National Fuel Gas (NFG) 10-Q 31 Jan 20 2020 Q1 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - $ / shares	3 Months Ended
	Dec. 31, 2019	Jan. 31, 2020
Cover page.
Amendment Flag	false
Current Fiscal Year End Date	--09-30
Document Fiscal Period Focus	Q1
Document Fiscal Year Focus	2020
Document Period End Date	Dec. 31, 2019
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		86,560,898
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
	Dec. 31, 2019	Dec. 31, 2018
INCOME
Operating Revenues	$ 444,188	$ 490,247
Operating Expenses:
Property, Franchise and Other Taxes	23,144	24,005
Depreciation, Depletion and Amortization	74,918	64,255
Total Operating Expenses	296,168	328,564
Operating Income	148,020	161,683
Other Income (Expense):
Other Income (Deductions)	(3,040)	(9,602)
Interest Expense on Long-Term Debt	(25,443)	(25,439)
Other Interest Expense	(1,551)	(1,073)
Income Before Income Taxes	117,986	125,569
Income Tax Expense	31,395	22,909
Net Income Available for Common Stock	86,591	102,660
EARNINGS REINVESTED IN THE BUSINESS
Balance at Beginning of Period	1,272,601	1,098,900
Beginning Retained Earnings Unappropriated And Current Period Net Income	1,359,192	1,201,560
Dividends on Common Stock	(37,650)	(36,663)
Balance at December 31	$ 1,320,592	$ 1,172,334
Earnings Per Common Share, Basic:
Net Income Available for Common Stock (in dollars per share)	$ 1	$ 1.19
Earnings Per Common Share, Diluted:
Net Income Available for Common Stock (in dollars per share)	$ 1	$ 1.18
Weighted Average Common Shares Outstanding:
Used in Basic Calculation (shares)	86,378,450	86,032,729
Used in Diluted Calculation (shares)	86,883,152	86,708,814
Dividends Per Common Share:
Dividends Declared (in dollars per share)	$ 0.435	$ 0.425
Purchased Gas [Member]
Operating Expenses:
Purchased Gas	$ 92,272	$ 138,660
Utility and Energy Marketing [Member]
INCOME
Operating Revenues	228,026	272,092
Operating Expenses:
Operation and Maintenance	43,256	43,915
Exploration and Production and Other [Member]
INCOME
Operating Revenues	167,193	163,937
Operating Expenses:
Operation and Maintenance	36,693	32,795
Pipeline and Storage and Gathering [Member]
INCOME
Operating Revenues	48,969	54,218
Operating Expenses:
Operation and Maintenance	25,885	24,934
Guidance for Hedging [Member]
EARNINGS REINVESTED IN THE BUSINESS
Cumulative Effect of Adoption of Authoritative Guidance	(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	$ 7,437

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Statement of Comprehensive Income [Abstract]
Net Income Available for Common Stock	$ 86,591	$ 102,660
Other Comprehensive Income (Loss), Before Tax:
Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	495
Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period		44,518
Reclassification Adjustment for Realized (Gains) Losses on Derivative Financial Instruments in Net Income	(7,352)
Reclassification Adjustment for Realized (Gains) Losses on Derivative Financial Instruments in Net Income		20,517
Cumulative Effect of Adoption of Authoritative Guidance for Hedging	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	(11,738)
Other Comprehensive Income (Loss), Before Tax	(5,544)	53,297
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period	119
Income Tax Expense (Benefit) Related to Unrealized Gain (Loss) on Derivative Financial Instruments Arising During the Period		12,744
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Derivative Financial Instruments in Net Income	(2,031)
Reclassification Adjustment for Income Tax Benefit (Expense) on Realized Losses (Gains) from Derivative Financial Instruments in Net Income		5,794
Income Tax Benefit (Expense) on Cumulative Effect of Adoption of Authoritative Guidance for Hedging	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	(4,301)
Income Taxes – Net	(1,549)	14,237
Other Comprehensive Income (Loss)	(3,995)	39,060
Comprehensive Income	$ 82,596	$ 141,720

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands		Dec. 31, 2019	Sep. 30, 2019
ASSETS
Property, Plant and Equipment		$ 11,402,308	$ 11,204,838
Less - Accumulated Depreciation, Depletion and Amortization		5,756,084	5,695,328
Property, Plant and Equipment, Net, Total		5,646,224	5,509,510
Current Assets
Cash and Temporary Cash Investments		34,966	20,428
Hedging Collateral Deposits	[1]	9,666	6,832
Receivables – Net of Allowance for Uncollectible Accounts of $26,717and $25,788, Respectively		158,944	139,956
Unbilled Revenue		58,306	18,758
Gas Stored Underground		29,991	36,632
Materials and Supplies - at average cost		40,373	40,717
Unrecovered Purchased Gas Costs		1,619	2,246
Other Current Assets		96,831	97,054
Total Current Assets		430,696	362,623
Other Assets
Recoverable Future Taxes		116,188	115,197
Unamortized Debt Expense		13,578	14,005
Other Regulatory Assets		165,409	167,320
Deferred Charges		56,936	33,843
Other Investments		141,229	144,917
Goodwill		5,476	5,476
Prepaid Post-Retirement Benefit Costs		64,999	60,517
Fair Value of Derivative Financial Instruments		40,569	48,669
Other		21,354	80
Total Other Assets		625,738	590,024
Total Assets		6,702,658	6,462,157
Capitalization:
Common Stock, $1 Par Value Authorized - 200,000,000 Shares; Issued and Outstanding - 86,551,528 Shares and 86,315,287 Shares, Respectively		86,552	86,315
Paid in Capital		831,146	832,264
Earnings Reinvested in the Business		1,320,592	1,272,601
Accumulated Other Comprehensive Loss		(56,150)	(52,155)
Total Comprehensive Shareholders’ Equity		2,182,140	2,139,025
Long-Term Debt, Net of Current Portion and Unamortized Discount and Debt Issuance Costs		2,134,339	2,133,718
Total Capitalization		4,316,479	4,272,743
Current and Accrued Liabilities
Notes Payable to Banks and Commercial Paper		139,800	55,200
Current Portion of Long-Term Debt		0	0
Accounts Payable		126,985	132,208
Amounts Payable to Customers		3,444	4,017
Dividends Payable		37,650	37,547
Interest Payable on Long-Term Debt		29,461	18,508
Customer Advances		13,727	13,044
Customer Security Deposits		15,510	16,210
Other Accruals and Current Liabilities		173,603	139,600
Fair Value of Derivative Financial Instruments		6,282	5,574
Total Current and Accrued Liabilities		546,462	421,908
Deferred Credits
Deferred Income Taxes		708,774	653,382
Taxes Refundable to Customers		361,556	366,503
Cost of Removal Regulatory Liability		222,172	221,699
Other Regulatory Liabilities		148,350	142,367
Pension and Other Post-Retirement Liabilities		129,616	133,729
Asset Retirement Obligations		128,382	127,458
Other Deferred Credits		140,867	122,368
Total Deferred Credits		1,839,717	1,767,506
Commitments and Contingencies (Note 8)		0	0
Total Capitalization and Liabilities		$ 6,702,658	$ 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	Dec. 31, 2019	Sep. 30, 2019
Statement of Financial Position [Abstract]
Receivables, Allowance for Uncollectible Accounts	$ 26,717	$ 25,788
Common Stock, Par Value	$ 1	$ 1
Common Stock, Shares Authorized	200,000,000	200,000,000
Common Stock, Shares Issued	86,551,528	86,315,287
Common Stock, Shares Outstanding	86,551,528	86,315,287

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
OPERATING ACTIVITIES
Net Income Available for Common Stock	$ 86,591	$ 102,660
Adjustments to Reconcile Net Income to Net Cash Provided by Operating Activities:
Depreciation, Depletion and Amortization	74,918	64,255
Deferred Income Taxes	51,366	64,175
Stock-Based Compensation	3,266	5,311
Other	1,911	2,182
Change in:
Receivables and Unbilled Revenue	(58,655)	(101,541)
Gas Stored Underground and Materials and Supplies	6,985	8,353
Unrecovered Purchased Gas Costs	627	(4,496)
Other Current Assets	14	(1,195)
Accounts Payable	8,280	1,502
Amounts Payable to Customers	(573)	(3,394)
Customer Advances	683	(6,258)
Customer Security Deposits	(700)	(1,861)
Other Accruals and Current Liabilities	15,438	38,412
Other Assets	(28,259)	(42,400)
Other Liabilities	5,857	(21,333)
Net Cash Provided by Operating Activities	167,749	104,372
INVESTING ACTIVITIES
Capital Expenditures	(198,495)	(177,567)
Other	5,212	(2,549)
Net Cash Used in Investing Activities	(193,283)	(180,116)
Financing Activities
Changes in Notes Payable to Banks and Commercial Paper	84,600	0
Dividends Paid on Common Stock	(37,547)	(36,532)
Net Repurchases of Common Stock	(4,147)	(8,233)
Net Cash Provided by (Used in) Financing Activities	42,906	(44,765)
Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash	17,372	(120,509)
Cash, Cash Equivalents and Restricted Cash at October 1	27,260	233,047
Cash, Cash Equivalents and Restricted Cash at December 31	44,632	112,538
Supplemental Disclosure of Cash Flow Information, Non-Cash Investing Activities:
Non-Cash Capital Expenditures	$ 93,838	$ 86,175

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	3 Months Ended
	Dec. 31, 2019
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 three months ended December 31, 2019 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): Three Months Ended Three Months Ended Balance at October 1, 2019 Balance at December 31, 2019 Balance at October 1, 2018 Balance at December 31, 2018 Cash and Temporary Cash Investments $ 20,428 $ 34,966 $ 229,606 $ 109,754 Hedging Collateral Deposits 6,832 9,666 3,441 2,784 Cash, Cash Equivalents, and Restricted Cash $ 27,260 $ 44,632 $ 233,047 $ 112,538 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. Gas Stored Underground. In the Utility segment, gas stored underground is carried at lower of cost or net realizable value, on a LIFO method. Gas stored underground normally declines during the first and second quarters of the year and is replenished during the third and fourth quarters. In the Utility segment, the current cost of replacing gas withdrawn from storage is recorded in the Consolidated Statements of Income and a reserve for gas replacement is recorded in the Consolidated Balance Sheets under the caption “Other Accruals and Current Liabilities.” Such reserve, which amounted to $1.1 million at December 31, 2019 , 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 $1.7 billion at both December 31, 2019 and September 30, 2019. 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 $57.9 million and $53.5 million at December 31, 2019 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. At December 31, 2019 , the ceiling exceeded the book value of the oil and gas properties by approximately $59.1 million . In adjusting estimated future cash flows for hedging under the ceiling test at December 31, 2019 , estimated future net cash flows were increased by $9.1 million . Accumulated Other Comprehensive Loss. The components of Accumulated Other Comprehensive Loss and changes for the three months ended December 31, 2019 and 2018 , 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 December 31, 2019 Balance at October 1, 2019 $ 34,675 $ — $ (86,830 ) $ (52,155 ) Other Comprehensive Gains and Losses Before Reclassifications 376 — — 376 Amounts Reclassified From Other Comprehensive Income (Loss) (5,321 ) — — (5,321 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging 950 — — 950 Balance at December 31, 2019 $ 30,680 $ — $ (86,830 ) $ (56,150 ) Three Months Ended December 31, 2018 Balance at October 1, 2018 $ (28,611 ) $ 7,437 $ (46,576 ) $ (67,750 ) Other Comprehensive Gains and Losses Before Reclassifications 31,774 — — 31,774 Amounts Reclassified From Other Comprehensive Income (Loss) 14,723 — — 14,723 Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities — (7,437 ) — (7,437 ) Balance at December 31, 2018 $ 17,886 $ — $ (46,576 ) $ (28,690 ) 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. Reclassifications Out of Accumulated Other Comprehensive Loss. The details about the reclassification adjustments out of accumulated other comprehensive loss for the three months ended December 31, 2019 and 2018 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 December 31, 2019 2018 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $7,541 ($18,522 ) Operating Revenues Commodity Contracts 2 (902 ) Purchased Gas Foreign Currency Contracts (191 ) (1,093 ) Operating Revenues 7,352 (20,517 ) Total Before Income Tax (2,031 ) 5,794 Income Tax Expense $5,321 ($14,723 ) Net of Tax Other Current Assets . The components of the Company’s Other Current Assets are as follows (in thousands): At December 31, 2019 At September 30, 2019 Prepayments $ 9,135 $ 12,728 Prepaid Property and Other Taxes 15,340 14,361 Federal Income Taxes Receivable 42,389 42,388 State Income Taxes Receivable 5,576 8,579 Fair Values of Firm Commitments 9,803 7,538 Regulatory Assets 14,588 11,460 $ 96,831 $ 97,054 Other Assets . The components of the Company’s Other Assets are as follows (in thousands): At December 31, 2019 At September 30, 2019 Federal Income Taxes Receivable $ 21,273 $ — Other 81 80 $ 21,354 $ 80 Other Accruals and Current Liabilities . The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At December 31, 2019 At September 30, 2019 Accrued Capital Expenditures $ 59,933 $ 33,713 Regulatory Liabilities 50,713 50,332 Reserve for Gas Replacement 1,100 — Liability for Royalty and Working Interests 20,052 18,057 Non-Qualified Benefit Plan Liability 13,194 13,194 Other 28,611 24,304 $ 173,603 $ 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. For the quarter ended December 31, 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 733,617 securities and 318,106 securities excluded as being antidilutive for the quarter ended December 31, 2019 and December 31, 2018 respectively. Stock-Based Compensation. The Company granted 254,608 performance shares during the quarter ended December 31, 2019 . The weighted average fair value of such performance shares was $43.32 per share for the quarter ended December 31, 2019 . 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 quarter ended December 31, 2019 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 quarter ended December 31, 2019 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 quarter ended December 31, 2019 . The weighted average fair value of such nonperformance-based restricted stock units was $40.38 per share for the quarter ended December 31, 2019 . 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	3 Months Ended
	Dec. 31, 2019
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 three months ended December 31, 2019 and 2018 , 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 December 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 $ 119,874 $ — $ — $ — $ — $ — $ 119,874 Production of Crude Oil 37,664 — — — — — 37,664 Natural Gas Processing 688 — — — — — 688 Natural Gas Gathering Services — — 34,788 — — (34,788 ) — Natural Gas Transportation Service — 53,452 — 32,808 — (16,986 ) 69,274 Natural Gas Storage Service — 18,426 — — — (7,993 ) 10,433 Natural Gas Residential Sales — — — 144,370 — — 144,370 Natural Gas Commercial Sales — — — 18,841 — — 18,841 Natural Gas Industrial Sales — — — 1,270 — — 1,270 Natural Gas Marketing — — — — 34,108 (177 ) 33,931 Other 172 342 — (3,324 ) 1,120 (52 ) (1,742 ) Total Revenues from Contracts with Customers 158,398 72,220 34,788 193,965 35,228 (59,996 ) 434,603 Alternative Revenue Programs — — — 2,860 — — 2,860 Derivative Financial Instruments 7,541 — — — (816 ) — 6,725 Total Revenues $ 165,939 $ 72,220 $ 34,788 $ 196,825 $ 34,412 $ (59,996 ) $ 444,188 Quarter Ended December 31, 2018 (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 $ 135,911 $ — $ — $ — $ — $ — $ 135,911 Production of Crude Oil 37,555 — — — — — 37,555 Natural Gas Processing 975 — — — — — 975 Natural Gas Gathering Services — — 29,690 — — (29,690 ) — Natural Gas Transportation Service — 56,135 — 35,631 — (17,065 ) 74,701 Natural Gas Storage Service — 18,929 — — — (7,973 ) 10,956 Natural Gas Residential Sales — — — 166,867 — — 166,867 Natural Gas Commercial Sales — — — 22,047 — — 22,047 Natural Gas Industrial Sales — — — 1,501 — — 1,501 Natural Gas Marketing — — — — 49,287 (332 ) 48,955 Other 382 2,005 — (2,861 ) 1,007 (404 ) 129 Total Revenues from Contracts with Customers 174,823 77,069 29,690 223,185 50,294 (55,464 ) 499,597 Alternative Revenue Programs — — — (528 ) — — (528 ) Derivative Financial Instruments (11,947 ) — — — 3,125 — (8,822 ) Total Revenues $ 162,876 $ 77,069 $ 29,690 $ 222,657 $ 53,419 $ (55,464 ) $ 490,247 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: $125.6 million for the remainder of fiscal 2020; $148.7 million for fiscal 2021; $121.8 million for fiscal 2022; $87.6 million for fiscal 2023; $77.4 million for fiscal 2024; and $318.6 million thereafter.

Leases

Leases	3 Months Ended
	Dec. 31, 2019
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 December 31, 2019, 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 six months to eleven 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. 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 Operating Lease Expense $ 974 Variable Lease Expense (1) 134 Short-Term Lease Expense (2) 64 Sublease Income (80 ) Total Lease Expense $ 1,092 Short-Term Lease Costs Recorded to Property, Plant and Equipment (3) $ 7,512 (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 December 31, 2019, the weighted average remaining lease term was 8.7 years and the weighted average discount rate was 3.49% . 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 December 31, 2019 Assets: Deferred Charges $ 18,940 Liabilities: Other Accruals and Current Liabilities $ 3,298 Other Deferred Credits $ 15,434 For the three months ended December 31, 2019, cash paid for operating liabilities, and reported in cash flows provided by operating activities on the Company’s Consolidated Statement of Cash Flows, was $1.1 million . During the three months ended December 31, 2019, 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 December 31, 2019 (in thousands): At December 31, 2019 2020 (remaining 9 months) $ 2,575 2021 2,813 2022 2,264 2023 2,270 2024 2,237 Thereafter 9,717 Total Lease Payments 21,876 Less: Interest (3,144 ) Total Lease Liability $ 18,732 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	3 Months Ended
	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The FASB authoritative guidance regarding fair value measurements establishes a fair-value hierarchy and prioritizes the inputs used in valuation techniques that measure fair value. Those inputs are prioritized into three levels. Level 1 inputs are unadjusted quoted prices in active markets for assets or liabilities that the Company can access at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly at the measurement date. Level 3 inputs are unobservable inputs for the asset or liability at the measurement date. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The following table sets forth, by level within the fair value hierarchy, the Company's financial assets and liabilities (as applicable) that were accounted for at fair value on a recurring basis as of December 31, 2019 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 December 31, 2019 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 20,924 $ — $ — $ — $ 20,924 Derivative Financial Instruments: Commodity Futures Contracts – Gas 2,096 — — (2,096 ) — Over the Counter Swaps – Gas and Oil — 46,686 — (5,031 ) 41,655 Foreign Currency Contracts — 118 — (1,204 ) (1,086 ) Other Investments: Balanced Equity Mutual Fund 36,740 — — — 36,740 Fixed Income Mutual Fund 62,220 — — — 62,220 Common Stock – Financial Services Industry 933 — — — 933 Hedging Collateral Deposits 9,666 — — — 9,666 Total $ 132,579 $ 46,804 $ — $ (8,331 ) $ 171,052 Liabilities: Derivative Financial Instruments: Commodity Futures Contracts – Gas $ 7,741 $ — $ — $ (2,096 ) $ 5,645 Over the Counter Swaps – Gas and Oil — 5,524 — (5,031 ) 493 Foreign Currency Contracts — 1,348 — (1,204 ) 144 Total $ 7,741 $ 6,872 $ — $ (8,331 ) $ 6,282 Total Net Assets/(Liabilities) $ 124,838 $ 39,932 $ — $ — $ 164,770 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 December 31, 2019 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 $9.7 million (at December 31, 2019 ) 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 December 31, 2019 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, 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 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 December 31, 2019 , 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 December 31, 2019 and December 31, 2018 , there were no assets or liabilities measured at fair value and classified as Level 3. For the quarters ended December 31, 2019 and December 31, 2018 , no

Financial Instruments

Financial Instruments	3 Months Ended
	Dec. 31, 2019
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): December 31, 2019 September 30, 2019 Carrying Amount Fair Value Carrying Amount Fair Value Long-Term Debt $ 2,134,339 $ 2,253,232 $ 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 December 31, 2019 At September 30, 2019 Life Insurance Contracts $ 41,336 $ 41,074 Equity Mutual Fund 36,740 40,660 Fixed Income Mutual Fund 62,220 62,339 Marketable Equity Securities 933 844 $ 141,229 $ 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 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 December 31, 2019 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 the assessment of effectiveness were recognized in current earnings rather than as a component of other comprehensive income (loss). During the quarter ended December 31, 2018, the Company recorded a $6.5 million hedging ineffectiveness gain 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 December 31, 2019 , the Company had the following commodity derivative contracts (swaps and futures contracts) outstanding: Commodity Units Natural Gas 88.1 Bcf (short positions) Natural Gas 2.7 Bcf (long positions) Crude Oil 2,376,000 Bbls (short positions) As of December 31, 2019 , the Company was hedging a total of $77.3 million of forecasted transportation costs denominated in Canadian dollars with foreign currency forward contracts (long positions). As of December 31, 2019 , the Company had $41.8 million ( $30.7 million after tax) of net hedging gains included in the accumulated other comprehensive income (loss) balance. It is expected that $39.1 million ( $28.7 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 December 31, 2019 and 2018 (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 Three Months Ended December 31, 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 Three Months Ended December 31, 2019 2018 2019 2018 Commodity Contracts $ (1,555 ) $ 50,052 Operating Revenue $ 7,541 $ (18,522 ) Commodity Contracts 1,131 (1,279 ) Purchased Gas 2 (902 ) Foreign Currency Contracts 919 (4,255 ) Operating Revenue (191 ) (1,093 ) Total $ 495 $ 44,518 $ 7,352 $ (20,517 ) 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 December 31, 2019 , NFR had fair value hedges covering approximately 23.5 Bcf ( 23.3 Bcf of fixed price sales commitments and 0.2 Bcf of commitments related to the withdrawal of storage gas). 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 Three Months Ended December 31, 2019 (In Thousands) Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income for the Three Months Ended December 31, 2019 (In Thousands) Commodity Contracts Operating Revenues $ (732 ) $ 732 Commodity Contracts Purchased Gas $ — $ — $ (732 ) $ 732 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 and applicable foreign currency forward contracts with fourteen counterparties of which twelve are in a net gain position. On average, the Company had $3.4 million of credit exposure per counterparty in a gain position at December 31, 2019 . The maximum credit exposure per counterparty in a gain position at December 31, 2019 was $6.9 million . As of December 31, 2019 , no collateral was received from the counterparties by the Company. The Company's gain position on such derivative financial instruments had not exceeded the established thresholds at which the counterparties would be required to post collateral, nor had the counterparties' credit ratings declined to levels at which the counterparties were required to post collateral. As of December 31, 2019 , 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 December 31, 2019 , the fair market value of the derivative financial instrument assets with a credit-risk related contingency feature was $31.3 million according to the Company’s internal model (discussed in Note 4 — Fair Value Measurements). At December 31, 2019 , the fair market value of the derivative financial instrument liabilities with a credit-risk related contingency feature was $0.6 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 December 31, 2019 . For its exchange traded futures contracts, the Company was required to post $9.7 million in hedging collateral deposits as of December 31, 2019 . 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	3 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The effective tax rates for the quarters ended December 31, 2019 and December 31, 2018 were 26.6% and 18.2% , respectively. The increase in the effective tax rate was primarily the result of the reversal of a $5.0 million valuation allowance in fiscal 2019 related to sequestration of AMT credit refunds discussed below, 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. The 2017 Tax Reform Act repealed the corporate alternative minimum tax (AMT) and provides that the Company’s existing AMT credit carryovers are 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 are expected to be refunded between fiscal 2020 and fiscal 2023, if not previously utilized. During fiscal 2018, the Department of Treasury indicated that a portion of the refundable AMT credit carryovers would be subject to sequestration. Accordingly, the Company recorded a $5.0 million valuation allowance related to this sequestration in fiscal 2018. During the quarter ended December 31, 2018, the Office of Management and Budget determined that these AMT refunds would not be subject to sequestration. As such, the Company removed the valuation allowance. These amounts are recorded in Deferred Income Taxes and will be reclassified to a receivable when the amounts are expected to be realized in cash. The Company reclassified AMT credit refunds of $21.3 million and $42.1 million from Deferred Income Taxes to Other Assets at December 31, 2019 and 2018, respectively. The Company received $42.5 million of AMT credit refunds related to fiscal 2019 in January 2020.

Capitalization

Capitalization	3 Months Ended
	Dec. 31, 2019
Capitalization, Long-term Debt and Equity [Abstract]
Capitalization	Capitalization Summary of Changes in Common Stock Equity Common Stock Paid In Capital Earnings Reinvested in the Business Accumulated Other Comprehensive Income (Loss) Shares Amount (Thousands, except per share amounts) Balance at October 1, 2019 86,315 $ 86,315 $ 832,264 $ 1,272,601 $ (52,155 ) Net Income Available for Common Stock 86,591 Dividends Declared on Common Stock ($0.435 Per Share) (37,650 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging (950 ) Other Comprehensive Loss, Net of Tax (3,995 ) Share-Based Payment Expense (1) 2,828 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 237 237 (3,946 ) Balance at December 31, 2019 86,552 $ 86,552 $ 831,146 $ 1,320,592 $ (56,150 ) Balance at October 1, 2018 85,957 $ 85,957 $ 820,223 $ 1,098,900 $ (67,750 ) Net Income Available for Common Stock 102,660 Dividends Declared on Common Stock ($0.425 Per Share) (36,663 ) Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities 7,437 Other Comprehensive Income, Net of Tax 39,060 Share-Based Payment Expense (1) 4,917 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 314 314 (8,064 ) Balance at December 31, 2018 86,271 $ 86,271 $ 817,076 $ 1,172,334 $ (28,690 ) (1) Paid in Capital includes compensation costs associated with performance shares and/or restricted stock awards. The expense is included within Net Income Available For Common Stock, net of tax benefits. Common Stock. During the three months ended December 31, 2019 , the Company issued 86,635 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 9,480 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 three months ended December 31, 2019 . Holders of stock-based compensation awards will often tender shares of common stock to the Company for payment of applicable withholding taxes. During the three months ended December 31, 2019 , 91,120 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 December 31, 2019

Commitments And Contingencies

Commitments And Contingencies	3 Months Ended
	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	Commitments and Contingencies Environmental Matters. The Company is subject to various federal, state and local laws and regulations relating to the protection of the environment. The Company has established procedures for the ongoing evaluation of its operations to identify potential environmental exposures and to comply with regulatory requirements. It is the Company’s policy to accrue estimated environmental clean-up costs (investigation and remediation) when such amounts can reasonably be estimated and it is probable that the Company will be required to incur such costs. At December 31, 2019 , the Company has estimated its remaining clean-up costs related to former manufactured gas plant sites will be approximately $6.9 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 December 31, 2019 . 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	3 Months Ended
	Dec. 31, 2019
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 December 31, 2019 and September 30, 2019 is shown in the tables below. Quarter Ended December 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 $165,939 $48,969 $— $194,910 $409,818 $34,235 $135 $444,188 Intersegment Revenues $— $23,251 $34,788 $1,915 $59,954 $177 $(60,131) $— Segment Profit: Net Income $23,977 $18,105 $15,944 $26,583 $84,609 $371 $1,611 $86,591 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Segment Assets: At December 31, 2019 $2,059,681 $1,926,766 $559,064 $2,043,246 $6,588,757 $143,890 $(29,989) $6,702,658 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 December 31, 2018 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $162,876 $54,218 $— $220,012 $437,106 $53,087 $54 $490,247 Intersegment Revenues $— $22,851 $29,690 $2,645 $55,186 $332 $(55,518) $— Segment Profit: Net Income (Loss) $38,214 $25,102 $14,183 $25,649 $103,148 $82 $(570) $102,660

Retirement Plan And Other Post-

Retirement Plan And Other Post-Retirement Benefits	3 Months Ended
	Dec. 31, 2019
Retirement Benefits [Abstract]
Retirement Plan and Other Post-Retirement Benefits	Retirement Plan and Other Post-Retirement Benefits Components of Net Periodic Benefit Cost (in thousands): Retirement Plan Other Post-Retirement Benefits Three Months Ended December 31, 2019 2018 2019 2018 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) 1,527 819 6,249 3,971 Net Periodic Benefit Cost $ 6,352 $ 5,172 $ 2,598 $ 2,481 (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 three months ended December 31, 2019 , the Company contributed $7.8 million to its tax-qualified, noncontributory defined-benefit retirement plan (Retirement Plan) and $0.7 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 $17.0 million to $22.0 million . In the remainder of 2020 , the Company expects its contributions to its VEBA trusts to be in the range of $2.0 million to $2.5 million

Regulatory Matters

Regulatory Matters	3 Months Ended
	Dec. 31, 2019
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. 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. FERC Jurisdiction Supply Corporation filed a Section 4 rate case on July 31, 2019 proposing rate increases to be effective September 1, 2019. The proposed rates reflect an annual cost of service of $295.4 million , a rate base of $970.8 million and a proposed cost of equity of 15% . The FERC has accepted the filed rates and suspended the effective date of the increases until February 1, 2020, when the rates will be made effective, subject to refund. If the rates finally approved at the end of the proceeding exceed the rates that were in effect at July 31, 2019, but are less than rates put into effect subject to refund on February 1, 2020, Supply Corporation would be required to refund the difference between the rates collected subject to refund and the final approved rates, with interest at the FERC-approved rate. If the rates approved at the end of the proceeding are lower than the rates in effect at July 31, 2019, such lower rates will become effective prospectively from the date of the applicable FERC order, and refunds with interest will be limited to the difference between the rates collected subject to refund and the rates in effect at July 31, 2019.

Summary Of Significant Accoun_2

Summary Of Significant Accounting Policies (Policy)	3 Months Ended
	Dec. 31, 2019
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 three months ended December 31, 2019 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): Three Months Ended Three Months Ended Balance at October 1, 2019 Balance at December 31, 2019 Balance at October 1, 2018 Balance at December 31, 2018 Cash and Temporary Cash Investments $ 20,428 $ 34,966 $ 229,606 $ 109,754 Hedging Collateral Deposits 6,832 9,666 3,441 2,784 Cash, Cash Equivalents, and Restricted Cash $ 27,260 $ 44,632 $ 233,047 $ 112,538 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.
Gas Stored Underground	Gas Stored Underground. In the Utility segment, gas stored underground is carried at lower of cost or net realizable value, on a LIFO method. Gas stored underground normally declines during the first and second quarters of the year and is replenished during the third and fourth quarters. In the Utility segment, the current cost of replacing gas withdrawn from storage is recorded in the Consolidated Statements of Income and a reserve for gas replacement is recorded in the Consolidated Balance Sheets under the caption “Other Accruals and Current Liabilities.” Such reserve, which amounted to $1.1 million at December 31, 2019 , 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 $1.7 billion at both December 31, 2019 and September 30, 2019. 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 $57.9 million and $53.5 million at December 31, 2019 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. At December 31, 2019 , the ceiling exceeded the book value of the oil and gas properties by approximately $59.1 million . In adjusting estimated future cash flows for hedging under the ceiling test at December 31, 2019 , estimated future net cash flows were increased by $9.1 million .
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss. The components of Accumulated Other Comprehensive Loss and changes for the three months ended December 31, 2019 and 2018 , 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 December 31, 2019 Balance at October 1, 2019 $ 34,675 $ — $ (86,830 ) $ (52,155 ) Other Comprehensive Gains and Losses Before Reclassifications 376 — — 376 Amounts Reclassified From Other Comprehensive Income (Loss) (5,321 ) — — (5,321 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging 950 — — 950 Balance at December 31, 2019 $ 30,680 $ — $ (86,830 ) $ (56,150 ) Three Months Ended December 31, 2018 Balance at October 1, 2018 $ (28,611 ) $ 7,437 $ (46,576 ) $ (67,750 ) Other Comprehensive Gains and Losses Before Reclassifications 31,774 — — 31,774 Amounts Reclassified From Other Comprehensive Income (Loss) 14,723 — — 14,723 Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities — (7,437 ) — (7,437 ) Balance at December 31, 2018 $ 17,886 $ — $ (46,576 ) $ (28,690 ) 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.
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 three months ended December 31, 2019 and 2018 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 December 31, 2019 2018 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $7,541 ($18,522 ) Operating Revenues Commodity Contracts 2 (902 ) Purchased Gas Foreign Currency Contracts (191 ) (1,093 ) Operating Revenues 7,352 (20,517 ) Total Before Income Tax (2,031 ) 5,794 Income Tax Expense $5,321 ($14,723 ) Net of Tax
Other Current Assets	Other Current Assets . The components of the Company’s Other Current Assets are as follows (in thousands): At December 31, 2019 At September 30, 2019 Prepayments $ 9,135 $ 12,728 Prepaid Property and Other Taxes 15,340 14,361 Federal Income Taxes Receivable 42,389 42,388 State Income Taxes Receivable 5,576 8,579 Fair Values of Firm Commitments 9,803 7,538 Regulatory Assets 14,588 11,460 $ 96,831 $ 97,054
Other Assets	Other Assets . The components of the Company’s Other Assets are as follows (in thousands): At December 31, 2019 At September 30, 2019 Federal Income Taxes Receivable $ 21,273 $ — Other 81 80 $ 21,354 $ 80
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 December 31, 2019 At September 30, 2019 Accrued Capital Expenditures $ 59,933 $ 33,713 Regulatory Liabilities 50,713 50,332 Reserve for Gas Replacement 1,100 — Liability for Royalty and Working Interests 20,052 18,057 Non-Qualified Benefit Plan Liability 13,194 13,194 Other 28,611 24,304 $ 173,603 $ 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. For the quarter ended December 31, 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 733,617 securities and 318,106 securities excluded as being antidilutive for the quarter ended December 31, 2019 and December 31, 2018 respectively.
Stock-Based Compensation	Stock-Based Compensation. The Company granted 254,608 performance shares during the quarter ended December 31, 2019 . The weighted average fair value of such performance shares was $43.32 per share for the quarter ended December 31, 2019 . 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 quarter ended December 31, 2019 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 quarter ended December 31, 2019 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 quarter ended December 31, 2019 . The weighted average fair value of such nonperformance-based restricted stock units was $40.38 per share for the quarter ended December 31, 2019 . 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)	3 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Schedule of Cash, Cash Equivalents and Restricted Cash	The components, as reported on the Company’s Consolidated Balance Sheets, of the total cash, cash equivalents, and restricted cash presented on the Statement of Cash Flows are as follows (in thousands): Three Months Ended Three Months Ended Balance at October 1, 2019 Balance at December 31, 2019 Balance at October 1, 2018 Balance at December 31, 2018 Cash and Temporary Cash Investments $ 20,428 $ 34,966 $ 229,606 $ 109,754 Hedging Collateral Deposits 6,832 9,666 3,441 2,784 Cash, Cash Equivalents, and Restricted Cash $ 27,260 $ 44,632 $ 233,047 $ 112,538
Components of Accumulated Other Comprehensive Loss	The components of Accumulated Other Comprehensive Loss and changes for the three months ended December 31, 2019 and 2018 , 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 December 31, 2019 Balance at October 1, 2019 $ 34,675 $ — $ (86,830 ) $ (52,155 ) Other Comprehensive Gains and Losses Before Reclassifications 376 — — 376 Amounts Reclassified From Other Comprehensive Income (Loss) (5,321 ) — — (5,321 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging 950 — — 950 Balance at December 31, 2019 $ 30,680 $ — $ (86,830 ) $ (56,150 ) Three Months Ended December 31, 2018 Balance at October 1, 2018 $ (28,611 ) $ 7,437 $ (46,576 ) $ (67,750 ) Other Comprehensive Gains and Losses Before Reclassifications 31,774 — — 31,774 Amounts Reclassified From Other Comprehensive Income (Loss) 14,723 — — 14,723 Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities — (7,437 ) — (7,437 ) Balance at December 31, 2018 $ 17,886 $ — $ (46,576 ) $ (28,690 )
Schedule of Reclassifications Out of Accumulated Other Comprehensive Loss	The details about the reclassification adjustments out of accumulated other comprehensive loss for the three months ended December 31, 2019 and 2018 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 December 31, 2019 2018 Gains (Losses) on Derivative Financial Instrument Cash Flow Hedges: Commodity Contracts $7,541 ($18,522 ) Operating Revenues Commodity Contracts 2 (902 ) Purchased Gas Foreign Currency Contracts (191 ) (1,093 ) Operating Revenues 7,352 (20,517 ) Total Before Income Tax (2,031 ) 5,794 Income Tax Expense $5,321 ($14,723 ) Net of Tax
Schedule of Other Current Assets	The components of the Company’s Other Current Assets are as follows (in thousands): At December 31, 2019 At September 30, 2019 Prepayments $ 9,135 $ 12,728 Prepaid Property and Other Taxes 15,340 14,361 Federal Income Taxes Receivable 42,389 42,388 State Income Taxes Receivable 5,576 8,579 Fair Values of Firm Commitments 9,803 7,538 Regulatory Assets 14,588 11,460 $ 96,831 $ 97,054
Schedule of Other Assets	The components of the Company’s Other Assets are as follows (in thousands): At December 31, 2019 At September 30, 2019 Federal Income Taxes Receivable $ 21,273 $ — Other 81 80 $ 21,354 $ 80
Schedule of Other Accruals and Current Liabilities	The components of the Company’s Other Accruals and Current Liabilities are as follows (in thousands): At December 31, 2019 At September 30, 2019 Accrued Capital Expenditures $ 59,933 $ 33,713 Regulatory Liabilities 50,713 50,332 Reserve for Gas Replacement 1,100 — Liability for Royalty and Working Interests 20,052 18,057 Non-Qualified Benefit Plan Liability 13,194 13,194 Other 28,611 24,304 $ 173,603 $ 139,600

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	3 Months Ended
	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following tables provide a disaggregation of the Company's revenues for the three months ended December 31, 2019 and 2018 , 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 December 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 $ 119,874 $ — $ — $ — $ — $ — $ 119,874 Production of Crude Oil 37,664 — — — — — 37,664 Natural Gas Processing 688 — — — — — 688 Natural Gas Gathering Services — — 34,788 — — (34,788 ) — Natural Gas Transportation Service — 53,452 — 32,808 — (16,986 ) 69,274 Natural Gas Storage Service — 18,426 — — — (7,993 ) 10,433 Natural Gas Residential Sales — — — 144,370 — — 144,370 Natural Gas Commercial Sales — — — 18,841 — — 18,841 Natural Gas Industrial Sales — — — 1,270 — — 1,270 Natural Gas Marketing — — — — 34,108 (177 ) 33,931 Other 172 342 — (3,324 ) 1,120 (52 ) (1,742 ) Total Revenues from Contracts with Customers 158,398 72,220 34,788 193,965 35,228 (59,996 ) 434,603 Alternative Revenue Programs — — — 2,860 — — 2,860 Derivative Financial Instruments 7,541 — — — (816 ) — 6,725 Total Revenues $ 165,939 $ 72,220 $ 34,788 $ 196,825 $ 34,412 $ (59,996 ) $ 444,188 Quarter Ended December 31, 2018 (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 $ 135,911 $ — $ — $ — $ — $ — $ 135,911 Production of Crude Oil 37,555 — — — — — 37,555 Natural Gas Processing 975 — — — — — 975 Natural Gas Gathering Services — — 29,690 — — (29,690 ) — Natural Gas Transportation Service — 56,135 — 35,631 — (17,065 ) 74,701 Natural Gas Storage Service — 18,929 — — — (7,973 ) 10,956 Natural Gas Residential Sales — — — 166,867 — — 166,867 Natural Gas Commercial Sales — — — 22,047 — — 22,047 Natural Gas Industrial Sales — — — 1,501 — — 1,501 Natural Gas Marketing — — — — 49,287 (332 ) 48,955 Other 382 2,005 — (2,861 ) 1,007 (404 ) 129 Total Revenues from Contracts with Customers 174,823 77,069 29,690 223,185 50,294 (55,464 ) 499,597 Alternative Revenue Programs — — — (528 ) — — (528 ) Derivative Financial Instruments (11,947 ) — — — 3,125 — (8,822 ) Total Revenues $ 162,876 $ 77,069 $ 29,690 $ 222,657 $ 53,419 $ (55,464 ) $ 490,247

Leases (Tables)

Leases (Tables)	3 Months Ended
	Dec. 31, 2019
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 Operating Lease Expense $ 974 Variable Lease Expense (1) 134 Short-Term Lease Expense (2) 64 Sublease Income (80 ) Total Lease Expense $ 1,092 Short-Term Lease Costs Recorded to Property, Plant and Equipment (3) $ 7,512 (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 December 31, 2019 Assets: Deferred Charges $ 18,940 Liabilities: Other Accruals and Current Liabilities $ 3,298 Other Deferred Credits $ 15,434
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 December 31, 2019 (in thousands): At December 31, 2019 2020 (remaining 9 months) $ 2,575 2021 2,813 2022 2,264 2023 2,270 2024 2,237 Thereafter 9,717 Total Lease Payments 21,876 Less: Interest (3,144 ) Total Lease Liability $ 18,732
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)	3 Months Ended
	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following table sets forth, by level within the fair value hierarchy, the Company's financial assets and liabilities (as applicable) that were accounted for at fair value on a recurring basis as of December 31, 2019 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 December 31, 2019 (Thousands of Dollars) Level 1 Level 2 Level 3 Netting Adjustments (1) Total (1) Assets: Cash Equivalents – Money Market Mutual Funds $ 20,924 $ — $ — $ — $ 20,924 Derivative Financial Instruments: Commodity Futures Contracts – Gas 2,096 — — (2,096 ) — Over the Counter Swaps – Gas and Oil — 46,686 — (5,031 ) 41,655 Foreign Currency Contracts — 118 — (1,204 ) (1,086 ) Other Investments: Balanced Equity Mutual Fund 36,740 — — — 36,740 Fixed Income Mutual Fund 62,220 — — — 62,220 Common Stock – Financial Services Industry 933 — — — 933 Hedging Collateral Deposits 9,666 — — — 9,666 Total $ 132,579 $ 46,804 $ — $ (8,331 ) $ 171,052 Liabilities: Derivative Financial Instruments: Commodity Futures Contracts – Gas $ 7,741 $ — $ — $ (2,096 ) $ 5,645 Over the Counter Swaps – Gas and Oil — 5,524 — (5,031 ) 493 Foreign Currency Contracts — 1,348 — (1,204 ) 144 Total $ 7,741 $ 6,872 $ — $ (8,331 ) $ 6,282 Total Net Assets/(Liabilities) $ 124,838 $ 39,932 $ — $ — $ 164,770 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)	3 Months Ended
	Dec. 31, 2019
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): December 31, 2019 September 30, 2019 Carrying Amount Fair Value Carrying Amount Fair Value Long-Term Debt $ 2,134,339 $ 2,253,232 $ 2,133,718 $ 2,257,085
Schedule Of Other Investments	The components of the Company's Other Investments are as follows (in thousands): At December 31, 2019 At September 30, 2019 Life Insurance Contracts $ 41,336 $ 41,074 Equity Mutual Fund 36,740 40,660 Fixed Income Mutual Fund 62,220 62,339 Marketable Equity Securities 933 844 $ 141,229 $ 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 December 31, 2019 and 2018 (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 Three Months Ended December 31, 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 Three Months Ended December 31, 2019 2018 2019 2018 Commodity Contracts $ (1,555 ) $ 50,052 Operating Revenue $ 7,541 $ (18,522 ) Commodity Contracts 1,131 (1,279 ) Purchased Gas 2 (902 ) Foreign Currency Contracts 919 (4,255 ) Operating Revenue (191 ) (1,093 ) Total $ 495 $ 44,518 $ 7,352 $ (20,517 )
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 Three Months Ended December 31, 2019 (In Thousands) Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income for the Three Months Ended December 31, 2019 (In Thousands) Commodity Contracts Operating Revenues $ (732 ) $ 732 Commodity Contracts Purchased Gas $ — $ — $ (732 ) $ 732

Capitalization (Tables)

Capitalization (Tables)	3 Months Ended
	Dec. 31, 2019
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 Capital Earnings Reinvested in the Business Accumulated Other Comprehensive Income (Loss) Shares Amount (Thousands, except per share amounts) Balance at October 1, 2019 86,315 $ 86,315 $ 832,264 $ 1,272,601 $ (52,155 ) Net Income Available for Common Stock 86,591 Dividends Declared on Common Stock ($0.435 Per Share) (37,650 ) Cumulative Effect of Adoption of Authoritative Guidance for Hedging (950 ) Other Comprehensive Loss, Net of Tax (3,995 ) Share-Based Payment Expense (1) 2,828 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 237 237 (3,946 ) Balance at December 31, 2019 86,552 $ 86,552 $ 831,146 $ 1,320,592 $ (56,150 ) Balance at October 1, 2018 85,957 $ 85,957 $ 820,223 $ 1,098,900 $ (67,750 ) Net Income Available for Common Stock 102,660 Dividends Declared on Common Stock ($0.425 Per Share) (36,663 ) Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities 7,437 Other Comprehensive Income, Net of Tax 39,060 Share-Based Payment Expense (1) 4,917 Common Stock Issued (Repurchased) Under Stock and Benefit Plans 314 314 (8,064 ) Balance at December 31, 2018 86,271 $ 86,271 $ 817,076 $ 1,172,334 $ (28,690 ) (1) Paid in Capital includes compensation costs associated with performance shares and/or restricted stock awards. The expense is included within Net Income Available For Common Stock, net of tax benefits.

Business Segment Information (T

Business Segment Information (Tables)	3 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Financial Segment Information By Segment	Quarter Ended December 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 $165,939 $48,969 $— $194,910 $409,818 $34,235 $135 $444,188 Intersegment Revenues $— $23,251 $34,788 $1,915 $59,954 $177 $(60,131) $— Segment Profit: Net Income $23,977 $18,105 $15,944 $26,583 $84,609 $371 $1,611 $86,591 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Segment Assets: At December 31, 2019 $2,059,681 $1,926,766 $559,064 $2,043,246 $6,588,757 $143,890 $(29,989) $6,702,658 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 December 31, 2018 (Thousands) Exploration and Production Pipeline and Storage Gathering Utility Total Reportable Segments All Other Corporate and Intersegment Eliminations Total Consolidated Revenue from External Customers $162,876 $54,218 $— $220,012 $437,106 $53,087 $54 $490,247 Intersegment Revenues $— $22,851 $29,690 $2,645 $55,186 $332 $(55,518) $— Segment Profit: Net Income (Loss) $38,214 $25,102 $14,183 $25,649 $103,148 $82 $(570) $102,660

Retirement Plan And Other Pos_2

Retirement Plan And Other Post-Retirement Benefits (Tables)	3 Months Ended
	Dec. 31, 2019
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 December 31, 2019 2018 2019 2018 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) 1,527 819 6,249 3,971 Net Periodic Benefit Cost $ 6,352 $ 5,172 $ 2,598 $ 2,481 (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		12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Sep. 30, 2019	Sep. 30, 2020
Summary Of Significant Accounting Policies [Line Items]
Gas stored underground	$ (29,991)		$ (36,632)
Capitalized Costs Oil and Gas Producing Activities Net	1,700,000		1,700,000
Capitalized costs of unproved properties excluded from amortization	$ 57,900		53,500
Full cost ceiling test discount factor	10.00%
Amount Full Cost Ceiling Exceeds Book Value Of Oil And Gas Properties	$ 59,100
Increase estimated future net cash flows	$ 9,100
Antidilutive securities	733,617	318,106
Reserve For Gas Replacement [Member]
Summary Of Significant Accounting Policies [Line Items]
Gas stored underground	$ 1,100		$ 0
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)
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

Summary Of Significant Accoun_5

Summary Of Significant Accounting Policies (Consolidated Statements Of Cash Flows) (Details) - USD ($) $ in Thousands	Dec. 31, 2019		Sep. 30, 2019		Dec. 31, 2018	Sep. 30, 2018
Cash and Cash Equivalents [Line Items]
Cash and Temporary Cash Investments	$ 34,966		$ 20,428		$ 109,754	$ 229,606
Hedging Collateral Deposits	9,666	[1]	6,832	[1]	2,784	3,441
Cash, Cash Equivalents and Restricted Cash	$ 44,632		$ 27,260		$ 112,538	$ 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
	Dec. 31, 2019	Dec. 31, 2018
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	$ (52,155)	$ (67,750)
Other Comprehensive Gains and Losses Before Reclassifications	376	31,774
Amounts Reclassified From Other Comprehensive Income (Loss)	(5,321)	14,723
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)
Balance at End of Period	(56,150)	(28,690)
Gains And Losses On Derivative Financial Instruments [Member]
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	34,675
Other Comprehensive Gains and Losses Before Reclassifications	376
Amounts Reclassified From Other Comprehensive Income (Loss)	(5,321)
Cumulative Effect of Adoption of Authoritative Guidance for Hedging	950
Balance at End of Period	30,680
Gains And Losses On Derivative Financial Instruments [Member]
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period		(28,611)
Other Comprehensive Gains and Losses Before Reclassifications		31,774
Amounts Reclassified From Other Comprehensive Income (Loss)		14,723
Reclassification Adjustment for the Cumulative Effect of Adoption of Authoritative Guidance for Financial Assets and Liabilities		0
Balance at End of Period		17,886
Gains And Losses On Securities Available For Sale [Member]
Accumulated Other Comprehensive Loss [Roll Forward]
Balance at Beginning of Period	0	7,437
Other Comprehensive Gains and Losses Before Reclassifications	0	0
Amounts Reclassified From Other Comprehensive Income (Loss)	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)
Balance at End of Period	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)
Other Comprehensive Gains and Losses Before Reclassifications	0	0
Amounts Reclassified From Other Comprehensive Income (Loss)	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
Balance at End of Period	$ (86,830)	$ (46,576)

Summary Of Significant Accoun_7

Summary Of Significant Accounting Policies (Reclassification Out Of Accumulated Other Comprehensive Loss) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Operating Revenues	$ 444,188	$ 490,247
Other Income (Deductions)	(3,040)	(9,602)
Income Before Income Taxes	117,986	125,569
Income Tax Expense	(31,395)	(22,909)
Net Income Available for Common Stock	86,591	102,660
Amount Of Gain Or (Loss) Reclassified From Accumulated Other Comprehensive Loss [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Income Before Income Taxes	7,352	(20,517)
Income Tax Expense	(2,031)	5,794
Net Income Available for Common Stock	5,321	(14,723)
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	7,541
Amount Of Gain Or (Loss) Reclassified From Accumulated Other Comprehensive Loss [Member] | Commodity Contracts [Member] | Gains And Losses On Derivative Financial Instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Operating Revenues		(18,522)
Purchased Gas [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Loss [Line Items]
Purchased Gas	92,272	138,660
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	2
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		(902)
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	$ (191)
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		$ (1,093)

Summary Of Significant Accoun_8

Summary Of Significant Accounting Policies (Components Of Other Current Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Sep. 30, 2019
Summary Of Significant Accounting Policies [Line Items]
Prepayments	$ 9,135	$ 12,728
Prepaid Property and Other Taxes	15,340	14,361
Fair Values of Firm Commitments	9,803	7,538
Regulatory Assets	14,588	11,460
Other Current Assets	96,831	97,054
State [Member]
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	5,576	8,579
Other Current Assets [Member] | Federal [Member]
Summary Of Significant Accounting Policies [Line Items]
Income Taxes Receivable	$ 42,389	$ 42,388

Summary Of Significant Accoun_9

Summary Of Significant Accounting Policies (Other Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Sep. 30, 2019	Dec. 31, 2018
Other Assets [Line Items]
Other	$ 81	$ 80
Other Assets	21,354	80
Other Noncurrent Assets [Member] | Federal [Member]
Other Assets [Line Items]
Income Taxes Receivable	$ 21,273	$ 0	$ 42,100

Summary Of Significant Accou_10

Summary Of Significant Accounting Policies (Schedule Of Other Accruals And Current Liabilities) (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Sep. 30, 2019
Summary Of Significant Accounting Policies [Line Items]
Regulatory Liabilities	$ 50,713	$ 50,332
Reserve for Gas Replacement	(29,991)	(36,632)
Liability for Royalty and Working Interests	20,052	18,057
Other Accruals and Current Liabilities	173,603	139,600
Accrued Capital Expenditures [Member]
Summary Of Significant Accounting Policies [Line Items]
Other	59,933	33,713
Reserve For Gas Replacement [Member]
Summary Of Significant Accounting Policies [Line Items]
Reserve for Gas Replacement	1,100	0
Other Accruals [Member]
Summary Of Significant Accounting Policies [Line Items]
Other	28,611	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	Dec. 31, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Future Revenue Amounts Related to Remaining Performance Obligations	$ 125.6
Remaining Performance Obligation, Expected Timing of Satisfaction	9 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	$ 148.7
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	$ 121.8
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	$ 87.6
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	$ 77.4
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	$ 318.6
Remaining Performance Obligation, Expected Timing of Satisfaction

Revenue from Contracts with C_4

Revenue from Contracts with Customers (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue	$ 444,188	$ 490,247
Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	158,398	174,823
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	7,541	(11,947)
Revenue	165,939	162,876
Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	72,220	77,069
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0
Revenue	72,220	77,069
Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	34,788	29,690
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0
Revenue	34,788	29,690
Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	193,965	223,185
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	2,860	(528)
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0
Revenue	196,825	222,657
All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	35,228	50,294
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	(816)	3,125
Revenue	34,412	53,419
Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(59,996)	(55,464)
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	0	0
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	0	0
Revenue	(59,996)	(55,464)
Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	434,603	499,597
Alternative Revenue Programs Outside Scope of Authoritative Guidance on Revenue Recognition	2,860	(528)
Derivative Financial Instruments Outside Scope of Authoritative Guidance on Revenue Recognition	6,725	(8,822)
Revenue	444,188	490,247
Production of Natural Gas [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	119,874	135,911
Production of Natural Gas [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Natural Gas [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Natural Gas [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Natural Gas [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Natural Gas [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Natural Gas [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	119,874	135,911
Production of Crude Oil [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	37,664	37,555
Production of Crude Oil [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Crude Oil [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Crude Oil [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Crude Oil [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Crude Oil [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Production of Crude Oil [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	37,664	37,555
Natural Gas Processing [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	688	975
Natural Gas Processing [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Processing [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Processing [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Processing [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Processing [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Processing [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	688	975
Natural Gas Gathering Services [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Gathering Services [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Gathering Services [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	34,788	29,690
Natural Gas Gathering Services [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Gathering Services [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Gathering Services [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(34,788)	(29,690)
Natural Gas Gathering Services [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Transportation Service [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Transportation Service [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	53,452	56,135
Natural Gas Transportation Service [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Transportation Service [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	32,808	35,631
Natural Gas Transportation Service [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Transportation Service [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(16,986)	(17,065)
Natural Gas Transportation Service [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	69,274	74,701
Natural Gas Storage Service [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Storage Service [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	18,426	18,929
Natural Gas Storage Service [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Storage Service [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Storage Service [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Storage Service [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(7,993)	(7,973)
Natural Gas Storage Service [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	10,433	10,956
Natural Gas Residential Sales [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Residential Sales [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Residential Sales [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Residential Sales [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	144,370	166,867
Natural Gas Residential Sales [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Residential Sales [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Residential Sales [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	144,370	166,867
Natural Gas Commercial Sales [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Commercial Sales [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Commercial Sales [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Commercial Sales [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	18,841	22,047
Natural Gas Commercial Sales [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Commercial Sales [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Commercial Sales [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	18,841	22,047
Natural Gas Industrial Sales [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Industrial Sales [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Industrial Sales [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Industrial Sales [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,270	1,501
Natural Gas Industrial Sales [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Industrial Sales [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Industrial Sales [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,270	1,501
Natural Gas Marketing [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Marketing [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Marketing [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Marketing [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Natural Gas Marketing [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	34,108	49,287
Natural Gas Marketing [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(177)	(332)
Natural Gas Marketing [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	33,931	48,955
Other [Member] | Exploration And Production [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	172	382
Other [Member] | Pipeline And Storage [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	342	2,005
Other [Member] | Gathering [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0
Other [Member] | Utility [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(3,324)	(2,861)
Other [Member] | All Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,120	1,007
Other [Member] | Corporate And Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	(52)	(404)
Other [Member] | Total Consolidated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ (1,742)	$ 129

Leases (Narrative) (Details)

Leases (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Oct. 01, 2019
Lessee, Lease, Description [Line Items]
Right of Use Asset in Exchange for New Lease Liability	$ 0
Weighted Average Remaining Lease Term	8 years 8 months 12 days
Weighted Average Discount Rate	3.49%
Cash Paid for Operating Liabilities	$ 1,100
Buildings and Property [Member] | Minimum [Member]
Lessee, Lease, Description [Line Items]
Non-Cancelable Lease Term	6 months
Operating Lease Renewal Term	1 year
Buildings and Property [Member] | Maximum [Member]
Lessee, Lease, Description [Line Items]
Non-Cancelable Lease Term	11 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) $ in Thousands	3 Months Ended
	Dec. 31, 2019USD ($)
Lessee, Lease, Description [Line Items]
Operating Lease Expense	$ 974
Variable Lease Expense	134	[1]
Short-Term Lease Expense/Costs	64	[2]
Sublease Income	(80)
Total Lease Expense	1,092
Oil and Natural Gas Properties [Member]
Lessee, Lease, Description [Line Items]
Short-Term Lease Expense/Costs	$ 7,512	[3]
[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	Dec. 31, 2019USD ($)
Deferred Charges [Member]
Lessee, Lease, Description [Line Items]
Operating Lease Asset	$ 18,940
Other Accruals and Current Liabilities [Member]
Lessee, Lease, Description [Line Items]
Operating Lease Liability - Current	3,298
Other Deferred Credits [Member]
Lessee, Lease, Description [Line Items]
Operating Lease Liability - Noncurrent	$ 15,434

Leases (Schedule of Operating L

Leases (Schedule of Operating Lease Liability Maturities) (Details) $ in Thousands	Dec. 31, 2019USD ($)
Leases [Abstract]
2020 (remaining 9 months)	$ 2,575
2021	2,813
2022	2,264
2023	2,270
2024	2,237
Thereafter	9,717
Total Lease Payments	21,876
Less: Interest	(3,144)
Total Lease Liability	$ 18,732

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 ($)	Dec. 31, 2019		Sep. 30, 2019		Dec. 31, 2018	Sep. 30, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hedging collateral deposits	$ 9,666,000	[1]	$ 6,832,000	[1]	$ 2,784,000	$ 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	9,666,000		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	9,700,000		$ 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		Dec. 31, 2019		Sep. 30, 2019		Dec. 31, 2018	Sep. 30, 2018
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Cash Equivalents - Money Market Mutual Funds	[1]	$ 20,924		$ 10,521
Hedging Collateral Deposits		9,666	[1]	6,832	[1]	$ 2,784	$ 3,441
Total Assets	[1]	171,052		169,742
Total Liabilities	[1]	6,282		5,574
Total Net Assets/(Liabilities)	[1]	164,770		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]	5,645		5,094
Over The Counter Swaps - Gas And Oil [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	41,655		50,593
Derivative Liability	[1]	493		188
Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(1,086)		(2,047)
Derivative Liability	[1]	144		292
Balanced Equity Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments	[1]	36,740		40,660
Fixed Income Mutual Fund [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments	[1]	62,220		62,339
Common Stock - Financial Services Industry [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Other Investments	[1]	933		844
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Cash Equivalents - Money Market Mutual Funds		20,924		10,521
Hedging Collateral Deposits		9,666		6,832
Total Assets		132,579		123,251
Total Liabilities		7,741		7,149
Total Net Assets/(Liabilities)		124,838		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		2,096		2,055
Derivative Liability		7,741		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] | 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		36,740		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		62,220		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		933		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		46,804		52,081
Total Liabilities		6,872		4,015
Total Net Assets/(Liabilities)		39,932		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		46,686		52,076
Derivative Liability		5,524		1,671
Fair Value, Inputs, Level 2 [Member] | Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset		118		5
Derivative Liability		1,348		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] | 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]	(8,331)		(5,590)
Total Liabilities	[1]	(8,331)		(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]	(2,096)		(2,055)
Derivative Liability	[1]	(2,096)		(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]	(5,031)		(1,483)
Derivative Liability	[1]	(5,031)		(1,483)
Netting Adjustments [Member] | Foreign Currency Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivative Asset	[1]	(1,204)		(2,052)
Derivative Liability	[1]	(1,204)		(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
	Dec. 31, 2019USD ($)counterpartyMMcfbbl		Dec. 31, 2018USD ($)	Sep. 30, 2019USD ($)	[1]	Sep. 30, 2018USD ($)
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)			$ 6,500
Net hedging gains (losses) in accumulated other comprehensive income (loss)	$ 41,800
After tax net hedging gains (losses) in accumulated other comprehensive income (loss)	30,700
Pre-Tax Net Hedging Gains (Losses) Reclassified Within Twelve Months	39,100
After Tax Net Hedging Gains (Losses) Reclassified Within Twelve Months	28,700
Fair market value of derivative asset with a credit-risk related contingency	31,300
Fair market value of derivative liability with a credit-risk related contingency	600
Hedging collateral deposits	$ 9,666	[1]	$ 2,784	$ 6,832		$ 3,441
Cash Flow and Fair Value Commodity Hedges [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Hedge Duration	5 years
Over the Counter Swaps 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
Number of counterparties in net gain position | counterparty	12
Credit risk exposure per counterparty	$ 3,400
Maximum credit risk exposure per counterparty	6,900
Collateral Received by the Company	0
Hedging collateral deposits	$ 0
Withdrawal of Storage Gas Mmcf [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk fair value hedge derivatives, natural gas | MMcf	200
Fair Value Hedges MMCf [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Nonmonetary notional amount of price risk fair value hedge derivatives, natural gas | MMcf	23,500
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	23,300
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	88,100
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	2,700
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	2,376,000
Exchange Traded Futures Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Hedging collateral deposits	$ 9,700
Foreign Currency Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Notional Amount	$ 77,300
Credit Risk Related Contingency Feature [Member] | Over the Counter Swaps and Foreign Currency Forward Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Number of counterparties with a common credit-risk related contingency | counterparty	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	Dec. 31, 2019	Sep. 30, 2019
Financial Instruments, Owned, at Fair Value [Abstract]
Carrying Amount	$ 2,134,339	$ 2,133,718
Fair Value	$ 2,253,232	$ 2,257,085

Financial Investments (Other In

Financial Investments (Other Investments) (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Sep. 30, 2019
Investment Holdings [Line Items]
Life Insurance Contracts	$ 41,336	$ 41,074
Other Investments	141,229	144,917
Equity Mutual Fund [Member]
Investment Holdings [Line Items]
Fair Value	36,740	40,660
Fixed Income Mutual Fund [Member]
Investment Holdings [Line Items]
Fair Value	62,220	62,339
Marketable Equity Securities [Member]
Investment Holdings [Line Items]
Fair Value	$ 933	$ 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
	Dec. 31, 2019	Dec. 31, 2018
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)	$ 495
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)		$ 44,518
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	7,352
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income		(20,517)
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)	919
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)		(4,255)
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	(191)
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income		(1,093)
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)	(1,555)
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)		50,052
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	7,541
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income		(18,522)
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)	1,131
Amount of Derivative Gain or (Loss) Recognized in Other Comprehensive Income (Loss) on the Consolidated Statement of Comprehensive Income (Loss)		(1,279)
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income	$ 2
Amount of Derivative Gain or (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) on the Consolidated Balance Sheet into the Consolidated Statement of Income		$ (902)

Financial Instruments (Schedu_2

Financial Instruments (Schedule Of Derivatives And Hedged Items In Fair Value Hedging Relationships) (Details) $ in Thousands	3 Months Ended
	Dec. 31, 2019USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain or (Loss) on Derivative Recognized in the Consolidated Statement of Income	$ (732)
Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income	732
Operating Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain or (Loss) on Derivative Recognized in the Consolidated Statement of Income	(732)
Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income	732
Purchased Gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain or (Loss) on Derivative Recognized in the Consolidated Statement of Income	0
Amount of Gain or (Loss) on the Hedged Item Recognized in the Consolidated Statement of Income	$ 0

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Jan. 31, 2020
Income Taxes [Line Items]
Effective Tax Rate	26.60%	18.20%
Reversal of Estimate for Potential Sequestration of AMT Credit Refunds			$ 5,000
Reduction to Income Tax Expense Due to Remeasurement of Deferred Income Tax Assets and Liabilities				$ 5,000
Alternative Minimum Tax Credit [Member]
Income Taxes [Line Items]
Tax Credit Carryforwards				$ 85,000
Subsequent Event [Member]
Income Taxes [Line Items]
AMT Credit Refund Received					$ 42,500
Federal [Member] | Other Noncurrent Assets [Member]
Income Taxes [Line Items]
Income Taxes Receivable	$ 21,273	$ 42,100	$ 0

Capitalization (Narrative) (Det

Capitalization (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Sep. 30, 2019
Debt Instrument [Line Items]
Shares tendered	91,120
Current Portion of Long-Term Debt	$ 0	$ 0
Restricted Stock Units [Member]
Debt Instrument [Line Items]
Common stock issued	86,635
Performance Shares [Member]
Debt Instrument [Line Items]
Common stock issued	231,246
Board Of Directors [Member]
Debt Instrument [Line Items]
Common stock issued	9,480

Capitalization and Short-Term B

Capitalization and Short-Term Borrowings (Summary of Changes in Common Stock Equity) (Details) - USD ($) $ in Thousands		3 Months Ended
		Dec. 31, 2019	Dec. 31, 2018
Schedule of Capitalization, Equity [Line Items]
Beginning balance (shares)		86,315,287
Beginning balance		$ 832,264
Balance at Beginning of Period		1,272,601	$ 1,098,900
Balance at Beginning of Period		(52,155)	(67,750)
Net Income Available for Common Stock		86,591	102,660
Dividends Declared on Common Stock		(37,650)	(36,663)
Other Comprehensive Income (Loss), Net of Tax		$ (3,995)	39,060
Ending balance (shares)		86,551,528
Ending balance		$ 831,146
Balance at December 31		1,320,592	1,172,334
Balance at End of Period		(56,150)	(28,690)
Paid-in Capital [Member]
Schedule of Capitalization, Equity [Line Items]
Beginning balance		832,264	820,223
Share-Based Payment Expense	[1]	2,828	4,917
Common Stock Repurchased under Stock and Benefit Plans		(3,946)	(8,064)
Ending balance		831,146	817,076
Earnings Reinvested in The Business [Member]
Schedule of Capitalization, Equity [Line Items]
Balance at Beginning of Period		1,272,601	1,098,900
Net Income Available for Common Stock		86,591	102,660
Dividends Declared on Common Stock		(37,650)	(36,663)
Balance at December 31		1,320,592	1,172,334
Accumulated Other Comprehensive Income (Loss) [Member]
Schedule of Capitalization, Equity [Line Items]
Balance at Beginning of Period		(52,155)	(67,750)
Other Comprehensive Income (Loss), Net of Tax		(3,995)	39,060
Balance at End of Period		$ (56,150)	$ (28,690)
Common Stock [Member]
Schedule of Capitalization, Equity [Line Items]
Beginning balance (shares)		86,315,000	85,957,000
Beginning balance (value)		$ 86,315	$ 85,957
Common Stock Issued Under Stock and Benefit Plans (Shares)		237,000	314,000
Common Stock Issued Under Stock and Benefit Plans (Value)		$ 237	$ 314
Ending balance (shares)		86,552,000	86,271,000
Ending balance (value)		$ 86,552	$ 86,271
Guidance for Hedging [Member]
Schedule of Capitalization, Equity [Line Items]
Cumulative Effect of Adoption of Authoritative Guidance		(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)
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
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
[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	3 Months Ended
	Dec. 31, 2019USD ($)
Site Contingency [Line Items]
Estimated minimum liability for environmental remediation	$ 6.9
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)	3 Months Ended
	Dec. 31, 2019segment
Segment Reporting [Abstract]
Number of reportable segments	4

Business Segment Information (F

Business Segment Information (Financial Segment Information By Segment) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Sep. 30, 2019
Segment Reporting Information [Line Items]
Revenue	$ 444,188	$ 490,247
Segment Profit: Net Income (Loss)	86,591	102,660
Segment Assets	6,702,658		$ 6,462,157
Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	444,188	490,247
Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	0	0
Exploration And Production [Member]
Segment Reporting Information [Line Items]
Revenue	165,939	162,876
Segment Profit: Net Income (Loss)	23,977	38,214
Segment Assets	2,059,681		1,972,776
Exploration And Production [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	165,939	162,876
Exploration And Production [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	0	0
Pipeline And Storage [Member]
Segment Reporting Information [Line Items]
Revenue	72,220	77,069
Segment Profit: Net Income (Loss)	18,105	25,102
Segment Assets	1,926,766		1,893,514
Pipeline And Storage [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	48,969	54,218
Pipeline And Storage [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	23,251	22,851
Gathering [Member]
Segment Reporting Information [Line Items]
Revenue	34,788	29,690
Segment Profit: Net Income (Loss)	15,944	14,183
Segment Assets	559,064		547,995
Gathering [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	0	0
Gathering [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	34,788	29,690
Utility [Member]
Segment Reporting Information [Line Items]
Revenue	196,825	222,657
Segment Profit: Net Income (Loss)	26,583	25,649
Segment Assets	2,043,246		1,991,338
Utility [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	194,910	220,012
Utility [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	1,915	2,645
Total Reportable Segments [Member]
Segment Reporting Information [Line Items]
Segment Profit: Net Income (Loss)	84,609	103,148
Segment Assets	6,588,757		6,405,623
Total Reportable Segments [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	409,818	437,106
Total Reportable Segments [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	59,954	55,186
All Other [Member]
Segment Reporting Information [Line Items]
Revenue	34,412	53,419
Segment Profit: Net Income (Loss)	371	82
Segment Assets	143,890		122,241
All Other [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	34,235	53,087
All Other [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	177	332
Corporate And Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue	(59,996)	(55,464)
Segment Profit: Net Income (Loss)	1,611	(570)
Segment Assets	(29,989)		$ (65,707)
Corporate And Intersegment Eliminations [Member] | Revenue from External Customers [Member]
Segment Reporting Information [Line Items]
Revenue	135	54
Corporate And Intersegment Eliminations [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenue	$ (60,131)	$ (55,518)

Retirement Plan And Other Pos_3

Retirement Plan And Other Post-Retirement Benefits (Narrative) (Details) $ in Millions	3 Months Ended
	Dec. 31, 2019USD ($)
Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Company's contributions	$ 7.8
VEBA Trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Company's contributions	0.7
Minimum [Member] | Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	17
Minimum [Member] | VEBA Trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	2
Maximum [Member] | Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	22
Maximum [Member] | VEBA Trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Estimated future contributions in remainder of fiscal year	$ 2.5

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
		Dec. 31, 2019	Dec. 31, 2018
Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service Cost		$ 2,330	$ 2,120
Interest Cost		7,483	9,594
Expected Return on Plan Assets		(15,016)	(15,591)
Amortization of Prior Service Cost (Credit)		182	206
Amortization of Losses		9,846	8,024
Net Amortization and Deferral For Regulatory Purposes (Including Volumetric Adjustments)	[1]	1,527	819
Net Periodic Benefit Cost		6,352	5,172
Other Post-Retirement Benefit Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service Cost		402	380
Interest Cost		3,228	4,286
Expected Return on Plan Assets		(7,308)	(7,539)
Amortization of Prior Service Cost (Credit)		(107)	(107)
Amortization of Losses		134	1,490
Net Amortization and Deferral For Regulatory Purposes (Including Volumetric Adjustments)	[1]	6,249	3,971
Net Periodic Benefit Cost		$ 2,598	$ 2,481
[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	3 Months Ended
	Dec. 31, 2019USD ($)
Regulatory Matters [Line Items]
Approved Return on Equity	8.70%
Supply Corporation [Member]
Regulatory Matters [Line Items]
Proposed Annual Cost of Service	$ 295.4
Proposed Rate Base	$ 970.8
Proposed Return on Equity	15.00%