	3 Months Ended
	Dec. 31, 2023
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, 2023 September 30, 2023 Carrying Fair Value Carrying Fair Value Long-Term Debt $ 2,385,523 $ 2,286,446 $ 2,384,485 $ 2,210,478 The fair value amounts are not intended to reflect principal amounts that the Company will ultimately be required to pay. Carrying amounts for other financial instruments recorded on the Company’s Consolidated Balance Sheets approximate fair value. The fair value of long-term debt was calculated using observable inputs (U.S. Treasuries 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, 2023 At September 30, 2023 Life Insurance Contracts $ 42,639 $ 42,242 Equity Mutual Fund 17,484 15,837 Fixed Income Mutual Fund 16,510 15,897 $ 76,633 $ 73,976 Investments in life insurance contracts are stated at their cash surrender values or net present value. Investments in an equity mutual fund and a fixed income mutual fund are stated at fair value based on quoted market prices with changes in fair value recognized in net income. The insurance contracts and equity mutual fund are primarily informal funding mechanisms for various benefit obligations the Company has to certain employees. The fixed income mutual fund is primarily an informal funding mechanism for certain regulatory obligations that the Company has to Utility segment customers in its Pennsylvania jurisdiction and for various benefit obligations the Company has to certain employees. Derivative Financial Instruments. The Company uses derivative financial instruments to manage commodity price risk in the Exploration and Production segment. The Company enters into over-the-counter no cost collar and swap agreements for natural gas to manage the price risk associated with forecasted sales of natural gas. In addition, the Company also enters into foreign exchange forward contracts to manage the risk of currency fluctuations associated with transportation costs denominated in Canadian currency in the Exploration and Production segment. These instruments are accounted for as cash flow hedges. The duration of the Company’s cash flow hedges does not typically exceed 5 years while the foreign currency forward contracts do not exceed 7 years. On June 30, 2022, the Company completed the sale of Seneca’s California assets. The terms of the purchase and sale agreement specified that the Company could receive up to three annual contingent payments between calendar year 2023 and calendar year 2025, not to exceed $10 million per year, with the amount of each annual payment calculated as $1.0 million for each $1 per barrel that the ICE Brent Average for each calendar year exceeds $95 per barrel up to $105 per barrel. The calendar 2023 contingency period expired with the ICE Brent Average falling below $95 per barrel. The Company has determined that this contingent consideration meets the definition of a derivative under the authoritative accounting guidance. Changes in the fair value of this contingent consideration are marked-to-market each reporting period, with changes in fair value recognized in Other Income (Deductions) on the Consolidated Statement of Income. The fair value of this contingent consideration was estimated to be $3.1 million and $7.3 million at December 31, 2023 and September 30, 2023, respectively. A $4.2 million mark-to-market adjustment to reduce the fair value of the contingent consideration was recorded during the quarter ended December 31, 2023. 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, 2023 and September 30, 2023. Cash Flow Hedges For derivative financial instruments that are designated and qualify as a cash flow hedge, the gain or loss on the derivative is reported as a component of other comprehensive income (loss) and reclassified into earnings in the period or periods during which the hedged transaction affects earnings. As of December 31, 2023, the Company had 380.2 Bcf of natural gas commodity derivative contracts (swaps and no cost collars) outstanding. As of December 31, 2023, the Company was hedging a total of $53.7 million of forecasted transportation costs denominated in Canadian dollars with foreign currency forward contracts. As of December 31, 2023, the Company had $127.1 million of net hedging gains after taxes included in the accumulated other comprehensive income (loss) balance. Of this amount, it is expected that $92.3 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, 2023 and 2022 (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 2023 2022 2023 2022 Commodity Contracts $ 187,989 $ 297,120 Operating Revenue $ 19,755 $ (159,162) Foreign Currency Contracts 1,178 473 Operating Revenue (47) (180) Total $ 189,167 $ 297,593 $ 19,708 $ (159,342) Credit Risk The Company may be exposed to credit risk on any of the derivative financial instruments that are in a gain position. Credit risk relates to the risk of loss that the Company would incur as a result of nonperformance by counterparties pursuant to the terms of their contractual obligations. To mitigate such credit risk, management performs a credit check, and then on a quarterly basis monitors counterparty credit exposure. The majority of the Company’s counterparties are financial institutions and energy traders. The Company has over-the-counter swap positions, no cost collars and applicable foreign currency forward contracts with nineteen counterparties of which all nineteen are in a net gain position. On average, the Company had $9.6 million of credit exposure per counterparty in a gain position at December 31, 2023. The maximum credit exposure per counterparty in a gain position at December 31, 2023 was $35.6 million. As of December 31, 2023, 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, 2023, sixteen of the nineteen counterparties to the Company’s outstanding derivative financial contracts (specifically the over-the-counter swaps, over-the-counter no cost collars and applicable foreign currency forward contracts) had a common credit-risk related contingency feature. In the event the Company’s credit rating increases or falls below a certain threshold (applicable debt ratings), the available credit that could be extended to the Company when it is in a derivative financial liability position would either increase or decrease. A decline in the Company’s credit rating, in and of itself, would not cause the Company to be required to post or increase the level of its hedging collateral deposits (in the form of cash deposits, letters of credit or treasury debt instruments). If the Company’s outstanding derivative financial instrument contracts with a credit-risk contingency feature were in a liability position (or if the liability were larger) and/or the Company’s credit rating declined, then hedging collateral deposits or an increase to such deposits could be required. At December 31, 2023, the Company did not have any derivative financial instrument liabilities with a credit-risk related contingency feature according to the Company’s internal model (discussed in Note 3 – Fair Value Measurements), and no hedging collateral deposits were required to be posted by the Company at December 31, 2023. Depending on the movement of commodity prices in the future, it is possible that the Company's derivative asset positions could swing into liability positions, at which point the Company could be required to post hedging collateral deposits.

Income Taxes

Income Taxes	3 Months Ended
	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The effective tax rates for the quarters ended December 31, 2023 and December 31, 2022 were 24.5% and 25.3%, respectively. The reduction in effective income tax rates was primarily driven by a methodology change for repairs and maintenance tax deductions.

Capitalization

Capitalization	3 Months Ended
	Dec. 31, 2023
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, 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 Balance at October 1, 2022 91,478 $ 91,478 $ 1,027,066 $ 1,587,085 $ (625,733) Net Income Available for Common Stock 169,689 Dividends Declared on Common Stock ($0.475 Per Share) (43,598) Other Comprehensive Income, Net of Tax 331,987 Share-Based Payment Expense (1) 5,118 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 309 309 (6,545) Balance at December 31, 2022 91,787 $ 91,787 $ 1,025,639 $ 1,713,176 $ (293,746) (1) Paid in Capital includes compensation costs associated with performance shares and/or restricted stock awards. The expense is included within Net Income Available For Common Stock, net of tax benefits. Common Stock. During the three months ended December 31, 2023, the Company issued 111,832 original issue shares of common stock for restricted stock units that vested and 251,255 original issue shares of common stock for performance shares that vested. The Company also issued 9,128 original issue shares of common stock to the non-employee directors of the Company who receive compensation under the Company’s 2009 Non-Employee Director Equity Compensation Plan, including the reinvestment of dividends for certain non-employee directors who elected to defer their shares pursuant to the dividend reinvestment feature of the Company's Deferred Compensation Plan for Directors and Officers (the "DCP") during the three months ended December 31, 2023. In addition, the Company issued 1,055 original issue shares of common stock to officers of the Company who elected to defer their shares pursuant to the dividend reinvestment feature of the Company's DCP Plan during the three months ended December 31, 2023. Holders of stock-based compensation awards will often tender shares of common stock to the Company for payment of applicable withholding taxes. During the three months ended December 31, 2023, 77,094 shares of common stock were tendered to the Company for such purposes. The Company considers all shares tendered as cancelled shares restored to the status of authorized but unissued shares, in accordance with New Jersey law. Short-Term Borrowings. On February 28, 2022, the Company entered into a Credit Agreement (as amended from time to time, the "Credit Agreement") with a syndicate of twelve banks. The Credit Agreement replaced the previous Fourth Amended and Restated Credit Agreement and a previous 364-Day Credit Agreement. The Credit Agreement provides a $1.0 billion unsecured committed revolving credit facility with a maturity date of February 26, 2027. On February 7, 2024, the Company and certain lenders under the Credit Agreement consented to an extension of the maturity date of the Credit Agreement from February 26, 2027 to February 25, 2028. As a result, the Company has aggregate commitments available under the Credit Agreement of $1.0 billion before February 26, 2027, and $940 million in aggregate commitments available on and after February 26, 2027 to February 25, 2028. Current Portion of Long-Term Debt. None of the Company's long-term debt as of December 31, 2023 and September 30, 2023 had a maturity date within the following twelve-month period.

Commitments And Contingencies

Commitments And Contingencies	3 Months Ended
	Dec. 31, 2023
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, 2023, the Company has estimated its remaining clean-up costs related to former manufactured gas plant sites will be approximately $3.2 million. The Company's liability for such clean-up costs has been recorded in Other Liabilities on the Consolidated Balance Sheet at December 31, 2023. The Company has recovered its environmental clean-up costs through rate recovery and is currently not aware of any material additional exposure to environmental liabilities. However, changes in environmental laws and regulations, new information or other factors could have an adverse financial impact on the Company. Northern Access Project. On February 3, 2017, Supply Corporation and Empire received FERC approval of the Northern Access project described herein. Shortly thereafter, the NYDEC issued a Notice of Denial of the federal Clean Water Act Section 401 Water Quality Certification and other state stream and wetland permits for the New York portion of the project (the Water Quality Certification for the Pennsylvania portion of the project was received in January of 2017). Subsequently, FERC issued an Order finding that the NYDEC exceeded the statutory time frame to take action under the Clean Water Act and, therefore, waived its opportunity to approve or deny the Water Quality Certification. FERC denied rehearing requests associated with its Order and FERC's decisions were appealed. The Second Circuit Court of Appeals issued an order upholding the FERC waiver orders. In addition, in the Company's state court litigation challenging the NYDEC's actions with regard to various state permits, the New York State Supreme Court issued a decision finding these permits to be preempted. The Company remains committed to the project and, on June 29, 2022, received an extension of time from FERC, until December 31, 2024, to construct the project which is the subject of an ongoing appeal at the U.S. Court of Appeals for the D.C. Circuit. As of December 31, 2023, the Company has spent approximately $56.0 million on the project, all of which is recorded on the balance sheet. Other. The Company is involved in other litigation and regulatory matters arising in the normal course of business. These other matters may include, for example, negligence claims and tax, regulatory or other governmental audits, inspections, investigations and other proceedings. These matters may involve state and federal taxes, safety, compliance with regulations, rate base, cost of service and purchased gas cost issues, among other things. While these other matters arising in the normal course of business could have a material effect on earnings and cash flows in the period in which they are resolved, an estimate of the possible loss or range of loss, if any, cannot be made at this time.

Business Segment Information

Business Segment Information	3 Months Ended
	Dec. 31, 2023
Segment Reporting [Abstract]
Business Segment Information	Business Segment Information The Company reports financial results for four segments: Exploration and Production, Pipeline and Storage, Gathering and Utility. The division of the Company’s operations into reportable segments is based upon a combination of factors including differences in products and services, regulatory environment and geographic factors. The data presented in the tables below reflect financial information for the segments and reconcile to consolidated amounts. As stated in the 2023 Form 10-K, the Company evaluates segment performance based on income before discontinued operations (when applicable). When this is not applicable, the Company evaluates performance based on net income. There have not been any changes in the basis of segmentation nor in the basis of measuring segment profit or loss from those used in the Company’s 2023 Form 10-K. A listing of segment assets at December 31, 2023 and September 30, 2023 is shown in the tables below. 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 (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, 2023 $3,057,345 $2,439,479 $936,547 $2,301,116 $8,734,487 $4,758 $(151,753) $8,587,492 At September 30, 2023 $2,814,218 $2,427,214 $912,923 $2,247,743 $8,402,098 $4,795 $(126,633) $8,280,260 Quarter Ended December 31, 2022 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $276,973 $67,621 $2,646 $311,619 $658,859 $— $— $658,859 Intersegment Revenues $— $30,034 $53,767 $62 $83,863 $— $(83,863) $— Segment Profit: Net Income (Loss) $91,192 $29,476 $24,738 $23,817 $169,223 $(280) $746 $169,689

Retirement Plan And Other Post-

Retirement Plan And Other Post-Retirement Benefits	3 Months Ended
	Dec. 31, 2023
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, 2023 2022 2023 2022 Service Cost $ 1,049 $ 1,297 $ 109 $ 147 Interest Cost 10,890 10,629 3,890 3,912 Expected Return on Plan Assets (17,086) (16,648) (6,660) (6,403) Amortization of Prior Service Cost (Credit) 91 109 (107) (107) Amortization of (Gains) Losses (335) (1,920) (567) (2,189) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 4,057 5,378 2,238 3,820 Net Periodic Benefit Cost (Income) $ (1,334) $ (1,155) $ (1,097) $ (820) (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, 2023. In the remainder of fiscal 2024, the Company expects its contributions to the Retirement Plan to be in the range of zero to $5.0 million. The Company did not make any contributions to its VEBA trusts for its other post-retirement benefits during the three months ended December 31, 2023, and does not anticipate making any such contributions during the remainder of fiscal 2024.

Regulatory Matters

Regulatory Matters	3 Months Ended
	Dec. 31, 2023
Regulatory Assets and Liabilities, Other Disclosure [Abstract]
Regulatory Matters	Regulatory Matters New York Jurisdiction Distribution Corporation's current delivery rates in its New York jurisdiction were approved by the NYPSC in an order issued on April 20, 2017 with rates becoming effective May 1, 2017 ("2017 Rate Order"). The 2017 Rate Order provided for a return on equity of 8.7% and directed the implementation of an earnings sharing mechanism to be in place beginning on April 1, 2018. On October 31, 2023, Distribution Corporation made a filing with the NYPSC seeking an increase of approximately $88 million in its total annual operating revenues for the projected rate year ending September 30, 2025, with a proposed effective date of October 1, 2024 that includes the maximum suspension period permitted under the New York Public Service Law ("2023 Rate Filing"). The Company is also proposing, among other things, to continue its leak prone pipe replacement program and to implement a number of initiatives that will facilitate achievement of the emissions reduction goals of the CLCPA. On August 13, 2021, the NYPSC issued an order extending the date through which qualified pipeline replacement costs incurred by the Company can be recovered using the existing system modernization tracker for two years (until March 31, 2023). On December 9, 2022, the Company filed a petition with the NYPSC to effectuate a system improvement tracker through which qualified pipeline replacement costs through September 30, 2024 would be tracked and recovered, and to recover certain deferred costs associated with the existing system modernization tracker, effective April 1, 2023. The NYPSC approved the petition by order dated March 17, 2023 contingent on the Company not filing a base rate case that would result in new rates becoming effective prior to October 1, 2024. The 2023 Rate Filing proposes to stop accruing and collecting revenues under its current system modernization and system improvement trackers and shift those revenues into the Company’s new base delivery rates. In the absence of a multi-year rate plan settlement, the Company is requesting that it be allowed to reinstate a tracking mechanism similar to the existing system modernization tracker. Pennsylvania Jurisdiction On October 28, 2022, Distribution Corporation made a filing with the PaPUC seeking an increase in its annual base rate operating revenues of $28.1 million. A settlement involving all active parties to the proceeding was reached and filed with the PaPUC on April 13, 2023. The settlement provided for, among other things, an increase in Distribution Corporation’s annual base rate operating revenues of $23 million. The PaPUC approved the settlement in full, without modification or correction, on June 15, 2023 and new rates went into effect on August 1, 2023. FERC Jurisdiction Supply Corporation filed a NGA Section 4 rate case at FERC on July 31, 2023 proposing rate increases to be effective February 1, 2024. The proposed rates reflect an annual cost of service of $385.4 million, a rate base of $1.32 billion and a proposed cost of equity of 15.12%. If the proposed rate increases finally approved at the end of the proceeding exceed the rates that were in effect at July 31, 2023, but are less than rates put into effect subject to refund on February 1, 2024, Supply Corporation would be required to refund the difference between the rates collected subject to refund and the final approved rates, with interest at the FERC-approved rate. If the rates approved at the end of the proceeding are lower than the rates in effect at July 31, 2023, such lower rates will become effective prospectively from the effective date provided by the applicable FERC order, and refunds with interest will be limited to the difference between the rates collected subject to refund and the rates in effect at July 31, 2023. Empire’s 2019 rate settlement provides that Empire must make a rate case filing no later than May 1, 2025.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Pay vs Performance Disclosure
Net Income Available for Common Stock	$ 133,020	$ 169,689

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Dec. 31, 2023
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, 2023
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 oil and gas producing properties accounted for under the full cost method of accounting. The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Earnings For Interim Periods	Earnings for Interim Periods. The Company, in its opinion, has included all adjustments (which consist of only normally recurring adjustments, unless otherwise disclosed in this Quarterly Report on Form 10-Q) that are necessary for a fair statement of the results of operations for the reported periods. The consolidated financial statements and notes thereto, included herein, should be read in conjunction with the financial statements and notes for the years ended September 30, 2023, 2022 and 2021 that are included in the Company's 2023 Form 10-K. The consolidated financial statements for the year ended September 30, 2024 will be audited by the Company's independent registered public accounting firm after the end of the fiscal year.
Consolidated Statements of Cash Flows	The Company considers all highly liquid debt instruments purchased with a maturity date of generally three months or less to be cash equivalents. The Company’s restricted cash is composed entirely of amounts reported as Hedging Collateral Deposits on the Consolidated Balance Sheets. Hedging Collateral Deposits is an account title for cash held in margin accounts funded by the Company to serve as collateral for derivative financial instruments in an unrealized loss position. In accordance with its accounting policy, the Company does not offset hedging collateral deposits paid or received against related derivative financial instruments liability or asset balances.
Allowance for Uncollectible Accounts	Allowance for Uncollectible Accounts.
Gas Stored Underground	Gas Stored Underground. In the Utility segment, gas stored underground is carried at lower of cost or net realizable value, on a LIFO method. Gas stored underground normally declines during the first and second quarters of the year and is replenished during the third and fourth quarters. In the Utility segment, the current cost of replacing gas withdrawn from storage is recorded in the Consolidated Statements of Income and a reserve for gas replacement is recorded in the Consolidated Balance Sheets under the caption “Other Accruals and Current Liabilities.” Such reserve, which amounted to $1.2 million at December 31, 2023, 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, oil and gas 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 oil and gas properties unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves of oil and gas attributable to a cost center. The Company's capitalized costs relating to oil and gas producing activities, net of accumulated depreciation, depletion and amortization, were $2.5 billion and $2.4 billion at December 31, 2023 and September 30, 2023, respectively. Capitalized costs include costs related to unproved properties, which are excluded from amortization until proved reserves are found or it is determined that the unproved properties are impaired. Such costs amounted to $159.1 million and $161.1 million at December 31, 2023 and September 30, 2023, respectively. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. The amount of any impairment is transferred to the pool of capitalized costs being amortized. Capitalized costs are subject to the SEC full cost ceiling test. The ceiling test, which is performed each quarter, determines a limit, or ceiling, on the amount of property acquisition, exploration and development costs that can be capitalized. The ceiling under this test represents (a) the present value of estimated future net cash flows, excluding future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet, using a discount factor of 10%, which is computed by applying prices of oil and gas (as adjusted for hedging) to estimated future production of proved oil and gas 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 gas and oil prices used to calculate the full cost ceiling are based on an unweighted arithmetic average of the first day of the month oil and gas prices 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. At December 31, 2023, the ceiling exceeded the book value of the oil and gas properties by approximately $84.4 million. The estimated future net cash flows were increased by $307.0 million for hedging under the ceiling test at December 31, 2023.
Earnings Per Common Share	Earnings Per Common Share.
Stock-Based Compensation	Stock-Based Compensation. The Company granted 361,729 performance shares during the quarter ended December 31, 2023. The weighted average fair value of such performance shares was $44.23 per share for the quarter ended December 31, 2023. 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, 2023 include awards that must meet a performance goal related to either relative return on capital over a three-year or five-year performance cycle ("ROC performance shares"), methane intensity and greenhouse gas emissions reductions over a three-year performance cycle ("ESG performance shares") or relative shareholder return over a three-year or five-year performance cycle ("TSR performance shares"). The performance goal related to the ROC performance shares over the respective performance cycles is the Company’s total return on capital relative to the total return on capital of other companies in a group selected by the Compensation Committee (“Report Group”). Total return on capital for a given company means the average of the Report Group companies’ returns on capital for each twelve-month period corresponding to each of the Company’s fiscal years during the performance cycle, based on data reported for the Report Group companies in the Bloomberg database. The number of these ROC performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value of the ROC performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the ESG performance shares over the three-year performance cycle consists of two parts: reductions in the rates of intensity of methane emissions for each of the Company's operating segments, and reduction of the consolidated Company's total greenhouse gas emissions. The Company's Compensation Committee set specific target levels for methane intensity rates and total greenhouse gas emissions, and the performance goal is intended to incentivize and reward performance to the extent management achieves methane intensity and greenhouse gas reduction targets making progress towards the Company's 2030 goals. The number of these ESG performance shares that will vest and be paid out will depend upon the number of methane intensity segment targets achieved and whether the Company meets the total greenhouse gas emissions target. The fair value of these ESG performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the TSR performance shares over the respective performance cycles is the Company’s three-year (or five-year) total shareholder return relative to the three-year (or five-year) total shareholder return of the other companies in the Report Group. Three-year (or five-year) total shareholder return for a given company will be based on the data reported for that company (with the starting and ending stock prices over the performance cycle calculated as the average closing stock price for the prior calendar month and with dividends reinvested in that company’s securities at each ex-dividend date) in the Bloomberg database. The number of these TSR performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value price at the date of grant for the TSR performance shares is determined using a Monte Carlo simulation technique, which includes a reduction in value for the present value of forgone dividends over the vesting term of the award. This price is multiplied by the number of TSR performance shares awarded, the result of which is recorded as compensation expense over the vesting term of the award. The Company granted 219,578 restricted stock units during the quarter ended December 31, 2023. The weighted average fair value of such restricted stock units was $42.44 per share for the quarter ended December 31, 2023. 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, 2023
Accounting Policies [Abstract]
Schedule of Cash, Cash Equivalents and Restricted Cash	The components, as reported on the Company’s Consolidated Balance Sheets, of the total cash, cash equivalents, and restricted cash presented on the Statement of Cash Flows are as follows (in thousands): Three Months Ended Three Months Ended Balance at Balance at October 1, 2023 Balance at Balance at October 1, 2022 Cash and Temporary Cash Investments $ 41,685 $ 55,447 $ 244,475 $ 46,048 Hedging Collateral Deposits — — 1,600 91,670 Cash, Cash Equivalents, and Restricted Cash $ 41,685 $ 55,447 $ 246,075 $ 137,718
Schedule of Allowance for Uncollectible Accounts	Activity in the allowance for uncollectible accounts for the three months ended December 31, 2023 and 2022 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, 2023 Allowance for Uncollectible Accounts $ 36,295 $ 4,157 $ 119 $ (3,455) $ 37,116 Three Months Ended December 31, 2022 Allowance for Uncollectible Accounts $ 40,228 $ 5,035 $ 228 $ (1,566) $ 43,925
Components of Accumulated Other Comprehensive Income (Loss)	The components of Accumulated Other Comprehensive Income (Loss) and changes for the three months ended December 31, 2023 and 2022, 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, 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 Three Months Ended December 31, 2022 Balance at October 1, 2022 $ (572,163) $ (53,570) $ (625,733) Other Comprehensive Gains and Losses Before Reclassifications 216,216 — 216,216 Amounts Reclassified From Other Comprehensive Income 115,771 — 115,771 Balance at December 31, 2022 $ (240,176) $ (53,570) $ (293,746)
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, 2023 and 2022 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 2023 2022 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $19,755 ($159,162) Operating Revenues Foreign Currency Contracts (47) (180) Operating Revenues 19,708 (159,342) Total Before Income Tax (5,468) 43,571 Income Tax Expense $14,240 ($115,771) 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, 2023 At September 30, 2023 Prepayments $ 17,993 $ 18,966 Prepaid Property and Other Taxes 14,778 14,186 Federal Income Taxes Receivable 10,799 14,602 State Income Taxes Receivable 18,208 16,133 Regulatory Assets 37,622 36,373 $ 99,400 $ 100,260
Schedule of Other Accruals and Current Liabilities	The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At December 31, 2023 At September 30, 2023 Accrued Capital Expenditures $ 75,485 $ 43,323 Regulatory Liabilities 35,770 38,105 Reserve for Gas Replacement 1,247 — Liability for Royalty and Working Interests 25,529 17,679 Non-Qualified Benefit Plan Liability 13,052 13,052 Other 48,926 48,815 $ 200,009 $ 160,974

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	3 Months Ended
	Dec. 31, 2023
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, 2023 and 2022, presented by type of service from each reportable segment. 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 Quarter Ended December 31, 2022 (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 $ 432,359 $ — $ — $ — $ — $ — $ 432,359 Production of Crude Oil 628 — — — — — 628 Natural Gas Processing 374 — — — — — 374 Natural Gas Gathering Service — — 56,413 — — (53,767) 2,646 Natural Gas Transportation Service — 76,201 — 28,378 — (20,817) 83,762 Natural Gas Storage Service — 21,286 — — — (8,996) 12,290 Natural Gas Residential Sales — — — 244,306 — — 244,306 Natural Gas Commercial Sales — — — 34,495 — — 34,495 Natural Gas Industrial Sales — — — 1,638 — — 1,638 Other 2,774 168 — (259) — (283) 2,400 Total Revenues from Contracts with Customers 436,135 97,655 56,413 308,558 — (83,863) 814,898 Alternative Revenue Programs — — — 3,123 — — 3,123 Derivative Financial Instruments (159,162) — — — — — (159,162) Total Revenues $ 276,973 $ 97,655 $ 56,413 $ 311,681 $ — $ (83,863) $ 658,859

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Dec. 31, 2023
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, 2023 and September 30, 2023. Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Recurring Fair Value Measures At fair value as of December 31, 2023 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 32,781 $ — $ — $ — $ 32,781 Derivative Financial Instruments: Over the Counter Swaps – Gas — 140,548 — (16,722) 123,826 Over the Counter No Cost Collars – Gas — 57,917 — — 57,917 Contingent Consideration for Asset Sale — 3,078 — — 3,078 Foreign Currency Contracts — 505 — (587) (82) Other Investments: Balanced Equity Mutual Fund 17,484 — — — 17,484 Fixed Income Mutual Fund 16,510 — — — 16,510 Total $ 66,775 $ 202,048 $ — $ (17,309) $ 251,514 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 16,722 $ — $ (16,722) $ — Foreign Currency Contracts — 587 — (587) — Total $ — $ 17,309 $ — $ (17,309) $ — Total Net Assets/(Liabilities) $ 66,775 $ 184,739 $ — $ — $ 251,514 Recurring Fair Value Measures At fair value as of September 30, 2023 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 39,332 $ — $ — $ — $ 39,332 Derivative Financial Instruments: Over the Counter Swaps – Gas — 65,800 — (37,508) 28,292 Over the Counter No Cost Collars – Gas — 30,966 — (14,745) 16,221 Contingent Consideration for Asset Sale — 7,277 — — 7,277 Foreign Currency Contracts — 150 — (1,453) (1,303) Other Investments: Balanced Equity Mutual Fund 15,837 — — — 15,837 Fixed Income Mutual Fund 15,897 — — — 15,897 Total $ 71,066 $ 104,193 $ — $ (53,706) $ 121,553 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 68,311 $ — $ (37,508) $ 30,803 Over the Counter No Cost Collars – Gas — 14,950 — (14,745) 205 Foreign Currency Contracts — 1,454 — (1,453) 1 Total $ — $ 84,715 $ — $ (53,706) $ 31,009 Total Net Assets/(Liabilities) $ 71,066 $ 19,478 $ — $ — $ 90,544 (1) Netting Adjustments represent the impact of legally-enforceable master netting arrangements that allow the Company to net gain and loss positions held with the same counterparties. The net asset or net liability for each counterparty is recorded as an asset or liability on the Company’s balance sheet.

Financial Instruments (Tables)

Financial Instruments (Tables)	3 Months Ended
	Dec. 31, 2023
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, 2023 September 30, 2023 Carrying Fair Value Carrying Fair Value Long-Term Debt $ 2,385,523 $ 2,286,446 $ 2,384,485 $ 2,210,478
Schedule Of Other Investments	The components of the Company's Other Investments are as follows (in thousands): At December 31, 2023 At September 30, 2023 Life Insurance Contracts $ 42,639 $ 42,242 Equity Mutual Fund 17,484 15,837 Fixed Income Mutual Fund 16,510 15,897 $ 76,633 $ 73,976
Schedule of Derivative Financial Instruments Designated And Qualifying As Cash Flow Hedges On The Statement Of Financial Performance	The Effect of Derivative Financial Instruments on the Statement of Financial Performance for the Three Months Ended December 31, 2023 and 2022 (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 2023 2022 2023 2022 Commodity Contracts $ 187,989 $ 297,120 Operating Revenue $ 19,755 $ (159,162) Foreign Currency Contracts 1,178 473 Operating Revenue (47) (180) Total $ 189,167 $ 297,593 $ 19,708 $ (159,342)

Capitalization (Tables)

Capitalization (Tables)	3 Months Ended
	Dec. 31, 2023
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, 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 Balance at October 1, 2022 91,478 $ 91,478 $ 1,027,066 $ 1,587,085 $ (625,733) Net Income Available for Common Stock 169,689 Dividends Declared on Common Stock ($0.475 Per Share) (43,598) Other Comprehensive Income, Net of Tax 331,987 Share-Based Payment Expense (1) 5,118 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 309 309 (6,545) Balance at December 31, 2022 91,787 $ 91,787 $ 1,025,639 $ 1,713,176 $ (293,746) (1) Paid in Capital includes compensation costs associated with performance shares and/or restricted stock awards. The expense is included within Net Income Available For Common Stock, net of tax benefits.

Business Segment Information (T

Business Segment Information (Tables)	3 Months Ended
	Dec. 31, 2023
Segment Reporting [Abstract]
Financial Segment Information By Segment	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 (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, 2023 $3,057,345 $2,439,479 $936,547 $2,301,116 $8,734,487 $4,758 $(151,753) $8,587,492 At September 30, 2023 $2,814,218 $2,427,214 $912,923 $2,247,743 $8,402,098 $4,795 $(126,633) $8,280,260 Quarter Ended December 31, 2022 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $276,973 $67,621 $2,646 $311,619 $658,859 $— $— $658,859 Intersegment Revenues $— $30,034 $53,767 $62 $83,863 $— $(83,863) $— Segment Profit: Net Income (Loss) $91,192 $29,476 $24,738 $23,817 $169,223 $(280) $746 $169,689

Retirement Plan And Other Pos_2

Retirement Plan And Other Post-Retirement Benefits (Tables)	3 Months Ended
	Dec. 31, 2023
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, 2023 2022 2023 2022 Service Cost $ 1,049 $ 1,297 $ 109 $ 147 Interest Cost 10,890 10,629 3,890 3,912 Expected Return on Plan Assets (17,086) (16,648) (6,660) (6,403) Amortization of Prior Service Cost (Credit) 91 109 (107) (107) Amortization of (Gains) Losses (335) (1,920) (567) (2,189) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 4,057 5,378 2,238 3,820 Net Periodic Benefit Cost (Income) $ (1,334) $ (1,155) $ (1,097) $ (820) (1) The Company’s policy is to record retirement plan and other post-retirement benefit costs in the Utility segment on a volumetric basis to reflect the fact that the Utility segment experiences higher throughput of natural gas in the winter months and lower throughput of natural gas in the summer months.

Summary Of Significant Accoun_4

Summary Of Significant Accounting Policies (Consolidated Statements Of Cash Flows) (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022
Accounting Policies [Abstract]
Cash and Temporary Cash Investments	$ 41,685	$ 55,447	$ 244,475	$ 46,048
Hedging Collateral Deposits	0	0	1,600	91,670
Cash, Cash Equivalents, and Restricted Cash	$ 41,685	$ 55,447	$ 246,075	$ 137,718

Summary Of Significant Accoun_5

Summary Of Significant Accounting Policies (Allowance for Uncollectible Accounts) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Allowance for Uncollectible Accounts [Roll Forward]
Balance at Beginning of Period	$ 36,295	$ 40,228
Additions Charged to Costs and Expenses	4,157	5,035
Discounts on Purchased Receivables	119	228
Net Accounts Receivable Written-Off	(3,455)	(1,566)
Balance at End of Period	$ 37,116	$ 43,925

Summary Of Significant Accoun_6

Summary Of Significant Accounting Policies (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Sep. 30, 2023	Sep. 30, 2024
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground	$ 26,891		$ 32,509
Capitalized Costs Oil and Gas Producing Activities Net	2,500,000		2,400,000
Capitalized costs of unproved properties excluded from amortization	$ 159,100		$ 161,100
Full cost ceiling test discount factor (as a percent)	10%
Amount Full Cost Ceiling Exceeds Book Value Of Oil And Gas Properties	$ 84,400
Increase estimated future net cash flows	$ 307,000
Antidilutive securities (in shares)	0	1,987
Reserve For Gas Replacement
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground	$ 1,200
Restricted Stock Units
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period (in shares)	219,578
Granted in fiscal year, weighted average grant date fair value (in USD per share)	$ 42.44
Performance Shares
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period (in shares)	361,729
Granted in fiscal year, weighted average grant date fair value (in USD per share)	$ 44.23
Greenhouse gas emissions reductions, performance cycle	3 years
Performance Shares | Minimum
Summary Of Significant Accounting Policies [Line Items]
Return on capital, performance cycle (in years)	3 years
Relative shareholder return, performance cycle	3 years
Performance Shares | Maximum
Summary Of Significant Accounting Policies [Line Items]
Return on capital, performance cycle (in years)	5 years
Relative shareholder return, performance cycle	5 years
Subsequent Event | Reserve For Gas Replacement
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground				$ 0

Summary Of Significant Accoun_7

Summary Of Significant Accounting Policies (Components Of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	$ (55,060)	$ (625,733)
Other Comprehensive Gains and Losses Before Reclassifications	136,681	216,216
Amounts Reclassified From Other Comprehensive Income	(14,240)	115,771
Ending balance	67,381	(293,746)
Gains and Losses on Derivative Financial Instruments
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	4,623	(572,163)
Other Comprehensive Gains and Losses Before Reclassifications	136,681	216,216
Amounts Reclassified From Other Comprehensive Income	(14,240)	115,771
Ending balance	127,064	(240,176)
Funded Status of the Pension and Other Post-Retirement Benefit Plans
Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Beginning balance	(59,683)	(53,570)
Other Comprehensive Gains and Losses Before Reclassifications	0	0
Amounts Reclassified From Other Comprehensive Income	0	0
Ending balance	$ (59,683)	$ (53,570)

Summary Of Significant Accoun_8

Summary Of Significant Accounting Policies (Reclassification Out Of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Reclassification Adjustments out of Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating Revenues	$ 525,361	$ 658,859
Total Before Income Tax	176,107	227,241
Income Tax Expense	(43,087)	(57,552)
Net Income Available for Common Stock	133,020	169,689
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	19,708	(159,342)
Income Tax Expense	(5,468)	43,571
Net Income Available for Common Stock	14,240	(115,771)
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	19,755	(159,162)
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	$ (47)	$ (180)

Summary Of Significant Accoun_9

Summary Of Significant Accounting Policies (Components Of Other Current Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Sep. 30, 2023
Summary Of Significant Accounting Policies [Line Items]
Prepayments	$ 17,993	$ 18,966
Prepaid Property and Other Taxes	14,778	14,186
Regulatory Assets	37,622	36,373
Other Current Assets	99,400	100,260
Federal
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	10,799	14,602
State
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	$ 18,208	$ 16,133

Summary Of Significant Accou_10

Summary Of Significant Accounting Policies (Schedule Of Other Accruals And Current Liabilities) (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Sep. 30, 2023
Accounting Policies [Abstract]
Accrued Capital Expenditures	$ 75,485	$ 43,323
Regulatory Liabilities	35,770	38,105
Reserve for Gas Replacement	1,247	0
Liability for Royalty and Working Interests	25,529	17,679
Non-Qualified Benefit Plan Liability	13,052	13,052
Other	48,926	48,815
Other Accruals and Current Liabilities	$ 200,009	$ 160,974

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	$ 500,050	$ 814,898
Alternative Revenue Programs	5,556	3,123
Derivative Financial Instruments	19,755	(159,162)
Total Revenues	525,361	658,859
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	(87,666)	(83,863)
Alternative Revenue Programs	0	0
Derivative Financial Instruments	0	0
Total Revenues	(87,666)	(83,863)
Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	234,264	436,135
Alternative Revenue Programs	0	0
Derivative Financial Instruments	19,755	(159,162)
Total Revenues	254,019	276,973
Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	94,413	97,655
Alternative Revenue Programs	0	0
Derivative Financial Instruments	0	0
Total Revenues	94,413	97,655
Gathering | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	62,588	56,413
Alternative Revenue Programs	0	0
Derivative Financial Instruments	0	0
Total Revenues	62,588	56,413
Utility | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	196,451	308,558
Alternative Revenue Programs	5,556	3,123
Derivative Financial Instruments	0	0
Total Revenues	202,007	311,681
Production of Natural Gas
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	232,661	432,359
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	232,661	432,359
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	687	628
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	687	628
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	267	374
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	267	374
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	4,596	2,646
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	(57,992)	(53,767)
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	62,588	56,413
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	80,541	83,762
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	(20,362)	(20,817)
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	71,618	76,201
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	29,285	28,378
Natural Gas Storage Service
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	12,233	12,290
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	(9,059)	(8,996)
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	21,292	21,286
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	146,546	244,306
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	146,546	244,306
Natural Gas Commercial Sales
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	20,281	34,495
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	20,281	34,495
Natural Gas Industrial Sales
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	904	1,638
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	(2)	0
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	906	1,638
Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,334	2,400
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	(251)	(283)
Other | Exploration and Production | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	649	2,774
Other | Pipeline and Storage | Total Reportable Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,503	168
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	$ (567)	$ (259)

Revenue from Contracts with C_4

Revenue from Contracts with Customers (Narrative) (Details) $ in Millions	Dec. 31, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 159.1
Remaining performance obligation, period	9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 191.6
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligations	$ 149.2
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	$ 123.3
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	$ 107.5
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	$ 581
Remaining performance obligation, period

Fair Value Measurements (Recurr

Fair Value Measurements (Recurring Fair Value Measures Of Assets And Liabilities) (Details) - USD ($) $ in Thousands		Dec. 31, 2023		Sep. 30, 2023
Assets:
Cash Equivalents – Money Market Mutual Funds	[1]	$ 32,781		$ 39,332
Derivative Financial Instruments:
Derivative Asset, Statement of Financial Position [Extensible Enumeration]		Fair Value of Derivative Financial Instruments		Fair Value of Derivative Financial Instruments
Total Assets	[1]	$ 251,514		$ 121,553
Derivative Financial Instruments:
Derivative Liability, Statement of Financial Position [Extensible Enumeration]		Fair Value of Derivative Financial Instruments		Fair Value of Derivative Financial Instruments
Total Liabilities	[1]	$ 0		$ 31,009
Total Net Assets/(Liabilities)	[1]	251,514		90,544
Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset	[1]	123,826		28,292
Derivative Financial Instruments:
Derivative Liability	[1]	0		30,803
Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		57,917	[1]	16,221
Derivative Financial Instruments:
Derivative Liability	[1]			205
Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset	[1]	3,078		7,277
Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset	[1]	(82)		(1,303)
Derivative Financial Instruments:
Derivative Liability	[1]	0		1
Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	17,484		15,837
Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	16,510		15,897
Level 1
Assets:
Cash Equivalents – Money Market Mutual Funds		32,781		39,332
Derivative Financial Instruments:
Total Assets		66,775		71,066
Derivative Financial Instruments:
Total Liabilities		0		0
Total Net Assets/(Liabilities)		66,775		71,066
Level 1 | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability		0		0
Level 1 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability				0
Level 1 | Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset		0		0
Level 1 | Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability		0		0
Level 1 | Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments		17,484		15,837
Level 1 | Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments		16,510		15,897
Level 2
Assets:
Cash Equivalents – Money Market Mutual Funds		0		0
Derivative Financial Instruments:
Total Assets		202,048		104,193
Derivative Financial Instruments:
Total Liabilities		17,309		84,715
Total Net Assets/(Liabilities)		184,739		19,478
Level 2 | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset		140,548		65,800
Derivative Financial Instruments:
Derivative Liability		16,722		68,311
Level 2 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		57,917		30,966
Derivative Financial Instruments:
Derivative Liability				14,950
Level 2 | Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset		3,078		7,277
Level 2 | Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset		505		150
Derivative Financial Instruments:
Derivative Liability		587		1,454
Level 2 | Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments		0		0
Level 2 | Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments		0		0
Level 3
Assets:
Cash Equivalents – Money Market Mutual Funds		0		0
Derivative Financial Instruments:
Total Assets		0		0
Derivative Financial Instruments:
Total Liabilities		0		0
Total Net Assets/(Liabilities)		0		0
Level 3 | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability		0		0
Level 3 | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability				0
Level 3 | Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset		0		0
Level 3 | Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset		0		0
Derivative Financial Instruments:
Derivative Liability		0		0
Level 3 | Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments		0		0
Level 3 | Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments		0		0
Netting Adjustments
Assets:
Cash Equivalents – Money Market Mutual Funds	[1]	0		0
Derivative Financial Instruments:
Total Assets	[1]	(17,309)		(53,706)
Derivative Financial Instruments:
Total Liabilities	[1]	(17,309)		(53,706)
Total Net Assets/(Liabilities)	[1]	0		0
Netting Adjustments | Over the Counter Swaps – Gas
Derivative Financial Instruments:
Derivative Asset	[1]	(16,722)		(37,508)
Derivative Financial Instruments:
Derivative Liability	[1]	(16,722)		(37,508)
Netting Adjustments | Over the Counter No Cost Collars – Gas
Derivative Financial Instruments:
Derivative Asset		0	[1]	(14,745)
Derivative Financial Instruments:
Derivative Liability	[1]			(14,745)
Netting Adjustments | Contingent Consideration for Asset Sale
Derivative Financial Instruments:
Derivative Asset	[1]	0		0
Netting Adjustments | Foreign Currency Contracts
Derivative Financial Instruments:
Derivative Asset	[1]	(587)		(1,453)
Derivative Financial Instruments:
Derivative Liability	[1]	(587)		(1,453)
Netting Adjustments | Balanced Equity Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	0		0
Netting Adjustments | Fixed Income Mutual Fund
Derivative Financial Instruments:
Other Investments	[1]	$ 0		$ 0
[1] Netting Adjustments represent the impact of legally-enforceable master netting arrangements that allow the Company to net gain and loss positions held with the same counterparties. The net asset or net liability for each counterparty is recorded as an asset or liability on the Company’s balance sheet.

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details)	12 Months Ended	36 Months Ended
	Dec. 31, 2023 USD ($)	Dec. 31, 2025 USD ($) payment	Sep. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)	Sep. 30, 2022 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hedging Collateral Deposits	$ 0		$ 0	$ 1,600,000	$ 91,670,000
California Asset Sale | Forecast
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Maximum Annual Contingent Payment		$ 10,000,000
Amount of Each Incremental Contingency Payment		1,000,000
Incremental price, exceeding ICE Brent Average Price (in dollars per barrel)		1
California Asset Sale | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
ICE Brent Average (in dollars per barrel)	95
California Asset Sale | Minimum | Forecast
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
ICE Brent Average (in dollars per barrel)		$ 95
California Asset Sale | Maximum | Forecast
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Number Of Annual Contingent Payments | payment		3
ICE Brent Average (in dollars per barrel)		$ 105
Derivative Financial Instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Level 3 Fair Value	$ 0			$ 0

Financial Instruments (Narrativ

Financial Instruments (Narrative) (Details) Bcf in Billions	3 Months Ended	12 Months Ended	36 Months Ended
	Dec. 31, 2023 USD ($) counterparty Bcf	Dec. 31, 2023 USD ($) counterparty Bcf	Dec. 31, 2025 USD ($) payment	Sep. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)	Sep. 30, 2022 USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Foreign Currency Forward Contract Hedge Duration	7 years
After tax net hedging gains in accumulated other comprehensive income (loss)	$ 127,100,000	$ 127,100,000
After Tax Net Hedging Gains Reclassified Within Twelve Months	92,300,000
Fair market value of derivative liability with a credit-risk related contingency	0	0
Hedging Collateral Deposits	0	0		$ 0	$ 1,600,000	$ 91,670,000
California Asset Sale | Forecast
Derivative Instruments, Gain (Loss) [Line Items]
Maximum Annual Contingent Payment			$ 10,000,000
Amount of Each Incremental Contingency Payment			1,000,000
Incremental price, exceeding ICE Brent Average Price (in dollars per barrel)			1
California Asset Sale | Present Value of Contingent Consideration
Derivative Instruments, Gain (Loss) [Line Items]
Value of Contingent Consideration Received from Sale of Assets	3,100,000	3,100,000		$ 7,300,000
California Asset Sale | Mark to Market of Contingent Consideration
Derivative Instruments, Gain (Loss) [Line Items]
Mark-to-Market Adjustment for Contingent Consideration	$ (4,200,000)
California Asset Sale | Minimum
Derivative Instruments, Gain (Loss) [Line Items]
ICE Brent Average (in dollars per barrel)		$ 95
California Asset Sale | Minimum | Forecast
Derivative Instruments, Gain (Loss) [Line Items]
ICE Brent Average (in dollars per barrel)			$ 95
California Asset Sale | Maximum | Forecast
Derivative Instruments, Gain (Loss) [Line Items]
Number Of Annual Contingent Payments | payment			3
ICE Brent Average (in dollars per barrel)			$ 105
Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Hedge Duration	5 years
Over the Counter Swaps, No Cost Collars and Foreign Currency Forward Contracts
Derivative Instruments, Gain (Loss) [Line Items]
Number of counterparties in which the company holds over-the-counter swap positions | counterparty	19	19
Number of counterparties in net gain position | counterparty	19	19
Credit risk exposure per counterparty	$ 9,600,000	$ 9,600,000
Maximum Credit Risk Exposure Per Counterparty	35,600,000
Collateral Received by the Company	$ 0	$ 0
Number of counterparties with a common credit-risk related contingency | counterparty	16	16
Hedging Collateral Deposits	$ 0	$ 0
Natural Gas Bcf | Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk cash flow hedge derivatives, natural gas | Bcf	380.2	380.2
Foreign Currency Contracts
Derivative Instruments, Gain (Loss) [Line Items]
Hedging Notional Amount of Forecasted Transportation Costs	$ 53,700,000	$ 53,700,000

Financial Instruments (Long-Ter

Financial Instruments (Long-Term Debt) (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Sep. 30, 2023
Financial Instruments, Owned, at Fair Value, by Type, Alternative [Abstract]
Carrying Amount	$ 2,385,523	$ 2,384,485
Fair Value	$ 2,286,446	$ 2,210,478

Financial Instruments (Other In

Financial Instruments (Other Investments) (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Sep. 30, 2023
Investment Holdings [Line Items]
Life Insurance Contracts	$ 42,639	$ 42,242
Other Investments	76,633	73,976
Equity Mutual Fund
Investment Holdings [Line Items]
Mutual Funds	17,484	15,837
Fixed Income Mutual Fund
Investment Holdings [Line Items]
Mutual Funds	$ 16,510	$ 15,897

Financial Instruments (Schedule

Financial Instruments (Schedule Of Derivative Financial Instruments Designated And Qualifying As Cash Flow Hedges On The Statement Of Financial Performance) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
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)	$ 189,167	$ 297,593
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	19,708	(159,342)
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)	187,989	297,120
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	19,755	(159,162)
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)	1,178	473
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	$ (47)	$ (180)

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details)	3 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Effective Tax Rate	24.50%	25.30%

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, 2023	Dec. 31, 2022
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)		91,819,405
Beginning balance		$ 2,963,376
Net Income Available for Common Stock		133,020	$ 169,689
Dividends Declared on Common Stock		(45,597)	(43,598)
Other Comprehensive Income, Net of Tax		$ 122,441	$ 331,987
Ending balance (in shares)		92,115,581
Ending balance		$ 3,174,002
Dividends per share (in dollars per share)		$ 0.495	$ 0.475
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)		91,819,000	91,478,000
Beginning balance		$ 91,819	$ 91,478
Common Stock Issued Under Stock and Benefit Plans (Shares)		297,000	309,000
Common Stock Issued Under Stock and Benefit Plans		$ 297	$ 309
Ending balance (in shares)		92,116,000	91,787,000
Ending balance		$ 92,116	$ 91,787
Paid In Capital
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance		1,040,761	1,027,066
Share-Based Payment Expense	[1]	4,135	5,118
Stock Repurchased under Stock and Benefit Plans		(3,670)	(6,545)
Ending balance		1,041,226	1,025,639
Earnings Reinvested in the Business
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance		1,885,856	1,587,085
Net Income Available for Common Stock		133,020	169,689
Dividends Declared on Common Stock		(45,597)	(43,598)
Ending balance		1,973,279	1,713,176
Accumulated Other Comprehensive Income (Loss)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance		(55,060)	(625,733)
Other Comprehensive Income, Net of Tax		122,441	331,987
Ending balance		$ 67,381	$ (293,746)
[1] Paid in Capital includes compensation costs associated with performance shares and/or restricted stock awards. The expense is included within Net Income Available For Common Stock, net of tax benefits.

Capitalization (Narrative) (Det

Capitalization (Narrative) (Details) $ in Millions	3 Months Ended
	Dec. 31, 2023 USD ($) shares	Feb. 26, 2027 USD ($)	Sep. 30, 2023 USD ($)	Feb. 28, 2022 USD ($) bank
Debt Instrument [Line Items]
Shares tendered (in shares)	77,094
Current Portion of Long-Term Debt | $	$ 0		$ 0
Credit Agreement
Debt Instrument [Line Items]
Number of banks In syndicate | bank				12
Maximum borrowing capacity | $				$ 1,000
Credit Agreement | Forecast
Debt Instrument [Line Items]
Maximum borrowing capacity | $		$ 940
Restricted Stock Units
Debt Instrument [Line Items]
Common stock issued (in shares)	111,832
Performance Shares
Debt Instrument [Line Items]
Common stock issued (in shares)	251,255
Board Of Directors
Debt Instrument [Line Items]
Common stock issued (in shares)	9,128
Officer DCP Plan
Debt Instrument [Line Items]
Common stock issued (in shares)	1,055

Commitments And Contingencies (

Commitments And Contingencies (Details) $ in Millions	Dec. 31, 2023 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Estimated minimum liability for environmental remediation	$ 3.2
Project costs	$ 56

Business Segment Information (N

Business Segment Information (Narrative) (Details)	3 Months Ended
	Dec. 31, 2023 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, 2023	Dec. 31, 2022	Sep. 30, 2023
Segment Reporting Information [Line Items]
Revenue from External Customers	$ 525,361	$ 658,859
Intersegment Revenues	0	0
Segment Profit: Net Income (Loss)	133,020	169,689
Segment Assets:	8,587,492		$ 8,280,260
Total Reportable Segments | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	525,361	658,859
Intersegment Revenues	87,666	83,863
Segment Profit: Net Income (Loss)	131,914	169,223
Segment Assets:	8,734,487		8,402,098
Exploration and Production | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	254,019	276,973
Intersegment Revenues	0	0
Segment Profit: Net Income (Loss)	52,483	91,192
Segment Assets:	3,057,345		2,814,218
Pipeline and Storage | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	64,826	67,621
Intersegment Revenues	29,587	30,034
Segment Profit: Net Income (Loss)	24,055	29,476
Segment Assets:	2,439,479		2,427,214
Gathering | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	4,596	2,646
Intersegment Revenues	57,992	53,767
Segment Profit: Net Income (Loss)	28,825	24,738
Segment Assets:	936,547		912,923
Utility | Total Reportable Segments
Segment Reporting Information [Line Items]
Revenue from External Customers	201,920	311,619
Intersegment Revenues	87	62
Segment Profit: Net Income (Loss)	26,551	23,817
Segment Assets:	2,301,116		2,247,743
All Other | All Other
Segment Reporting Information [Line Items]
Revenue from External Customers	0	0
Intersegment Revenues	0	0
Segment Profit: Net Income (Loss)	(121)	(280)
Segment Assets:	4,758		4,795
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	(87,666)	(83,863)
Segment Profit: Net Income (Loss)	1,227	$ 746
Segment Assets:	$ (151,753)		$ (126,633)

Retirement Plan And Other Pos_3

Retirement Plan And Other Post-Retirement Benefits (Components Of Net Periodic Benefit Cost) (Details) - USD ($) $ in Thousands		3 Months Ended
		Dec. 31, 2023	Dec. 31, 2022
Retirement Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost		$ 1,049	$ 1,297
Interest Cost		10,890	10,629
Expected Return on Plan Assets		(17,086)	(16,648)
Amortization of Prior Service Cost (Credit)		91	109
Amortization of (Gains) Losses		(335)	(1,920)
Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments)	[1]	4,057	5,378
Net Periodic Benefit Cost (Income)		(1,334)	(1,155)
Other Post-Retirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service Cost		109	147
Interest Cost		3,890	3,912
Expected Return on Plan Assets		(6,660)	(6,403)
Amortization of Prior Service Cost (Credit)		(107)	(107)
Amortization of (Gains) Losses		(567)	(2,189)
Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments)	[1]	2,238	3,820
Net Periodic Benefit Cost (Income)		$ (1,097)	$ (820)
[1] The Company’s policy is to record retirement plan and other post-retirement benefit costs in the Utility segment on a volumetric basis to reflect the fact that the Utility segment experiences higher throughput of natural gas in the winter months and lower throughput of natural gas in the summer months.

Retirement Plan And Other Pos_4

Retirement Plan And Other Post-Retirement Benefits (Narrative) (Details) $ in Millions	3 Months Ended
	Dec. 31, 2023 USD ($)
Retirement Plan
Defined Benefit Plan Disclosure [Line Items]
Company's contributions	$ 0
Retirement Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	0
Retirement Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	5
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					80 Months Ended
	Oct. 31, 2023	Aug. 01, 2023	Jul. 31, 2023	Oct. 28, 2022	Dec. 31, 2023
Supply Corporation
Regulatory Matters [Line Items]
Public Utilities Proposed Annual Cost of Service			$ 385.4
Public Utilities Proposed Rate Base			$ 1,320
Proposed Return on Equity (as a percent)			15.12%
NEW YORK
Regulatory Matters [Line Items]
Approved Return on Equity (as a percent)					8.70%
Proposed Base Rate Increase	$ 88
PENNSYLVANIA
Regulatory Matters [Line Items]
Proposed Base Rate Increase				$ 28.1
Public Utilities Authorized Rate Increase, Amount		$ 23