National Fuel Gas (NFG) 10-Q 4 May 23 2023 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - $ / shares	6 Months Ended
	Mar. 31, 2023	Apr. 30, 2023
Cover [Abstract]
Amendment Flag	false
Current Fiscal Year End Date	--09-30
Document Fiscal Period Focus	Q2
Document Fiscal Year Focus	2023
Document Period End Date	Mar. 31, 2023
Document Quarterly Report	true
Document Transition Report	false
Document Type	10-Q
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
Entity Central Index Key	0000070145
Entity Common Stock, Shares Outstanding		91,803,996
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Emerging Growth Company	false
Entity File Number	1-3880
Entity Filer Category	Large Accelerated Filer
Entity Incorporation, State or Country Code	NJ
Entity Registrant Name	NATIONAL FUEL GAS COMPANY
Entity Shell Company	false
Entity Small Business	false
Entity Tax Identification Number	13-1086010
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 Listing, Par Value Per Share	$ 1

Consolidated Statements Of Inco

Consolidated Statements Of Income And Earnings Reinvested In The Business (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022
INCOME
Operating Revenues	$ 717,261	$ 701,720	$ 1,376,119	$ 1,248,277
Operating Expenses:
Purchased Gas	243,839	199,592	415,035	301,219
Property, Franchise and Other Taxes	25,367	27,717	51,572	52,219
Depreciation, Depletion and Amortization	100,964	91,245	197,564	179,823
Total Operating Expenses	495,884	455,354	900,371	792,252
Operating Income	221,377	246,366	475,748	456,025
Other Income (Expense):
Other Income (Deductions)	2,884	10,018	9,203	8,940
Interest Expense on Long-Term Debt	(27,583)	(30,079)	(57,188)	(60,209)
Other Interest Expense	(5,861)	(1,519)	(9,704)	(2,680)
Income Before Income Taxes	190,817	224,786	418,059	402,076
Income Tax Expense	49,937	57,458	107,489	102,356
Net Income Available for Common Stock	140,880	167,328	310,570	299,720
EARNINGS REINVESTED IN THE BUSINESS
Balance at Beginning of Period	1,713,176	1,281,963	1,587,085	1,191,175
Beginning Retained Earnings Unappropriated And Current Period Net Income	1,854,056	1,449,291	1,897,655	1,490,895
Dividends on Common Stock	(43,602)	(41,608)	(87,201)	(83,212)
Balance at March 31	$ 1,810,454	$ 1,407,683	$ 1,810,454	$ 1,407,683
Earnings Per Common Share, Basic:
Net Income Available for Common Stock (in dollars per share)	$ 1.53	$ 1.83	$ 3.39	$ 3.28
Earnings Per Common Share, Diluted:
Net Income Available for Common Stock (in dollars per share)	$ 1.53	$ 1.82	$ 3.37	$ 3.26
Weighted Average Common Shares Outstanding:
Used in Basic Calculation (shares)	91,794,765	91,444,638	91,686,110	91,354,488
Used in Diluted Calculation (shares)	92,256,348	92,064,711	92,264,717	92,047,467
Dividends Per Common Share:
Dividends Declared (in dollars per share)	$ 0.475	$ 0.455	$ 0.950	$ 0.910
Utility [Member]
INCOME
Operating Revenues	$ 406,758	$ 369,092	$ 718,376	$ 605,776
Operating Expenses:
Operation and Maintenance	56,453	53,476	106,805	100,120
Exploration and Production and Other [Member]
INCOME
Operating Revenues	244,552	261,676	521,525	505,957
Operating Expenses:
Operation and Maintenance	31,782	49,806	58,655	95,425
Pipeline and Storage and Gathering [Member]
INCOME
Operating Revenues	65,951	70,952	136,218	136,544
Operating Expenses:
Operation and Maintenance	$ 37,479	$ 33,518	$ 70,740	$ 63,446

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022
Statement of Comprehensive Income [Abstract]
Net Income Available for Common Stock	$ 140,880	$ 167,328	$ 310,570	$ 299,720
Other Comprehensive Income (Loss), Before Tax:
Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	310,544	(641,606)	608,137	(478,474)
Reclassification Adjustment for Realized (Gains) Losses on Derivative Financial Instruments in Net Income	18,940	130,221	178,281	292,809
Other Post-Retirement Adjustment for Regulatory Proceeding	0	(7,351)	0	(7,351)
Other Comprehensive Income (Loss), Before Tax	329,484	(518,736)	786,418	(193,016)
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	85,394	(175,605)	166,770	(130,956)
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Derivative Financial Instruments in Net Income	5,208	35,641	48,779	80,141
Income Tax Expense (Benefit) Related to Other Post-Retirement Adjustment for Regulatory Proceeding	0	(1,544)	0	(1,544)
Income Taxes – Net	90,602	(141,508)	215,549	(52,359)
Other Comprehensive Income (Loss)	238,882	(377,228)	570,869	(140,657)
Comprehensive Income (Loss)	$ 379,762	$ (209,900)	$ 881,439	$ 159,063

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2023	Sep. 30, 2022
ASSETS
Property, Plant and Equipment	$ 12,978,137	$ 12,551,909
Less - Accumulated Depreciation, Depletion and Amortization	6,162,406	5,985,432
Property, Plant and Equipment, Net, Total	6,815,731	6,566,477
Current Assets
Cash and Temporary Cash Investments	71,533	46,048
Hedging Collateral Deposits	0	91,670	[1]
Receivables - Net of Allowance for Uncollectible Accounts of $48,146 and $40,228, Respectively	257,965	361,626
Unbilled Revenue	60,018	30,075
Gas Stored Underground	6,554	32,364
Materials and Supplies - at average cost	45,204	40,637
Unrecovered Purchased Gas Costs	26,851	99,342
Other Current Assets	75,233	59,369
Total Current Assets	543,358	761,131
Other Assets
Recoverable Future Taxes	104,426	106,247
Unamortized Debt Expense	8,062	8,884
Other Regulatory Assets	61,497	67,101
Deferred Charges	85,053	77,472
Other Investments	74,618	95,025
Goodwill	5,476	5,476
Prepaid Pension and Post-Retirement Benefit Costs	224,701	196,597
Fair Value of Derivative Financial Instruments	42,424	9,175
Other	1,896	2,677
Total Other Assets	608,153	568,654
Total Assets	7,967,242	7,896,262
Capitalization:
Common Stock, $1 Par Value Authorized - 200,000,000 Shares; Issued and Outstanding - 91,795,080 Shares and 91,478,064 Shares, Respectively	91,795	91,478
Paid in Capital	1,031,341	1,027,066
Earnings Reinvested in the Business	1,810,454	1,587,085
Accumulated Other Comprehensive Loss	(54,864)	(625,733)
Total Comprehensive Shareholders’ Equity	2,878,726	2,079,896
Long-Term Debt, Net of Current Portion and Unamortized Discount and Debt Issuance Costs	2,085,235	2,083,409
Total Capitalization	4,963,961	4,163,305
Current and Accrued Liabilities
Notes Payable to Banks and Commercial Paper	410,000	60,000
Current Portion of Long-Term Debt	0	549,000
Accounts Payable	119,497	178,945
Amounts Payable to Customers	2,830	419
Dividends Payable	43,602	43,452
Interest Payable on Long-Term Debt	14,303	17,376
Customer Advances	0	26,108
Customer Security Deposits	34,382	24,283
Other Accruals and Current Liabilities	257,923	257,327
Fair Value of Derivative Financial Instruments	34,763	785,659
Total Current and Accrued Liabilities	917,300	1,942,569
Other Liabilities
Deferred Income Taxes	1,000,526	698,229
Taxes Refundable to Customers	354,274	362,098
Cost of Removal Regulatory Liability	265,626	259,947
Other Regulatory Liabilities	189,378	188,803
Other Post-Retirement Liabilities	2,977	3,065
Asset Retirement Obligations	160,910	161,545
Other Liabilities	112,290	116,701
Total Other Liabilities	2,085,981	1,790,388
Commitments and Contingencies (Note 8)	0	0
Total Capitalization and Liabilities	$ 7,967,242	$ 7,896,262
[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.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2023	Sep. 30, 2022
Statement of Financial Position [Abstract]
Receivables, Allowance for Uncollectible Accounts	$ 48,146	$ 40,228
Common Stock, Par Value	$ 1	$ 1
Common Stock, Shares Authorized	200,000,000	200,000,000
Common Stock, Shares Issued	91,795,080	91,478,064
Common Stock, Shares Outstanding	91,795,080	91,478,064

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
OPERATING ACTIVITIES
Net Income Available for Common Stock	$ 310,570	$ 299,720
Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities:
Depreciation, Depletion and Amortization	197,564	179,823
Deferred Income Taxes	80,745	94,212
Stock-Based Compensation	11,286	10,631
Reduction of Other Post-Retirement Regulatory Liability	0	(18,533)
Other	10,758	14,494
Change in:
Receivables and Unbilled Revenue	71,760	(166,584)
Gas Stored Underground and Materials, Supplies and Emission Allowances	21,243	32,040
Unrecovered Purchased Gas Costs	72,491	29,377
Other Current Assets	(15,864)	(8,605)
Accounts Payable	(29,169)	2,006
Amounts Payable to Customers	2,411	3,401
Customer Advances	(26,108)	(17,223)
Customer Security Deposits	10,099	1,474
Other Accruals and Current Liabilities	28,741	11,164
Other Assets	(26,901)	(32,659)
Other Liabilities	(8,417)	(9,119)
Net Cash Provided by Operating Activities	711,209	425,619
INVESTING ACTIVITIES
Capital Expenditures	(496,362)	(415,415)
Net Proceeds from Sale of Oil and Gas Producing Properties	0	13,525
Deposit Paid for Upstream Assets	(12,700)	0
Sale of Fixed Income Mutual Fund Shares in Grantor Trust	10,000	30,000
Other	14,413	13,689
Net Cash Used in Investing Activities	(484,649)	(358,201)
FINANCING ACTIVITIES
Proceeds from Issuance of Short-Term Note Payable to Bank	250,000	0
Net Change in Other Short-Term Notes Payable to Banks and Commercial Paper	100,000	59,500
Reduction of Long-Term Debt	(549,000)	0
Dividends Paid on Common Stock	(87,051)	(83,091)
Net Repurchases of Common Stock	(6,694)	(9,026)
Net Cash Used in Financing Activities	(292,745)	(32,617)
Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash	(66,185)	34,801
Cash, Cash Equivalents and Restricted Cash at October 1	137,718	120,138
Cash, Cash Equivalents and Restricted Cash at March 31	71,533	154,939
Supplemental Disclosure of Cash Flow Information, Non-Cash Investing Activities:
Non-Cash Capital Expenditures	$ 64,495	$ 63,490

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	6 Months Ended
	Mar. 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, 2022, 2021 and 2020 that are included in the Company's 2022 Form 10-K. The consolidated financial statements for the year ended September 30, 2023 will be audited by the Company's independent registered public accounting firm after the end of the fiscal year. The earnings for the six months ended March 31, 2023 should not be taken as a prediction of earnings for the entire fiscal year ending September 30, 2023. Most of the business of the Utility segment is seasonal in nature and is influenced by weather conditions. Due to the seasonal nature of the heating business in the Utility segment, earnings during the winter months normally represent a substantial part of the earnings that this business is expected to achieve for the entire fiscal year. The Company’s business segments are discussed more fully in Note 9 – Business Segment Information. Consolidated Statements of Cash Flows. The components, as reported on the Company’s Consolidated Balance Sheets, of the total cash, cash equivalents, and restricted cash presented on the Statement of Cash Flows are as follows (in thousands): Six Months Ended Six Months Ended Balance at Balance at October 1, 2022 Balance at Balance at October 1, 2021 Cash and Temporary Cash Investments $ 71,533 $ 46,048 $ 52,569 $ 31,528 Hedging Collateral Deposits — 91,670 102,370 88,610 Cash, Cash Equivalents, and Restricted Cash $ 71,533 $ 137,718 $ 154,939 $ 120,138 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 are charged off against the allowance approximately twelve months after the account is final billed or when it is anticipated that the receivable will not be recovered. Activity in the allowance for uncollectible accounts for the six months ended March 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 Six Months Ended March 31, 2023 Allowance for Uncollectible Accounts $ 40,228 $ 10,973 $ 916 $ (3,971) $ 48,146 Six Months Ended March 31, 2022 Allowance for Uncollectible Accounts $ 31,639 $ 9,684 $ 790 $ (630) $ 41,483 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 $106.8 million at March 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 $2.2 billion and $1.9 billion at March 31, 2023 and September 30, 2022, 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 $73.0 million and $66.0 million at March 31, 2023 and September 30, 2022, 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 March 31, 2023, the ceiling exceeded the book value of the oil and gas properties by approximately $2.7 billion. The estimated future net cash flows were decreased by $936.8 million for hedging under the ceiling test at March 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 March 31, 2023. Accumulated Other Comprehensive Loss. The components of Accumulated Other Comprehensive Loss and changes for the six months ended March 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 March 31, 2023 Balance at January 1, 2023 $ (240,176) $ (53,570) $ (293,746) Other Comprehensive Gains and Losses Before Reclassifications 225,150 — 225,150 Amounts Reclassified From Other Comprehensive Income 13,732 — 13,732 Balance at March 31, 2023 $ (1,294) $ (53,570) $ (54,864) Six Months Ended March 31, 2023 Balance at October 1, 2022 $ (572,163) $ (53,570) $ (625,733) Other Comprehensive Gains and Losses Before Reclassifications 441,367 — 441,367 Amounts Reclassified From Other Comprehensive Income 129,502 — 129,502 Balance at March 31, 2023 $ (1,294) $ (53,570) $ (54,864) Three Months Ended March 31, 2022 Balance at January 1, 2022 $ (213,391) $ (63,635) $ (277,026) Other Comprehensive Gains and Losses Before Reclassifications (466,001) — (466,001) Amounts Reclassified From Other Comprehensive Loss 94,580 — 94,580 Other Post-Retirement Adjustment for Regulatory Proceeding — (5,807) (5,807) Balance at March 31, 2022 $ (584,812) $ (69,442) $ (654,254) Six Months Ended March 31, 2022 Balance at October 1, 2021 $ (449,962) $ (63,635) $ (513,597) Other Comprehensive Gains and Losses Before Reclassifications (347,518) — (347,518) Amounts Reclassified From Other Comprehensive Loss 212,668 — 212,668 Other Post-Retirement Adjustment for Regulatory Proceeding — (5,807) (5,807) Balance at March 31, 2022 $ (584,812) $ (69,442) $ (654,254) During the quarter ended March 31, 2022, the PaPUC concluded a regulatory proceeding that addressed the recovery of other post-employment benefit (“OPEB”) expenses in Distribution Corporation's Pennsylvania service territory. As a result of that proceeding, Distribution Corporation suspended regulatory accounting for OPEB expenses in Pennsylvania and a regulatory deferral of $7.4 million ($5.8 million after-tax) related to the funded status of Distribution Corporation’s other post-retirement benefit plans in Pennsylvania was reclassified to accumulated other comprehensive loss. For further discussion of this regulatory proceeding, refer to Note 11 — Regulatory Matters under the heading “Pennsylvania Jurisdiction.” Reclassifications Out of Accumulated Other Comprehensive Loss. The details about the reclassification adjustments out of accumulated other comprehensive loss for the six months ended March 31, 2023 and 2022 are as follows (amounts in parentheses indicate debits to the income statement) (in thousands): Details About Accumulated Other Comprehensive Loss Components Amount of Gain or (Loss) Reclassified from Accumulated Other Comprehensive Loss Affected Line Item in the Statement Where Net Income is Presented Three Months Ended Six Months Ended March 31, 2023 2022 2023 2022 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts ($18,768) ($130,271) ($177,930) ($292,899) Operating Revenues Foreign Currency Contracts (172) 50 (351) 90 Operating Revenues (18,940) (130,221) (178,281) (292,809) Total Before Income Tax 5,208 35,641 48,779 80,141 Income Tax Expense ($13,732) ($94,580) ($129,502) ($212,668) Net of Tax Other Current Assets . The components of the Company’s Other Current Assets are as follows (in thousands): At March 31, 2023 At September 30, 2022 Prepayments $ 14,821 $ 17,757 Prepaid Property and Other Taxes 23,218 14,321 Prepaid State Income Taxes 5,132 5,933 Regulatory Assets 32,062 21,358 $ 75,233 $ 59,369 Other Accruals and Current Liabilities . The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At March 31, 2023 At September 30, 2022 Accrued Capital Expenditures $ 39,232 $ 64,720 Regulatory Liabilities 39,662 31,293 Reserve for Gas Replacement 106,835 — Liability for Royalty and Working Interests 14,365 86,206 Non-Qualified Benefit Plan Liability 17,474 17,474 Other 40,355 57,634 $ 257,923 $ 257,327 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 and six months ended March 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 9,909 securities and 4,094 securities excluded as being antidilutive for the quarter and six months ended March 31, 2023, respectively. There were 13,815 securities and 11,883 securities excluded as being antidilutive for the quarter and six months ended March 31, 2022, respectively. Stock-Based Compensation. The Company granted 202,259 performance shares during the six months ended March 31, 2023. The weighted average fair value of such performance shares was $64.28 per share for the six months ended March 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 six months ended March 31, 2023 include awards that must meet a performance goal related to either relative return on capital over a three-year performance cycle ("ROC performance shares"), methane intensity and greenhouse gas emissions reductions over a three-year performance cycle ("ESG performance shares") or relative shareholder return over a three-year performance cycle ("TSR performance shares"). The performance goal related to the ROC performance shares over the three-year performance cycle is the Company’s total return on capital relative to the total return on capital of other companies in a group selected by the Compensation Committee (“Report Group”). Total return on capital for a given company means the average of the Report Group companies’ returns on capital for each twelve-month period corresponding to each of the Company’s fiscal years during the performance cycle, based on data reported for the Report Group companies in the Bloomberg database. The number of these ROC performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value of the ROC performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the 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 three-year performance cycle is the Company’s three-year total shareholder return relative to the three-year total shareholder return of the other companies in the Report Group. Three-year total shareholder return for a given company will be based on the data reported for that company (with the starting and ending stock prices over the performance cycle calculated as the average closing stock price for the prior calendar month and with dividends reinvested in that company’s securities at each ex-dividend date) in the Bloomberg database. The number of these TSR performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value price at the date of grant for the TSR performance shares is determined using a Monte Carlo simulation technique, which includes a reduction in value for the present value of forgone dividends over the vesting term of the award. This price is multiplied by the number of TSR performance shares awarded, the result of which is recorded as compensation expense over the vesting term of the award. The Company granted 115,073 restricted stock units during the six months ended March 31, 2023. The weighted average fair value of such restricted stock units was $59.69 per share for the six months ended March 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.

Asset Acquisitions and Divestit

Asset Acquisitions and Divestitures	6 Months Ended
	Mar. 31, 2023
Asset Acquisition [Abstract]
Asset Acquisitions and Divestitures	Asset Acquisitions and Divestitures On March 22, 2023, the Company entered into a purchase and sale agreement to acquire certain upstream assets located in Potter and Tioga counties, Pennsylvania from SWN Production Company, LLC effective as of January 1, 2023 for total consideration of $127.0 million, subject to certain purchase price adjustments at closing. These assets are contiguous with existing Company-owned upstream assets in Pennsylvania. The Company made a deposit of $12.7 million at the signing of the purchase and sale agreement and intends to finance the remaining acquisition cost using short and/or long-term borrowings. The transaction is expected to close before the end of June 2023. On June 30, 2022, the Company completed the sale of Seneca’s California assets, all of which are in the Exploration and Production segment, to Sentinel Peak Resources California LLC for a total sale price of $253.5 million, consisting of $240.9 million in cash and contingent consideration valued at $12.6 million at closing. The Company pursued this sale given the strong commodity price environment and the Company's strategic focus in the Appalachian Basin. Under the terms of the purchase and sale agreement, the Company can 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 sale price, which reflected an effective date of April 1, 2022, was reduced for production revenues less expenses that were retained by Seneca from the effective date to the closing date. Under the full cost method of accounting for oil and natural gas properties, $220.7 million of the sale price at closing was accounted for as reduction of capitalized costs since the disposition did not alter the relationship between capitalized costs and proved reserves of oil and gas attributable to the cost center. The remainder of the sale price ($32.8 million) was applied against assets that are not subject to the full cost method of accounting, with the Company recognizing a gain of $12.7 million on the sale of such assets. The majority of this gain related to the sale of emission allowances. The Company also eliminated the asset retirement obligation associated with Seneca’s California oil and gas assets. This obligation amounted to $50.1 million and was accounted for as a reduction of capitalized costs under the full cost method of accounting.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	6 Months Ended
	Mar. 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 quarter and six months ended March 31, 2023 and 2022, presented by type of service from each reportable segment. Quarter Ended March 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 $ 259,770 $ — $ — $ — $ — $ — $ 259,770 Production of Crude Oil 526 — — — — — 526 Natural Gas Processing 209 — — — — — 209 Natural Gas Gathering Service — — 56,981 — — (55,253) 1,728 Natural Gas Transportation Service — 73,794 — 35,796 — (21,751) 87,839 Natural Gas Storage Service — 21,470 — — — (9,219) 12,251 Natural Gas Residential Sales — — — 318,649 — — 318,649 Natural Gas Commercial Sales — — — 48,966 — — 48,966 Natural Gas Industrial Sales — — — 2,768 — (4) 2,764 Other 2,815 (161) — (1,864) — (264) 526 Total Revenues from Contracts with Customers 263,320 95,103 56,981 404,315 — (86,491) 733,228 Alternative Revenue Programs — — — 2,801 — — 2,801 Derivative Financial Instruments (18,768) — — — — — (18,768) Total Revenues $ 244,552 $ 95,103 $ 56,981 $ 407,116 $ — $ (86,491) $ 717,261 Six Months Ended March 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 $ 692,129 $ — $ — $ — $ — $ — $ 692,129 Production of Crude Oil 1,154 — — — — — 1,154 Natural Gas Processing 583 — — — — — 583 Natural Gas Gathering Service — — 113,394 — — (109,020) 4,374 Natural Gas Transportation Service — 149,996 — 64,174 — (42,568) 171,602 Natural Gas Storage Service — 42,756 — — — (18,215) 24,541 Natural Gas Residential Sales — — — 562,955 — — 562,955 Natural Gas Commercial Sales — — — 83,461 — — 83,461 Natural Gas Industrial Sales — — — 4,407 — (4) 4,403 Other 5,589 7 — (2,124) — (548) 2,924 Total Revenues from Contracts with Customers 699,455 192,759 113,394 712,873 — (170,355) 1,548,126 Alternative Revenue Programs — — — 5,923 — — 5,923 Derivative Financial Instruments (177,930) — — — — — (177,930) Total Revenues $ 521,525 $ 192,759 $ 113,394 $ 718,796 $ — $ (170,355) $ 1,376,119 Quarter Ended March 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 $ 335,961 $ — $ — $ — $ — $ — $ 335,961 Production of Crude Oil 49,613 — — — — — 49,613 Natural Gas Processing 985 — — — — — 985 Natural Gas Gathering Service — — 52,604 — — (49,447) 3,157 Natural Gas Transportation Service — 72,671 — 41,483 — (18,233) 95,921 Natural Gas Storage Service — 21,451 — — — (9,253) 12,198 Natural Gas Residential Sales — — — 287,027 — — 287,027 Natural Gas Commercial Sales — — — 43,193 — — 43,193 Natural Gas Industrial Sales — — — 2,193 — — 2,193 Other 5,305 1,275 — (4,147) — (143) 2,290 Total Revenues from Contracts with Customers 391,864 95,397 52,604 369,749 — (77,076) 832,538 Alternative Revenue Programs — — — (547) — — (547) Derivative Financial Instruments (130,271) — — — — — (130,271) Total Revenues $ 261,593 $ 95,397 $ 52,604 $ 369,202 $ — $ (77,076) $ 701,720 Six Months Ended March 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 $ 697,242 $ — $ — $ — $ — $ — $ 697,242 Production of Crude Oil 91,984 — — — — — 91,984 Natural Gas Processing 2,013 — — — — — 2,013 Natural Gas Gathering Service — — 104,829 — — (97,627) 7,202 Natural Gas Transportation Service — 138,940 — 69,257 — (35,858) 172,339 Natural Gas Storage Service — 42,251 — — — (18,278) 23,973 Natural Gas Residential Sales — — — 466,038 — — 466,038 Natural Gas Commercial Sales — — — 67,191 — — 67,191 Natural Gas Industrial Sales — — — 3,340 — — 3,340 Other 7,451 2,556 — (6,147) 6 (293) 3,573 Total Revenues from Contracts with Customers 798,690 183,747 104,829 599,679 6 (152,056) 1,534,895 Alternative Revenue Programs — — — 6,281 — — 6,281 Derivative Financial Instruments (292,899) — — — — — (292,899) Total Revenues $ 505,791 $ 183,747 $ 104,829 $ 605,960 $ 6 $ (152,056) $ 1,248,277 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: $106.0 million for the remainder of fiscal 2023; $206.4 million for fiscal 2024; $181.1 million for fiscal 2025; $146.9 million for fiscal 2026; $123.0 million for fiscal 2027; and $692.6 million thereafter.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Mar. 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 March 31, 2023 and September 30, 2022. 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 March 31, 2023 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 53,519 $ — $ — $ — $ 53,519 Derivative Financial Instruments: Over the Counter Swaps – Gas — 59,179 — (52,327) 6,852 Over the Counter No Cost Collars – Gas — 56,879 — (26,070) 30,809 Contingent Consideration for Asset Sale — 5,903 — — 5,903 Foreign Currency Contracts — 213 — (1,353) (1,140) Other Investments: Balanced Equity Mutual Fund 15,924 — — — 15,924 Fixed Income Mutual Fund 15,949 — — — 15,949 Total $ 85,392 $ 122,174 $ — $ (79,750) $ 127,816 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 91,509 $ — $ (52,327) $ 39,182 Over the Counter No Cost Collars – Gas — 21,616 — (26,070) (4,454) Foreign Currency Contracts — 1,388 — (1,353) 35 Total $ — $ 114,513 $ — $ (79,750) $ 34,763 Total Net Assets/(Liabilities) $ 85,392 $ 7,661 $ — $ — $ 93,053 Recurring Fair Value Measures At fair value as of September 30, 2022 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 35,015 $ — $ — $ — $ 35,015 Hedging Collateral Deposits 91,670 — — — 91,670 Derivative Financial Instruments: Over the Counter Swaps – Gas — 5,177 — (4,178) 999 Contingent Consideration for Asset Sale — 8,176 — — 8,176 Foreign Currency Contracts — 128 — (128) — Other Investments: Balanced Equity Mutual Fund 19,506 — — — 19,506 Fixed Income Mutual Fund 33,348 — — — 33,348 Total $ 179,539 $ 13,481 $ — $ (4,306) $ 188,714 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 517,464 $ — $ (4,178) $ 513,286 Over the Counter No Cost Collars – Gas — 270,453 — — 270,453 Foreign Currency Contracts — 2,048 — (128) 1,920 Total $ — $ 789,965 $ — $ (4,306) $ 785,659 Total Net Assets/(Liabilities) $ 179,539 $ (776,484) $ — $ — $ (596,945) (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 March 31, 2023 and September 30, 2022 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. Hedging collateral deposits of $91.7 million at September 30, 2022, which were associated with the price swap agreements, no cost collars and foreign currency contracts, have been reported in Level 1. 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 and crude oil 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 March 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 March 31, 2023 also includes the contingent consideration associated with the sale of the Exploration and Production segment's California assets on June 30, 2022, which is discussed at Note 2 – Asset Acquisitions and Divestitures and at Note 5 – Financial Instruments. 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	6 Months Ended
	Mar. 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): March 31, 2023 September 30, 2022 Carrying Fair Value Carrying Fair Value Long-Term Debt $ 2,085,235 $ 1,951,250 $ 2,632,409 $ 2,453,209 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 March 31, 2023 At September 30, 2022 Life Insurance Contracts $ 42,745 $ 42,171 Equity Mutual Fund 15,924 19,506 Fixed Income Mutual Fund 15,949 33,348 $ 74,618 $ 95,025 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, as discussed in Note 11 – Regulatory Matters, 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 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 8 years. On June 30, 2022, the Company completed the sale of Seneca’s California assets. Under the terms of the purchase and sale agreement, the Company can 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 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 $5.9 million and $8.2 million at March 31, 2023 and September 30, 2022, respectively. A $2.5 million mark-to-market adjustment was recorded during the quarter ended March 31, 2023. A $2.3 million mark-to-market adjustment was recorded during the six months ended March 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 March 31, 2023 and September 30, 2022. 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 March 31, 2023, the Company had 462.9 Bcf of natural gas commodity derivative contracts (swaps and no cost collars) outstanding. As of March 31, 2023, the Company was hedging a total of $51.0 million of forecasted transportation costs denominated in Canadian dollars with foreign currency forward contracts. As of March 31, 2023, the Company had $1.3 million of net hedging losses after taxes included in the accumulated other comprehensive income (loss) balance. It is expected that $37.4 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 March 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 $ 310,623 $ (642,240) Operating Revenue $ (18,768) $ (130,271) Foreign Currency Contracts (79) 634 Operating Revenue (172) 50 Total $ 310,544 $ (641,606) $ (18,940) $ (130,221) The Effect of Derivative Financial Instruments on the Statement of Financial Performance for the Six Months Ended March 31, 2023 and 2022 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or Location of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income Amount of Derivative Gain or 2023 2022 2023 2022 Commodity Contracts $ 607,743 $ (479,114) Operating Revenue $ (177,930) $ (292,899) Foreign Currency Contracts 394 640 Operating Revenue (351) 90 Total $ 608,137 $ (478,474) $ (178,281) $ (292,809) 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 sixteen counterparties of which eight are in a net gain position. On average, the Company had $4.6 million of credit exposure per counterparty in a gain position at March 31, 2023. The maximum credit exposure per counterparty in a gain position at March 31, 2023 was $11.1 million. As of March 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 March 31, 2023, fourteen of the sixteen 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 extended to the Company 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 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 March 31, 2023, the fair market value of the derivative financial instrument liabilities with a credit-risk related contingency feature was $7.1 million according to the Company’s internal model (discussed in Note 4 – Fair Value Measurements), and no hedging collateral deposits were required to be posted by the Company at March 31, 2023. Depending on the movement of commodity prices in the future, it is possible that these liability positions could swing into asset positions, at which point the Company would be exposed to credit risk on its derivative financial instruments. In that case, the Company's counterparties could be required to post hedging collateral deposits.

Income Taxes

Income Taxes	6 Months Ended
	Mar. 31, 2023
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The effective tax rates for the quarters ended March 31, 2023 and March 31, 2022 were 26.2% and 25.6%, respectively. The effective tax rates for the six months ended March 31, 2023 and March 31, 2022 were 25.7% and 25.5% , respectively. During the quarter and six months ended March 31, 2022, the Company was able to utilize the Enhanced Oil Recovery tax credit, which was not available during the quarter and six months ended March 31, 2023 due to the sale of its California properties.

Capitalization

Capitalization	6 Months Ended
	Mar. 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 January 1, 2023 91,787 $ 91,787 $ 1,025,639 $ 1,713,176 $ (293,746) Net Income Available for Common Stock 140,880 Dividends Declared on Common Stock ($0.475 Per Share) (43,602) Other Comprehensive Income, Net of Tax 238,882 Share-Based Payment Expense (1) 5,200 Common Stock Issued Under Stock and Benefit Plans 8 8 502 Balance at March 31, 2023 91,795 $ 91,795 $ 1,031,341 $ 1,810,454 $ (54,864) Balance at October 1, 2022 91,478 $ 91,478 $ 1,027,066 $ 1,587,085 $ (625,733) Net Income Available for Common Stock 310,570 Dividends Declared on Common Stock ($0.95 Per Share) (87,201) Other Comprehensive Income, Net of Tax 570,869 Share-Based Payment Expense (1) 10,318 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 317 317 (6,043) Balance at March 31, 2023 91,795 $ 91,795 $ 1,031,341 $ 1,810,454 $ (54,864) Balance at January 1, 2022 91,437 $ 91,437 $ 1,013,821 $ 1,281,963 $ (277,026) Net Income Available for Common Stock 167,328 Dividends Declared on Common Stock ($0.455 Per Share) (41,608) Other Comprehensive Loss, Net of Tax (377,228) Share-Based Payment Expense (1) 4,692 Common Stock Issued Under Stock and Benefit Plans 12 12 271 Balance at March 31, 2022 91,449 $ 91,449 $ 1,018,784 $ 1,407,683 $ (654,254) Balance at October 1, 2021 91,182 $ 91,182 $ 1,017,446 $ 1,191,175 $ (513,597) Net Income Available for Common Stock 299,720 Dividends Declared on Common Stock ($0.91 Per Share) (83,212) Other Comprehensive Loss, Net of Tax (140,657) Share-Based Payment Expense (1) 9,732 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 267 267 (8,394) Balance at March 31, 2022 91,449 $ 91,449 $ 1,018,784 $ 1,407,683 $ (654,254) (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 six months ended March 31, 2023, the Company issued 12,055 original issue shares of common stock as a result of SARs exercises, 113,531 original issue shares of common stock for restricted stock units that vested and 278,687 original issue shares of common stock for performance shares that vested. The Company also issued 14,680 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 six months ended March 31, 2023. In addition, the Company issued 824 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 six months ended March 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 six months ended March 31, 2023, 102,761 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 June 30, 2022, the Company entered into a new 364-Day Credit Agreement (the "364-Day Credit Agreement") with a syndicate of five banks, all of which are also lenders under the Credit Agreement. The 364-Day Credit Agreement provides an additional $250.0 million unsecured committed delayed draw term loan credit facility with a maturity date of June 29, 2023. The Company elected to draw $250.0 million under the facility on October 27, 2022. The Company used the proceeds for general corporate purposes, which included using $150.0 million for the November 2022 redemption of a portion of the Company's outstanding long-term debt with a maturity date in March 2023. Current Portion of Long-Term Debt. None of the Company's long-term debt as of March 31, 2023 had a maturity date within the following twelve-month period. The Current Portion of Long-Term Debt at September 30, 2022 consisted of $500.0 million of 3.75% notes and $49.0 million of 7.395% notes. The Company redeemed $150.0 million of the 3.75% notes on November 25, 2022 using a portion of the proceeds from short-term borrowings, as discussed above. In March 2023, the Company redeemed the remaining $350.0 million of the 3.75% notes as well as the $49.0 million of 7.395% notes.

Commitments And Contingencies

Commitments And Contingencies	6 Months Ended
	Mar. 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 March 31, 2023, the Company has estimated its remaining clean-up costs related to former manufactured gas plant sites will be approximately $3.8 million. The Company's liability for such clean-up costs has been recorded in Other Liabilities on the Consolidated Balance Sheet at March 31, 2023. The Company expects to recover its environmental clean-up costs through rate recovery over a period of less than one year 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. As of March 31, 2023, the Company has spent approximately $55.9 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	6 Months Ended
	Mar. 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 2022 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 2022 Form 10-K. A listing of segment assets at March 31, 2023 and September 30, 2022 is shown in the tables below. Quarter Ended March 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 $244,552 $64,223 $1,728 $406,758 $717,261 $— $— $717,261 Intersegment Revenues $— $30,880 $55,253 $358 $86,491 $— $(86,491) $— Segment Profit: Net Income (Loss) $60,982 $23,858 $24,334 $31,720 $140,894 $(69) $55 $140,880 Six Months Ended March 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 $521,525 $131,844 $4,374 $718,376 $1,376,119 $— $— $1,376,119 Intersegment Revenues $— $60,915 $109,020 $420 $170,355 $— $(170,355) $— Segment Profit: Net Income (Loss) $152,174 $53,335 $49,072 $55,537 $310,118 $(350) $802 $310,570 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Segment Assets: At March 31, 2023 $2,489,665 $2,357,852 $882,405 $2,363,918 $8,093,840 $2,105 $(128,703) $7,967,242 At September 30, 2022 $2,507,541 $2,394,697 $878,796 $2,299,473 $8,080,507 $2,036 $(186,281) $7,896,262 Quarter Ended March 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 $261,593 $67,795 $3,157 $369,092 $701,637 $— $83 $701,720 Intersegment Revenues $— $27,602 $49,447 $110 $77,159 $— $(77,159) $— Segment Profit: Net Income (Loss) $71,121 $25,470 $22,092 $53,048 $171,731 $— $(4,403) $167,328 Six Months Ended March 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 $505,791 $129,342 $7,202 $605,776 $1,248,111 $— $166 $1,248,277 Intersegment Revenues $— $54,405 $97,627 $184 $152,216 $6 $(152,222) $— Segment Profit: Net Income (Loss) $133,490 $50,637 $45,229 $75,178 $304,534 $(7) $(4,807) $299,720

Retirement Plan And Other Post-

Retirement Plan And Other Post-Retirement Benefits	6 Months Ended
	Mar. 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 March 31, 2023 2022 2023 2022 Service Cost $ 1,297 $ 2,190 $ 147 $ 332 Interest Cost 10,629 5,707 3,912 2,267 Expected Return on Plan Assets (16,648) (13,074) (6,403) (7,340) Amortization of Prior Service Cost (Credit) 109 134 (107) (107) Amortization of (Gains) Losses (1,920) 6,601 (2,189) (1,903) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 5,378 8,418 3,493 4,274 Net Periodic Benefit Cost (Income) $ (1,155) $ 9,976 $ (1,147) $ (2,477) Retirement Plan Other Post-Retirement Benefits Six Months Ended March 31, 2023 2022 2023 2022 Service Cost $ 2,594 $ 4,379 $ 293 $ 664 Interest Cost 21,258 11,414 7,824 4,533 Expected Return on Plan Assets (33,297) (26,147) (12,806) (14,680) Amortization of Prior Service Cost (Credit) 218 268 (214) (214) Amortization of (Gains) Losses (3,840) 13,202 (4,378) (3,805) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 10,756 12,838 7,314 10,519 Net Periodic Benefit Cost (Income) $ (2,311) $ 15,954 $ (1,967) $ (2,983) (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) or its VEBA trusts for its other post-retirement benefits during the six months ended March 31, 2023, and does not anticipate making any such contributions during the remainder of fiscal 2023.

Regulatory Matters

Regulatory Matters	6 Months Ended
	Mar. 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. The 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. The order also authorized the Company to recover approximately $15 million annually for pension and OPEB expenses from customers. Because the Company’s future pension and OPEB costs were projected to be satisfied with existing funds held in reserve, in July 2022, Distribution Corporation made a filing with the NYPSC to effectuate a pension and OPEB surcredit to customers to offset these amounts being collected in base rates effective October 1, 2022. On September 16, 2022, the NYPSC issued an order approving the filing. The surcredit will remain in effect until modified by the NYPSC in another proceeding, or until December 31, 2024, whichever is earlier. With the implementation of this surcredit, Distribution Corporation will no longer be funding the Retirement Plan or its VEBA trusts in its New York jurisdiction. 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 via 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. On January 19, 2023, the NYPSC issued an order in its Effects of COVID-19 on Utility Service (20-M-0266) and Energy Affordability for Low Income Utility Customers (14-M-0565) proceedings whereby a Phase 2 Utility Arrears Relief Program was authorized. Specifically, the order directed Distribution Corporation and certain other New York utilities to, among other things, address arrears on residential non-energy affordability program (EAP) ratepayer accounts that did not receive a credit under the NYPSC’s Phase 1 program and small commercial ratepayer accounts by issuing a one-time bill credit to such customers to reduce or eliminate accrued arrears through May 1, 2022. The credits shall be processed within 90 days of the effective date of the order, provided that residential non-EAP customers who had their service disconnected for non-payment in 2022 shall be allowed the opportunity to have their service reinstated in order to receive the credit through June 30, 2023. The order further directs utilities to suspend residential service terminations for non-payment while arrears credits are applied to accounts through March 1, 2023, or 30 days after credits have been applied, whichever is later. The order authorizes the utilities to recover the Phase 2 costs (the arrears credits and associated carrying charges) through a surcharge. Utilities proposed various offsets to Phase 2 program costs, and Distribution Corporation has proposed certain offsets as part of an uncollectible expense reconciliation proposal. On February 17, 2023, Distribution Corporation made a filing with the NYPSC seeking approval of its uncollectible expense reconciliation mechanism and a determination is pending. Application of the proposed offsets and collection periods will be determined when the NYPSC rules on the uncollectible expense reconciliation filing. Pennsylvania Jurisdiction Distribution Corporation’s current delivery rates in its Pennsylvania jurisdiction were approved by the PaPUC on November 30, 2006 as part of a settlement agreement that became effective January 1, 2007. 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 with a proposed effective date of December 27, 2022. On December 8, 2022, the PaPUC issued an order suspending the filing until July 27, 2023 by operation of law unless directed otherwise by the PaPUC. Following discovery, the submission of testimony and an evidentiary hearing, the parties to the proceeding agreed to a settlement that authorizes, among other things, an increase in Distribution Corporation’s annual base rate operating revenues of $23 million as of August 1, 2023. On April 13, 2023, Distribution Corporation filed a joint petition with the PaPUC seeking approval of the settlement on behalf of all active parties to the proceeding. The joint petition is currently pending before the PaPUC. Effective October 1, 2021, pursuant to a tariff supplement filed with the PaPUC, Distribution Corporation reduced base rates by $7.7 million in order to stop collecting OPEB expenses from customers. It also began to refund to customers overcollected OPEB expenses in the amount of $50.0 million. All matters with respect to this tariff supplement were finalized on February 24, 2022 with the PaPUC’s approval of an Administrative Law Judge’s Recommended Decision. Concurrent with that decision, the Company discontinued regulatory accounting for OPEB expenses and recorded an $18.5 million adjustment during the quarter ended March 31, 2022 to reduce its regulatory liability for previously deferred OPEB income amounts through September 30, 2021 and to increase Other Income (Deductions) on the consolidated financial statements by a like amount. The Company also increased customer refunds of overcollected OPEB expenses from $50.0 million to $54.0 million. All refunds specified in the tariff supplement are being funded entirely by grantor trust assets held by the Company, most of which are included in a fixed income mutual fund that is a component of Other Investments on the Company’s Consolidated Balance Sheet. With the elimination of OPEB expenses in base rates, Distribution Corporation is no longer funding the grantor trust or its VEBA trusts in its Pennsylvania jurisdiction. FERC Jurisdiction Supply Corporation’s 2020 rate settlement provides that no party may make a rate filing for new rates to be effective before February 1, 2024, except that Supply Corporation may file an NGA general Section 4 rate case to change rates if the corporate federal income tax rate is increased. If no case has been filed, Supply Corporation must file for rates to be effective February 1, 2025. Empire’s 2019 rate settlement provides that Empire must make a rate case filing no later than May 1, 2025.

Summary Of Significant Accoun_2

Summary Of Significant Accounting Policies (Policy)	6 Months Ended
	Mar. 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, 2022, 2021 and 2020 that are included in the Company's 2022 Form 10-K. The consolidated financial statements for the year ended September 30, 2023 will be audited by the Company's independent registered public accounting firm after the end of the fiscal year.
Consolidated Statements of Cash Flows	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): Six Months Ended Six Months Ended Balance at Balance at October 1, 2022 Balance at Balance at October 1, 2021 Cash and Temporary Cash Investments $ 71,533 $ 46,048 $ 52,569 $ 31,528 Hedging Collateral Deposits — 91,670 102,370 88,610 Cash, Cash Equivalents, and Restricted Cash $ 71,533 $ 137,718 $ 154,939 $ 120,138 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. 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 are charged off against the allowance approximately twelve months after the account is final billed or when it is anticipated that the receivable will not be recovered. Activity in the allowance for uncollectible accounts for the six months ended March 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 Six Months Ended March 31, 2023 Allowance for Uncollectible Accounts $ 40,228 $ 10,973 $ 916 $ (3,971) $ 48,146 Six Months Ended March 31, 2022 Allowance for Uncollectible Accounts $ 31,639 $ 9,684 $ 790 $ (630) $ 41,483
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 $106.8 million at March 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 $2.2 billion and $1.9 billion at March 31, 2023 and September 30, 2022, 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 $73.0 million and $66.0 million at March 31, 2023 and September 30, 2022, 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 March 31, 2023, the ceiling exceeded the book value of the oil and gas properties by approximately $2.7 billion. The estimated future net cash flows were decreased by $936.8 million for hedging under the ceiling test at March 31, 2023.
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss. The components of Accumulated Other Comprehensive Loss and changes for the six months ended March 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 March 31, 2023 Balance at January 1, 2023 $ (240,176) $ (53,570) $ (293,746) Other Comprehensive Gains and Losses Before Reclassifications 225,150 — 225,150 Amounts Reclassified From Other Comprehensive Income 13,732 — 13,732 Balance at March 31, 2023 $ (1,294) $ (53,570) $ (54,864) Six Months Ended March 31, 2023 Balance at October 1, 2022 $ (572,163) $ (53,570) $ (625,733) Other Comprehensive Gains and Losses Before Reclassifications 441,367 — 441,367 Amounts Reclassified From Other Comprehensive Income 129,502 — 129,502 Balance at March 31, 2023 $ (1,294) $ (53,570) $ (54,864) Three Months Ended March 31, 2022 Balance at January 1, 2022 $ (213,391) $ (63,635) $ (277,026) Other Comprehensive Gains and Losses Before Reclassifications (466,001) — (466,001) Amounts Reclassified From Other Comprehensive Loss 94,580 — 94,580 Other Post-Retirement Adjustment for Regulatory Proceeding — (5,807) (5,807) Balance at March 31, 2022 $ (584,812) $ (69,442) $ (654,254) Six Months Ended March 31, 2022 Balance at October 1, 2021 $ (449,962) $ (63,635) $ (513,597) Other Comprehensive Gains and Losses Before Reclassifications (347,518) — (347,518) Amounts Reclassified From Other Comprehensive Loss 212,668 — 212,668 Other Post-Retirement Adjustment for Regulatory Proceeding — (5,807) (5,807) Balance at March 31, 2022 $ (584,812) $ (69,442) $ (654,254)
Reclassifications Out of Accumulated Other Comprehensive Loss	Reclassifications Out of Accumulated Other Comprehensive Loss. The details about the reclassification adjustments out of accumulated other comprehensive loss for the six months ended March 31, 2023 and 2022 are as follows (amounts in parentheses indicate debits to the income statement) (in thousands): Details About Accumulated Other Comprehensive Loss Components Amount of Gain or (Loss) Reclassified from Accumulated Other Comprehensive Loss Affected Line Item in the Statement Where Net Income is Presented Three Months Ended Six Months Ended March 31, 2023 2022 2023 2022 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts ($18,768) ($130,271) ($177,930) ($292,899) Operating Revenues Foreign Currency Contracts (172) 50 (351) 90 Operating Revenues (18,940) (130,221) (178,281) (292,809) Total Before Income Tax 5,208 35,641 48,779 80,141 Income Tax Expense ($13,732) ($94,580) ($129,502) ($212,668) Net of Tax
Other Current Assets	Other Current Assets . The components of the Company’s Other Current Assets are as follows (in thousands): At March 31, 2023 At September 30, 2022 Prepayments $ 14,821 $ 17,757 Prepaid Property and Other Taxes 23,218 14,321 Prepaid State Income Taxes 5,132 5,933 Regulatory Assets 32,062 21,358 $ 75,233 $ 59,369
Other Accruals and Current Liabilities	Other Accruals and Current Liabilities . The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At March 31, 2023 At September 30, 2022 Accrued Capital Expenditures $ 39,232 $ 64,720 Regulatory Liabilities 39,662 31,293 Reserve for Gas Replacement 106,835 — Liability for Royalty and Working Interests 14,365 86,206 Non-Qualified Benefit Plan Liability 17,474 17,474 Other 40,355 57,634 $ 257,923 $ 257,327
Earnings Per Common Share	Earnings Per Common Share. Basic earnings per common share is computed by dividing income or loss by the weighted average number of common shares outstanding for the period. Diluted earnings per common share reflects the potential dilution that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. For purposes of determining earnings per common share, the potentially dilutive securities the Company had outstanding were restricted stock units and performance shares. For the quarter and six months ended March 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 9,909 securities and 4,094 securities
Stock-Based Compensation	Stock-Based Compensation. The Company granted 202,259 performance shares during the six months ended March 31, 2023. The weighted average fair value of such performance shares was $64.28 per share for the six months ended March 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 six months ended March 31, 2023 include awards that must meet a performance goal related to either relative return on capital over a three-year performance cycle ("ROC performance shares"), methane intensity and greenhouse gas emissions reductions over a three-year performance cycle ("ESG performance shares") or relative shareholder return over a three-year performance cycle ("TSR performance shares"). The performance goal related to the ROC performance shares over the three-year performance cycle is the Company’s total return on capital relative to the total return on capital of other companies in a group selected by the Compensation Committee (“Report Group”). Total return on capital for a given company means the average of the Report Group companies’ returns on capital for each twelve-month period corresponding to each of the Company’s fiscal years during the performance cycle, based on data reported for the Report Group companies in the Bloomberg database. The number of these ROC performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value of the ROC performance shares is calculated by multiplying the expected number of shares that will be issued by the average market price of Company common stock on the date of grant reduced by the present value of forgone dividends over the vesting term of the award. The fair value is recorded as compensation expense over the vesting term of the award. The performance goal related to the 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 three-year performance cycle is the Company’s three-year total shareholder return relative to the three-year total shareholder return of the other companies in the Report Group. Three-year total shareholder return for a given company will be based on the data reported for that company (with the starting and ending stock prices over the performance cycle calculated as the average closing stock price for the prior calendar month and with dividends reinvested in that company’s securities at each ex-dividend date) in the Bloomberg database. The number of these TSR performance shares that will vest and be paid will depend upon the Company’s performance relative to the Report Group and not upon the absolute level of return achieved by the Company. The fair value price at the date of grant for the TSR performance shares is determined using a Monte Carlo simulation technique, which includes a reduction in value for the present value of forgone dividends over the vesting term of the award. This price is multiplied by the number of TSR performance shares awarded, the result of which is recorded as compensation expense over the vesting term of the award. The Company granted 115,073 restricted stock units during the six months ended March 31, 2023. The weighted average fair value of such restricted stock units was $59.69 per share for the six months ended March 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)	6 Months Ended
	Mar. 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): Six Months Ended Six Months Ended Balance at Balance at October 1, 2022 Balance at Balance at October 1, 2021 Cash and Temporary Cash Investments $ 71,533 $ 46,048 $ 52,569 $ 31,528 Hedging Collateral Deposits — 91,670 102,370 88,610 Cash, Cash Equivalents, and Restricted Cash $ 71,533 $ 137,718 $ 154,939 $ 120,138
Schedule of Allowance for Uncollectible Accounts	Activity in the allowance for uncollectible accounts for the six months ended March 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 Six Months Ended March 31, 2023 Allowance for Uncollectible Accounts $ 40,228 $ 10,973 $ 916 $ (3,971) $ 48,146 Six Months Ended March 31, 2022 Allowance for Uncollectible Accounts $ 31,639 $ 9,684 $ 790 $ (630) $ 41,483
Components of Accumulated Other Comprehensive Loss	The components of Accumulated Other Comprehensive Loss and changes for the six months ended March 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 March 31, 2023 Balance at January 1, 2023 $ (240,176) $ (53,570) $ (293,746) Other Comprehensive Gains and Losses Before Reclassifications 225,150 — 225,150 Amounts Reclassified From Other Comprehensive Income 13,732 — 13,732 Balance at March 31, 2023 $ (1,294) $ (53,570) $ (54,864) Six Months Ended March 31, 2023 Balance at October 1, 2022 $ (572,163) $ (53,570) $ (625,733) Other Comprehensive Gains and Losses Before Reclassifications 441,367 — 441,367 Amounts Reclassified From Other Comprehensive Income 129,502 — 129,502 Balance at March 31, 2023 $ (1,294) $ (53,570) $ (54,864) Three Months Ended March 31, 2022 Balance at January 1, 2022 $ (213,391) $ (63,635) $ (277,026) Other Comprehensive Gains and Losses Before Reclassifications (466,001) — (466,001) Amounts Reclassified From Other Comprehensive Loss 94,580 — 94,580 Other Post-Retirement Adjustment for Regulatory Proceeding — (5,807) (5,807) Balance at March 31, 2022 $ (584,812) $ (69,442) $ (654,254) Six Months Ended March 31, 2022 Balance at October 1, 2021 $ (449,962) $ (63,635) $ (513,597) Other Comprehensive Gains and Losses Before Reclassifications (347,518) — (347,518) Amounts Reclassified From Other Comprehensive Loss 212,668 — 212,668 Other Post-Retirement Adjustment for Regulatory Proceeding — (5,807) (5,807) Balance at March 31, 2022 $ (584,812) $ (69,442) $ (654,254)
Schedule of Reclassifications Out of Accumulated Other Comprehensive Loss	The details about the reclassification adjustments out of accumulated other comprehensive loss for the six months ended March 31, 2023 and 2022 are as follows (amounts in parentheses indicate debits to the income statement) (in thousands): Details About Accumulated Other Comprehensive Loss Components Amount of Gain or (Loss) Reclassified from Accumulated Other Comprehensive Loss Affected Line Item in the Statement Where Net Income is Presented Three Months Ended Six Months Ended March 31, 2023 2022 2023 2022 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts ($18,768) ($130,271) ($177,930) ($292,899) Operating Revenues Foreign Currency Contracts (172) 50 (351) 90 Operating Revenues (18,940) (130,221) (178,281) (292,809) Total Before Income Tax 5,208 35,641 48,779 80,141 Income Tax Expense ($13,732) ($94,580) ($129,502) ($212,668) Net of Tax
Schedule of Other Current Assets	The components of the Company’s Other Current Assets are as follows (in thousands): At March 31, 2023 At September 30, 2022 Prepayments $ 14,821 $ 17,757 Prepaid Property and Other Taxes 23,218 14,321 Prepaid State Income Taxes 5,132 5,933 Regulatory Assets 32,062 21,358 $ 75,233 $ 59,369
Schedule of Other Accruals and Current Liabilities	The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At March 31, 2023 At September 30, 2022 Accrued Capital Expenditures $ 39,232 $ 64,720 Regulatory Liabilities 39,662 31,293 Reserve for Gas Replacement 106,835 — Liability for Royalty and Working Interests 14,365 86,206 Non-Qualified Benefit Plan Liability 17,474 17,474 Other 40,355 57,634 $ 257,923 $ 257,327

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	6 Months Ended
	Mar. 31, 2023
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following tables provide a disaggregation of the Company's revenues for the quarter and six months ended March 31, 2023 and 2022, presented by type of service from each reportable segment. Quarter Ended March 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 $ 259,770 $ — $ — $ — $ — $ — $ 259,770 Production of Crude Oil 526 — — — — — 526 Natural Gas Processing 209 — — — — — 209 Natural Gas Gathering Service — — 56,981 — — (55,253) 1,728 Natural Gas Transportation Service — 73,794 — 35,796 — (21,751) 87,839 Natural Gas Storage Service — 21,470 — — — (9,219) 12,251 Natural Gas Residential Sales — — — 318,649 — — 318,649 Natural Gas Commercial Sales — — — 48,966 — — 48,966 Natural Gas Industrial Sales — — — 2,768 — (4) 2,764 Other 2,815 (161) — (1,864) — (264) 526 Total Revenues from Contracts with Customers 263,320 95,103 56,981 404,315 — (86,491) 733,228 Alternative Revenue Programs — — — 2,801 — — 2,801 Derivative Financial Instruments (18,768) — — — — — (18,768) Total Revenues $ 244,552 $ 95,103 $ 56,981 $ 407,116 $ — $ (86,491) $ 717,261 Six Months Ended March 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 $ 692,129 $ — $ — $ — $ — $ — $ 692,129 Production of Crude Oil 1,154 — — — — — 1,154 Natural Gas Processing 583 — — — — — 583 Natural Gas Gathering Service — — 113,394 — — (109,020) 4,374 Natural Gas Transportation Service — 149,996 — 64,174 — (42,568) 171,602 Natural Gas Storage Service — 42,756 — — — (18,215) 24,541 Natural Gas Residential Sales — — — 562,955 — — 562,955 Natural Gas Commercial Sales — — — 83,461 — — 83,461 Natural Gas Industrial Sales — — — 4,407 — (4) 4,403 Other 5,589 7 — (2,124) — (548) 2,924 Total Revenues from Contracts with Customers 699,455 192,759 113,394 712,873 — (170,355) 1,548,126 Alternative Revenue Programs — — — 5,923 — — 5,923 Derivative Financial Instruments (177,930) — — — — — (177,930) Total Revenues $ 521,525 $ 192,759 $ 113,394 $ 718,796 $ — $ (170,355) $ 1,376,119 Quarter Ended March 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 $ 335,961 $ — $ — $ — $ — $ — $ 335,961 Production of Crude Oil 49,613 — — — — — 49,613 Natural Gas Processing 985 — — — — — 985 Natural Gas Gathering Service — — 52,604 — — (49,447) 3,157 Natural Gas Transportation Service — 72,671 — 41,483 — (18,233) 95,921 Natural Gas Storage Service — 21,451 — — — (9,253) 12,198 Natural Gas Residential Sales — — — 287,027 — — 287,027 Natural Gas Commercial Sales — — — 43,193 — — 43,193 Natural Gas Industrial Sales — — — 2,193 — — 2,193 Other 5,305 1,275 — (4,147) — (143) 2,290 Total Revenues from Contracts with Customers 391,864 95,397 52,604 369,749 — (77,076) 832,538 Alternative Revenue Programs — — — (547) — — (547) Derivative Financial Instruments (130,271) — — — — — (130,271) Total Revenues $ 261,593 $ 95,397 $ 52,604 $ 369,202 $ — $ (77,076) $ 701,720 Six Months Ended March 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 $ 697,242 $ — $ — $ — $ — $ — $ 697,242 Production of Crude Oil 91,984 — — — — — 91,984 Natural Gas Processing 2,013 — — — — — 2,013 Natural Gas Gathering Service — — 104,829 — — (97,627) 7,202 Natural Gas Transportation Service — 138,940 — 69,257 — (35,858) 172,339 Natural Gas Storage Service — 42,251 — — — (18,278) 23,973 Natural Gas Residential Sales — — — 466,038 — — 466,038 Natural Gas Commercial Sales — — — 67,191 — — 67,191 Natural Gas Industrial Sales — — — 3,340 — — 3,340 Other 7,451 2,556 — (6,147) 6 (293) 3,573 Total Revenues from Contracts with Customers 798,690 183,747 104,829 599,679 6 (152,056) 1,534,895 Alternative Revenue Programs — — — 6,281 — — 6,281 Derivative Financial Instruments (292,899) — — — — — (292,899) Total Revenues $ 505,791 $ 183,747 $ 104,829 $ 605,960 $ 6 $ (152,056) $ 1,248,277

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Mar. 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 March 31, 2023 and September 30, 2022. 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 March 31, 2023 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 53,519 $ — $ — $ — $ 53,519 Derivative Financial Instruments: Over the Counter Swaps – Gas — 59,179 — (52,327) 6,852 Over the Counter No Cost Collars – Gas — 56,879 — (26,070) 30,809 Contingent Consideration for Asset Sale — 5,903 — — 5,903 Foreign Currency Contracts — 213 — (1,353) (1,140) Other Investments: Balanced Equity Mutual Fund 15,924 — — — 15,924 Fixed Income Mutual Fund 15,949 — — — 15,949 Total $ 85,392 $ 122,174 $ — $ (79,750) $ 127,816 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 91,509 $ — $ (52,327) $ 39,182 Over the Counter No Cost Collars – Gas — 21,616 — (26,070) (4,454) Foreign Currency Contracts — 1,388 — (1,353) 35 Total $ — $ 114,513 $ — $ (79,750) $ 34,763 Total Net Assets/(Liabilities) $ 85,392 $ 7,661 $ — $ — $ 93,053 Recurring Fair Value Measures At fair value as of September 30, 2022 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 35,015 $ — $ — $ — $ 35,015 Hedging Collateral Deposits 91,670 — — — 91,670 Derivative Financial Instruments: Over the Counter Swaps – Gas — 5,177 — (4,178) 999 Contingent Consideration for Asset Sale — 8,176 — — 8,176 Foreign Currency Contracts — 128 — (128) — Other Investments: Balanced Equity Mutual Fund 19,506 — — — 19,506 Fixed Income Mutual Fund 33,348 — — — 33,348 Total $ 179,539 $ 13,481 $ — $ (4,306) $ 188,714 Liabilities: Derivative Financial Instruments: Over the Counter Swaps – Gas $ — $ 517,464 $ — $ (4,178) $ 513,286 Over the Counter No Cost Collars – Gas — 270,453 — — 270,453 Foreign Currency Contracts — 2,048 — (128) 1,920 Total $ — $ 789,965 $ — $ (4,306) $ 785,659 Total Net Assets/(Liabilities) $ 179,539 $ (776,484) $ — $ — $ (596,945) (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)	6 Months Ended
	Mar. 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): March 31, 2023 September 30, 2022 Carrying Fair Value Carrying Fair Value Long-Term Debt $ 2,085,235 $ 1,951,250 $ 2,632,409 $ 2,453,209
Schedule Of Other Investments	The components of the Company's Other Investments are as follows (in thousands): At March 31, 2023 At September 30, 2022 Life Insurance Contracts $ 42,745 $ 42,171 Equity Mutual Fund 15,924 19,506 Fixed Income Mutual Fund 15,949 33,348 $ 74,618 $ 95,025
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 March 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 $ 310,623 $ (642,240) Operating Revenue $ (18,768) $ (130,271) Foreign Currency Contracts (79) 634 Operating Revenue (172) 50 Total $ 310,544 $ (641,606) $ (18,940) $ (130,221) The Effect of Derivative Financial Instruments on the Statement of Financial Performance for the Six Months Ended March 31, 2023 and 2022 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or Location of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income Amount of Derivative Gain or 2023 2022 2023 2022 Commodity Contracts $ 607,743 $ (479,114) Operating Revenue $ (177,930) $ (292,899) Foreign Currency Contracts 394 640 Operating Revenue (351) 90 Total $ 608,137 $ (478,474) $ (178,281) $ (292,809)

Capitalization (Tables)

Capitalization (Tables)	6 Months Ended
	Mar. 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 January 1, 2023 91,787 $ 91,787 $ 1,025,639 $ 1,713,176 $ (293,746) Net Income Available for Common Stock 140,880 Dividends Declared on Common Stock ($0.475 Per Share) (43,602) Other Comprehensive Income, Net of Tax 238,882 Share-Based Payment Expense (1) 5,200 Common Stock Issued Under Stock and Benefit Plans 8 8 502 Balance at March 31, 2023 91,795 $ 91,795 $ 1,031,341 $ 1,810,454 $ (54,864) Balance at October 1, 2022 91,478 $ 91,478 $ 1,027,066 $ 1,587,085 $ (625,733) Net Income Available for Common Stock 310,570 Dividends Declared on Common Stock ($0.95 Per Share) (87,201) Other Comprehensive Income, Net of Tax 570,869 Share-Based Payment Expense (1) 10,318 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 317 317 (6,043) Balance at March 31, 2023 91,795 $ 91,795 $ 1,031,341 $ 1,810,454 $ (54,864) Balance at January 1, 2022 91,437 $ 91,437 $ 1,013,821 $ 1,281,963 $ (277,026) Net Income Available for Common Stock 167,328 Dividends Declared on Common Stock ($0.455 Per Share) (41,608) Other Comprehensive Loss, Net of Tax (377,228) Share-Based Payment Expense (1) 4,692 Common Stock Issued Under Stock and Benefit Plans 12 12 271 Balance at March 31, 2022 91,449 $ 91,449 $ 1,018,784 $ 1,407,683 $ (654,254) Balance at October 1, 2021 91,182 $ 91,182 $ 1,017,446 $ 1,191,175 $ (513,597) Net Income Available for Common Stock 299,720 Dividends Declared on Common Stock ($0.91 Per Share) (83,212) Other Comprehensive Loss, Net of Tax (140,657) Share-Based Payment Expense (1) 9,732 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 267 267 (8,394) Balance at March 31, 2022 91,449 $ 91,449 $ 1,018,784 $ 1,407,683 $ (654,254) (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)	6 Months Ended
	Mar. 31, 2023
Segment Reporting [Abstract]
Financial Segment Information By Segment	Quarter Ended March 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 $244,552 $64,223 $1,728 $406,758 $717,261 $— $— $717,261 Intersegment Revenues $— $30,880 $55,253 $358 $86,491 $— $(86,491) $— Segment Profit: Net Income (Loss) $60,982 $23,858 $24,334 $31,720 $140,894 $(69) $55 $140,880 Six Months Ended March 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 $521,525 $131,844 $4,374 $718,376 $1,376,119 $— $— $1,376,119 Intersegment Revenues $— $60,915 $109,020 $420 $170,355 $— $(170,355) $— Segment Profit: Net Income (Loss) $152,174 $53,335 $49,072 $55,537 $310,118 $(350) $802 $310,570 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Segment Assets: At March 31, 2023 $2,489,665 $2,357,852 $882,405 $2,363,918 $8,093,840 $2,105 $(128,703) $7,967,242 At September 30, 2022 $2,507,541 $2,394,697 $878,796 $2,299,473 $8,080,507 $2,036 $(186,281) $7,896,262 Quarter Ended March 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 $261,593 $67,795 $3,157 $369,092 $701,637 $— $83 $701,720 Intersegment Revenues $— $27,602 $49,447 $110 $77,159 $— $(77,159) $— Segment Profit: Net Income (Loss) $71,121 $25,470 $22,092 $53,048 $171,731 $— $(4,403) $167,328 Six Months Ended March 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 $505,791 $129,342 $7,202 $605,776 $1,248,111 $— $166 $1,248,277 Intersegment Revenues $— $54,405 $97,627 $184 $152,216 $6 $(152,222) $— Segment Profit: Net Income (Loss) $133,490 $50,637 $45,229 $75,178 $304,534 $(7) $(4,807) $299,720

Retirement Plan And Other Pos_2

Retirement Plan And Other Post-Retirement Benefits (Tables)	6 Months Ended
	Mar. 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 March 31, 2023 2022 2023 2022 Service Cost $ 1,297 $ 2,190 $ 147 $ 332 Interest Cost 10,629 5,707 3,912 2,267 Expected Return on Plan Assets (16,648) (13,074) (6,403) (7,340) Amortization of Prior Service Cost (Credit) 109 134 (107) (107) Amortization of (Gains) Losses (1,920) 6,601 (2,189) (1,903) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 5,378 8,418 3,493 4,274 Net Periodic Benefit Cost (Income) $ (1,155) $ 9,976 $ (1,147) $ (2,477) Retirement Plan Other Post-Retirement Benefits Six Months Ended March 31, 2023 2022 2023 2022 Service Cost $ 2,594 $ 4,379 $ 293 $ 664 Interest Cost 21,258 11,414 7,824 4,533 Expected Return on Plan Assets (33,297) (26,147) (12,806) (14,680) Amortization of Prior Service Cost (Credit) 218 268 (214) (214) Amortization of (Gains) Losses (3,840) 13,202 (4,378) (3,805) Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 10,756 12,838 7,314 10,519 Net Periodic Benefit Cost (Income) $ (2,311) $ 15,954 $ (1,967) $ (2,983) (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 (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022	Sep. 30, 2022	Sep. 30, 2023
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground	$ 6,554		$ 6,554		$ 32,364
Capitalized Costs Oil and Gas Producing Activities Net	$ 2,200,000		2,200,000		1,900,000
Capitalized costs of unproved properties excluded from amortization			$ 73,000		66,000
Full cost ceiling test discount factor	10%		10%
Amount Full Cost Ceiling Exceeds Book Value Of Oil And Gas Properties	$ 2,700,000		$ 2,700,000
Decrease estimated future net cash flows	(936,800)
Other Post-Retirement Adjustment for Regulatory Proceeding	$ 0	$ (7,351)	$ 0	$ (7,351)
Other Post-Retirement Adjustment for Regulatory Proceeding After Tax		$ (5,807)		$ (5,807)
Antidilutive securities	9,909	13,815	4,094	11,883
Reserve For Gas Replacement [Member]
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground	$ 106,835		$ 106,835		$ 0
Restricted Stock Units [Member]
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period			115,073
Granted in fiscal year, weighted average grant date fair value			$ 59.69
Performance Shares [Member]
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period			202,259
Granted in fiscal year, weighted average grant date fair value			$ 64.28
Subsequent Event [Member] | Reserve For Gas Replacement [Member]
Summary Of Significant Accounting Policies [Line Items]
Gas Stored Underground						$ 0

Summary Of Significant Accoun_5

Summary Of Significant Accounting Policies (Consolidated Statements Of Cash Flows) (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Sep. 30, 2022		Mar. 31, 2022	Sep. 30, 2021
Cash and Cash Equivalents [Line Items]
Cash and Temporary Cash Investments	$ 71,533	$ 46,048		$ 52,569	$ 31,528
Hedging Collateral Deposits	0	91,670	[1]	102,370	88,610
Cash, Cash Equivalents and Restricted Cash	$ 71,533	$ 137,718		$ 154,939	$ 120,138
[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.

Summary Of Significant Accoun_6

Summary Of Significant Accounting Policies (Allowance for Uncollectible Accounts) (Details) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Allowance for Uncollectible Accounts [Roll Forward]
Balance at Beginning of Period	$ 40,228	$ 31,639
Additions Charged to Costs and Expenses	10,973	9,684
Discounts on Purchased Receivables	916	790
Net Accounts Receivable Written-Off	(3,971)	(630)
Balance at End of Period	$ 48,146	$ 41,483

Summary Of Significant Accoun_7

Summary Of Significant Accounting Policies (Components Of Accumulated Other Comprehensive Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	$ (293,746)	$ (277,026)	$ (625,733)	$ (513,597)
Other Comprehensive Gains and Losses Before Reclassifications	225,150	(466,001)	441,367	(347,518)
Amounts Reclassified From Other Comprehensive Income (Loss)	13,732	94,580	129,502	212,668
Other Post-Retirement Adjustment for Regulatory Proceeding		(5,807)		(5,807)
Balance at End of Period	(54,864)	(654,254)	(54,864)	(654,254)
Gains And Losses On Derivative Financial Instruments [Member]
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	(240,176)	(213,391)	(572,163)	(449,962)
Other Comprehensive Gains and Losses Before Reclassifications	225,150	(466,001)	441,367	(347,518)
Amounts Reclassified From Other Comprehensive Income (Loss)	13,732	94,580	129,502	212,668
Other Post-Retirement Adjustment for Regulatory Proceeding		0		0
Balance at End of Period	(1,294)	(584,812)	(1,294)	(584,812)
Funded Status Of The Pension And Other Post-Retirement Benefit Plans [Member]
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	(53,570)	(63,635)	(53,570)	(63,635)
Other Comprehensive Gains and Losses Before Reclassifications	0	0	0	0
Amounts Reclassified From Other Comprehensive Income (Loss)	0	0	0	0
Other Post-Retirement Adjustment for Regulatory Proceeding		(5,807)		(5,807)
Balance at End of Period	$ (53,570)	$ (69,442)	$ (53,570)	$ (69,442)

Summary Of Significant Accoun_8

Summary Of Significant Accounting Policies (Reclassification Out Of Accumulated Other Comprehensive Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Operating Revenues	$ 717,261	$ 701,720	$ 1,376,119	$ 1,248,277
Income Before Income Taxes	190,817	224,786	418,059	402,076
Income Tax Expense	(49,937)	(57,458)	(107,489)	(102,356)
Net Income Available for Common Stock	140,880	167,328	310,570	299,720
Amount Of Gain Or (Loss) Reclassified From Accumulated Other Comprehensive Loss [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Income Before Income Taxes	(18,940)	(130,221)	(178,281)	(292,809)
Income Tax Expense	5,208	35,641	48,779	80,141
Net Income Available for Common Stock	(13,732)	(94,580)	(129,502)	(212,668)
Amount Of Gain Or (Loss) Reclassified From Accumulated Other Comprehensive Loss [Member] | Commodity Contracts [Member] | Gains And Losses On Derivative Financial Instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Operating Revenues	(18,768)	(130,271)	(177,930)	(292,899)
Foreign Currency Contracts [Member] | Amount Of Gain Or (Loss) Reclassified From Accumulated Other Comprehensive Loss [Member] | Gains And Losses On Derivative Financial Instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Operating Revenues	$ (172)	$ 50	$ (351)	$ 90

Summary Of Significant Accoun_9

Summary Of Significant Accounting Policies (Components Of Other Current Assets) (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Sep. 30, 2022
Summary Of Significant Accounting Policies [Line Items]
Prepayments	$ 14,821	$ 17,757
Prepaid Property and Other Taxes	23,218	14,321
Regulatory Assets	32,062	21,358
Other Current Assets	75,233	59,369
State [Member]
Summary Of Significant Accounting Policies [Line Items]
Prepaid State Income Taxes	$ 5,132	$ 5,933

Summary Of Significant Accou_10

Summary Of Significant Accounting Policies (Schedule Of Other Accruals And Current Liabilities) (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Sep. 30, 2022
Summary Of Significant Accounting Policies [Line Items]
Regulatory Liabilities	$ 39,662	$ 31,293
Reserve for Gas Replacement	6,554	32,364
Liability for Royalty and Working Interests	14,365	86,206
Other Accruals and Current Liabilities	257,923	257,327
Accrued Capital Expenditures [Member]
Summary Of Significant Accounting Policies [Line Items]
Other	39,232	64,720
Reserve For Gas Replacement [Member]
Summary Of Significant Accounting Policies [Line Items]
Reserve for Gas Replacement	106,835	0
Other Accruals [Member]
Summary Of Significant Accounting Policies [Line Items]
Other	40,355	57,634
Non-Qualified [Member] | Current [Member]
Summary Of Significant Accounting Policies [Line Items]
Non-Qualified Benefit Plan Liability	$ 17,474	$ 17,474

Asset Acquisitions and Divest_2

Asset Acquisitions and Divestitures (Narrative) (Details) - USD ($)	6 Months Ended		12 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Sep. 30, 2022	Jun. 30, 2022
Asset Acquisitions and Divestitures [Line Items]
Deposit Paid for Upstream Assets	$ 12,700,000	$ 0
Net Proceeds from Sale of Oil and Gas Producing Properties	0	$ 13,525,000
SWN Upstream Asset Acquisition [Member]
Asset Acquisitions and Divestitures [Line Items]
Consideration for Asset Acquisition of Upstream Assets	127,000,000
Deposit Paid for Upstream Assets	12,700,000
California Asset Sale [Member]
Asset Acquisitions and Divestitures [Line Items]
Consideration for Asset Sale				$ 253,500,000
Net Proceeds from Sale of Oil and Gas Producing Properties			$ 240,900,000
Maximum Annual Contingent Payments				10,000,000
Amount of Each Incremental Contingent Payment				1,000,000
Incremental Dollar Per Barrel That ICE Brent Average Exceeds Price				1
Gain on Sale of Assets			12,700,000
Asset Retirement Obligation Reduction			50,100,000
California Asset Sale [Member] | Minimum [Member]
Asset Acquisitions and Divestitures [Line Items]
ICE Brent Average per Barrel				95
California Asset Sale [Member] | Maximum [Member]
Asset Acquisitions and Divestitures [Line Items]
ICE Brent Average per Barrel				105
California Asset Sale [Member] | Present Value of Contingent Consideration [Member]
Asset Acquisitions and Divestitures [Line Items]
Value of Contingent Consideration from Asset Sale	$ 5,900,000		$ 8,200,000	12,600,000
Full Cost Method of Accounting Assets [Member] | California Asset Sale [Member]
Asset Acquisitions and Divestitures [Line Items]
Property, Plant and Equipment Disposal				220,700,000
Assets Not Subject to Full Cost Method of Accounting [Member] | California Asset Sale [Member]
Asset Acquisitions and Divestitures [Line Items]
Property, Plant and Equipment Disposal				$ 32,800,000

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Narrative) (Details) $ in Millions	Mar. 31, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 106
Remaining Performance Obligation, Expected Timing of Satisfaction	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 206.4
Remaining Performance Obligation, Expected Timing of Satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 181.1
Remaining Performance Obligation, Expected Timing of Satisfaction	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]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 146.9
Remaining Performance Obligation, Expected Timing of Satisfaction	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]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 123
Remaining Performance Obligation, Expected Timing of Satisfaction	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]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 692.6
Remaining Performance Obligation, Expected Timing of Satisfaction

Revenue from Contracts with C_4

Revenue from Contracts with Customers (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022
Disaggregation of Revenue [Line Items]
Revenue	$ 717,261	$ 701,720	$ 1,376,119	$ 1,248,277
Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	263,320	391,864	699,455	798,690
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	(18,768)	(130,271)	(177,930)	(292,899)
Revenue	244,552	261,593	521,525	505,791
Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	95,103	95,397	192,759	183,747
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Revenue	95,103	95,397	192,759	183,747
Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	56,981	52,604	113,394	104,829
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Revenue	56,981	52,604	113,394	104,829
Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	404,315	369,749	712,873	599,679
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	2,801	(547)	5,923	6,281
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Revenue	407,116	369,202	718,796	605,960
All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	6
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Revenue	0	0	0	6
Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(86,491)	(77,076)	(170,355)	(152,056)
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Revenue	(86,491)	(77,076)	(170,355)	(152,056)
Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	733,228	832,538	1,548,126	1,534,895
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	2,801	(547)	5,923	6,281
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	(18,768)	(130,271)	(177,930)	(292,899)
Revenue	717,261	701,720	1,376,119	1,248,277
Production of Natural Gas [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	259,770	335,961	692,129	697,242
Production of Natural Gas [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Natural Gas [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Natural Gas [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Natural Gas [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Natural Gas [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Natural Gas [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	259,770	335,961	692,129	697,242
Production of Crude Oil [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	526	49,613	1,154	91,984
Production of Crude Oil [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Crude Oil [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Crude Oil [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Crude Oil [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Crude Oil [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Production of Crude Oil [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	526	49,613	1,154	91,984
Natural Gas Processing [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	209	985	583	2,013
Natural Gas Processing [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Processing [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Processing [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Processing [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Processing [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Processing [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	209	985	583	2,013
Natural Gas Gathering Service [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Gathering Service [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Gathering Service [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	56,981	52,604	113,394	104,829
Natural Gas Gathering Service [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Gathering Service [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Gathering Service [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(55,253)	(49,447)	(109,020)	(97,627)
Natural Gas Gathering Service [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,728	3,157	4,374	7,202
Natural Gas Transportation Service [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Transportation Service [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	73,794	72,671	149,996	138,940
Natural Gas Transportation Service [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Transportation Service [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	35,796	41,483	64,174	69,257
Natural Gas Transportation Service [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Transportation Service [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(21,751)	(18,233)	(42,568)	(35,858)
Natural Gas Transportation Service [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	87,839	95,921	171,602	172,339
Natural Gas Storage Service [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Storage Service [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	21,470	21,451	42,756	42,251
Natural Gas Storage Service [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Storage Service [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Storage Service [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Storage Service [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(9,219)	(9,253)	(18,215)	(18,278)
Natural Gas Storage Service [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	12,251	12,198	24,541	23,973
Natural Gas Residential Sales [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	318,649	287,027	562,955	466,038
Natural Gas Residential Sales [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Residential Sales [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	318,649	287,027	562,955	466,038
Natural Gas Commercial Sales [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	48,966	43,193	83,461	67,191
Natural Gas Commercial Sales [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Commercial Sales [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	48,966	43,193	83,461	67,191
Natural Gas Industrial Sales [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Industrial Sales [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Industrial Sales [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Industrial Sales [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,768	2,193	4,407	3,340
Natural Gas Industrial Sales [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Industrial Sales [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(4)	0	(4)	0
Natural Gas Industrial Sales [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,764	2,193	4,403	3,340
Other [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,815	5,305	5,589	7,451
Other [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(161)	1,275	7	2,556
Other [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Other [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(1,864)	(4,147)	(2,124)	(6,147)
Other [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	6
Other [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(264)	(143)	(548)	(293)
Other [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ 526	$ 2,290	$ 2,924	$ 3,573

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details) - USD ($)		Mar. 31, 2023	Sep. 30, 2022		Mar. 31, 2022	Sep. 30, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hedging Collateral Deposits		$ 0	$ 91,670,000	[1]	$ 102,370,000	$ 88,610,000
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hedging Collateral Deposits	[1]		$ 91,670,000
Derivative Financial Instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Level 3 Fair Value		$ 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 (Recurr

Fair Value Measurements (Recurring Fair Value Measures Of Assets And Liabilities) (Details) - USD ($) $ in Thousands		Mar. 31, 2023	Sep. 30, 2022		Mar. 31, 2022	Sep. 30, 2021
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Cash Equivalents - Money Market Mutual Funds	[1]	$ 53,519	$ 35,015
Hedging Collateral Deposits		0	91,670	[1]	$ 102,370	$ 88,610
Total Assets	[1]	127,816	188,714
Total Liabilities	[1]	34,763	785,659
Total Net Assets/(Liabilities)	[1]	93,053	(596,945)
Over the Counter Swaps - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	6,852	999
Derivative Liability	[1]	39,182	513,286
Over the Counter No Cost Collars - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	30,809
Derivative Liability	[1]	(4,454)	270,453
Contingent Consideration for Asset Sale [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	5,903	8,176
Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(1,140)	0
Derivative Liability	[1]	35	1,920
Balanced Equity Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments	[1]	15,924	19,506
Fixed Income Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments	[1]	15,949	33,348
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Cash Equivalents - Money Market Mutual Funds		53,519	35,015
Hedging Collateral Deposits	[1]		91,670
Total Assets		85,392	179,539
Total Liabilities		0	0
Total Net Assets/(Liabilities)		85,392	179,539
Fair Value, Inputs, Level 1 [Member] | Over the Counter Swaps - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liability		0	0
Fair Value, Inputs, Level 1 [Member] | Over the Counter No Cost Collars - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		0
Derivative Liability		0	0
Fair Value, Inputs, Level 1 [Member] | Contingent Consideration for Asset Sale [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		0	0
Fair Value, Inputs, Level 1 [Member] | Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liability		0	0
Fair Value, Inputs, Level 1 [Member] | Balanced Equity Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments		15,924	19,506
Fair Value, Inputs, Level 1 [Member] | Fixed Income Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments		15,949	33,348
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Cash Equivalents - Money Market Mutual Funds		0	0
Hedging Collateral Deposits	[1]		0
Total Assets		122,174	13,481
Total Liabilities		114,513	789,965
Total Net Assets/(Liabilities)		7,661	(776,484)
Fair Value, Inputs, Level 2 [Member] | Over the Counter Swaps - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		59,179	5,177
Derivative Liability		91,509	517,464
Fair Value, Inputs, Level 2 [Member] | Over the Counter No Cost Collars - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		56,879
Derivative Liability		21,616	270,453
Fair Value, Inputs, Level 2 [Member] | Contingent Consideration for Asset Sale [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		5,903	8,176
Fair Value, Inputs, Level 2 [Member] | Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		213	128
Derivative Liability		1,388	2,048
Fair Value, Inputs, Level 2 [Member] | Balanced Equity Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments		0	0
Fair Value, Inputs, Level 2 [Member] | Fixed Income Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments		0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Cash Equivalents - Money Market Mutual Funds		0	0
Hedging Collateral Deposits	[1]		0
Total Assets		0	0
Total Liabilities		0	0
Total Net Assets/(Liabilities)		0	0
Fair Value, Inputs, Level 3 [Member] | Over the Counter Swaps - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liability		0	0
Fair Value, Inputs, Level 3 [Member] | Over the Counter No Cost Collars - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		0
Derivative Liability		0	0
Fair Value, Inputs, Level 3 [Member] | Contingent Consideration for Asset Sale [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		0	0
Fair Value, Inputs, Level 3 [Member] | Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liability		0	0
Fair Value, Inputs, Level 3 [Member] | Balanced Equity Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments		0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Income Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments		0	0
Netting Adjustments [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Cash Equivalents - Money Market Mutual Funds	[1]	0	0
Hedging Collateral Deposits	[1]		0
Total Assets	[1]	(79,750)	(4,306)
Total Liabilities	[1]	(79,750)	(4,306)
Total Net Assets/(Liabilities)	[1]	0	0
Netting Adjustments [Member] | Over the Counter Swaps - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(52,327)	(4,178)
Derivative Liability	[1]	(52,327)	(4,178)
Netting Adjustments [Member] | Over the Counter No Cost Collars - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(26,070)
Derivative Liability	[1]	(26,070)	0
Netting Adjustments [Member] | Contingent Consideration for Asset Sale [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	0	0
Netting Adjustments [Member] | Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(1,353)	(128)
Derivative Liability	[1]	(1,353)	(128)
Netting Adjustments [Member] | Balanced Equity Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments	[1]	0	0
Netting Adjustments [Member] | Fixed Income Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
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.

Financial Instruments (Narrativ

Financial Instruments (Narrative) (Details)	3 Months Ended	6 Months Ended
	Mar. 31, 2023 USD ($) counterparty MMcf	Mar. 31, 2023 USD ($) counterparty MMcf	Sep. 30, 2022 USD ($)		Jun. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Sep. 30, 2021 USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Foreign Currency Forward Contract Hedge Duration		8 years
After tax net hedging gains (losses) in accumulated other comprehensive loss	$ (1,300,000)	$ (1,300,000)
After Tax Net Hedging Gains (Losses) Reclassified Within Twelve Months		37,400,000
Fair market value of derivative liability with a credit-risk related contingency	7,100,000	7,100,000
Hedging Collateral Deposits	0	0	$ 91,670,000	[1]		$ 102,370,000	$ 88,610,000
California Asset Sale [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Maximum Annual Contingent Payments					$ 10,000,000
Amount of Each Incremental Contingent Payment					1,000,000
Incremental Dollar Per Barrel That ICE Brent Average Exceeds Price					1
California Asset Sale [Member] | Present Value of Contingent Consideration [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Value of Contingent Consideration from Asset Sale	5,900,000	5,900,000	$ 8,200,000		12,600,000
California Asset Sale [Member] | Mark to Market of Contingent Consideration [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Mark-to-Market Adjustment for Contingent Consideration	$ (2,500,000)	$ (2,300,000)
California Asset Sale [Member] | Minimum [Member]
Derivative Instruments, Gain (Loss) [Line Items]
ICE Brent Average per Barrel					95
California Asset Sale [Member] | Maximum [Member]
Derivative Instruments, Gain (Loss) [Line Items]
ICE Brent Average per Barrel					$ 105
Cash Flow Hedges [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Hedge Duration		5 years
Over the Counter Swaps, No Cost Collars and Foreign Currency Forward Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Number of counterparties in which the company holds over-the-counter swap positions | counterparty	16	16
Number of counterparties in net gain position | counterparty	8	8
Credit risk exposure per counterparty	$ 4,600,000	$ 4,600,000
Maximum Credit Risk Exposure Per Counterparty		11,100,000
Collateral Received by the Company	0	0
Hedging Collateral Deposits	$ 0	$ 0
Natural Gas MMCf [Member] | Cash Flow Hedges [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk cash flow hedge derivatives, natural gas | MMcf	462,900	462,900
Foreign Currency Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Notional Amount	$ 51,000,000	$ 51,000,000
Credit Risk Related Contingency Feature [Member] | Over the Counter Swaps, No Cost Collars and Foreign Currency Forward Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Number of counterparties with a common credit-risk related contingency | counterparty	14	14
[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 (Long-Ter

Financial Instruments (Long-Term Debt) (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Sep. 30, 2022
Financial Instruments, Owned, at Fair Value, by Type, Alternative [Abstract]
Carrying Amount	$ 2,085,235	$ 2,632,409
Fair Value	$ 1,951,250	$ 2,453,209

Financial Instruments (Other In

Financial Instruments (Other Investments) (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Sep. 30, 2022
Investment Holdings [Line Items]
Life Insurance Contracts	$ 42,745	$ 42,171
Other Investments	74,618	95,025
Equity Mutual Fund [Member]
Investment Holdings [Line Items]
Fair Value	15,924	19,506
Fixed Income Mutual Fund [Member]
Investment Holdings [Line Items]
Fair Value	$ 15,949	$ 33,348

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		6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 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)	$ 310,544	$ (641,606)	$ 608,137	$ (478,474)
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	(18,940)	(130,221)	(178,281)	(292,809)
Foreign Currency Contracts [Member] | Operating Revenues [Member]
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)	(79)	634	394	640
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	(172)	50	(351)	90
Commodity Contracts [Member] | Operating Revenues [Member]
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)	310,623	(642,240)	607,743	(479,114)
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	$ (18,768)	$ (130,271)	$ (177,930)	$ (292,899)

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details)	3 Months Ended		6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022
Income Tax Disclosure [Abstract]
Effective Tax Rate	26.20%	25.60%	25.70%	25.50%

Capitalization (Narrative) (Det

Capitalization (Narrative) (Details) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2023	Nov. 25, 2022	Sep. 30, 2022
Debt Instrument [Line Items]
Common stock shares issued due to SARs exercises	12,055
Shares tendered	102,761
Current Portion of Long-Term Debt	$ 0		$ 549,000
364-Day Credit Agreement
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	250,000
Committed Credit Facility Amount Drawn	250,000
3.75% Notes Due March 2023 [Member]
Debt Instrument [Line Items]
Debt instrument redeemed	$ 350,000	$ 150,000
Current Portion of Long-Term Debt			$ 500,000
Long-term debt, interest rate	3.75%	3.75%	3.75%
7.395% Notes Due March 2023 [Member]
Debt Instrument [Line Items]
Debt instrument redeemed	$ 49,000
Current Portion of Long-Term Debt			$ 49,000
Long-term debt, interest rate	7.395%		7.395%
Restricted Stock Units [Member]
Debt Instrument [Line Items]
Common stock issued	113,531
Performance Shares [Member]
Debt Instrument [Line Items]
Common stock issued	278,687
Board Of Directors [Member]
Debt Instrument [Line Items]
Common stock issued	14,680
Officer DCP Plan [Member]
Debt Instrument [Line Items]
Common stock issued	824

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		6 Months Ended
		Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022
Schedule of Capitalization, Equity [Line Items]
Beginning balance (shares)				91,478,064
Beginning balance				$ 1,027,066
Balance at Beginning of Period		$ 1,713,176	$ 1,281,963	1,587,085	$ 1,191,175
Balance at Beginning of Period		(293,746)	(277,026)	(625,733)	(513,597)
Net Income Available for Common Stock		140,880	167,328	310,570	299,720
Dividends Declared on Common Stock		(43,602)	(41,608)	(87,201)	(83,212)
Other Comprehensive Income (Loss), Net of Tax		$ 238,882	(377,228)	$ 570,869	(140,657)
Ending balance (shares)		91,795,080		91,795,080
Ending balance		$ 1,031,341		$ 1,031,341
Balance at March 31		1,810,454	1,407,683	1,810,454	1,407,683
Balance at End of Period		$ (54,864)	$ (654,254)	$ (54,864)	$ (654,254)
Dividends per share		$ 0.475	$ 0.455	$ 0.95	$ 0.91
Paid-in Capital [Member]
Schedule of Capitalization, Equity [Line Items]
Beginning balance		$ 1,025,639	$ 1,013,821	$ 1,027,066	$ 1,017,446
Share-Based Payment Expense	[1]	5,200	4,692	10,318	9,732
Common Stock Issued Under Stock and Benefit Plans		502	271
Stock Repurchased under Stock and Benefit Plans				(6,043)	(8,394)
Ending balance		1,031,341	1,018,784	1,031,341	1,018,784
Earnings Reinvested in The Business [Member]
Schedule of Capitalization, Equity [Line Items]
Balance at Beginning of Period		1,713,176	1,281,963	1,587,085	1,191,175
Net Income Available for Common Stock		140,880	167,328	310,570	299,720
Dividends Declared on Common Stock		(43,602)	(41,608)	(87,201)	(83,212)
Balance at March 31		1,810,454	1,407,683	1,810,454	1,407,683
Accumulated Other Comprehensive Income (Loss) [Member]
Schedule of Capitalization, Equity [Line Items]
Balance at Beginning of Period		(293,746)	(277,026)	(625,733)	(513,597)
Other Comprehensive Income (Loss), Net of Tax		238,882	(377,228)	570,869	(140,657)
Balance at End of Period		$ (54,864)	$ (654,254)	$ (54,864)	$ (654,254)
Common Stock [Member]
Schedule of Capitalization, Equity [Line Items]
Beginning balance (shares)		91,787,000	91,437,000	91,478,000	91,182,000
Beginning balance (value)		$ 91,787	$ 91,437	$ 91,478	$ 91,182
Common Stock Issued Under Stock and Benefit Plans (Shares)		8,000	12,000	317,000	267,000
Common Stock Issued Under Stock and Benefit Plans		$ 8	$ 12	$ 317	$ 267
Ending balance (shares)		91,795,000	91,449,000	91,795,000	91,449,000
Ending balance (value)		$ 91,795	$ 91,449	$ 91,795	$ 91,449
[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.

Commitments And Contingencies (

Commitments And Contingencies (Details) $ in Millions	6 Months Ended
	Mar. 31, 2023 USD ($)
Commitments and Contingencies [Line Items]
Estimated minimum liability for environmental remediation	$ 3.8
Project Costs	$ 55.9
Less Than One Year [Member]
Commitments and Contingencies [Line Items]
Rate recovery period	1 year

Business Segment Information (N

Business Segment Information (Narrative) (Details)	6 Months Ended
	Mar. 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		6 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022	Sep. 30, 2022
Segment Reporting Information [Line Items]
Revenue	$ 717,261	$ 701,720	$ 1,376,119	$ 1,248,277
Segment Profit: Net Income (Loss)	140,880	167,328	310,570	299,720
Segment Assets	7,967,242		7,967,242		$ 7,896,262
Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	717,261	701,720	1,376,119	1,248,277
Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	0	0	0	0
Exploration And Production [Member]
Segment Reporting Information [Line Items]
Revenue	244,552	261,593	521,525	505,791
Segment Profit: Net Income (Loss)	60,982	71,121	152,174	133,490
Segment Assets	2,489,665		2,489,665		2,507,541
Exploration And Production [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	244,552	261,593	521,525	505,791
Exploration And Production [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	0	0	0	0
Pipeline And Storage [Member]
Segment Reporting Information [Line Items]
Revenue	95,103	95,397	192,759	183,747
Segment Profit: Net Income (Loss)	23,858	25,470	53,335	50,637
Segment Assets	2,357,852		2,357,852		2,394,697
Pipeline And Storage [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	64,223	67,795	131,844	129,342
Pipeline And Storage [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	30,880	27,602	60,915	54,405
Gathering [Member]
Segment Reporting Information [Line Items]
Revenue	56,981	52,604	113,394	104,829
Segment Profit: Net Income (Loss)	24,334	22,092	49,072	45,229
Segment Assets	882,405		882,405		878,796
Gathering [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	1,728	3,157	4,374	7,202
Gathering [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	55,253	49,447	109,020	97,627
Utility [Member]
Segment Reporting Information [Line Items]
Revenue	407,116	369,202	718,796	605,960
Segment Profit: Net Income (Loss)	31,720	53,048	55,537	75,178
Segment Assets	2,363,918		2,363,918		2,299,473
Utility [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	406,758	369,092	718,376	605,776
Utility [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	358	110	420	184
Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)	140,894	171,731	310,118	304,534
Segment Assets	8,093,840		8,093,840		8,080,507
Total Reportable Segments [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	717,261	701,637	1,376,119	1,248,111
Total Reportable Segments [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	86,491	77,159	170,355	152,216
All Other [Member]
Segment Reporting Information [Line Items]
Revenue	0	0	0	6
Segment Profit: Net Income (Loss)	(69)	0	(350)	(7)
Segment Assets	2,105		2,105		2,036
All Other [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	0	0	0	0
All Other [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	0	0	0	6
Corporate And Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue	(86,491)	(77,076)	(170,355)	(152,056)
Segment Profit: Net Income (Loss)	55	(4,403)	802	(4,807)
Segment Assets	(128,703)		(128,703)		$ (186,281)
Corporate And Intersegment Eliminations [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	0	83	0	166
Corporate And Intersegment Eliminations [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	$ (86,491)	$ (77,159)	$ (170,355)	$ (152,222)

Retirement Plan And Other Pos_3

Retirement Plan And Other Post-Retirement Benefits (Narrative) (Details) $ in Millions	6 Months Ended
	Mar. 31, 2023 USD ($)
Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Company's contributions	$ 0
VEBA Trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Company's contributions	$ 0

Retirement Plan And Other Pos_4

Retirement Plan And Other Post-Retirement Benefits (Components Of Net Periodic Benefit Cost) (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2023	Mar. 31, 2022
Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service Cost		$ 1,297	$ 2,190	$ 2,594	$ 4,379
Interest Cost		10,629	5,707	21,258	11,414
Expected Return on Plan Assets		(16,648)	(13,074)	(33,297)	(26,147)
Amortization of Prior Service Cost (Credit)		109	134	218	268
Amortization of (Gains) Losses		(1,920)	6,601	(3,840)	13,202
Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments)	[1]	5,378	8,418	10,756	12,838
Net Periodic Benefit Cost (Income)		(1,155)	9,976	(2,311)	15,954
Other Post-Retirement Benefit Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service Cost		147	332	293	664
Interest Cost		3,912	2,267	7,824	4,533
Expected Return on Plan Assets		(6,403)	(7,340)	(12,806)	(14,680)
Amortization of Prior Service Cost (Credit)		(107)	(107)	(214)	(214)
Amortization of (Gains) Losses		(2,189)	(1,903)	(4,378)	(3,805)
Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments)	[1]	3,493	4,274	7,314	10,519
Net Periodic Benefit Cost (Income)		$ (1,147)	$ (2,477)	$ (1,967)	$ (2,983)
[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.

Regulatory Matters (Details)

Regulatory Matters (Details) - USD ($) $ in Thousands	6 Months Ended		12 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Sep. 30, 2022
Regulatory Matters [Line Items]
Reduction of Other Post-Retirement Regulatory Liability	$ 0	$ (18,533)
NEW YORK
Regulatory Matters [Line Items]
Approved Return on Equity	8.70%
Authorized Annual Recovery from Customers for Pension and OPEB Expense	$ 15,000
PENNSYLVANIA
Regulatory Matters [Line Items]
Proposed Base Rate Increase	28,100
Authorized Base Rate Increase	$ 23,000
Approved Base Rate Reduction related to OPEB Expenses			$ (7,700)
Proposed Refund to Customers from Over-Collection of OPEB Expenses			50,000
Reduction of Other Post-Retirement Regulatory Liability			(18,500)
Approved Refund to Customers from Over-Collection of OPEB Expenses			$ 54,000