Supplementary Information For Oil And Gas Producing Activities (Tables)

12 Months Ended

Sep. 30, 2017

Supplementary Information For Oil And Gas Producing Activities Unaudited [Abstract]

Capitalized Costs Relating To Oil And Gas Producing Activities

Capitalized Costs Relating to Oil and Gas Producing Activities

	At September 30
	2017		2016
	(Thousands)
Proved Properties(1)	$	4,832,301	$	4,554,929
Unproved Properties	80,932		135,285
	4,913,233		4,690,214
Less — Accumulated Depreciation, Depletion and Amortization	3,765,710		3,657,239
	$	1,147,523	$	1,032,975

(1) Includes asset retirement costs of $54.4 million and $63.6 million at September 30, 2017 and 2016, respectively.

Summary Of Capitalized Costs Of Unproved Properties Excluded From Amortization

Following is a summary of costs excluded from amortization at September 30, 2017:

	Total as of September 30, 2017		Year Costs Incurred
			2017		2016		2015		Prior
	(Thousands)
Acquisition Costs	$	55,193	$	—	$	—	$	—	$	55,193
Development Costs	11,879		4,388		6,707		416		368
Exploration Costs	13,388		2,376		7,593		3,419		—
Capitalized Interest	472		235		149		88		—
	$	80,932	$	6,999	$	14,449	$	3,923	$	55,561

Costs Incurred In Oil And Gas Property Acquisition, Exploration And Development Activities

Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities

	Year Ended September 30
	2017			2016			2015
	(Thousands)
United States
Property Acquisition Costs:
Proved	$	8,908		$	1,342		$	1,767
Unproved	262			2,165			19,998
Exploration Costs(1)	40,975			27,561			53,222
Development Costs(2)	200,639			219,386			454,605
Asset Retirement Costs	(9,175		)	(49,653		)	37,595
	$	241,609		$	200,801		$	567,187

(1) Amounts for 2017, 2016 and 2015 include capitalized interest of $0.3 million, $0.3 million and $0.4 million, respectively.

(2) Amounts for 2017, 2016 and 2015 include capitalized interest of $0.2 million, $0.2 million and $0.5 million, respectively.

Results Of Operations For Producing Activities

Results of Operations for Producing Activities

	Year Ended September 30
	2017		2016			2015
United States	(Thousands, except per Mcfe amounts)
Operating Revenues:
Natural Gas (includes transfers to operations of $2,357, $1,765 and $1,946, respectively)(1)	$	399,975	$	282,619		$	350,673
Oil, Condensate and Other Liquids	126,517		103,533			156,048
Total Operating Revenues(2)	526,492		386,152			506,721
Production/Lifting Costs	165,991		153,914			167,800
Franchise/Ad Valorem Taxes	15,372		13,794			20,167
Purchased Emission Allowance Expense	1,391		700			3,089
Accretion Expense	4,896		6,663			6,186
Depreciation, Depletion and Amortization ($0.63, $0.85 and $1.49 per Mcfe of production, respectively)	108,471		136,579			234,480
Impairment of Oil and Gas Producing Properties	—		948,307			1,126,257
Income Tax Expense (Benefit)	86,657		(368,940		)	(444,393		)
Results of Operations for Producing Activities (excluding corporate overheads and interest charges)	$	143,714	$	(504,865	)	$	(606,865	)

(1) There were no revenues from sales to affiliates for all years presented.

(2) Exclusive of hedging gains and losses. See further discussion in Note G — Financial Instruments.

Proved Developed And Undeveloped Oil And Gas Reserve Quantities

	Gas MMcf
	U. S.
	Appalachian Region			West Coast Region		Total Company
Proved Developed and Undeveloped Reserves:
September 30, 2014	1,624,062			58,822		1,682,884
Extensions and Discoveries	633,360		(1)	—		633,360
Revisions of Previous Estimates	(28,124	)		(6,317	)	(34,441	)
Production	(136,404	)	(2)	(3,159	)	(139,563	)
Sale of Minerals in Place	(112	)		—		(112	)
September 30, 2015	2,092,782			49,346		2,142,128
Extensions and Discoveries	185,347		(1)	—		185,347
Revisions of Previous Estimates	(245,029	)		(3,132	)	(248,161	)
Production	(140,457	)	(2)	(3,090	)	(143,547	)
Sale of Minerals in Place	(261,192	)		—		(261,192	)
September 30, 2016	1,631,451			43,124		1,674,575
Extensions and Discoveries	386,649		(1)	8		386,657
Revisions of Previous Estimates	84,480			6,369		90,849
Production	(154,093	)	(2)	(2,995	)	(157,088	)
Sale of Minerals in Place	(21,873	)		—		(21,873	)
September 30, 2017	1,926,614			46,506		1,973,120
Proved Developed Reserves:
September 30, 2014	1,119,901			57,907		1,177,808
September 30, 2015	1,267,498			49,346		1,316,844
September 30, 2016	1,089,492			43,124		1,132,616
September 30, 2017	1,316,596			46,506		1,363,102
Proved Undeveloped Reserves:
September 30, 2014	504,161			915		505,076
September 30, 2015	825,284			—		825,284
September 30, 2016	541,959			—		541,959
September 30, 2017	610,018			—		610,018

(1) Extensions and discoveries include 598 Bcf (during 2015), 179 Bcf (during 2016) and 181 Bcf (during 2017), of Marcellus Shale gas in the Appalachian region.

(2) Production includes 130,291 MMcf (during 2015), 135,598 MMcf (during 2016) and 145,452 MMcf (during 2017), from Marcellus Shale fields (which exceed 15% of total reserves).

	Oil Mbbl
	U. S.
	Appalachian Region		West Coast Region		Total Company
Proved Developed and Undeveloped Reserves:
September 30, 2014	253		38,224		38,477
Extensions and Discoveries	—		533		533
Revisions of Previous Estimates	(3	)	(2,251	)	(2,254	)
Production	(30	)	(3,004	)	(3,034	)
September 30, 2015	220		33,502		33,722
Extensions and Discoveries	—		530		530
Revisions of Previous Estimates	(46	)	(2,201	)	(2,247	)
Production	(28	)	(2,895	)	(2,923	)
Sales of Minerals in Place	(73	)	—		(73	)
September 30, 2016	73		28,936		29,009
Extensions and Discoveries	—		674		674
Revisions of Previous Estimates	(12	)	3,305		3,293
Production	(4	)	(2,736	)	(2,740	)
Sales of Minerals in Place	(29	)	—		(29	)
September 30, 2017	28		30,179		30,207
Proved Developed Reserves:
September 30, 2014	253		37,002		37,255
September 30, 2015	220		33,150		33,370
September 30, 2016	73		28,698		28,771
September 30, 2017	28		29,771		29,799
Proved Undeveloped Reserves:
September 30, 2014	—		1,222		1,222
September 30, 2015	—		352		352
September 30, 2016	—		238		238
September 30, 2017	—		408		408

Standardized Measure Of Discounted Future Net Cash Flows Relating To Proved Oil And Gas Reserves

	Year Ended September 30
	2017		2016		2015
	(Thousands)
United States
Future Cash Inflows	$	6,144,317	$	3,768,463	$	6,916,775
Less:
Future Production Costs	2,378,262		1,994,916		2,854,142
Future Development Costs	411,578		375,152		761,922
Future Income Tax Expense at Applicable Statutory Rate	1,160,469		303,397		1,117,433
Future Net Cash Flows	2,194,008		1,094,998		2,183,278
Less:
10% Annual Discount for Estimated Timing of Cash Flows	1,080,962		452,470		860,244
Standardized Measure of Discounted Future Net Cash Flows	$	1,113,046	$	642,528	$	1,323,034

Principal Sources Of Change In The Standardized Measure Of Discounted Future Net Cash Flows

The principal sources of change in the standardized measure of discounted future net cash flows were as follows:

	Year Ended September 30
	2017			2016			2015
	(Thousands)
United States
Standardized Measure of Discounted Future
Net Cash Flows at Beginning of Year	$	642,528		$	1,323,034		$	2,066,878
Sales, Net of Production Costs	(345,075		)	(218,444		)	(318,753		)
Net Changes in Prices, Net of Production Costs	828,187			(1,066,593		)	(1,752,843		)
Extensions and Discoveries	170,500			47,742			266,159
Changes in Estimated Future Development Costs	8,816			143,752			164,510
Sales of Minerals in Place	(9,849		)	(95,849		)	(1		)
Previously Estimated Development Costs Incurred	101,134			92,840			161,833
Net Change in Income Taxes at Applicable Statutory Rate	(393,353		)	387,739			545,442
Revisions of Previous Quantity Estimates	39,078			6,202			(16,573		)
Accretion of Discount and Other	71,080			22,105			206,382
Standardized Measure of Discounted Future Net Cash Flows at End of Year	$	1,113,046		$	642,528		$	1,323,034