Supplementary Information For Oil And Gas Producing Activities (Tables)

12 Months Ended

Sep. 30, 2016

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
	2016		2015
	(Thousands)
Proved Properties(1)	$	4,554,929	$	4,473,721
Unproved Properties	135,285		176,327
	4,690,214		4,650,048
Less — Accumulated Depreciation, Depletion and Amortization	3,657,239		2,572,348
	$	1,032,975	$	2,077,700

(1) Includes asset retirement costs of $63.6 million and $113.3 million at September 30, 2016 and 2015, respectively.

Summary Of Capitalized Costs Of Unproved Properties Excluded From Amortization

Following is a summary of costs excluded from amortization at September 30, 2016:

	Total as of September 30, 2016		Year Costs Incurred
			2016		2015		2014		Prior
	(Thousands)
Acquisition Costs	$	55,193	$	—	$	—	$	7,057	$	48,136
Development Costs	52,780		40,597		7,911		1,436		2,836
Exploration Costs	26,822		17,340		9,482		—		—
Capitalized Interest	490		339		151		—		—
	$	135,285	$	58,276	$	17,544	$	8,493	$	50,972

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
	2016			2015		2014
	(Thousands)
United States
Property Acquisition Costs:
Proved	$	1,342		$	1,767	$	18,213
Unproved	2,165			19,998		7,884
Exploration Costs(1)	27,561			53,222		71,850
Development Costs(2)	219,386			454,605		490,164
Asset Retirement Costs	(49,653		)	37,595		(4,946		)
	$	200,801		$	567,187	$	583,165

(1) Amounts for 2016, 2015 and 2014 include capitalized interest of $0.3 million, $0.4 million and $0.7 million, respectively.

(2) Amounts for 2016, 2015 and 2014 include capitalized interest of $0.2 million, $0.5 million and $0.7 million, respectively.

Results Of Operations For Producing Activities

Results of Operations for Producing Activities

	Year Ended September 30
	2016			2015			2014
United States	(Thousands, except per Mcfe amounts)
Operating Revenues:
Natural Gas (includes revenues from sales to affiliates of $2 (2016) and $1 (2015 and 2014) and transfers to operations of $1,765, $1,946 and $2,145, respectively)	$	282,619		$	350,673		$	515,080
Oil, Condensate and Other Liquids	103,533			156,048			298,179
Total Operating Revenues(1)	386,152			506,721			813,259
Production/Lifting Costs	153,914			167,800			165,534
Franchise/Ad Valorem Taxes	13,794			20,167			20,765
Purchased Emission Allowance Expense	700			3,089			—
Accretion Expense	6,663			6,186			6,192
Depreciation, Depletion and Amortization ($0.85, $1.49 and $1.82 per Mcfe of production)	136,579			234,480			291,651
Impairment of Oil and Gas Producing Properties	948,307			1,126,257			—
Income Tax Expense (Benefit)	(368,940		)	(444,393		)	140,484
Results of Operations for Producing Activities (excluding corporate overheads and interest charges)	$	(504,865	)	$	(606,865	)	$	188,633

(1) 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, 2013	1,238,738			60,777		1,299,515
Extensions and Discoveries	446,821		(1)	—		446,821
Revisions of Previous Estimates	43,690			1,358		45,048
Production	(139,097	)	(2)	(3,210	)	(142,307	)
Purchases of Minerals in Place	33,986			—		33,986
Sale of Minerals in Place	(76	)		(103	)	(179	)
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
Proved Developed Reserves:
September 30, 2013	807,055			59,862		866,917
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
Proved Undeveloped Reserves:
September 30, 2013	431,683			915		432,598
September 30, 2014	504,161			915		505,076
September 30, 2015	825,284			—		825,284
September 30, 2016	541,959			—		541,959

(1) Extensions and discoveries include 442 Bcf (during 2014), 598 Bcf (during 2015) and 179 Bcf (during 2016), of Marcellus Shale gas in the Appalachian Region.

(2) Production includes 131,590 MMcf (during 2014), 130,291 MMcf (during 2015) and 135,598 MMcf (during 2016), 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, 2013	283		41,315		41,598
Extensions and Discoveries	18		1,521		1,539
Revisions of Previous Estimates	(17	)	(1,677	)	(1,694	)
Production	(31	)	(3,005	)	(3,036	)
Purchases of Minerals in Place	—		83		83
Sales of Minerals in Place	—		(13	)	(13	)
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
Proved Developed Reserves:
September 30, 2013	283		38,082		38,365
September 30, 2014	253		37,002		37,255
September 30, 2015	220		33,150		33,370
September 30, 2016	73		28,698		28,771
Proved Undeveloped Reserves:
September 30, 2013	—		3,233		3,233
September 30, 2014	—		1,222		1,222
September 30, 2015	—		352		352
September 30, 2016	—		238		238

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

	Year Ended September 30
	2016		2015		2014
	(Thousands)
United States
Future Cash Inflows	$	3,768,463	$	6,916,775	$	10,001,545
Less:
Future Production Costs	1,994,916		2,854,142		2,795,657
Future Development Costs	375,152		761,922		790,033
Future Income Tax Expense at Applicable Statutory Rate	303,397		1,117,433		2,434,370
Future Net Cash Flows	1,094,998		2,183,278		3,981,485
Less:
10% Annual Discount for Estimated Timing of Cash Flows	452,470		860,244		1,914,607
Standardized Measure of Discounted Future Net Cash Flows	$	642,528	$	1,323,034	$	2,066,878

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
	2016			2015			2014
	(Thousands)
United States
Standardized Measure of Discounted Future
Net Cash Flows at Beginning of Year	$	1,323,034		$	2,066,878		$	1,966,366
Sales, Net of Production Costs	(218,444		)	(318,753		)	(626,960		)
Net Changes in Prices, Net of Production Costs	(1,066,593		)	(1,752,843		)	(38,723		)
Extensions and Discoveries	47,742			266,159			381,008
Changes in Estimated Future Development Costs	143,752			164,510			68,731
Purchases of Minerals in Place	—			—			34,705
Sales of Minerals in Place	(95,849		)	(1		)	(691		)
Previously Estimated Development Costs Incurred	92,840			161,833			179,502
Net Change in Income Taxes at Applicable Statutory Rate	387,739			545,442			(231,807		)
Revisions of Previous Quantity Estimates	6,202			(16,573		)	55,184
Accretion of Discount and Other	22,105			206,382			279,563
Standardized Measure of Discounted Future Net Cash Flows at End of Year	$	642,528		$	1,323,034		$	2,066,878