National Fuel Gas (NFG) 10-Q 1 May 20 2020 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - $ / shares	6 Months Ended
	Mar. 31, 2020	Apr. 30, 2020
Cover [Abstract]
Amendment Flag	false
Current Fiscal Year End Date	--09-30
Document Fiscal Period Focus	Q2
Document Fiscal Year Focus	2020
Document Period End Date	Mar. 31, 2020
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		86,573,652
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, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019
INCOME
Operating Revenues	$ 491,095	$ 552,544	$ 935,283	$ 1,042,791
Operating Expenses:
Purchased Gas	118,270	195,037	210,542	333,697
Property, Franchise and Other Taxes	22,743	22,535	45,887	46,540
Depreciation, Depletion and Amortization	77,912	65,664	152,830	129,918
Impairment of Oil and Gas Producing Properties	177,761	0	177,761	0
Total Operating Expenses	515,675	399,185	811,843	727,748
Operating Income (Loss)	(24,580)	153,359	123,440	315,043
Other Income (Expense):
Other Income (Deductions)	(17,480)	(5,919)	(20,520)	(15,521)
Interest Expense on Long-Term Debt	(25,270)	(25,273)	(50,713)	(50,713)
Other Interest Expense	(1,892)	(1,787)	(3,443)	(2,860)
Income (Loss) Before Income Taxes	(69,222)	120,380	48,764	245,949
Income Tax Expense	36,846	29,785	68,241	52,693
Net Income (Loss) Available for Common Stock	(106,068)	90,595	(19,477)	193,256
EARNINGS REINVESTED IN THE BUSINESS
Balance at Beginning of Period	1,320,592	1,172,334	1,272,601	1,098,900
Beginning Retained Earnings Unappropriated And Current Period Net Income	1,214,524	1,262,929	1,253,124	1,292,156
Dividends on Common Stock	(37,654)	(36,678)	(75,304)	(73,342)
Balance at March 31	$ 1,176,870	$ 1,236,657	$ 1,176,870	$ 1,236,657
Earnings Per Common Share, Basic:
Net Income (Loss) Available for Common Stock (in dollars per share)	$ (1.23)	$ 1.05	$ (0.23)	$ 2.24
Earnings Per Common Share, Diluted:
Net Income (Loss) Available for Common Stock (in dollars per share)	$ (1.23)	$ 1.04	$ (0.23)	$ 2.23
Weighted Average Common Shares Outstanding:
Used in Basic Calculation (shares)	86,561,066	86,290,047	86,469,258	86,159,932
Used in Diluted Calculation (shares)	86,561,066	86,767,673	86,469,258	86,738,809
Dividends Per Common Share:
Dividends Declared (in dollars per share)	$ 0.435	$ 0.425	$ 0.870	$ 0.850
Utility and Energy Marketing [Member]
INCOME
Operating Revenues	$ 282,634	$ 357,654	$ 510,660	$ 629,747
Operating Expenses:
Operation and Maintenance	51,725	48,559	94,981	92,475
Exploration and Production and Other [Member]
INCOME
Operating Revenues	156,542	146,467	323,735	310,403
Operating Expenses:
Operation and Maintenance	39,959	40,141	76,652	72,936
Pipeline and Storage and Gathering [Member]
INCOME
Operating Revenues	51,919	48,423	100,888	102,641
Operating Expenses:
Operation and Maintenance	27,305	27,249	53,190	52,182
Guidance for Hedging [Member]
EARNINGS REINVESTED IN THE BUSINESS
Cumulative Effect of Adoption of Authoritative Guidance	0	0	(950)	0
Guidance for Recognition and Measurement of Financial Assets and Liabilities [Member]
EARNINGS REINVESTED IN THE BUSINESS
Cumulative Effect of Adoption of Authoritative Guidance	0	0	0	7,437
Guidance for Reclassification of Stranded Tax Effects [Member]
EARNINGS REINVESTED IN THE BUSINESS
Cumulative Effect of Adoption of Authoritative Guidance	$ 0	$ 10,406	$ 0	$ 10,406

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019
Statement of Comprehensive Income [Abstract]
Net Income (Loss) Available for Common Stock	$ (106,068)	$ 90,595	$ (19,477)	$ 193,256
Other Comprehensive Income (Loss), Before Tax:
Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	76,304		76,799
Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period		(26,000)		19,390
Reclassification Adjustment for Realized (Gains) Losses on Derivative Financial Instruments in Net Income	(25,034)		(32,386)
Reclassification Adjustment for Realized (Gains) Losses on Derivative Financial Instruments in Net Income		4,739		24,384
Cumulative Effect of Adoption of Authoritative Guidance for Hedging	0	0	1,313	0
Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities to Earnings Reinvested in the Business	0	0	0	(11,738)
Other Comprehensive Income (Loss), Before Tax	51,270	(21,261)	45,726	32,036
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	20,854		20,974
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period		(7,399)		5,593
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Derivative Financial Instruments in Net Income	(6,817)		(8,849)
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Derivative Financial Instruments in Net Income		1,328		6,874
Income Tax Benefit (Expense) on Cumulative Effect of Adoption of Authoritative Guidance for Hedging	0	0	363	0
Reclassification Adjustment for Income Tax Benefit (Expense) on the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities to Earnings Reinvested in the Business	0	0	0	(4,301)
Reclassification Adjustment for Stranded Tax Effects Related to the 2017 Tax Reform Act to Earnings Reinvested in the Business	0	10,406	0	10,406
Income Taxes – Net	14,037	4,335	12,488	18,572
Other Comprehensive Income (Loss)	37,233	(25,596)	33,238	13,464
Comprehensive Income (Loss)	$ (68,835)	$ 64,999	$ 13,761	$ 206,720

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands		Mar. 31, 2020	Sep. 30, 2019
ASSETS
Property, Plant and Equipment		$ 11,559,528	$ 11,204,838
Less - Accumulated Depreciation, Depletion and Amortization		6,003,658	5,695,328
Property, Plant and Equipment, Net, Total		5,555,870	5,509,510
Current Assets
Cash and Temporary Cash Investments		111,655	20,428
Hedging Collateral Deposits	[1]	10,728	6,832
Receivables - Net of Allowance for Uncollectible Accounts of $29,627 and $25,788, Respectively		172,011	139,956
Unbilled Revenue		44,715	18,758
Gas Stored Underground		8,860	36,632
Materials and Supplies - at average cost		48,113	40,717
Unrecovered Purchased Gas Costs		0	2,246
Other Current Assets		100,188	97,054
Total Current Assets		496,270	362,623
Other Assets
Recoverable Future Taxes		115,934	115,197
Unamortized Debt Expense		13,151	14,005
Other Regulatory Assets		161,800	167,320
Deferred Charges		56,855	33,843
Other Investments		137,044	144,917
Goodwill		5,476	5,476
Prepaid Post-Retirement Benefit Costs		71,381	60,517
Fair Value of Derivative Financial Instruments		94,797	48,669
Other		81	80
Total Other Assets		656,519	590,024
Total Assets		6,708,659	6,462,157
Capitalization:
Common Stock, $1 Par Value Authorized - 200,000,000 Shares; Issued and Outstanding - 86,561,532 Shares and 86,315,287 Shares, Respectively		86,562	86,315
Paid in Capital		835,444	832,264
Earnings Reinvested in the Business		1,176,870	1,272,601
Accumulated Other Comprehensive Loss		(18,917)	(52,155)
Total Comprehensive Shareholders’ Equity		2,079,959	2,139,025
Long-Term Debt, Net of Current Portion and Unamortized Discount and Debt Issuance Costs		2,134,964	2,133,718
Total Capitalization		4,214,923	4,272,743
Current and Accrued Liabilities
Notes Payable to Banks and Commercial Paper		230,000	55,200
Current Portion of Long-Term Debt		0	0
Accounts Payable		106,938	132,208
Amounts Payable to Customers		17,213	4,017
Dividends Payable		37,654	37,547
Interest Payable on Long-Term Debt		18,508	18,508
Customer Advances		615	13,044
Customer Security Deposits		14,999	16,210
Other Accruals and Current Liabilities		150,239	139,600
Fair Value of Derivative Financial Instruments		7,652	5,574
Total Current and Accrued Liabilities		583,818	421,908
Deferred Credits
Deferred Income Taxes		777,299	653,382
Taxes Refundable to Customers		360,331	366,503
Cost of Removal Regulatory Liability		224,546	221,699
Other Regulatory Liabilities		157,371	142,367
Pension and Other Post-Retirement Liabilities		126,959	133,729
Asset Retirement Obligations		128,779	127,458
Other Deferred Credits		134,633	122,368
Total Deferred Credits		1,909,918	1,767,506
Commitments and Contingencies (Note 8)		0	0
Total Capitalization and Liabilities		$ 6,708,659	$ 6,462,157
[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, 2020	Sep. 30, 2019
Statement of Financial Position [Abstract]
Receivables, Allowance for Uncollectible Accounts	$ 29,627	$ 25,788
Common Stock, Par Value	$ 1	$ 1
Common Stock, Shares Authorized	200,000,000	200,000,000
Common Stock, Shares Issued	86,561,532	86,315,287
Common Stock, Shares Outstanding	86,561,532	86,315,287

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
OPERATING ACTIVITIES
Net Income (Loss) Available for Common Stock	$ (19,477)	$ 193,256
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities:
Impairment of Oil and Gas Producing Properties	177,761	0
Depreciation, Depletion and Amortization	152,830	129,918
Deferred Income Taxes	104,883	90,468
Stock-Based Compensation	7,580	10,731
Other	9,800	7,997
Change in:
Receivables and Unbilled Revenue	(58,248)	(130,377)
Gas Stored Underground and Materials and Supplies	20,086	29,093
Unrecovered Purchased Gas Costs	2,246	(1,556)
Other Current Assets	(3,134)	10,438
Accounts Payable	(5,465)	10,226
Amounts Payable to Customers	13,196	12,069
Customer Advances	(12,429)	(13,176)
Customer Security Deposits	(1,211)	(7,184)
Other Accruals and Current Liabilities	9,076	48,028
Other Assets	(10,359)	(38,686)
Other Liabilities	3,857	(10,410)
Net Cash Provided by Operating Activities	390,992	340,835
INVESTING ACTIVITIES
Capital Expenditures	(395,486)	(386,579)
Other	4,167	(2,616)
Net Cash Used in Investing Activities	(391,319)	(389,195)
Financing Activities
Changes in Notes Payable to Banks and Commercial Paper	174,800	0
Dividends Paid on Common Stock	(75,197)	(73,197)
Net Repurchases of Common Stock	(4,153)	(8,864)
Net Cash Provided by (Used in) Financing Activities	95,450	(82,061)
Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash	95,123	(130,421)
Cash, Cash Equivalents and Restricted Cash at October 1	27,260	233,047
Cash, Cash Equivalents and Restricted Cash at March 31	122,383	102,626
Supplemental Disclosure of Cash Flow Information, Non-Cash Investing Activities:
Non-Cash Capital Expenditures	$ 59,490	$ 74,929

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	6 Months Ended
	Mar. 31, 2020
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 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, 2019 , 2018 and 2017 that are included in the Company's 2019 Form 10-K. The consolidated financial statements for the year ended September 30, 2020 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, 2020 should not be taken as a prediction of earnings for the entire fiscal year ending September 30, 2020 . Most of the business of both the Utility segment and the Company's NFR operations (included in the All Other category) is seasonal in nature and is influenced by weather conditions. Due to the seasonal nature of the heating business in the Utility segment and in the Company's NFR operations, earnings during the winter months normally represent a substantial part of the earnings that those businesses are 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 October 1, 2019 Balance at March 31, 2020 Balance at October 1, 2018 Balance at March 31, 2019 Cash and Temporary Cash Investments $ 20,428 $ 111,655 $ 229,606 $ 100,643 Hedging Collateral Deposits 6,832 10,728 3,441 1,983 Cash, Cash Equivalents, and Restricted Cash $ 27,260 $ 122,383 $ 233,047 $ 102,626 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 hedging positions. 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 is determined based on historical experience, the age and other specific information about customer accounts. Account balances are charged off against the allowance twelve months after the account is final billed or when it is anticipated that the receivable will not be recovered. In light of the current COVID-19 crisis, government mandates have resulted in the shut-down of a significant number of businesses in the Company’s service territories and many individuals are currently out of work. The financial strains on businesses and individuals could have a significant impact on their ability to pay their bills, which could lead to a significant increase in uncollectible expense for customer receivables, primarily within the Utility segment. While the combination of the current low cost of natural gas service and the steps taken by the federal government to alleviate the financial burden on companies and individuals should act as an offset to the overall economic situation, the Company is anticipating that there will be some level of increase in uncollectible expense depending on the extent and duration of the pandemic crisis. To date, the Company has not experienced any discernible change in the rate at which its customers pay their bills. 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 $24.0 million at March 31, 2020 , 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 $1.6 billion and $1.7 billion at March 31, 2020 and September 30, 2019, 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 $74.8 million and $53.5 million at March 31, 2020 and September 30, 2019 , 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 unevaluated 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 impairment is required to be charged to earnings in that quarter. The book value of the oil and gas properties exceeded the ceiling at March 31, 2020. As such, the Company recognized a pre-tax impairment charge of $177.8 million for the quarter ended March 31, 2020. Deferred income tax benefits of $48.5 million related to the impairment charge were also recognized for the quarter ended March 31, 2020. In adjusting estimated future cash flows for hedging under the ceiling test at March 31, 2020 , estimated future net cash flows were increased by $32.7 million . The principal assets of the Utility, Pipeline and Storage and Gathering segments, consisting primarily of gas plant in service, are recorded at the historical cost when originally devoted to service. In light of COVID-19, government mandates have resulted in the shut-down of a significant number of businesses in the Company’s service territories and many individuals are currently out of work. It is possible that the extent and duration of this crisis could reduce projected cash flows associated with the use of these assets, which could in turn lead to a decrease in fair value and result in a potential impairment of the recorded value of such assets. While there were no indications of any conditions that could result in impairments at March 31, 2020, management will continue to monitor the situation on a quarterly basis. Accumulated Other Comprehensive Loss. The components of Accumulated Other Comprehensive Loss and changes for the six months ended March 31, 2020 and 2019 , net of related tax effect, are as follows (amounts in parentheses indicate debits) (in thousands): Gains and Losses on Derivative Financial Instruments Gains and Losses on Securities Available for Sale Funded Status of the Pension and Other Post-Retirement Benefit Plans Total Three Months Ended March 31, 2020 Balance at January 1, 2020 $ 30,680 $ — $ (86,830 ) $ (56,150 ) Other Comprehensive Gains and Losses Before Reclassifications 55,450 — — 55,450 Amounts Reclassified From Other Comprehensive Income (Loss) (18,217 ) — — (18,217 ) Balance at March 31, 2020 $ 67,913 $ — $ (86,830 ) $ (18,917 ) Six Months Ended March 31, 2020 Balance at October 1, 2019 $ 34,675 $ — $ (86,830 ) $ (52,155 ) Other Comprehensive Gains and Losses Before Reclassifications 55,825 — — 55,825 Amounts Reclassified From Other Comprehensive Income (Loss) (23,537 ) — — (23,537 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging 950 — — 950 Balance at March 31, 2020 $ 67,913 $ — $ (86,830 ) $ (18,917 ) Three Months Ended March 31, 2019 Balance at January 1, 2019 $ 17,886 $ — $ (46,576 ) $ (28,690 ) Other Comprehensive Gains and Losses Before Reclassifications (18,601 ) — — (18,601 ) Amounts Reclassified From Other Comprehensive Income (Loss) 3,411 — — 3,411 Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act 1,866 — (12,272 ) (10,406 ) Balance at March 31, 2019 $ 4,562 $ — $ (58,848 ) $ (54,286 ) Six Months Ended March 31, 2019 Balance at October 1, 2018 $ (28,611 ) $ 7,437 $ (46,576 ) $ (67,750 ) Other Comprehensive Gains and Losses Before Reclassifications 13,797 — — 13,797 Amounts Reclassified From Other Comprehensive Income (Loss) 17,510 — — 17,510 Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities — (7,437 ) — (7,437 ) Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act 1,866 — (12,272 ) (10,406 ) Balance at March 31, 2019 $ 4,562 $ — $ (58,848 ) $ (54,286 ) In August 2017, the FASB issued authoritative guidance which changes the financial reporting of hedging relationships to better portray the economic results of an entity's risk management activities and to simplify the application of hedge accounting. The Company adopted this authoritative guidance effective October 1, 2019, recognizing a cumulative effect adjustment that decreased retained earnings by $1.0 million and increased accumulated other comprehensive income by the same amount. In January 2016, the FASB issued authoritative guidance regarding the recognition and measurement of financial assets and liabilities. The authoritative guidance primarily affects the accounting for equity investments and the presentation and disclosure requirements for financial instruments. All equity investments in unconsolidated entities will be measured at fair value through earnings rather than through accumulated other comprehensive income. The Company adopted this authoritative guidance effective October 1, 2018 and, as called for by the modified retrospective method of adoption, recorded a cumulative effect adjustment during the quarter ended December 31, 2018 to increase retained earnings by $7.4 million and decrease accumulated other comprehensive income by the same amount. In February 2018, the FASB issued authoritative guidance that allows an entity to elect a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the 2017 Tax Reform Act and requires certain disclosures about stranded tax effects. The Company adopted this authoritative guidance effective January 1, 2019 and recorded a cumulative effect adjustment related to deferred income taxes associated with hedging activities and pension and post-retirement benefit obligations for the quarter ended March 31, 2019 to increase retained earnings by $10.4 million and decrease accumulated other comprehensive income by the same amount. 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, 2020 and 2019 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 March 31, Six Months Ended March 31, 2020 2019 2020 2019 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $23,396 ($4,260 ) $30,937 ($22,782 ) Operating Revenues Commodity Contracts 1,909 (280 ) 1,911 (1,182 ) Purchased Gas Foreign Currency Contracts (271 ) (199 ) (462 ) (420 ) Operating Revenues 25,034 (4,739 ) 32,386 (24,384 ) Total Before Income Tax (6,817 ) 1,328 (8,849 ) 6,874 Income Tax Expense $18,217 ($3,411 ) $23,537 ($17,510 ) Net of Tax Other Current Assets . The components of the Company’s Other Current Assets are as follows (in thousands): At March 31, 2020 At September 30, 2019 Prepayments $ 6,289 $ 12,728 Prepaid Property and Other Taxes 23,702 14,361 Federal Income Taxes Receivable 42,385 42,388 State Income Taxes Receivable 3,455 8,579 Fair Values of Firm Commitments 8,775 7,538 Regulatory Assets 15,582 11,460 $ 100,188 $ 97,054 Other Accruals and Current Liabilities . The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At March 31, 2020 At September 30, 2019 Accrued Capital Expenditures $ 31,886 $ 33,713 Regulatory Liabilities 45,338 50,332 Reserve for Gas Replacement 23,978 — Liability for Royalty and Working Interests 13,987 18,057 Non-Qualified Benefit Plan Liability 13,194 13,194 Other 21,856 24,304 $ 150,239 $ 139,600 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 SARs, restricted stock units and performance shares. As the Company recognized a net loss for both the quarter and six months ended March 31, 2020 , the aforementioned securities, amounting to 310,015 and 406,748 securities, were not recognized in the diluted earnings per share calculation for the quarter and six months ended March 31, 2020, respectively. For 2019, 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. SARs, restricted stock units and performance shares that are antidilutive are excluded from the calculation of diluted earnings per common share. There were 159,023 securities and 175,443 securities excluded as being antidilutive for the quarter and six months ended March 31, 2019 , respectively. Stock-Based Compensation. The Company granted 254,608 performance shares during the six months ended March 31, 2020 . The weighted average fair value of such performance shares was $43.32 per share for the six months ended March 31, 2020 . 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. Half of the performance shares granted during the six months ended March 31, 2020 must meet a performance goal related to relative return on capital over a three-year performance cycle. The performance goal over the 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 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 these 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 other half of the performance shares granted during the six months ended March 31, 2020 must meet a performance goal related to relative total shareholder return over a three-year performance cycle. The performance goal over the 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 total shareholder return performance shares ("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 150,839 nonperformance-based restricted stock units during the six months ended March 31, 2020 . The weighted average fair value of such nonperformance-based restricted stock units was $40.38 per share for the six months ended March 31, 2020 . 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 nonperformance-based restricted stock units do not entitle the participant to receive dividends during the vesting period. The accounting for nonperformance-based restricted stock units is the same as the accounting for restricted share awards, except that the fair value at the date of grant of the restricted stock units must be reduced by the present value of forgone dividends over the vesting term of the award.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	6 Months Ended
	Mar. 31, 2020
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	Revenue from Contracts with Customers The Company adopted authoritative guidance regarding revenue recognition on October 1, 2018 using the modified retrospective method of adoption for open contracts as of October 1, 2018. A cumulative effect adjustment to retained earnings was not necessary since no revenue recognition differences were identified when comparing the revenue recognition criteria under the new authoritative guidance to the previous guidance. The Company records revenue related to its derivative financial instruments in the Exploration and Production segment as well as in its NFR operations (included in the All Other category). 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 new authoritative guidance since they are accounted for under other existing accounting guidance. The following tables provide a disaggregation of the Company's revenues for the quarter and six months ended March 31, 2020 and 2019 , presented by type of service from each reportable segment. As reported in the Company's 2019 Form 10-K, the Company's NFR operations were previously reported as the Energy Marketing segment, however the Company is no longer reporting the energy marketing operations as a separate reportable segment. Prior year disaggregation of revenue information shown below has been restated to reflect this change in presentation. Quarter Ended March 31, 2020 (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 $ 100,777 $ — $ — $ — $ — $ — $ 100,777 Production of Crude Oil 30,268 — — — — — 30,268 Natural Gas Processing 714 — — — — — 714 Natural Gas Gathering Services — — 35,267 — — (35,267 ) — Natural Gas Transportation Service — 58,454 — 39,832 — (21,976 ) 76,310 Natural Gas Storage Service — 20,524 — — — (9,087 ) 11,437 Natural Gas Residential Sales — — — 185,323 — — 185,323 Natural Gas Commercial Sales — — — 27,296 — — 27,296 Natural Gas Industrial Sales — — — 1,144 — — 1,144 Natural Gas Marketing — — — — 36,404 (79 ) 36,325 Other 405 267 — (3,524 ) 851 (65 ) (2,066 ) Total Revenues from Contracts with Customers 132,164 79,245 35,267 250,071 37,255 (66,474 ) 467,528 Alternative Revenue Programs — — — 4,422 — — 4,422 Derivative Financial Instruments 23,396 — — — (4,251 ) — 19,145 Total Revenues $ 155,560 $ 79,245 $ 35,267 $ 254,493 $ 33,004 $ (66,474 ) $ 491,095 Six Months Ended March 31, 2020 (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 $ 220,651 $ — $ — $ — $ — $ — $ 220,651 Production of Crude Oil 67,931 — — — — — 67,931 Natural Gas Processing 1,402 — — — — — 1,402 Natural Gas Gathering Services — — 70,055 — — (70,055 ) — Natural Gas Transportation Service — 111,906 — 72,640 — (38,963 ) 145,583 Natural Gas Storage Service — 38,950 — — — (17,079 ) 21,871 Natural Gas Residential Sales — — — 329,693 — — 329,693 Natural Gas Commercial Sales — — — 46,137 — — 46,137 Natural Gas Industrial Sales — — — 2,413 — — 2,413 Natural Gas Marketing — — — — 70,513 (256 ) 70,257 Other 578 609 — (6,848 ) 1,971 (118 ) (3,808 ) Total Revenues from Contracts with Customers 290,562 151,465 70,055 444,035 72,484 (126,471 ) 902,130 Alternative Revenue Programs — — — 7,283 — — 7,283 Derivative Financial Instruments 30,937 — — — (5,067 ) — 25,870 Total Revenues $ 321,499 $ 151,465 $ 70,055 $ 451,318 $ 67,417 $ (126,471 ) $ 935,283 Quarter Ended March 31, 2019 (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 $ 121,824 $ — $ — $ — $ — $ — $ 121,824 Production of Crude Oil 34,878 — — — — — 34,878 Natural Gas Processing 971 — — — — — 971 Natural Gas Gathering Services — — 29,368 — — (29,366 ) 2 Natural Gas Transportation Service — 52,239 — 45,083 — (19,819 ) 77,503 Natural Gas Storage Service — 19,360 — — — (8,333 ) 11,027 Natural Gas Residential Sales — — — 229,254 — — 229,254 Natural Gas Commercial Sales — — — 34,255 — — 34,255 Natural Gas Industrial Sales — — — 1,867 — — 1,867 Natural Gas Marketing — — — — 58,516 (43 ) 58,473 Other 493 740 — (5,963 ) 318 (105 ) (4,517 ) Total Revenues from Contracts with Customers 158,166 72,339 29,368 304,496 58,834 (57,666 ) 565,537 Alternative Revenue Programs — — — (1,466 ) — — (1,466 ) Derivative Financial Instruments (12,064 ) — — — 537 — (11,527 ) Total Revenues $ 146,102 $ 72,339 $ 29,368 $ 303,030 $ 59,371 $ (57,666 ) $ 552,544 Six Months Ended March 31, 2019 (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 $ 257,735 $ — $ — $ — $ — $ — $ 257,735 Production of Crude Oil 72,433 — — — — — 72,433 Natural Gas Processing 1,945 — — — — — 1,945 Natural Gas Gathering Services — — 59,058 — — (59,056 ) 2 Natural Gas Transportation Service — 108,375 — 80,714 — (36,884 ) 152,205 Natural Gas Storage Service — 38,289 — — — (16,306 ) 21,983 Natural Gas Residential Sales — — — 396,121 — — 396,121 Natural Gas Commercial Sales — — — 56,301 — — 56,301 Natural Gas Industrial Sales — — — 3,368 — — 3,368 Natural Gas Marketing — — — — 107,803 (375 ) 107,428 Other 876 2,744 — (8,824 ) 1,325 (510 ) (4,389 ) Total Revenues from Contracts with Customers 332,989 149,408 59,058 527,680 109,128 (113,131 ) 1,065,132 Alternative Revenue Programs — — — (1,993 ) — — (1,993 ) Derivative Financial Instruments (24,011 ) — — — 3,663 — (20,348 ) Total Revenues $ 308,978 $ 149,408 $ 59,058 $ 525,687 $ 112,791 $ (113,131 ) $ 1,042,791 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: $92.0 million for the remainder of fiscal 2020; $171.8 million for fiscal 2021; $142.5 million for fiscal 2022; $97.9 million for fiscal 2023; $86.4 million for fiscal 2024; and $361.5 million thereafter.

Leases

Leases	6 Months Ended
	Mar. 31, 2020
Leases [Abstract]
Leases	Leases On October 1, 2019, the Company adopted authoritative guidance regarding lease accounting, which requires entities that lease the use of property, plant and equipment to recognize on the balance sheet the assets and liabilities for the rights and obligations created by all leases, including leases classified as operating leases. The Company implemented the new standard using the optional transition method and elected to apply the following practical expedients provided in the authoritative guidance: 1. For contracts that commenced prior to and existed as of October 1, 2019, a package of practical expedients to not reassess whether a contract is or contains a lease, lease classification, and initial direct costs under the new authoritative guidance; 2. An election not to apply the recognition requirements in the new authoritative guidance to short-term leases (a lease that at commencement date has a lease term of one year or less); 3. A practical expedient to not reassess certain land easements that existed prior to October 1, 2019 and were not previously accounted for as leases under the prior authoritative guidance; and 4. A practical expedient that permits combining lease and non-lease components in a contract and accounting for the combination as a lease (elected by asset-class). Upon adoption, the Company increased assets and liabilities on its Consolidated Balance Sheet by $19.7 million . The adoption did not result in a cumulative effect adjustment to earnings reinvested in the business or have a material impact on the Company’s Consolidated Statement of Income or Consolidated Statement of Cash Flows. Comparative periods, including disclosures relating to those periods, were not restated. Nature of Leases The Company primarily leases building space and drilling rigs, and on a limited basis compressor equipment and other miscellaneous assets. The Company determines if an arrangement is a lease at the inception of the arrangement. To the extent that an arrangement represents a lease, the Company classifies that lease as an operating or a finance lease in accordance with the authoritative guidance. As of March 31, 2020 the Company did not have any finance leases. Aside from a sublease of office space at the Company’s corporate headquarters, the Company does not have any material arrangements where the Company is the lessor. Buildings and Property The Company enters into building and property rental agreements with third parties for office space, certain field locations and other properties used in the Company’s operations. Building and property leases include the Company’s corporate headquarters in Williamsville, New York, and Exploration and Production segment offices in Houston, Texas, and Pittsburgh, Pennsylvania. The primary non-cancelable terms of the Company’s building and property leases range from three months to ten years . Most building leases include one or more options to renew, generally at the Company’s sole discretion, with renewal terms that can extend the lease terms from one year to fourteen years . Renewal options are included in the lease term if they are reasonably certain to be exercised. The agreements do not contain any material restrictive covenants. In March 2020, the Company entered into a lease agreement that has not yet commenced. This lease agreement is a building and property lease for a term of ten years expected to commence in June 2021. Total estimated base rent payments over the lease term are approximately $8.4 million . There is also an option to extend the term of the lease for one additional period of eighteen months . Drilling Rigs The Company enters into contracts for drilling rig services with third party contractors to support Seneca’s development activities in Pennsylvania and California. Seneca’s drilling rig arrangements are structured with a non-cancelable primary term of one year or less. Upon mutual agreement with the contractor, Seneca has the option to extend the contract with amended terms and conditions, including a renegotiated day rate fee. The Company has strategically entered into shorter-term drilling rig arrangements to allow for operational and financial flexibility to respond to changes in its operating and economic environment. The Company uses discretion in choosing to extend or not extend drilling rig contracts on a rig by rig basis depending on market and operating conditions present at the time the contract expires, including prices for natural gas and oil. Due to these considerations, the Company concluded that it is not reasonably certain that it will elect to extend any of its drilling rig arrangements beyond their primary non-cancelable terms of one year or less. Consequently, the Company’s drilling rig leases are deemed to be short-term leases subject to the exemption for balance sheet recognition. These costs are capitalized as part of oil and natural gas properties on the Consolidated Balance Sheet when incurred. Significant Judgments Lease Identification The Company uses judgment when determining whether or not an arrangement is or contains a lease. A contract is or contains a lease if the contract conveys the right to use an explicitly or implicitly identified asset that is physically distinct and the Company has the right to control the use of the identified asset for a period of time. When determining right of control, the Company evaluates whether it directs the use of the asset and obtains substantially all of the economic benefits from the use of the asset. Discount Rate The Company uses a discount rate to calculate the present value of lease payments in order to determine lease classification and measurement of the lease asset and liability. In the absence of a rate of interest that is readily determinable in the contract, the Company estimates the incremental borrowing rate (IBR) for each lease. The IBR reflects the rate of interest that the Company would pay on the lease commencement date to borrow an amount equal to the lease payments on a collateralized basis over a similar term in similar economic environments. Firm Transportation and Storage Contracts The Company’s subsidiaries enter into long-term arrangements to both reserve firm transportation capacity on third party pipelines and provide firm transportation and storage services to third party shippers. The Company’s firm capacity contracts with non-affiliated entities do not provide rights to use substantially all of the underlying pipeline or storage asset. As such, the Company has concluded that these arrangements are not leases under the authoritative guidance. Oil and Gas Leases The new authoritative guidance does not apply to leases to explore for or use minerals, oil or natural gas resources, including the right to explore for those natural resources and rights to use the land in which those natural resources are contained. As such, the Company has concluded that its oil and gas exploration and production leases and gas storage leases are not leases under the authoritative guidance. Amounts Recognized in the Financial Statements Operating lease costs, excluding those relating to short-term drilling rig leases that are capitalized as part of oil and natural gas properties under full cost pool accounting, are presented in Operations and Maintenance expense on the Consolidated Statement of Income. The following table summarizes the components of the Company’s total operating lease costs (in thousands): Three Months Ended Six Months Ended Operating Lease Expense $ 943 1,916 Variable Lease Expense (1) 137 272 Short-Term Lease Expense (2) 76 140 Sublease Income (80 ) (161 ) Total Lease Expense $ 1,076 $ 2,167 Short-Term Lease Costs Recorded to Property, Plant and Equipment (3) $ 6,776 $ 14,289 (1) Variable lease payments that are not dependent on an index or rate are not included in the lease liability. (2) Short-term lease costs exclude expenses related to leases with a lease term of one month or less. (3) Short-term lease costs relating to drilling rig leases that are capitalized as part of oil and natural gas properties under full cost pool accounting. Right-of-use assets and lease liabilities are recognized at the commencement date of a leasing arrangement based on the present value of lease payments over the lease term. As of March 31, 2020 , the weighted average remaining lease term was 8.6 years and the weighted average discount rate was 3.50% . The Company’s right-of-use operating lease assets are reflected as Deferred Charges on the Consolidated Balance Sheet. The corresponding operating lease liabilities are reflected in Other Accruals and Current Liabilities (current) and Other Deferred Credits (noncurrent). Short-term leases that have a lease term of one year or less are not recorded on the Consolidated Balance Sheet. The following amounts related to operating leases were recorded on the Company’s Consolidated Balance Sheet (in thousands): At March 31, 2020 Assets: Deferred Charges $ 18,260 Liabilities: Other Accruals and Current Liabilities $ 3,390 Other Deferred Credits $ 14,870 For the six months ended March 31, 2020 , cash paid for operating liabilities, and reported in cash flows provided by operating activities on the Company’s Consolidated Statement of Cash Flows, was $2.2 million . During the six months ended March 31, 2020 , the Company did not record any right-of-use assets in exchange for new lease liabilities. The following schedule of operating lease liability maturities summarizes the undiscounted lease payments owed by the Company to lessors pursuant to contractual agreements in effect as of March 31, 2020 (in thousands): At March 31, 2020 2020 (remaining 6 months) $ 1,877 2021 2,868 2022 2,278 2023 2,270 2024 2,237 Thereafter 9,717 Total Lease Payments 21,247 Less: Interest (2,987 ) Total Lease Liability $ 18,260 The future minimum operating lease payments as of September 30, 2019, as reported in the Company's 2019 Form 10-K, under the prior authoritative guidance are as follows (in thousands): At September 30, 2019 2020 (1) $ 12,356 2021 2,813 2022 2,264 2023 2,270 2024 2,237 Thereafter 9,717 Total Operating Lease Obligations $ 31,657 (1) The future minimum operating lease payment amount for 2020 includes short-term leases, including drilling rigs, that are not included in the schedule of operating lease liability maturities above under the new authoritative guidance.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Mar. 31, 2020
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, 2020 and September 30, 2019 . Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The fair value presentation for over the counter swaps combines gas and oil swaps because a significant number of the counterparties enter into both gas and oil swap agreements with the Company. Recurring Fair Value Measures At fair value as of March 31, 2020 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 95,966 $ — $ — $ — $ 95,966 Derivative Financial Instruments: Commodity Futures Contracts – Gas 935 — — (935 ) — Over the Counter Swaps – Gas and Oil — 103,068 — (2,732 ) 100,336 Over the Counter No Cost Collars - Gas — — — (751 ) (751 ) Foreign Currency Contracts — — — (4,788 ) (4,788 ) Other Investments: Balanced Equity Mutual Fund 31,956 — — — 31,956 Fixed Income Mutual Fund 63,094 — — — 63,094 Common Stock – Financial Services Industry 577 — — — 577 Hedging Collateral Deposits 10,728 — — — 10,728 Total $ 203,256 $ 103,068 $ — $ (9,206 ) $ 297,118 Liabilities: Derivative Financial Instruments: Commodity Futures Contracts – Gas $ 6,863 $ — $ — $ (935 ) $ 5,928 Over the Counter Swaps – Gas and Oil — 3,398 — (2,732 ) 666 Over the Counter No Cost Collars – Gas — 970 — (751 ) 219 Foreign Currency Contracts — 5,627 — (4,788 ) 839 Total $ 6,863 $ 9,995 $ — $ (9,206 ) $ 7,652 Total Net Assets/(Liabilities) $ 196,393 $ 93,073 $ — $ — $ 289,466 Recurring Fair Value Measures At fair value as of September 30, 2019 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 10,521 $ — $ — $ — $ 10,521 Derivative Financial Instruments: Commodity Futures Contracts – Gas 2,055 — — (2,055 ) — Over the Counter Swaps – Gas and Oil — 52,076 — (1,483 ) 50,593 Foreign Currency Contracts — 5 — (2,052 ) (2,047 ) Other Investments: Balanced Equity Mutual Fund 40,660 — — — 40,660 Fixed Income Mutual Fund 62,339 — — — 62,339 Common Stock – Financial Services Industry 844 — — — 844 Hedging Collateral Deposits 6,832 — — — 6,832 Total $ 123,251 $ 52,081 $ — $ (5,590 ) $ 169,742 Liabilities: Derivative Financial Instruments: Commodity Futures Contracts – Gas $ 7,149 $ — $ — $ (2,055 ) $ 5,094 Over the Counter Swaps – Gas and Oil — 1,671 — (1,483 ) 188 Foreign Currency Contracts — 2,344 — (2,052 ) 292 Total $ 7,149 $ 4,015 $ — $ (5,590 ) $ 5,574 Total Net Assets/(Liabilities) $ 116,102 $ 48,066 $ — $ — $ 164,168 (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 At March 31, 2020 and September 30, 2019 , the derivative financial instruments reported in Level 1 consist of natural gas NYMEX and ICE futures contracts used by NFR (included in the All Other category). Hedging collateral deposits of $10.7 million (at March 31, 2020 ) and $6.8 million (at September 30, 2019 ), which were associated with these futures contracts, have been reported in Level 1 as well. The derivative financial instruments reported in Level 2 at March 31, 2020 and September 30, 2019 consist of natural gas price swap agreements used in the Company’s Exploration and Production segment and in its NFR operations, natural gas no cost collars used in the Company's Exploration and Production segment, crude oil price swap agreements used in the Company’s Exploration and Production segment, basis hedge swap agreements used by NFR and foreign currency contracts used in the Company's Exploration and Production segment. The fair value of the Level 2 price swap agreements and no cost collars is based on an internal, discounted cash flow model that uses observable inputs (i.e. LIBOR based discount rates 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 accounting rules 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, 2020 , the Company determined that nonperformance risk 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. For the quarters ended March 31, 2020 and March 31, 2019 , there were no assets or liabilities measured at fair value and classified as Level 3. For the quarters ended March 31, 2020 and March 31, 2019 , no

Financial Instruments

Financial Instruments	6 Months Ended
	Mar. 31, 2020
Financial Instruments, Owned, at Fair Value [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, 2020 September 30, 2019 Carrying Amount Fair Value Carrying Amount Fair Value Long-Term Debt $ 2,134,964 $ 1,948,127 $ 2,133,718 $ 2,257,085 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/LIBOR 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, 2020 At September 30, 2019 Life Insurance Contracts $ 41,417 $ 41,074 Equity Mutual Fund 31,956 40,660 Fixed Income Mutual Fund 63,094 62,339 Marketable Equity Securities 577 844 $ 137,044 $ 144,917 Investments in life insurance contracts are stated at their cash surrender values or net present value. Investments in an equity mutual fund, a fixed income mutual fund and the stock of an insurance company (marketable equity securities) are stated at fair value based on quoted market prices with changes in fair value recognized in net income. The insurance contracts and marketable equity and fixed income securities are primarily informal funding mechanisms 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 as well as by NFR (included in the All Other category). The Company enters into futures contracts, over-the-counter no cost collars and over-the-counter swap agreements for natural gas and crude oil to manage the price risk associated with forecasted sales of gas and oil. 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 Company also enters into futures contracts and swaps, which are accounted for as cash flow hedges, to manage the price risk associated with forecasted gas purchases. The Company enters into futures contracts and swaps to mitigate risk associated with fixed price sales commitments, fixed price purchase commitments, and the decline in value of natural gas held in storage. These instruments are accounted for as fair value hedges. The duration of the Company’s combined cash flow and fair value commodity hedges does not typically exceed 5 years while the foreign currency forward contracts do not exceed 7 years . The Exploration and Production segment holds the majority of the Company’s derivative financial instruments. 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, 2020 and September 30, 2019 . Substantially all of the derivative financial instruments reported on those line items relate to commodity contracts and a small portion relates to foreign currency forward contracts. Cash Flow Hedges For derivative 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. Prior to October 1, 2019, gains and losses on the derivative representing either hedge ineffectiveness or hedge components excluded from the assessment of effectiveness were recognized in current earnings rather than as a component of other comprehensive income (loss). During the quarter and six months ended March 31, 2019, the Company recorded $6.7 million and $0.2 million , respectively, of hedging ineffectiveness losses that impacted operating revenue. With the October 1, 2019 adoption of the authoritative guidance that changes the financial reporting of hedging relationships and simplifies the application of hedge accounting, derivative instruments that are designated and qualify as a cash flow hedge will no longer have hedge ineffectiveness or a component excluded from the assessment of the effectiveness. As of March 31, 2020 , the Company had the following commodity derivative contracts (swaps, no cost collars and futures contracts) outstanding: Commodity Units Natural Gas 108.4 Bcf (short positions) Natural Gas 17.4 Bcf (long positions) Crude Oil 2,160,000 Bbls (short positions) As of March 31, 2020 , the Company was hedging a total of $86.5 million of forecasted transportation costs denominated in Canadian dollars with foreign currency forward contracts (long positions). As of March 31, 2020 , the Company had $93.1 million ( $67.9 million after tax) of net hedging gains included in the accumulated other comprehensive income (loss) balance. It is expected that $80.9 million ( $59.0 million after tax) of unrealized gains 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, 2020 and 2019 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss) for the 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 2020 2019 2020 2019 Commodity Contracts $ 81,108 $ (27,228 ) Operating Revenue $ 23,396 $ (4,260 ) Commodity Contracts (134 ) (54 ) Purchased Gas 1,909 (280 ) Foreign Currency Contracts (4,670 ) 1,282 Operating Revenue (271 ) (199 ) Total $ 76,304 $ (26,000 ) $ 25,034 $ (4,739 ) The Effect of Derivative Financial Instruments on the Statement of Financial Performance for the Six Months Ended March 31, 2020 and 2019 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss) for the 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 2020 2019 2020 2019 Commodity Contracts $ 79,553 $ 22,825 Operating Revenue $ 30,937 $ (22,782 ) Commodity Contracts 997 (1,333 ) Purchased Gas 1,911 (1,182 ) Foreign Currency Contracts (3,751 ) (2,102 ) Operating Revenue (462 ) (420 ) Total $ 76,799 $ 19,390 $ 32,386 $ (24,384 ) Fair Value Hedges The Company utilizes fair value hedges to mitigate risk associated with fixed price sales commitments, fixed price purchase commitments and the decline in the value of certain natural gas held in storage. With respect to fixed price sales commitments, the Company enters into long positions to mitigate the risk of price increases for natural gas supplies that could occur after the Company enters into fixed price sales agreements with its customers. With respect to fixed price purchase commitments, the Company enters into short positions to mitigate the risk of price decreases that could occur after the Company locks into fixed price purchase deals with its suppliers. With respect to storage hedges, the Company enters into short positions to mitigate the risk of price decreases that could result in a lower of cost or net realizable value writedown of the value of natural gas in storage that is recorded in the Company’s financial statements. As of March 31, 2020 , NFR had fair value hedges covering approximately 22.2 Bcf on its fixed price sales commitments. For derivative instruments that are designated and qualify as a fair value hedge, the gain or loss on the derivative as well as the offsetting gain or loss on the hedged item attributable to the hedged risk completely offset each other in current earnings, as shown below. Derivatives in Fair Value Hedging Relationships Location of Gain or (Loss) on Derivative and Hedged Item Recognized in the Consolidated Statement of Income Amount of Gain or (Loss) on Derivative Recognized in the Consolidated Statement of Income for the Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income for the Commodity Contracts Operating Revenues $ (4,994 ) $ 4,994 Commodity Contracts Purchased Gas $ 431 $ (431 ) $ (4,563 ) $ 4,563 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 fourteen counterparties of which twelve are in a net gain position. On average, the Company had $7.9 million of credit exposure per counterparty in a gain position at March 31, 2020 . The maximum credit exposure per counterparty in a gain position at March 31, 2020 was $17.0 million . As of March 31, 2020 , 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, 2020 , eleven of the fourteen counterparties to the Company’s outstanding derivative instrument contracts (specifically the over-the-counter swaps 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 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 instrument contracts were in a liability position (or if the liability were larger) and/or the Company’s credit rating declined, then additional hedging collateral deposits may be required. At March 31, 2020 , the fair market value of the derivative financial instrument assets with a credit-risk related contingency feature was $94.8 million according to the Company’s internal model (discussed in Note 4 — Fair Value Measurements). At March 31, 2020 , the fair market value of the derivative financial instrument liabilities with a credit-risk related contingency feature was $1.6 million according to the Company's internal model. For its over-the-counter swap agreements and foreign currency forward contracts, no hedging collateral deposits were required to be posted by the Company at March 31, 2020 . For its exchange traded futures contracts, the Company was required to post $10.7 million in hedging collateral deposits as of March 31, 2020 . As these are exchange traded futures contracts, there are no specific credit-risk related contingency features. The Company posts or receives hedging collateral based on open positions and margin requirements it has with its counterparties. The Company’s requirement to post hedging collateral deposits and the Company's right to receive hedging collateral deposits is based on the fair value determined by the Company’s counterparties, which may differ from the Company’s assessment of fair value. Hedging collateral deposits may also include closed derivative positions in which the broker has not cleared the cash from the account to offset the derivative liability. The Company records liabilities related to closed derivative positions in Other Accruals and Current Liabilities on the Consolidated Balance Sheet. These liabilities are relieved when the broker clears the cash from the hedging collateral deposit account.

Income Taxes

Income Taxes	6 Months Ended
	Mar. 31, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The effective tax rates for the quarters ended March 31, 2020 and March 31, 2019 were negative 53.2% and positive 24.7% , respectively. The change in the effective tax rate was primarily the result of recording a valuation allowance against certain deferred tax assets, discussed below. The effective tax rates for the six months ended March 31, 2020 and March 31, 2019 were 139.9% and 21.4% , respectively. The increase in the tax rate is a result of the deferred tax valuation allowance, differences between the book and tax treatment of stock compensation, as well as the elimination of the Enhanced Oil Recovery tax credit in fiscal 2020. A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax assets will not be realized. For the quarter ended March 31, 2020, the Company recorded a full valuation allowance against certain state deferred tax assets in the amount of $56.8 million based on its conclusion, considering all available evidence (both positive and negative), that it was more likely than not that the deferred tax assets would not be realized. A significant item of objective negative evidence considered was a projected three-year cumulative pre-tax loss primarily due to non-cash impairments of proved natural gas and oil properties due to declining commodity prices. Changes in judgment regarding future realization of these deferred tax assets may result in a reversal of all or a portion of the valuation allowance. The Company will continue to re-assess this position each quarter. On March 27, 2020, the “Coronavirus Aid, Relief and Economic Security (CARES) Act” was signed into law. The CARES Act, among other things, includes provisions relating to alternative minimum tax (AMT) credit refunds, refundable payroll tax credits, deferment of employer side social security payments, net operating loss carryback periods, and modifications to the net interest deduction limitation. The Company has filed for the acceleration of the remaining AMT credit refunds (under CARES) of $42.5 million , which has been recorded as a current receivable as of March 31, 2020. In addition, the Company is pursuing certain payroll tax related provisions included in the CARES Act. Prior to the CARES Act, the 2017 Tax Reform Act repealed the corporate alternative minimum tax and provided that the Company’s existing AMT credit carryovers were refundable, if not utilized to reduce tax, beginning in fiscal 2019. As of September 30, 2018, the Company had $85.0 million of AMT credit carryovers that were expected to be refunded between fiscal 2020 and fiscal 2023, if not previously utilized. The Company received the first installment for $42.5 million of AMT credit refunds related to fiscal 2019 in January 2020.

Capitalization

Capitalization	6 Months Ended
	Mar. 31, 2020
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, 2020 86,552 $ 86,552 $ 831,146 $ 1,320,592 $ (56,150 ) Net Income (Loss) Available for Common Stock (106,068 ) Dividends Declared on Common Stock ($0.435 Per Share) (37,654 ) Other Comprehensive Income, Net of Tax 37,233 Share-Based Payment Expense (1) 3,876 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 10 10 422 Balance at March 31, 2020 86,562 $ 86,562 $ 835,444 $ 1,176,870 $ (18,917 ) Balance at October 1, 2019 86,315 $ 86,315 $ 832,264 $ 1,272,601 $ (52,155 ) Net Income (Loss) Available for Common Stock (19,477 ) Dividends Declared on Common Stock ($0.87 Per Share) (75,304 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging (950 ) Other Comprehensive Income, Net of Tax 33,238 Share-Based Payment Expense (1) 6,704 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 247 247 (3,524 ) Balance at March 31, 2020 86,562 $ 86,562 $ 835,444 $ 1,176,870 $ (18,917 ) Balance at January 1, 2019 86,271 $ 86,271 $ 817,076 $ 1,172,334 $ (28,690 ) Net Income Available for Common Stock 90,595 Dividends Declared on Common Stock ($0.425 Per Share) (36,678 ) Cumulative Effect of Adoption of Authoritative Guidance for Reclassification of Stranded Tax Effects 10,406 Other Comprehensive Loss, Net of Tax (25,596 ) Share-Based Payment Expense (1) 5,038 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 30 30 (277 ) Balance at March 31, 2019 86,301 $ 86,301 $ 821,837 $ 1,236,657 $ (54,286 ) Balance at October 1, 2018 85,957 $ 85,957 $ 820,223 $ 1,098,900 $ (67,750 ) Net Income Available for Common Stock 193,256 Dividends Declared on Common Stock ($0.85 Per Share) (73,342 ) Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities 7,437 Cumulative Effect of Adoption of Authoritative Guidance for Reclassification of Stranded Tax Effects 10,406 Other Comprehensive Income, Net of Tax 13,464 Share-Based Payment Expense (1) 9,955 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 344 344 (8,341 ) Balance at March 31, 2019 86,301 $ 86,301 $ 821,837 $ 1,236,657 $ (54,286 ) (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, 2020 , the Company issued 87,135 original issue shares of common stock for restricted stock units that vested and 231,246 original issue shares of common stock for performance shares that vested. The Company also issued 19,133 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, as partial consideration for the directors’ services during the six months ended March 31, 2020 . 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, 2020 , 91,269 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. Current Portion of Long-Term Debt. None of the Company's long-term debt as of March 31, 2020 and September 30, 2019

Commitments And Contingencies

Commitments And Contingencies	6 Months Ended
	Mar. 31, 2020
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, 2020 , the Company has estimated its remaining clean-up costs related to former manufactured gas plant sites will be approximately $6.8 million , which includes a $3.7 million estimated minimum liability to remediate a former manufactured gas plant site located in New York. In March 2018, the NYDEC issued a Record of Decision for this New York site and the minimum liability reflects the remedy selected in the Record of Decision. The Company's liability for such clean-up costs has been recorded in Other Deferred Credits on the Consolidated Balance Sheet at March 31, 2020 . The Company expects to recover its environmental clean-up costs through rate recovery over a period of approximately 3 years 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). The United States Court of Appeals for the Second Circuit (the “Second Circuit Court of Appeals”) held in the Company’s favor in its appeal of this decision, vacating the NYDEC denial and remanding to the NYDEC. The NYDEC subsequently issued a second denial, which the Company has appealed to the Second Circuit Court of Appeals. The court has held this appeal in abeyance pending the outcome of the FERC waiver appeal, described below. While the Company’s initial appeal was pending before the Second Circuit Court of Appeals, the 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 have been appealed and are pending in a separate action before the Second Circuit Court of Appeals. In addition, the Company commenced legal action in New York State Supreme Court challenging the NYDEC's actions with regard to various state permits. The Company remains committed to the project. In light of these pending legal actions and the need to complete necessary project development activities in advance of construction, the in-service date for the project is expected to be no earlier than fiscal 2022. 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, 2020
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. As reported in the Company's 2019 Form 10-K, the Company previously reported financial results for five business segments: Exploration and Production, Pipeline and Storage, Gathering, Utility and Energy Marketing. However, management made the decision to eliminate the Energy Marketing segment as a reportable segment based on the fact that the energy marketing operations do not meet any of the quantitative thresholds specified by authoritative guidance related to segment reporting. Furthermore, from a qualitative standpoint, management’s focus has changed regarding the energy marketing operations, and management no longer considers the energy marketing operations to be integral to the overall operations of the Company. As a result of this change in focus and the fact that the energy marketing operations cannot be aggregated into one of the other four reportable business segments, the energy marketing operations have been included in the All Other category in the disclosures that follow. Prior year segment information shown below has been restated to reflect this change in presentation. The data presented in the tables below reflect financial information for the segments and reconciliations to consolidated amounts. As stated in the 2019 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 2019 Form 10-K. A listing of segment assets at March 31, 2020 and September 30, 2019 is shown in the tables below. Quarter Ended March 31, 2020 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $155,560 $51,919 $— $250,556 $458,035 $32,925 $135 $491,095 Intersegment Revenues $— $27,326 $35,267 $3,937 $66,530 $79 $(66,609) $— Segment Profit: Net Income (Loss) $(175,275) $22,087 $19,898 $31,499 $(101,791) $1,169 $(5,446) $(106,068) Six Months Ended March 31, 2020 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $321,499 $100,888 $— $445,465 $867,852 $67,161 $270 $935,283 Intersegment Revenues $— $50,577 $70,055 $5,853 $126,485 $256 $(126,741) $— Segment Profit: Net Income (Loss) $(151,299) $40,192 $35,842 $58,082 $(17,183) $1,540 $(3,834) $(19,477) (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, 2020 $2,014,520 $1,916,849 $576,589 $2,049,424 $6,557,382 $134,926 $16,351 $6,708,659 At September 30, 2019 $1,972,776 $1,893,514 $547,995 $1,991,338 $6,405,623 $122,241 $(65,707) $6,462,157 Quarter Ended March 31, 2019 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $146,102 $48,421 $2 $298,636 $493,161 $59,328 $55 $552,544 Intersegment Revenues $— $23,918 $29,366 $4,394 $57,678 $43 $(57,721) $— Segment Profit: Net Income $21,873 $17,749 $12,690 $35,589 $87,901 $416 $2,278 $90,595 Six Months Ended March 31, 2019 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $308,978 $102,639 $2 $518,647 $930,266 $112,416 $109 $1,042,791 Intersegment Revenues $— $46,769 $59,056 $7,040 $112,865 $375 $(113,240) $— Segment Profit: Net Income $60,087 $42,851 $26,872 $61,237 $191,047 $499 $1,710 $193,256

Retirement Plan And Other Post-

Retirement Plan And Other Post-Retirement Benefits	6 Months Ended
	Mar. 31, 2020
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, 2020 2019 2020 2019 Service Cost $ 2,330 $ 2,120 $ 402 $ 380 Interest Cost 7,483 9,594 3,228 4,286 Expected Return on Plan Assets (15,016 ) (15,591 ) (7,308 ) (7,539 ) Amortization of Prior Service Cost (Credit) 182 206 (107 ) (107 ) Amortization of Losses 9,846 8,024 134 1,490 Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 5,519 4,786 8,846 6,565 Net Periodic Benefit Cost $ 10,344 $ 9,139 $ 5,195 $ 5,075 Retirement Plan Other Post-Retirement Benefits Six Months Ended March 31, 2020 2019 2020 2019 Service Cost $ 4,659 $ 4,241 $ 804 $ 760 Interest Cost 14,965 19,189 6,457 8,572 Expected Return on Plan Assets (30,032 ) (31,184 ) (14,616 ) (15,078 ) Amortization of Prior Service Cost (Credit) 365 413 (214 ) (214 ) Amortization of Losses 19,692 16,048 267 2,980 Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 7,047 5,604 15,094 10,536 Net Periodic Benefit Cost $ 16,696 $ 14,311 $ 7,792 $ 7,556 (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. During the six months ended March 31, 2020 , the Company contributed $19.3 million to its tax-qualified, noncontributory defined-benefit retirement plan (Retirement Plan) and $2.1 million to its VEBA trusts for its other post-retirement benefits. In the remainder of 2020 , the Company expects its contributions to the Retirement Plan to be in the range of $5.0 million to $10.0 million . In the remainder of 2020 , the Company expects its contributions to its VEBA trusts to be in the range of $0.5 million to $1.0 million . The market turbulence resulting from COVID-19 has not had a significant impact to the plan assets or funded status of the Retirement Plan or VEBA trusts at this time. The Company will continue to monitor the performance of its Retirement Plan and VEBA trusts during the pandemic crisis to determine if funding requirements will need to increase during the remainder of 2020.

Regulatory Matters

Regulatory Matters	6 Months Ended
	Mar. 31, 2020
Regulatory Assets and Liabilities, Other Disclosures [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% . The order also directed the implementation of an earnings sharing mechanism to be in place beginning on April 1, 2018. In New York, on March 13, 2020, the Company agreed to NYPSC Staff’s request that the Company suspend service terminations and disconnections. The Company is anticipating that there will be some level of increase in uncollectible expense depending on the depth and duration of the pandemic crisis. It is uncertain at this point as to whether there would be any regulatory relief for the Utility segment with regard to an increase in costs associated with the pandemic crisis. Pennsylvania Jurisdiction Distribution Corporation’s Pennsylvania jurisdiction delivery rates are being charged to customers in accordance with a rate settlement approved by the PaPUC. The rate settlement does not specify any requirement to file a future rate case. On March 26, 2020, the PaPUC ratified an Emergency Order that established a Service Termination Moratorium intended to continue during the pendency of Governor Wolf’s March 6, 2020 Proclamation of Disaster Emergency associated with COVID-19. Similar to New York, it is uncertain at this point as to whether there would be any regulatory relief with regard to any increase in the Utility’s uncollectible expense. FERC Jurisdiction Supply Corporation filed a Section 4 rate case on July 31, 2019 proposing rate increases to be effective September 1, 2019. On February 4, 2020, Supply Corporation and the parties in the case reached a settlement in principle (the Settlement) to resolve the rate case. Supply Corporation’s subsequent motion to put in place Interim Settlement Rates effective February 1, 2020, was approved by FERC’s Chief Administrative Law Judge on February 21, 2020. The Settlement was filed with FERC on March 13, 2020 and on April 20, 2020 the presiding Administrative Law Judge certified the Settlement to FERC for approval. The “black box” settlement provides for new rates (Period 1 and Period 2 Rates). The Period 1 Rates, the Interim Settlement Rates, are estimated to increase Supply Corporation’s revenues on a yearly basis by approximately $35.5 million , assuming current contract levels. After Period 2 Rates are implemented, which will be the later of April 1, 2022, or the in-service of Supply Corporation’s FM-100 Modernization Project, Supply Corporation’s yearly revenues will have increased by an additional approximately $15.0 million . As well, the Settlement provides for increased depreciation rates and the right to track pipeline safety and greenhouse costs that result from future costs incurred for new rules and the PHMSA Mega Rule. Under the terms of the Settlement, Supply Corporation will also undertake certain actions for its customers, including convening regular customer meetings to address system operations. Under the Settlement, 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 income tax rate is increased. If no case has been filed, Supply Corporation must file for rates to be effective February 1, 2025.

Summary Of Significant Accoun_2

Summary Of Significant Accounting Policies (Policy)	6 Months Ended
	Mar. 31, 2020
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 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, 2019 , 2018 and 2017 that are included in the Company's 2019 Form 10-K. The consolidated financial statements for the year ended September 30, 2020 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, 2020 should not be taken as a prediction of earnings for the entire fiscal year ending September 30, 2020 . Most of the business of both the Utility segment and the Company's NFR operations (included in the All Other category) is seasonal in nature and is influenced by weather conditions. Due to the seasonal nature of the heating business in the Utility segment and in the Company's NFR operations, earnings during the winter months normally represent a substantial part of the earnings that those businesses are 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	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 October 1, 2019 Balance at March 31, 2020 Balance at October 1, 2018 Balance at March 31, 2019 Cash and Temporary Cash Investments $ 20,428 $ 111,655 $ 229,606 $ 100,643 Hedging Collateral Deposits 6,832 10,728 3,441 1,983 Cash, Cash Equivalents, and Restricted Cash $ 27,260 $ 122,383 $ 233,047 $ 102,626 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 hedging positions. 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 is determined based on historical experience, the age and other specific information about customer accounts. Account balances are charged off against the allowance twelve months after the account is final billed or when it is anticipated that the receivable will not be recovered. In light of the current COVID-19 crisis, government mandates have resulted in the shut-down of a significant number of businesses in the Company’s service territories and many individuals are currently out of work. The financial strains on businesses and individuals could have a significant impact on their ability to pay their bills, which could lead to a significant increase in uncollectible expense for customer receivables, primarily within the Utility segment. While the combination of the current low cost of natural gas service and the steps taken by the federal government to alleviate the financial burden on companies and individuals should act as an offset to the overall economic situation, the Company is anticipating that there will be some level of increase in uncollectible expense depending
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 $24.0 million at March 31, 2020 , 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 $1.6 billion and $1.7 billion at March 31, 2020 and September 30, 2019, 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 $74.8 million and $53.5 million at March 31, 2020 and September 30, 2019 , 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 unevaluated 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 impairment is required to be charged to earnings in that quarter. The book value of the oil and gas properties exceeded the ceiling at March 31, 2020. As such, the Company recognized a pre-tax impairment charge of $177.8 million for the quarter ended March 31, 2020. Deferred income tax benefits of $48.5 million related to the impairment charge were also recognized for the quarter ended March 31, 2020. In adjusting estimated future cash flows for hedging under the ceiling test at March 31, 2020 , estimated future net cash flows were increased by $32.7 million .
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss. The components of Accumulated Other Comprehensive Loss and changes for the six months ended March 31, 2020 and 2019 , net of related tax effect, are as follows (amounts in parentheses indicate debits) (in thousands): Gains and Losses on Derivative Financial Instruments Gains and Losses on Securities Available for Sale Funded Status of the Pension and Other Post-Retirement Benefit Plans Total Three Months Ended March 31, 2020 Balance at January 1, 2020 $ 30,680 $ — $ (86,830 ) $ (56,150 ) Other Comprehensive Gains and Losses Before Reclassifications 55,450 — — 55,450 Amounts Reclassified From Other Comprehensive Income (Loss) (18,217 ) — — (18,217 ) Balance at March 31, 2020 $ 67,913 $ — $ (86,830 ) $ (18,917 ) Six Months Ended March 31, 2020 Balance at October 1, 2019 $ 34,675 $ — $ (86,830 ) $ (52,155 ) Other Comprehensive Gains and Losses Before Reclassifications 55,825 — — 55,825 Amounts Reclassified From Other Comprehensive Income (Loss) (23,537 ) — — (23,537 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging 950 — — 950 Balance at March 31, 2020 $ 67,913 $ — $ (86,830 ) $ (18,917 ) Three Months Ended March 31, 2019 Balance at January 1, 2019 $ 17,886 $ — $ (46,576 ) $ (28,690 ) Other Comprehensive Gains and Losses Before Reclassifications (18,601 ) — — (18,601 ) Amounts Reclassified From Other Comprehensive Income (Loss) 3,411 — — 3,411 Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act 1,866 — (12,272 ) (10,406 ) Balance at March 31, 2019 $ 4,562 $ — $ (58,848 ) $ (54,286 ) Six Months Ended March 31, 2019 Balance at October 1, 2018 $ (28,611 ) $ 7,437 $ (46,576 ) $ (67,750 ) Other Comprehensive Gains and Losses Before Reclassifications 13,797 — — 13,797 Amounts Reclassified From Other Comprehensive Income (Loss) 17,510 — — 17,510 Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities — (7,437 ) — (7,437 ) Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act 1,866 — (12,272 ) (10,406 ) Balance at March 31, 2019 $ 4,562 $ — $ (58,848 ) $ (54,286 ) In August 2017, the FASB issued authoritative guidance which changes the financial reporting of hedging relationships to better portray the economic results of an entity's risk management activities and to simplify the application of hedge accounting. The Company adopted this authoritative guidance effective October 1, 2019, recognizing a cumulative effect adjustment that decreased retained earnings by $1.0 million and increased accumulated other comprehensive income by the same amount. In January 2016, the FASB issued authoritative guidance regarding the recognition and measurement of financial assets and liabilities. The authoritative guidance primarily affects the accounting for equity investments and the presentation and disclosure requirements for financial instruments. All equity investments in unconsolidated entities will be measured at fair value through earnings rather than through accumulated other comprehensive income. The Company adopted this authoritative guidance effective October 1, 2018 and, as called for by the modified retrospective method of adoption, recorded a cumulative effect adjustment during the quarter ended December 31, 2018 to increase retained earnings by $7.4 million and decrease accumulated other comprehensive income by the same amount. In February 2018, the FASB issued authoritative guidance that allows an entity to elect a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the 2017 Tax Reform Act and requires certain disclosures about stranded tax effects. The Company adopted this authoritative guidance effective January 1, 2019 and recorded a cumulative effect adjustment related to deferred income taxes associated with hedging activities and pension and post-retirement benefit obligations for the quarter ended March 31, 2019 to increase retained earnings by $10.4 million and decrease accumulated other comprehensive income by the same amount.
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, 2020 and 2019 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 March 31, Six Months Ended March 31, 2020 2019 2020 2019 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $23,396 ($4,260 ) $30,937 ($22,782 ) Operating Revenues Commodity Contracts 1,909 (280 ) 1,911 (1,182 ) Purchased Gas Foreign Currency Contracts (271 ) (199 ) (462 ) (420 ) Operating Revenues 25,034 (4,739 ) 32,386 (24,384 ) Total Before Income Tax (6,817 ) 1,328 (8,849 ) 6,874 Income Tax Expense $18,217 ($3,411 ) $23,537 ($17,510 ) 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, 2020 At September 30, 2019 Prepayments $ 6,289 $ 12,728 Prepaid Property and Other Taxes 23,702 14,361 Federal Income Taxes Receivable 42,385 42,388 State Income Taxes Receivable 3,455 8,579 Fair Values of Firm Commitments 8,775 7,538 Regulatory Assets 15,582 11,460 $ 100,188 $ 97,054
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, 2020 At September 30, 2019 Accrued Capital Expenditures $ 31,886 $ 33,713 Regulatory Liabilities 45,338 50,332 Reserve for Gas Replacement 23,978 — Liability for Royalty and Working Interests 13,987 18,057 Non-Qualified Benefit Plan Liability 13,194 13,194 Other 21,856 24,304 $ 150,239 $ 139,600
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 SARs, restricted stock units and performance shares. As the Company recognized a net loss for both the quarter and six months ended March 31, 2020 , the aforementioned securities, amounting to 310,015 and 406,748 securities, were not recognized in the diluted earnings per share calculation for the quarter and six months ended March 31, 2020, respectively. For 2019, 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. SARs, restricted stock units and performance shares that are antidilutive are excluded from the calculation of diluted earnings per common share. There were 159,023 securities and 175,443 securities excluded as being antidilutive for the quarter and six months ended March 31, 2019 , respectively.
Stock-Based Compensation	Stock-Based Compensation. The Company granted 254,608 performance shares during the six months ended March 31, 2020 . The weighted average fair value of such performance shares was $43.32 per share for the six months ended March 31, 2020 . 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. Half of the performance shares granted during the six months ended March 31, 2020 must meet a performance goal related to relative return on capital over a three-year performance cycle. The performance goal over the 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 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 these 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 other half of the performance shares granted during the six months ended March 31, 2020 must meet a performance goal related to relative total shareholder return over a three-year performance cycle. The performance goal over the 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 total shareholder return performance shares ("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 150,839 nonperformance-based restricted stock units during the six months ended March 31, 2020 . The weighted average fair value of such nonperformance-based restricted stock units was $40.38 per share for the six months ended March 31, 2020 . 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 nonperformance-based restricted stock units do not entitle the participant to receive dividends during the vesting period. The accounting for nonperformance-based restricted stock units is the same as the accounting for restricted share awards, except that the fair value at the date of grant of the restricted stock units must be reduced by the present value of forgone dividends over the vesting term of the award.

Summary Of Significant Accoun_3

Summary Of Significant Accounting Policies (Tables)	6 Months Ended
	Mar. 31, 2020
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 October 1, 2019 Balance at March 31, 2020 Balance at October 1, 2018 Balance at March 31, 2019 Cash and Temporary Cash Investments $ 20,428 $ 111,655 $ 229,606 $ 100,643 Hedging Collateral Deposits 6,832 10,728 3,441 1,983 Cash, Cash Equivalents, and Restricted Cash $ 27,260 $ 122,383 $ 233,047 $ 102,626
Components of Accumulated Other Comprehensive Loss	The components of Accumulated Other Comprehensive Loss and changes for the six months ended March 31, 2020 and 2019 , net of related tax effect, are as follows (amounts in parentheses indicate debits) (in thousands): Gains and Losses on Derivative Financial Instruments Gains and Losses on Securities Available for Sale Funded Status of the Pension and Other Post-Retirement Benefit Plans Total Three Months Ended March 31, 2020 Balance at January 1, 2020 $ 30,680 $ — $ (86,830 ) $ (56,150 ) Other Comprehensive Gains and Losses Before Reclassifications 55,450 — — 55,450 Amounts Reclassified From Other Comprehensive Income (Loss) (18,217 ) — — (18,217 ) Balance at March 31, 2020 $ 67,913 $ — $ (86,830 ) $ (18,917 ) Six Months Ended March 31, 2020 Balance at October 1, 2019 $ 34,675 $ — $ (86,830 ) $ (52,155 ) Other Comprehensive Gains and Losses Before Reclassifications 55,825 — — 55,825 Amounts Reclassified From Other Comprehensive Income (Loss) (23,537 ) — — (23,537 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging 950 — — 950 Balance at March 31, 2020 $ 67,913 $ — $ (86,830 ) $ (18,917 ) Three Months Ended March 31, 2019 Balance at January 1, 2019 $ 17,886 $ — $ (46,576 ) $ (28,690 ) Other Comprehensive Gains and Losses Before Reclassifications (18,601 ) — — (18,601 ) Amounts Reclassified From Other Comprehensive Income (Loss) 3,411 — — 3,411 Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act 1,866 — (12,272 ) (10,406 ) Balance at March 31, 2019 $ 4,562 $ — $ (58,848 ) $ (54,286 ) Six Months Ended March 31, 2019 Balance at October 1, 2018 $ (28,611 ) $ 7,437 $ (46,576 ) $ (67,750 ) Other Comprehensive Gains and Losses Before Reclassifications 13,797 — — 13,797 Amounts Reclassified From Other Comprehensive Income (Loss) 17,510 — — 17,510 Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities — (7,437 ) — (7,437 ) Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act 1,866 — (12,272 ) (10,406 ) Balance at March 31, 2019 $ 4,562 $ — $ (58,848 ) $ (54,286 )
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, 2020 and 2019 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 March 31, Six Months Ended March 31, 2020 2019 2020 2019 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $23,396 ($4,260 ) $30,937 ($22,782 ) Operating Revenues Commodity Contracts 1,909 (280 ) 1,911 (1,182 ) Purchased Gas Foreign Currency Contracts (271 ) (199 ) (462 ) (420 ) Operating Revenues 25,034 (4,739 ) 32,386 (24,384 ) Total Before Income Tax (6,817 ) 1,328 (8,849 ) 6,874 Income Tax Expense $18,217 ($3,411 ) $23,537 ($17,510 ) 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, 2020 At September 30, 2019 Prepayments $ 6,289 $ 12,728 Prepaid Property and Other Taxes 23,702 14,361 Federal Income Taxes Receivable 42,385 42,388 State Income Taxes Receivable 3,455 8,579 Fair Values of Firm Commitments 8,775 7,538 Regulatory Assets 15,582 11,460 $ 100,188 $ 97,054
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, 2020 At September 30, 2019 Accrued Capital Expenditures $ 31,886 $ 33,713 Regulatory Liabilities 45,338 50,332 Reserve for Gas Replacement 23,978 — Liability for Royalty and Working Interests 13,987 18,057 Non-Qualified Benefit Plan Liability 13,194 13,194 Other 21,856 24,304 $ 150,239 $ 139,600

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	6 Months Ended
	Mar. 31, 2020
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, 2020 and 2019 , presented by type of service from each reportable segment. As reported in the Company's 2019 Form 10-K, the Company's NFR operations were previously reported as the Energy Marketing segment, however the Company is no longer reporting the energy marketing operations as a separate reportable segment. Prior year disaggregation of revenue information shown below has been restated to reflect this change in presentation. Quarter Ended March 31, 2020 (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 $ 100,777 $ — $ — $ — $ — $ — $ 100,777 Production of Crude Oil 30,268 — — — — — 30,268 Natural Gas Processing 714 — — — — — 714 Natural Gas Gathering Services — — 35,267 — — (35,267 ) — Natural Gas Transportation Service — 58,454 — 39,832 — (21,976 ) 76,310 Natural Gas Storage Service — 20,524 — — — (9,087 ) 11,437 Natural Gas Residential Sales — — — 185,323 — — 185,323 Natural Gas Commercial Sales — — — 27,296 — — 27,296 Natural Gas Industrial Sales — — — 1,144 — — 1,144 Natural Gas Marketing — — — — 36,404 (79 ) 36,325 Other 405 267 — (3,524 ) 851 (65 ) (2,066 ) Total Revenues from Contracts with Customers 132,164 79,245 35,267 250,071 37,255 (66,474 ) 467,528 Alternative Revenue Programs — — — 4,422 — — 4,422 Derivative Financial Instruments 23,396 — — — (4,251 ) — 19,145 Total Revenues $ 155,560 $ 79,245 $ 35,267 $ 254,493 $ 33,004 $ (66,474 ) $ 491,095 Six Months Ended March 31, 2020 (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 $ 220,651 $ — $ — $ — $ — $ — $ 220,651 Production of Crude Oil 67,931 — — — — — 67,931 Natural Gas Processing 1,402 — — — — — 1,402 Natural Gas Gathering Services — — 70,055 — — (70,055 ) — Natural Gas Transportation Service — 111,906 — 72,640 — (38,963 ) 145,583 Natural Gas Storage Service — 38,950 — — — (17,079 ) 21,871 Natural Gas Residential Sales — — — 329,693 — — 329,693 Natural Gas Commercial Sales — — — 46,137 — — 46,137 Natural Gas Industrial Sales — — — 2,413 — — 2,413 Natural Gas Marketing — — — — 70,513 (256 ) 70,257 Other 578 609 — (6,848 ) 1,971 (118 ) (3,808 ) Total Revenues from Contracts with Customers 290,562 151,465 70,055 444,035 72,484 (126,471 ) 902,130 Alternative Revenue Programs — — — 7,283 — — 7,283 Derivative Financial Instruments 30,937 — — — (5,067 ) — 25,870 Total Revenues $ 321,499 $ 151,465 $ 70,055 $ 451,318 $ 67,417 $ (126,471 ) $ 935,283 Quarter Ended March 31, 2019 (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 $ 121,824 $ — $ — $ — $ — $ — $ 121,824 Production of Crude Oil 34,878 — — — — — 34,878 Natural Gas Processing 971 — — — — — 971 Natural Gas Gathering Services — — 29,368 — — (29,366 ) 2 Natural Gas Transportation Service — 52,239 — 45,083 — (19,819 ) 77,503 Natural Gas Storage Service — 19,360 — — — (8,333 ) 11,027 Natural Gas Residential Sales — — — 229,254 — — 229,254 Natural Gas Commercial Sales — — — 34,255 — — 34,255 Natural Gas Industrial Sales — — — 1,867 — — 1,867 Natural Gas Marketing — — — — 58,516 (43 ) 58,473 Other 493 740 — (5,963 ) 318 (105 ) (4,517 ) Total Revenues from Contracts with Customers 158,166 72,339 29,368 304,496 58,834 (57,666 ) 565,537 Alternative Revenue Programs — — — (1,466 ) — — (1,466 ) Derivative Financial Instruments (12,064 ) — — — 537 — (11,527 ) Total Revenues $ 146,102 $ 72,339 $ 29,368 $ 303,030 $ 59,371 $ (57,666 ) $ 552,544 Six Months Ended March 31, 2019 (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 $ 257,735 $ — $ — $ — $ — $ — $ 257,735 Production of Crude Oil 72,433 — — — — — 72,433 Natural Gas Processing 1,945 — — — — — 1,945 Natural Gas Gathering Services — — 59,058 — — (59,056 ) 2 Natural Gas Transportation Service — 108,375 — 80,714 — (36,884 ) 152,205 Natural Gas Storage Service — 38,289 — — — (16,306 ) 21,983 Natural Gas Residential Sales — — — 396,121 — — 396,121 Natural Gas Commercial Sales — — — 56,301 — — 56,301 Natural Gas Industrial Sales — — — 3,368 — — 3,368 Natural Gas Marketing — — — — 107,803 (375 ) 107,428 Other 876 2,744 — (8,824 ) 1,325 (510 ) (4,389 ) Total Revenues from Contracts with Customers 332,989 149,408 59,058 527,680 109,128 (113,131 ) 1,065,132 Alternative Revenue Programs — — — (1,993 ) — — (1,993 ) Derivative Financial Instruments (24,011 ) — — — 3,663 — (20,348 ) Total Revenues $ 308,978 $ 149,408 $ 59,058 $ 525,687 $ 112,791 $ (113,131 ) $ 1,042,791

Leases (Tables)

Leases (Tables)	6 Months Ended
	Mar. 31, 2020
Leases [Abstract]
Components of Operating Lease Costs	The following table summarizes the components of the Company’s total operating lease costs (in thousands): Three Months Ended Six Months Ended Operating Lease Expense $ 943 1,916 Variable Lease Expense (1) 137 272 Short-Term Lease Expense (2) 76 140 Sublease Income (80 ) (161 ) Total Lease Expense $ 1,076 $ 2,167 Short-Term Lease Costs Recorded to Property, Plant and Equipment (3) $ 6,776 $ 14,289 (1) Variable lease payments that are not dependent on an index or rate are not included in the lease liability. (2) Short-term lease costs exclude expenses related to leases with a lease term of one month or less. (3) Short-term lease costs relating to drilling rig leases that are capitalized as part of oil and natural gas properties under full cost pool accounting.
Balance Sheet Information Related to Operating Leases	The following amounts related to operating leases were recorded on the Company’s Consolidated Balance Sheet (in thousands): At March 31, 2020 Assets: Deferred Charges $ 18,260 Liabilities: Other Accruals and Current Liabilities $ 3,390 Other Deferred Credits $ 14,870
Schedule of Operating Lease Liability Maturities	The following schedule of operating lease liability maturities summarizes the undiscounted lease payments owed by the Company to lessors pursuant to contractual agreements in effect as of March 31, 2020 (in thousands): At March 31, 2020 2020 (remaining 6 months) $ 1,877 2021 2,868 2022 2,278 2023 2,270 2024 2,237 Thereafter 9,717 Total Lease Payments 21,247 Less: Interest (2,987 ) Total Lease Liability $ 18,260
Schedule of Future Minimum Operating Lease Payments	The future minimum operating lease payments as of September 30, 2019, as reported in the Company's 2019 Form 10-K, under the prior authoritative guidance are as follows (in thousands): At September 30, 2019 2020 (1) $ 12,356 2021 2,813 2022 2,264 2023 2,270 2024 2,237 Thereafter 9,717 Total Operating Lease Obligations $ 31,657 (1) The future minimum operating lease payment amount for 2020 includes short-term leases, including drilling rigs, that are not included in the schedule of operating lease liability maturities above under the new authoritative guidance.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Mar. 31, 2020
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, 2020 and September 30, 2019 . Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The fair value presentation for over the counter swaps combines gas and oil swaps because a significant number of the counterparties enter into both gas and oil swap agreements with the Company. Recurring Fair Value Measures At fair value as of March 31, 2020 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 95,966 $ — $ — $ — $ 95,966 Derivative Financial Instruments: Commodity Futures Contracts – Gas 935 — — (935 ) — Over the Counter Swaps – Gas and Oil — 103,068 — (2,732 ) 100,336 Over the Counter No Cost Collars - Gas — — — (751 ) (751 ) Foreign Currency Contracts — — — (4,788 ) (4,788 ) Other Investments: Balanced Equity Mutual Fund 31,956 — — — 31,956 Fixed Income Mutual Fund 63,094 — — — 63,094 Common Stock – Financial Services Industry 577 — — — 577 Hedging Collateral Deposits 10,728 — — — 10,728 Total $ 203,256 $ 103,068 $ — $ (9,206 ) $ 297,118 Liabilities: Derivative Financial Instruments: Commodity Futures Contracts – Gas $ 6,863 $ — $ — $ (935 ) $ 5,928 Over the Counter Swaps – Gas and Oil — 3,398 — (2,732 ) 666 Over the Counter No Cost Collars – Gas — 970 — (751 ) 219 Foreign Currency Contracts — 5,627 — (4,788 ) 839 Total $ 6,863 $ 9,995 $ — $ (9,206 ) $ 7,652 Total Net Assets/(Liabilities) $ 196,393 $ 93,073 $ — $ — $ 289,466 Recurring Fair Value Measures At fair value as of September 30, 2019 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 10,521 $ — $ — $ — $ 10,521 Derivative Financial Instruments: Commodity Futures Contracts – Gas 2,055 — — (2,055 ) — Over the Counter Swaps – Gas and Oil — 52,076 — (1,483 ) 50,593 Foreign Currency Contracts — 5 — (2,052 ) (2,047 ) Other Investments: Balanced Equity Mutual Fund 40,660 — — — 40,660 Fixed Income Mutual Fund 62,339 — — — 62,339 Common Stock – Financial Services Industry 844 — — — 844 Hedging Collateral Deposits 6,832 — — — 6,832 Total $ 123,251 $ 52,081 $ — $ (5,590 ) $ 169,742 Liabilities: Derivative Financial Instruments: Commodity Futures Contracts – Gas $ 7,149 $ — $ — $ (2,055 ) $ 5,094 Over the Counter Swaps – Gas and Oil — 1,671 — (1,483 ) 188 Foreign Currency Contracts — 2,344 — (2,052 ) 292 Total $ 7,149 $ 4,015 $ — $ (5,590 ) $ 5,574 Total Net Assets/(Liabilities) $ 116,102 $ 48,066 $ — $ — $ 164,168 (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, 2020
Financial Instruments, Owned, at Fair Value [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, 2020 September 30, 2019 Carrying Amount Fair Value Carrying Amount Fair Value Long-Term Debt $ 2,134,964 $ 1,948,127 $ 2,133,718 $ 2,257,085
Schedule Of Other Investments	The components of the Company's Other Investments are as follows (in thousands): At March 31, 2020 At September 30, 2019 Life Insurance Contracts $ 41,417 $ 41,074 Equity Mutual Fund 31,956 40,660 Fixed Income Mutual Fund 63,094 62,339 Marketable Equity Securities 577 844 $ 137,044 $ 144,917
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, 2020 and 2019 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss) for the 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 2020 2019 2020 2019 Commodity Contracts $ 81,108 $ (27,228 ) Operating Revenue $ 23,396 $ (4,260 ) Commodity Contracts (134 ) (54 ) Purchased Gas 1,909 (280 ) Foreign Currency Contracts (4,670 ) 1,282 Operating Revenue (271 ) (199 ) Total $ 76,304 $ (26,000 ) $ 25,034 $ (4,739 ) The Effect of Derivative Financial Instruments on the Statement of Financial Performance for the Six Months Ended March 31, 2020 and 2019 (Thousands of Dollars) Derivatives in Cash Flow Hedging Relationships Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss) for the 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 2020 2019 2020 2019 Commodity Contracts $ 79,553 $ 22,825 Operating Revenue $ 30,937 $ (22,782 ) Commodity Contracts 997 (1,333 ) Purchased Gas 1,911 (1,182 ) Foreign Currency Contracts (3,751 ) (2,102 ) Operating Revenue (462 ) (420 ) Total $ 76,799 $ 19,390 $ 32,386 $ (24,384 )
Schedule Of Derivatives And Hedged Items in Fair Value Hedging Relationships	For derivative instruments that are designated and qualify as a fair value hedge, the gain or loss on the derivative as well as the offsetting gain or loss on the hedged item attributable to the hedged risk completely offset each other in current earnings, as shown below. Derivatives in Fair Value Hedging Relationships Location of Gain or (Loss) on Derivative and Hedged Item Recognized in the Consolidated Statement of Income Amount of Gain or (Loss) on Derivative Recognized in the Consolidated Statement of Income for the Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income for the Commodity Contracts Operating Revenues $ (4,994 ) $ 4,994 Commodity Contracts Purchased Gas $ 431 $ (431 ) $ (4,563 ) $ 4,563

Capitalization (Tables)

Capitalization (Tables)	6 Months Ended
	Mar. 31, 2020
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, 2020 86,552 $ 86,552 $ 831,146 $ 1,320,592 $ (56,150 ) Net Income (Loss) Available for Common Stock (106,068 ) Dividends Declared on Common Stock ($0.435 Per Share) (37,654 ) Other Comprehensive Income, Net of Tax 37,233 Share-Based Payment Expense (1) 3,876 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 10 10 422 Balance at March 31, 2020 86,562 $ 86,562 $ 835,444 $ 1,176,870 $ (18,917 ) Balance at October 1, 2019 86,315 $ 86,315 $ 832,264 $ 1,272,601 $ (52,155 ) Net Income (Loss) Available for Common Stock (19,477 ) Dividends Declared on Common Stock ($0.87 Per Share) (75,304 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging (950 ) Other Comprehensive Income, Net of Tax 33,238 Share-Based Payment Expense (1) 6,704 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 247 247 (3,524 ) Balance at March 31, 2020 86,562 $ 86,562 $ 835,444 $ 1,176,870 $ (18,917 ) Balance at January 1, 2019 86,271 $ 86,271 $ 817,076 $ 1,172,334 $ (28,690 ) Net Income Available for Common Stock 90,595 Dividends Declared on Common Stock ($0.425 Per Share) (36,678 ) Cumulative Effect of Adoption of Authoritative Guidance for Reclassification of Stranded Tax Effects 10,406 Other Comprehensive Loss, Net of Tax (25,596 ) Share-Based Payment Expense (1) 5,038 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 30 30 (277 ) Balance at March 31, 2019 86,301 $ 86,301 $ 821,837 $ 1,236,657 $ (54,286 ) Balance at October 1, 2018 85,957 $ 85,957 $ 820,223 $ 1,098,900 $ (67,750 ) Net Income Available for Common Stock 193,256 Dividends Declared on Common Stock ($0.85 Per Share) (73,342 ) Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities 7,437 Cumulative Effect of Adoption of Authoritative Guidance for Reclassification of Stranded Tax Effects 10,406 Other Comprehensive Income, Net of Tax 13,464 Share-Based Payment Expense (1) 9,955 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 344 344 (8,341 ) Balance at March 31, 2019 86,301 $ 86,301 $ 821,837 $ 1,236,657 $ (54,286 ) (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, 2020
Segment Reporting [Abstract]
Financial Segment Information By Segment	Quarter Ended March 31, 2020 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $155,560 $51,919 $— $250,556 $458,035 $32,925 $135 $491,095 Intersegment Revenues $— $27,326 $35,267 $3,937 $66,530 $79 $(66,609) $— Segment Profit: Net Income (Loss) $(175,275) $22,087 $19,898 $31,499 $(101,791) $1,169 $(5,446) $(106,068) Six Months Ended March 31, 2020 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $321,499 $100,888 $— $445,465 $867,852 $67,161 $270 $935,283 Intersegment Revenues $— $50,577 $70,055 $5,853 $126,485 $256 $(126,741) $— Segment Profit: Net Income (Loss) $(151,299) $40,192 $35,842 $58,082 $(17,183) $1,540 $(3,834) $(19,477) (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, 2020 $2,014,520 $1,916,849 $576,589 $2,049,424 $6,557,382 $134,926 $16,351 $6,708,659 At September 30, 2019 $1,972,776 $1,893,514 $547,995 $1,991,338 $6,405,623 $122,241 $(65,707) $6,462,157 Quarter Ended March 31, 2019 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $146,102 $48,421 $2 $298,636 $493,161 $59,328 $55 $552,544 Intersegment Revenues $— $23,918 $29,366 $4,394 $57,678 $43 $(57,721) $— Segment Profit: Net Income $21,873 $17,749 $12,690 $35,589 $87,901 $416 $2,278 $90,595 Six Months Ended March 31, 2019 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $308,978 $102,639 $2 $518,647 $930,266 $112,416 $109 $1,042,791 Intersegment Revenues $— $46,769 $59,056 $7,040 $112,865 $375 $(113,240) $— Segment Profit: Net Income $60,087 $42,851 $26,872 $61,237 $191,047 $499 $1,710 $193,256

Retirement Plan And Other Pos_2

Retirement Plan And Other Post-Retirement Benefits (Tables)	6 Months Ended
	Mar. 31, 2020
Retirement Benefits [Abstract]
Components of Net Periodic Benefit Cost	Components of Net Periodic Benefit Cost (in thousands): Retirement Plan Other Post-Retirement Benefits Three Months Ended March 31, 2020 2019 2020 2019 Service Cost $ 2,330 $ 2,120 $ 402 $ 380 Interest Cost 7,483 9,594 3,228 4,286 Expected Return on Plan Assets (15,016 ) (15,591 ) (7,308 ) (7,539 ) Amortization of Prior Service Cost (Credit) 182 206 (107 ) (107 ) Amortization of Losses 9,846 8,024 134 1,490 Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 5,519 4,786 8,846 6,565 Net Periodic Benefit Cost $ 10,344 $ 9,139 $ 5,195 $ 5,075 Retirement Plan Other Post-Retirement Benefits Six Months Ended March 31, 2020 2019 2020 2019 Service Cost $ 4,659 $ 4,241 $ 804 $ 760 Interest Cost 14,965 19,189 6,457 8,572 Expected Return on Plan Assets (30,032 ) (31,184 ) (14,616 ) (15,078 ) Amortization of Prior Service Cost (Credit) 365 413 (214 ) (214 ) Amortization of Losses 19,692 16,048 267 2,980 Net Amortization and Deferral for Regulatory Purposes (Including Volumetric Adjustments) (1) 7,047 5,604 15,094 10,536 Net Periodic Benefit Cost $ 16,696 $ 14,311 $ 7,792 $ 7,556 (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, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019	Sep. 30, 2019	Sep. 30, 2020
Summary Of Significant Accounting Policies [Line Items]
Gas stored underground	$ (8,860)		$ (8,860)		$ (36,632)
Capitalized Costs Oil and Gas Producing Activities Net	$ 1,600,000		1,600,000		1,700,000
Capitalized costs of unproved properties excluded from amortization			$ 74,800		53,500
Full cost ceiling test discount factor	10.00%		10.00%
Impairment of Oil and Gas Producing Properties	$ 177,761	$ 0	$ 177,761	$ 0
Increase estimated future net cash flows	$ 32,700
Antidilutive securities	310,015	159,023	406,748	175,443
Reserve For Gas Replacement [Member]
Summary Of Significant Accounting Policies [Line Items]
Gas stored underground	$ 23,978		$ 23,978		$ 0
Impairment of Oil and Gas Producing Properties [Member]
Summary Of Significant Accounting Policies [Line Items]
Deferred Income Tax Benefit	48,500
Non-performance Based Restricted Stock Units [Member]
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period			150,839
Granted in fiscal year, weighted average grant date fair value			$ 40.38
Performance Shares [Member]
Summary Of Significant Accounting Policies [Line Items]
Share based compensation other than options grants in period			254,608
Granted in fiscal year, weighted average grant date fair value			$ 43.32
Subsequent Event [Member] | Reserve For Gas Replacement [Member]
Summary Of Significant Accounting Policies [Line Items]
Gas stored underground						$ 0
Guidance for Hedging [Member]
Summary Of Significant Accounting Policies [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance	$ (1,000)		$ (1,000)
Guidance for Recognition and Measurement of Financial Assets and Liabilities [Member]
Summary Of Significant Accounting Policies [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance		$ 7,400		$ 7,400
Guidance for Reclassification of Stranded Tax Effects [Member]
Summary Of Significant Accounting Policies [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance		$ 10,400		$ 10,400

Summary Of Significant Accoun_5

Summary Of Significant Accounting Policies (Consolidated Statements Of Cash Flows) (Details) - USD ($) $ in Thousands	Mar. 31, 2020		Sep. 30, 2019		Mar. 31, 2019	Sep. 30, 2018
Cash and Cash Equivalents [Line Items]
Cash and Temporary Cash Investments	$ 111,655		$ 20,428		$ 100,643	$ 229,606
Hedging Collateral Deposits	10,728	[1]	6,832	[1]	1,983	3,441
Cash, Cash Equivalents and Restricted Cash	$ 122,383		$ 27,260		$ 102,626	$ 233,047
[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 (Components Of Accumulated Other Comprehensive Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	$ (56,150)	$ (28,690)	$ (52,155)	$ (67,750)
Other Comprehensive Gains and Losses Before Reclassifications	55,450	(18,601)	55,825	13,797
Amounts Reclassified From Other Comprehensive Income (Loss)	(18,217)	3,411	(23,537)	17,510
Cumulative Effect of Adoption of Authoritative Guidance for Hedging			950
Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities				(7,437)
Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act	0	(10,406)	0	(10,406)
Balance at End of Period	(18,917)	(54,286)	(18,917)	(54,286)
Gains And Losses On Derivative Financial Instruments [Member]
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	30,680		34,675
Other Comprehensive Gains and Losses Before Reclassifications	55,450		55,825
Amounts Reclassified From Other Comprehensive Income (Loss)	(18,217)		(23,537)
Cumulative Effect of Adoption of Authoritative Guidance for Hedging			950
Balance at End of Period	67,913		67,913
Gains And Losses On Derivative Financial Instruments [Member]
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period		17,886		(28,611)
Other Comprehensive Gains and Losses Before Reclassifications		(18,601)		13,797
Amounts Reclassified From Other Comprehensive Income (Loss)		3,411		17,510
Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities				0
Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act		1,866		1,866
Balance at End of Period		4,562		4,562
Gains And Losses On Securities Available For Sale [Member]
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	0	0	0	7,437
Other Comprehensive Gains and Losses Before Reclassifications	0	0	0	0
Amounts Reclassified From Other Comprehensive Income (Loss)	0	0	0	0
Cumulative Effect of Adoption of Authoritative Guidance for Hedging			0
Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities				(7,437)
Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act		0		0
Balance at End of Period	0	0	0	0
Funded Status Of The Pension And Other Post-Retirement Benefit Plans [Member]
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	(86,830)	(46,576)	(86,830)	(46,576)
Other Comprehensive Gains and Losses Before Reclassifications	0	0	0	0
Amounts Reclassified From Other Comprehensive Income (Loss)	0	0	0	0
Cumulative Effect of Adoption of Authoritative Guidance for Hedging			0
Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities				0
Reclassification of Stranded Tax Effects Related to the 2017 Tax Reform Act		(12,272)		(12,272)
Balance at End of Period	$ (86,830)	$ (58,848)	$ (86,830)	$ (58,848)

Summary Of Significant Accoun_7

Summary Of Significant Accounting Policies (Reclassification Out Of Accumulated Other Comprehensive Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Operating Revenues	$ 491,095	$ 552,544	$ 935,283	$ 1,042,791
Purchased Gas	118,270	195,037	210,542	333,697
Other Income (Deductions)	(17,480)	(5,919)	(20,520)	(15,521)
Income (Loss) Before Income Taxes	(69,222)	120,380	48,764	245,949
Income Tax Expense	(36,846)	(29,785)	(68,241)	(52,693)
Net Income (Loss) Available for Common Stock	(106,068)	90,595	(19,477)	193,256
Amount Of Gain Or (Loss) Reclassified From Accumulated Other Comprehensive Loss [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Income (Loss) Before Income Taxes	25,034	(4,739)	32,386	(24,384)
Income Tax Expense	(6,817)	1,328	(8,849)	6,874
Net Income (Loss) Available for Common Stock	18,217	(3,411)	23,537	(17,510)
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	23,396		30,937
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		(4,260)		(22,782)
Purchased Gas [Member] | 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]
Purchased Gas	1,909		1,911
Purchased Gas [Member] | 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]
Purchased Gas		(280)		(1,182)
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	$ (271)		$ (462)
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		$ (199)		$ (420)

Summary Of Significant Accoun_8

Summary Of Significant Accounting Policies (Components Of Other Current Assets) (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Sep. 30, 2019
Summary Of Significant Accounting Policies [Line Items]
Prepayments	$ 6,289	$ 12,728
Prepaid Property and Other Taxes	23,702	14,361
Fair Values of Firm Commitments	8,775	7,538
Regulatory Assets	15,582	11,460
Other Current Assets	100,188	97,054
Federal [Member]
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	42,385	42,388
State [Member]
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	$ 3,455	$ 8,579

Summary Of Significant Accoun_9

Summary Of Significant Accounting Policies (Schedule Of Other Accruals And Current Liabilities) (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Sep. 30, 2019
Summary Of Significant Accounting Policies [Line Items]
Regulatory Liabilities	$ 45,338	$ 50,332
Reserve for Gas Replacement	(8,860)	(36,632)
Liability for Royalty and Working Interests	13,987	18,057
Other Accruals and Current Liabilities	150,239	139,600
Accrued Capital Expenditures [Member]
Summary Of Significant Accounting Policies [Line Items]
Other	31,886	33,713
Reserve For Gas Replacement [Member]
Summary Of Significant Accounting Policies [Line Items]
Reserve for Gas Replacement	23,978	0
Other Accruals [Member]
Summary Of Significant Accounting Policies [Line Items]
Other	21,856	24,304
Non-Qualified [Member] | Current [Member]
Summary Of Significant Accounting Policies [Line Items]
Non-Qualified Benefit Plan Liability	$ 13,194	$ 13,194

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Narrative) (Details) $ in Millions	Mar. 31, 2020USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 92
Remaining Performance Obligation, Expected Timing of Satisfaction	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 171.8
Remaining Performance Obligation, Expected Timing of Satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 142.5
Remaining Performance Obligation, Expected Timing of Satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 97.9
Remaining Performance Obligation, Expected Timing of Satisfaction	1 year
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	$ 86.4
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	$ 361.5
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, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019
Disaggregation of Revenue [Line Items]
Revenue	$ 491,095	$ 552,544	$ 935,283	$ 1,042,791
Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	132,164	158,166	290,562	332,989
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	23,396	(12,064)	30,937	(24,011)
Revenue	155,560	146,102	321,499	308,978
Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	79,245	72,339	151,465	149,408
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	79,245	72,339	151,465	149,408
Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	35,267	29,368	70,055	59,058
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	35,267	29,368	70,055	59,058
Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	250,071	304,496	444,035	527,680
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	4,422	(1,466)	7,283	(1,993)
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0	0	0
Revenue	254,493	303,030	451,318	525,687
All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	37,255	58,834	72,484	109,128
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	(4,251)	537	(5,067)	3,663
Revenue	33,004	59,371	67,417	112,791
Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(66,474)	(57,666)	(126,471)	(113,131)
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	(66,474)	(57,666)	(126,471)	(113,131)
Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	467,528	565,537	902,130	1,065,132
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	4,422	(1,466)	7,283	(1,993)
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	19,145	(11,527)	25,870	(20,348)
Revenue	491,095	552,544	935,283	1,042,791
Production of Natural Gas [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	100,777	121,824	220,651	257,735
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	100,777	121,824	220,651	257,735
Production of Crude Oil [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	30,268	34,878	67,931	72,433
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	30,268	34,878	67,931	72,433
Natural Gas Processing [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	714	971	1,402	1,945
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	714	971	1,402	1,945
Natural Gas Gathering Services [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Gathering Services [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Gathering Services [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	35,267	29,368	70,055	59,058
Natural Gas Gathering Services [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Gathering Services [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Gathering Services [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(35,267)	(29,366)	(70,055)	(59,056)
Natural Gas Gathering Services [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	2	0	2
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	58,454	52,239	111,906	108,375
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	39,832	45,083	72,640	80,714
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	(21,976)	(19,819)	(38,963)	(36,884)
Natural Gas Transportation Service [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	76,310	77,503	145,583	152,205
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	20,524	19,360	38,950	38,289
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	(9,087)	(8,333)	(17,079)	(16,306)
Natural Gas Storage Service [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	11,437	11,027	21,871	21,983
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	185,323	229,254	329,693	396,121
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	185,323	229,254	329,693	396,121
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	27,296	34,255	46,137	56,301
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	27,296	34,255	46,137	56,301
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	1,144	1,867	2,413	3,368
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	0	0	0	0
Natural Gas Industrial Sales [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,144	1,867	2,413	3,368
Natural Gas Marketing [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Marketing [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Marketing [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Marketing [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0	0
Natural Gas Marketing [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	36,404	58,516	70,513	107,803
Natural Gas Marketing [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(79)	(43)	(256)	(375)
Natural Gas Marketing [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	36,325	58,473	70,257	107,428
Other [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	405	493	578	876
Other [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	267	740	609	2,744
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	(3,524)	(5,963)	(6,848)	(8,824)
Other [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	851	318	1,971	1,325
Other [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(65)	(105)	(118)	(510)
Other [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ (2,066)	$ (4,517)	$ (3,808)	$ (4,389)

Leases (Narrative) (Details)

Leases (Narrative) (Details) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2020	Oct. 01, 2019
Lessee, Lease, Description [Line Items]
Right of Use Asset in Exchange for New Lease Liability	$ 0
Lease Payments	$ 21,247
Weighted Average Remaining Lease Term	8 years 7 months 6 days
Weighted Average Discount Rate	3.50%
Cash Paid for Operating Liabilities	$ 2,200
Buildings and Property [Member]
Lessee, Lease, Description [Line Items]
Non-Cancelable Lease Term	10 years
Operating Lease Renewal Term	18 months
Lease Payments	$ 8,400
Buildings and Property [Member] | Minimum [Member]
Lessee, Lease, Description [Line Items]
Non-Cancelable Lease Term	3 months
Operating Lease Renewal Term	1 year
Buildings and Property [Member] | Maximum [Member]
Lessee, Lease, Description [Line Items]
Non-Cancelable Lease Term	10 years
Operating Lease Renewal Term	14 years
Drilling Rigs [Member] | Maximum [Member]
Lessee, Lease, Description [Line Items]
Non-Cancelable Lease Term	1 year
Guidance for Leases [Member]
Lessee, Lease, Description [Line Items]
Increase in Assets and Liabilities Upon Adoption of Leasing Standard		$ 19,700

Leases (Components of Operating

Leases (Components of Operating Lease Costs) (Details) - USD ($) $ in Thousands		3 Months Ended	6 Months Ended
		Mar. 31, 2020	Mar. 31, 2020
Lessee, Lease, Description [Line Items]
Operating Lease Expense		$ 943	$ 1,916
Variable Lease Expense	[1]	137	272
Short-Term Lease Expense/Costs	[2]	76	140
Sublease Income		(80)	(161)
Total Lease Expense		1,076	2,167
Oil and Natural Gas Properties [Member]
Lessee, Lease, Description [Line Items]
Short-Term Lease Expense/Costs	[3]	$ 6,776	$ 14,289
[1]	Variable lease payments that are not dependent on an index or rate are not included in the lease liability.
[2]	Short-term lease costs exclude expenses related to leases with a lease term of one month or less.
[3]	Short-term lease costs relating to drilling rig leases that are capitalized as part of oil and natural gas properties under full cost pool accounting.

Leases (Balance Sheet Informati

Leases (Balance Sheet Information Related to Operating Leases) (Details) $ in Thousands	Mar. 31, 2020USD ($)
Deferred Charges [Member]
Lessee, Lease, Description [Line Items]
Operating Lease Asset	$ 18,260
Other Accruals and Current Liabilities [Member]
Lessee, Lease, Description [Line Items]
Operating Lease Liability - Current	3,390
Other Deferred Credits [Member]
Lessee, Lease, Description [Line Items]
Operating Lease Liability - Noncurrent	$ 14,870

Leases (Schedule of Operating L

Leases (Schedule of Operating Lease Liability Maturities) (Details) $ in Thousands	Mar. 31, 2020USD ($)
Leases [Abstract]
2020 (remaining 6 months)	$ 1,877
2021	2,868
2022	2,278
2023	2,270
2024	2,237
Thereafter	9,717
Total Lease Payments	21,247
Less: Interest	(2,987)
Total Lease Liability	$ 18,260

Leases (Schedule of Future Mini

Leases (Schedule of Future Minimum Operating Lease Payments) (Details) $ in Thousands	Sep. 30, 2019USD ($)
Leases [Abstract]
2020	$ 12,356	[1]
2021	2,813
2022	2,264
2023	2,270
2024	2,237
Thereafter	9,717
Total Operating Lease Obligations	$ 31,657
[1]	The future minimum operating lease payment amount for 2020 includes short-term leases, including drilling rigs, that are not included in the schedule of operating lease liability maturities above under the new authoritative guidance.

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details) - USD ($)	Mar. 31, 2020		Sep. 30, 2019		Mar. 31, 2019	Sep. 30, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hedging collateral deposits	$ 10,728,000	[1]	$ 6,832,000	[1]	$ 1,983,000	$ 3,441,000
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hedging collateral deposits	10,728,000		6,832,000
Fair Value, Inputs, Level 1 [Member] | Futures [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hedging collateral deposits	10,700,000		$ 6,800,000
Derivative Financial Instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Level 3 Fair Value	0				0
Level 1 or Level 2 Transfers	$ 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, 2020		Sep. 30, 2019		Mar. 31, 2019	Sep. 30, 2018
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Cash Equivalents - Money Market Mutual Funds	[1]	$ 95,966		$ 10,521
Hedging Collateral Deposits		10,728	[1]	6,832	[1]	$ 1,983	$ 3,441
Total Assets	[1]	297,118		169,742
Total Liabilities	[1]	7,652		5,574
Total Net Assets/(Liabilities)	[1]	289,466		164,168
Commodity Futures Contracts - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	0		0
Derivative Liability	[1]	5,928		5,094
Over The Counter Swaps - Gas And Oil [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	100,336		50,593
Derivative Liability	[1]	666		188
Over the Counter No Cost Collars - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(751)
Derivative Liability	[1]	219
Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(4,788)		(2,047)
Derivative Liability	[1]	839		292
Balanced Equity Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments	[1]	31,956		40,660
Fixed Income Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments	[1]	63,094		62,339
Common Stock - Financial Services Industry [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments	[1]	577		844
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Cash Equivalents - Money Market Mutual Funds		95,966		10,521
Hedging Collateral Deposits		10,728		6,832
Total Assets		203,256		123,251
Total Liabilities		6,863		7,149
Total Net Assets/(Liabilities)		196,393		116,102
Fair Value, Inputs, Level 1 [Member] | Commodity Futures Contracts - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		935		2,055
Derivative Liability		6,863		7,149
Fair Value, Inputs, Level 1 [Member] | Over The Counter Swaps - Gas And Oil [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
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		31,956		40,660
Fair Value, Inputs, Level 1 [Member] | Fixed Income Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments		63,094		62,339
Fair Value, Inputs, Level 1 [Member] | Common Stock - Financial Services Industry [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments		577		844
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		0		0
Total Assets		103,068		52,081
Total Liabilities		9,995		4,015
Total Net Assets/(Liabilities)		93,073		48,066
Fair Value, Inputs, Level 2 [Member] | Commodity Futures Contracts - 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 2 [Member] | Over The Counter Swaps - Gas And Oil [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		103,068		52,076
Derivative Liability		3,398		1,671
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		0
Derivative Liability		970
Fair Value, Inputs, Level 2 [Member] | Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		0		5
Derivative Liability		5,627		2,344
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 2 [Member] | Common Stock - Financial Services Industry [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		0		0
Total Assets		0		0
Total Liabilities		0		0
Total Net Assets/(Liabilities)		0		0
Fair Value, Inputs, Level 3 [Member] | Commodity Futures Contracts - 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 Swaps - Gas And Oil [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
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
Fair Value, Inputs, Level 3 [Member] | Common Stock - Financial Services Industry [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		0
Total Assets	[1]	(9,206)		(5,590)
Total Liabilities	[1]	(9,206)		(5,590)
Total Net Assets/(Liabilities)	[1]	0		0
Netting Adjustments [Member] | Commodity Futures Contracts - Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(935)		(2,055)
Derivative Liability	[1]	(935)		(2,055)
Netting Adjustments [Member] | Over The Counter Swaps - Gas And Oil [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(2,732)		(1,483)
Derivative Liability	[1]	(2,732)		(1,483)
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]	(751)
Derivative Liability	[1]	(751)
Netting Adjustments [Member] | Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(4,788)		(2,052)
Derivative Liability	[1]	(4,788)		(2,052)
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
Netting Adjustments [Member] | Common Stock - Financial Services Industry [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) $ in Thousands	3 Months Ended		6 Months Ended
	Mar. 31, 2020USD ($)counterpartyMMcfbbl		Mar. 31, 2020USD ($)counterpartyMMcfbbl		Sep. 30, 2019USD ($)	[1]	Mar. 31, 2019USD ($)	Sep. 30, 2018USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Foreign Currency Forward Contract Hedge Duration			7 years
Derivative Gain or (Loss) Recognized in the Consolidated Statement of Income (Ineffective Portion and Amount Excluded from Effectiveness Testing)	$ 6,700		$ 200
Net hedging gains (losses) in accumulated other comprehensive income (loss)	93,100		93,100
After tax net hedging gains (losses) in accumulated other comprehensive income (loss)	67,900		67,900
Pre-Tax Net Hedging Gains (Losses) Reclassified Within Twelve Months			80,900
After Tax Net Hedging Gains (Losses) Reclassified Within Twelve Months			59,000
Fair market value of derivative asset with a credit-risk related contingency	94,800		94,800
Fair market value of derivative liability with a credit-risk related contingency	1,600		1,600
Hedging collateral deposits	$ 10,728	[1]	$ 10,728	[1]	$ 6,832		$ 1,983	$ 3,441
Cash Flow and Fair Value Commodity Hedges [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Hedge Duration			5 years
Fixed Price Sales Commitments MMCf [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk fair value hedge derivatives, natural gas | MMcf	22,200		22,200
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	14		14
Number of counterparties in net gain position | counterparty	12		12
Credit risk exposure per counterparty	$ 7,900		$ 7,900
Maximum credit risk exposure per counterparty	17,000		17,000
Collateral Received by the Company	0		0
Hedging collateral deposits	$ 0		$ 0
Natural Gas MMCf [Member] | Cash Flow Hedges Short Position [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk cash flow hedge derivatives, natural gas | MMcf	108,400		108,400
Natural Gas MMCf [Member] | Cash Flow Hedges Long Position [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk cash flow hedge derivatives, natural gas | MMcf	17,400		17,400
Crude Oil Bbls [Member] | Cash Flow Hedges Short Position [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk cash flow hedge derivatives, crude oil | bbl	2,160,000		2,160,000
Exchange Traded Futures Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Hedging collateral deposits	$ 10,700		$ 10,700
Foreign Currency Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Notional Amount	$ 86,500		$ 86,500
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	11		11
[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, 2020	Sep. 30, 2019
Financial Instruments, Owned, at Fair Value [Abstract]
Carrying Amount	$ 2,134,964	$ 2,133,718
Fair Value	$ 1,948,127	$ 2,257,085

Financial Investments (Other In

Financial Investments (Other Investments) (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Sep. 30, 2019
Investment Holdings [Line Items]
Life Insurance Contracts	$ 41,417	$ 41,074
Other Investments	137,044	144,917
Equity Mutual Fund [Member]
Investment Holdings [Line Items]
Fair Value	31,956	40,660
Fixed Income Mutual Fund [Member]
Investment Holdings [Line Items]
Fair Value	63,094	62,339
Marketable Equity Securities [Member]
Investment Holdings [Line Items]
Fair Value	$ 577	$ 844

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, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019
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)	$ 76,304		$ 76,799
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)		$ (26,000)		$ 19,390
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	25,034		32,386
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income		(4,739)		(24,384)
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)	(4,670)		(3,751)
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)		1,282		(2,102)
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	(271)		(462)
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income		(199)		(420)
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)	81,108		79,553
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)		(27,228)		22,825
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	23,396		30,937
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income		(4,260)		(22,782)
Commodity Contracts [Member] | Purchased Gas [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)	(134)		997
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)		(54)		(1,333)
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	$ 1,909		$ 1,911
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income		$ (280)		$ (1,182)

Financial Instruments (Schedu_2

Financial Instruments (Schedule Of Derivatives And Hedged Items In Fair Value Hedging Relationships) (Details) $ in Thousands	6 Months Ended
	Mar. 31, 2020USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain or (Loss) on Derivative Recognized in the Consolidated Statement of Income	$ (4,563)
Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income	4,563
Operating Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain or (Loss) on Derivative Recognized in the Consolidated Statement of Income	(4,994)
Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income	4,994
Purchased Gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain or (Loss) on Derivative Recognized in the Consolidated Statement of Income	431
Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income	$ (431)

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019	Jan. 31, 2020	Sep. 30, 2018
Income Taxes [Line Items]
Effective Tax Rate	(53.20%)	24.70%	139.90%	21.40%
Valuation Allowance	$ 56.8		$ 56.8
AMT Credit Refund Received					$ 42.5
Alternative Minimum Tax Credit [Member]
Income Taxes [Line Items]
Tax Credit Carryforwards						$ 85
Other Current Assets [Member]
Income Taxes [Line Items]
Income Taxes Receivable	$ 42.5		$ 42.5

Capitalization (Narrative) (Det

Capitalization (Narrative) (Details) - USD ($) $ in Thousands	6 Months Ended
	Mar. 31, 2020	Sep. 30, 2019
Debt Instrument [Line Items]
Shares tendered	91,269
Current Portion of Long-Term Debt	$ 0	$ 0
Restricted Stock Units [Member]
Debt Instrument [Line Items]
Common stock issued	87,135
Performance Shares [Member]
Debt Instrument [Line Items]
Common stock issued	231,246
Board Of Directors [Member]
Debt Instrument [Line Items]
Common stock issued	19,133

Capitalization and Short-Term B

Capitalization and Short-Term Borrowings (Summary of Changes in Common Stock Equity) (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Mar. 31, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019
Schedule of Capitalization, Equity [Line Items]
Beginning balance (shares)				86,315,287
Beginning balance				$ 832,264
Balance at Beginning of Period		$ 1,320,592	$ 1,172,334	1,272,601	$ 1,098,900
Balance at Beginning of Period		(56,150)	(28,690)	(52,155)	(67,750)
Net Income (Loss) Available for Common Stock		(106,068)	90,595	(19,477)	193,256
Dividends Declared on Common Stock		(37,654)	(36,678)	(75,304)	(73,342)
Other Comprehensive Income (Loss), Net of Tax		$ 37,233	(25,596)	$ 33,238	13,464
Ending balance (shares)		86,561,532		86,561,532
Ending balance		$ 835,444		$ 835,444
Balance at March 31		1,176,870	1,236,657	1,176,870	1,236,657
Balance at End of Period		(18,917)	(54,286)	(18,917)	(54,286)
Paid-in Capital [Member]
Schedule of Capitalization, Equity [Line Items]
Beginning balance		831,146	817,076	832,264	820,223
Share-Based Payment Expense	[1]	3,876	5,038	6,704	9,955
Common Stock Issued Under Stock and Benefit Plans (Value)		422
Common Stock Repurchased under Stock and Benefit Plans			(277)	(3,524)	(8,341)
Ending balance		835,444	821,837	835,444	821,837
Earnings Reinvested in The Business [Member]
Schedule of Capitalization, Equity [Line Items]
Balance at Beginning of Period		1,320,592	1,172,334	1,272,601	1,098,900
Net Income (Loss) Available for Common Stock		(106,068)	90,595	(19,477)	193,256
Dividends Declared on Common Stock		(37,654)	(36,678)	75,304	73,342
Balance at March 31		1,176,870	1,236,657	1,176,870	1,236,657
Accumulated Other Comprehensive Income (Loss) [Member]
Schedule of Capitalization, Equity [Line Items]
Balance at Beginning of Period		(56,150)	(28,690)	(52,155)	(67,750)
Other Comprehensive Income (Loss), Net of Tax		37,233	(25,596)	33,238	13,464
Balance at End of Period		$ (18,917)	$ (54,286)	$ (18,917)	$ (54,286)
Common Stock [Member]
Schedule of Capitalization, Equity [Line Items]
Beginning balance (shares)		86,552,000	86,271,000	86,315,000	85,957,000
Beginning balance (value)		$ 86,552	$ 86,271	$ 86,315	$ 85,957
Common Stock Issued Under Stock and Benefit Plans (Shares)		10,000	30,000	247,000	344,000
Common Stock Issued Under Stock and Benefit Plans (Value)		$ 10	$ 30	$ 247	$ 344
Ending balance (shares)		86,562,000	86,301,000	86,562,000	86,301,000
Ending balance (value)		$ 86,562	$ 86,301	$ 86,562	$ 86,301
Guidance for Hedging [Member]
Schedule of Capitalization, Equity [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance		(1,000)		(1,000)
Guidance for Hedging [Member] | Earnings Reinvested in The Business [Member]
Schedule of Capitalization, Equity [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance		$ (950)		$ (950)
Guidance for Recognition and Measurement of Financial Assets and Liabilities [Member]
Schedule of Capitalization, Equity [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance			7,400		7,400
Guidance for Recognition and Measurement of Financial Assets and Liabilities [Member] | Earnings Reinvested in The Business [Member]
Schedule of Capitalization, Equity [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance			7,437		7,437
Guidance for Reclassification of Stranded Tax Effects [Member]
Schedule of Capitalization, Equity [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance			10,400		10,400
Guidance for Reclassification of Stranded Tax Effects [Member] | Earnings Reinvested in The Business [Member]
Schedule of Capitalization, Equity [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance			$ 10,406		$ 10,406
[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, 2020USD ($)
Site Contingency [Line Items]
Estimated minimum liability for environmental remediation	$ 6.8
Rate recovery period	3 years
Former Manufactured Gas Plant Site New York [Member]
Site Contingency [Line Items]
Estimated minimum liability for environmental remediation	$ 3.7

Business Segment Information (N

Business Segment Information (Narrative) (Details)	6 Months Ended
	Mar. 31, 2020segment
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, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019	Sep. 30, 2019
Segment Reporting Information [Line Items]
Revenue	$ 491,095	$ 552,544	$ 935,283	$ 1,042,791
Segment Profit: Net Income (Loss)	(106,068)	90,595	(19,477)	193,256
Segment Assets	6,708,659		6,708,659		$ 6,462,157
Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	491,095	552,544	935,283	1,042,791
Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	0	0	0	0
Exploration And Production [Member]
Segment Reporting Information [Line Items]
Revenue	155,560	146,102	321,499	308,978
Segment Profit: Net Income (Loss)	(175,275)	21,873	(151,299)	60,087
Segment Assets	2,014,520		2,014,520		1,972,776
Exploration And Production [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	155,560	146,102	321,499	308,978
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	79,245	72,339	151,465	149,408
Segment Profit: Net Income (Loss)	22,087	17,749	40,192	42,851
Segment Assets	1,916,849		1,916,849		1,893,514
Pipeline And Storage [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	51,919	48,421	100,888	102,639
Pipeline And Storage [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	27,326	23,918	50,577	46,769
Gathering [Member]
Segment Reporting Information [Line Items]
Revenue	35,267	29,368	70,055	59,058
Segment Profit: Net Income (Loss)	19,898	12,690	35,842	26,872
Segment Assets	576,589		576,589		547,995
Gathering [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	0	2	0	2
Gathering [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	35,267	29,366	70,055	59,056
Utility [Member]
Segment Reporting Information [Line Items]
Revenue	254,493	303,030	451,318	525,687
Segment Profit: Net Income (Loss)	31,499	35,589	58,082	61,237
Segment Assets	2,049,424		2,049,424		1,991,338
Utility [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	250,556	298,636	445,465	518,647
Utility [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	3,937	4,394	5,853	7,040
Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)	(101,791)	87,901	(17,183)	191,047
Segment Assets	6,557,382		6,557,382		6,405,623
Total Reportable Segments [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	458,035	493,161	867,852	930,266
Total Reportable Segments [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	66,530	57,678	126,485	112,865
All Other [Member]
Segment Reporting Information [Line Items]
Revenue	33,004	59,371	67,417	112,791
Segment Profit: Net Income (Loss)	1,169	416	1,540	499
Segment Assets	134,926		134,926		122,241
All Other [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	32,925	59,328	67,161	112,416
All Other [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	79	43	256	375
Corporate And Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue	(66,474)	(57,666)	(126,471)	(113,131)
Segment Profit: Net Income (Loss)	(5,446)	2,278	(3,834)	1,710
Segment Assets	16,351		16,351		$ (65,707)
Corporate And Intersegment Eliminations [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	135	55	270	109
Corporate And Intersegment Eliminations [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	$ (66,609)	$ (57,721)	$ (126,741)	$ (113,240)

Retirement Plan And Other Pos_3

Retirement Plan And Other Post-Retirement Benefits (Narrative) (Details) $ in Millions	6 Months Ended
	Mar. 31, 2020USD ($)
Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Company's contributions	$ 19.3
VEBA Trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Company's contributions	2.1
Minimum [Member] | Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	5
Minimum [Member] | VEBA Trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	0.5
Maximum [Member] | Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	10
Maximum [Member] | VEBA Trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	$ 1

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, 2020	Mar. 31, 2019	Mar. 31, 2020	Mar. 31, 2019
Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service Cost		$ 2,330	$ 2,120	$ 4,659	$ 4,241
Interest Cost		7,483	9,594	14,965	19,189
Expected Return on Plan Assets		(15,016)	(15,591)	(30,032)	(31,184)
Amortization of Prior Service Cost (Credit)		182	206	365	413
Amortization of Losses		9,846	8,024	19,692	16,048
Net Amortization and Deferral For Regulatory Purposes (Including Volumetric Adjustments)	[1]	5,519	4,786	7,047	5,604
Net Periodic Benefit Cost		10,344	9,139	16,696	14,311
Other Post-Retirement Benefit Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service Cost		402	380	804	760
Interest Cost		3,228	4,286	6,457	8,572
Expected Return on Plan Assets		(7,308)	(7,539)	(14,616)	(15,078)
Amortization of Prior Service Cost (Credit)		(107)	(107)	(214)	(214)
Amortization of Losses		134	1,490	267	2,980
Net Amortization and Deferral For Regulatory Purposes (Including Volumetric Adjustments)	[1]	8,846	6,565	15,094	10,536
Net Periodic Benefit Cost		$ 5,195	$ 5,075	$ 7,792	$ 7,556
[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) $ in Millions	6 Months Ended
	Mar. 31, 2020USD ($)
Supply Corporation [Member]
Regulatory Matters [Line Items]
Estimated Annual Increase to Revenues from Period 1 Interim Rates	$ 35.5
Additional Estimated Annual Revenue Increase from Implementation of Period 2 Rates	$ 15
NEW YORK
Regulatory Matters [Line Items]
Approved Return on Equity	8.70%