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Supplementary Information For Oil And Gas Producing Activities (Tables)
12 Months Ended
Sep. 30, 2014
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
 
2014
 
2013
 
(Thousands)
Proved Properties(1)
$
3,941,143

 
$
3,393,612

Unproved Properties
141,719

 
106,085

 
4,082,862

 
3,499,697

Less — Accumulated Depreciation, Depletion and Amortization
1,211,610

 
919,989

 
$
2,871,252

 
$
2,579,708

 
(1)
Includes asset retirement costs of $75.7 million and $80.6 million at September 30, 2014 and 2013, respectively.
Summary Of Capitalized Costs Of Unproved Properties Excluded From Amortization
Following is a summary of costs excluded from amortization at September 30, 2014:
 
 
Total
as of
September 30,
2014
 
Year Costs Incurred
 
 
2014
 
2013
 
2012
 
Prior
 
(Thousands)
Acquisition Costs
$
61,712

 
$
7,057

 
$
905

 
$
5,585

 
$
48,165

Development Costs
42,362

 
39,339

 
677

 
1,405

 
941

Exploration Costs
36,882

 
36,882

 

 

 

Capitalized Interest
763

 
763

 

 

 

 
$
141,719

 
$
84,041

 
$
1,582

 
$
6,990

 
$
49,106

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
 
2014
 
2013
 
2012
 
(Thousands)
United States
 
Property Acquisition Costs:
 
 
 
 
 
Proved
$
18,213

 
$
7,575

 
$
13,095

Unproved
7,884

 
9,274

 
13,867

Exploration Costs(1)
71,850

 
49,483

 
84,624

Development Costs(2)
490,164

 
460,554

 
576,397

Asset Retirement Costs
(4,946
)
 
37,546

 
10,344

 
$
583,165

 
$
564,432

 
$
698,327

 
(1)
Amounts for 2014, 2013 and 2012 include capitalized interest of $0.7 million, $0.4 million and $1.0 million, respectively.
(2)
Amounts for 2014, 2013 and 2012 include capitalized interest of $0.7 million, $0.7 million and $2.0 million, respectively.
Results Of Operations For Producing Activities
Results of Operations for Producing Activities
 
Year Ended September 30
 
2014
 
2013
 
2012
 
(Thousands, except per Mcfe amounts)
United States
 
 
 
 
 
Operating Revenues:
 
 
 
 
 
Natural Gas (includes revenues from sales to affiliates of $1 for all years presented and transfers to operations of $2,145, $612 and $0, respectively)
$
515,080

 
$
371,311

 
$
181,544

Oil, Condensate and Other Liquids
298,179

 
291,762

 
307,018

Total Operating Revenues(1)
813,259

 
663,073

 
488,562

Production/Lifting Costs
165,534

 
119,243

 
83,361

Franchise/Ad Valorem Taxes
20,765

 
17,200

 
23,620

Accretion Expense
6,192

 
3,929

 
3,084

Depreciation, Depletion and Amortization ($1.82, $1.98 and $2.19 per Mcfe of production)
291,651

 
238,467

 
182,759

Income Tax Expense
140,484

 
120,431

 
81,904

Results of Operations for Producing Activities (excluding corporate overheads and interest charges)
$
188,633

 
$
163,803

 
$
113,834

 
(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, 2011
606,606

  
68,316

 
674,922

Extensions and Discoveries
435,460

(1)
638

 
436,098

Revisions of Previous Estimates
(53,992
)
 
(2,463
)
 
(56,455
)
Production
(62,663
)
(2)
(3,468
)
 
(66,131
)
September 30, 2012
925,411

  
63,023

 
988,434

Extensions and Discoveries
360,922

(1)
702

 
361,624

Revisions of Previous Estimates
53,038

  
112

 
53,150

Production
(100,633
)
(2)
(3,060
)
 
(103,693
)
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

Proved Developed Reserves:
 
 
 
 


September 30, 2011
350,458

  
63,965

 
414,423

September 30, 2012
544,560

  
59,923

 
604,483

September 30, 2013
807,055

  
59,862

 
866,917

September 30, 2014
1,119,901

  
57,907

 
1,177,808

Proved Undeveloped Reserves:
 
 
 
 


September 30, 2011
256,148

  
4,351

 
260,499

September 30, 2012
380,851

  
3,100

 
383,951

September 30, 2013
431,683

  
915

 
432,598

September 30, 2014
504,161

  
915

 
505,076

 
(1)
Extensions and discoveries include 435 Bcf (during 2012), 355 Bcf (during 2013) and 442 Bcf (during 2014), of Marcellus Shale gas in the Appalachian Region.
(2)
Production includes 55,812 MMcf (during 2012), 93,999 MMcf (during 2013) and 131,590 MMcf (during 2014), 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, 2011
279

 
43,066

 
43,345

Extensions and Discoveries
28

 
1,229

 
1,257

Revisions of Previous Estimates
35

 
1,095

 
1,130

Production
(36
)
 
(2,834
)
 
(2,870
)
September 30, 2012
306

 
42,556

 
42,862

Extensions and Discoveries

 
2,443

 
2,443

Revisions of Previous Estimates
5

 
(881
)
 
(876
)
Production
(28
)
 
(2,803
)
 
(2,831
)
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

Proved Developed Reserves:
 
 
 
 

September 30, 2011
274

 
37,306

 
37,580

September 30, 2012
306

 
38,138

 
38,444

September 30, 2013
283

 
38,082

 
38,365

September 30, 2014
253

 
37,002

 
37,255

Proved Undeveloped Reserves:
 
 
 
 


September 30, 2011
5

 
5,760

 
5,765

September 30, 2012

 
4,418

 
4,418

September 30, 2013

 
3,233

 
3,233

September 30, 2014

 
1,222

 
1,222

Standardized Measure Of Discounted Future Net Cash Flows Relating To Proved Oil And Gas Reserves
 
Year Ended September 30
 
2014
 
2013
 
2012
 
(Thousands)
United States
 
 
 
 
 
Future Cash Inflows
$
10,001,545

 
$
8,943,942

 
$
7,373,129

Less:
 
 
 
 
 
Future Production Costs
2,795,657

 
2,334,393

 
1,919,530

Future Development Costs
790,033

 
749,876

 
619,573

Future Income Tax Expense at Applicable Statutory Rate
2,434,370

 
2,113,101

 
1,812,055

Future Net Cash Flows
3,981,485

 
3,746,572

 
3,021,971

Less:
 
 
 
 
 
10% Annual Discount for Estimated Timing of Cash Flows
1,914,607

 
1,780,206

 
1,552,180

Standardized Measure of Discounted Future Net Cash Flows
$
2,066,878

 
$
1,966,366

 
$
1,469,791

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
 
2014
 
2013
 
2012
 
(Thousands)
United States
 
 
 
 
 
Standardized Measure of Discounted Future
 
 
 
 
 
Net Cash Flows at Beginning of Year
$
1,966,366

 
$
1,469,791

 
$
1,524,157

Sales, Net of Production Costs
(626,960
)
 
(526,630
)
 
(381,581
)
Net Changes in Prices, Net of Production Costs
(38,723
)
 
339,655

 
(385,019
)
Extensions and Discoveries
381,008

 
390,255

 
224,474

Changes in Estimated Future Development Costs
68,731

 
6,117

 
29,627

Purchases of Minerals in Place
34,705

 

 

Sales of Minerals in Place
(691
)
 

 

Previously Estimated Development Costs Incurred
179,502

 
148,535

 
252,967

Net Change in Income Taxes at Applicable Statutory Rate
(231,807
)
 
(130,574
)
 
(19,280
)
Revisions of Previous Quantity Estimates
55,184

 
34,864

 
103,472

Accretion of Discount and Other
279,563

 
234,353

 
120,974

Standardized Measure of Discounted Future Net Cash Flows at End of Year
$
2,066,878

 
$
1,966,366

 
$
1,469,791