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Supplemental Oil and Natural Gas Data (Unaudited) (Tables) (Linn Energy, LLC [Member])
3 Months Ended 12 Months Ended
Mar. 31, 2013
Dec. 31, 2012
Linn Energy, LLC [Member]
   
Reserve Quantities [Line Items]    
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development  
Costs incurred in oil and natural gas property acquisition, exploration and development, whether capitalized or expensed, are presented below:
 
 
Year Ended December 31,
 
 
2012
 
2011
 
2010
 
 
(in thousands)
Property acquisition costs: (1)
 
 
 
 
 
 
Proved
 
$
2,531,419

 
$
1,328,328

 
$
1,290,826

Unproved
 
181,124

 
188,409

 
65,604

Exploration costs
 
452

 
80

 
74

Development costs
 
1,062,043

 
639,395

 
244,834

Asset retirement costs
 
4,675

 
2,427

 
748

Total costs incurred
 
$
3,779,713

 
$
2,158,639

 
$
1,602,086


(1) 
See Note 2 for details about the Company’s acquisitions.
Capitalized Costs Related to Oil, Natural Gas and NGL Production Activities
Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below:
 
March 31,
2013
 
December 31,
2012
 
(in thousands)
Proved properties:
 
 
 
Leasehold acquisition
$
8,464,014

 
$
8,603,888

Development
2,707,884

 
2,553,127

Unproved properties
374,202

 
454,315

 
11,546,100

 
11,611,330

Less accumulated depletion and amortization
(2,174,273
)
 
(2,025,656
)
 
$
9,371,827

 
$
9,585,674

Aggregate capitalized costs related to oil, natural gas and NGL production activities with applicable accumulated depletion and amortization are presented below:
 
 
December 31,
 
 
2012
 
2011
 
 
(in thousands)
Proved properties:
 
 
 
 
Leasehold acquisition
 
$
8,603,888

 
$
6,040,239

Development
 
2,553,127

 
1,484,486

Unproved properties
 
454,315

 
310,925

 
 
11,611,330

 
7,835,650

Less accumulated depletion and amortization
 
(2,025,656
)
 
(1,033,617
)
 
 
$
9,585,674

 
$
6,802,033

Results of Operations for Oil and Gas Producing Activities  
The results of operations for oil, natural gas and NGL producing activities (excluding corporate overhead and interest costs) are presented below:
 
 
Year Ended December 31,
 
 
2012
 
2011
 
2010
 
 
(in thousands)
Revenues and other:
 
 
 
 
 
 
Oil, natural gas and natural gas liquid sales
 
$
1,601,180

 
$
1,162,037

 
$
690,054

Gains on oil and natural gas derivatives
 
124,762

 
449,940

 
75,211

 
 
1,725,942

 
1,611,977

 
765,265

Production costs:
 
 

 
 

 
 

Lease operating expenses
 
317,699

 
232,619

 
158,382

Transportation expenses
 
77,322

 
28,358

 
19,594

Severance and ad valorem taxes
 
130,805

 
78,458

 
45,114

 
 
525,826

 
339,435

 
223,090

Other costs:
 
 
 
 
 
 
Exploration costs
 
1,915

 
2,390

 
5,168

Depletion and amortization
 
579,382

 
320,096

 
226,552

Impairment of long-lived assets
 
422,499

 

 
38,600

Gains on sale of assets and other, net
 
(1,369
)
 
(1,001
)
 

Texas margin tax (benefit) expense
 
(787
)
 
1,599

 
657

 
 
1,001,640

 
323,084

 
270,977

Results of operations
 
$
198,476

 
$
949,458

 
$
271,198

Estimated Quantities of Oil, Natural Gas and NGL Reserves  
An analysis of the change in estimated quantities of oil, natural gas and NGL reserves, all of which are located within the U.S., is shown below: 
 
 
Year Ended December 31, 2012
 
 
Natural Gas
(Bcf)
 
Oil
(MMBbls)
 
NGL
(MMBbls)
 
Total
(Bcfe)
Proved developed and undeveloped reserves:
 
 
 
 
 
 
 
 
Beginning of year
 
1,675

 
189.0

 
93.5

 
3,370

Revisions of previous estimates
 
(559
)
 
(26.5
)
 
(14.1
)
 
(803
)
Purchase of minerals in place
 
1,176

 
23.1

 
75.3

 
1,766

Extensions, discoveries and other additions
 
407

 
16.6

 
33.7

 
709

Production
 
(128
)
 
(10.7
)
 
(9.0
)
 
(246
)
End of year
 
2,571

 
191.5

 
179.4

 
4,796

Proved developed reserves:
 
 
 
 
 
 
 
 
Beginning of year
 
998

 
124.8

 
47.8

 
2,034

End of year
 
1,661

 
131.4

 
113.0

 
3,127

Proved undeveloped reserves:
 
 
 
 
 
 
 
 
Beginning of year
 
677

 
64.2

 
45.7

 
1,336

End of year
 
910

 
60.1

 
66.4

 
1,669

 
 
Year Ended December 31, 2011
 
 
Natural Gas (Bcf)
 
Oil
(MMBbls)
 
NGL (MMBbls)
 
Total
(Bcfe)
Proved developed and undeveloped reserves:
 
 
 
 
 
 
 
 
Beginning of year
 
1,233

 
156.4

 
70.9

 
2,597

Revisions of previous estimates
 
(71
)
 
(9.2
)
 
0.9

 
(121
)
Purchase of minerals in place
 
337

 
39.3

 
1.0

 
579

Extensions, discoveries and other additions
 
240

 
10.3

 
24.6

 
450

Production
 
(64
)
 
(7.8
)
 
(3.9
)
 
(135
)
End of year
 
1,675

 
189.0

 
93.5

 
3,370

Proved developed reserves:
 
 
 
 
 
 
 
 
Beginning of year
 
805

 
103.0

 
39.9

 
1,662

End of year
 
998

 
124.8

 
47.8

 
2,034

Proved undeveloped reserves:
 
 
 
 
 
 
 
 
Beginning of year
 
428

 
53.4

 
31.0

 
935

End of year
 
677

 
64.2

 
45.7

 
1,336

 
 
Year Ended December 31, 2010
 
 
Natural Gas (Bcf)
 
Oil
(MMBbls)
 
NGL (MMBbls)
 
Total
(Bcfe)
Proved developed and undeveloped reserves:
 
 
 
 
 
 
 
 
Beginning of year
 
774

 
102.1

 
54.2

 
1,712

Revisions of previous estimates
 
22

 
3.9

 
5.2

 
77

Purchase of minerals in place
 
369

 
49.1

 
1.2

 
671

Extensions, discoveries and other additions
 
118

 
6.1

 
13.3

 
234

Production
 
(50
)
 
(4.8
)
 
(3.0
)
 
(97
)
End of year
 
1,233

 
156.4

 
70.9

 
2,597

Proved developed reserves:
 
 
 
 
 
 
 
 
Beginning of year
 
549

 
77.9

 
33.9

 
1,220

End of year
 
805

 
103.0

 
39.9

 
1,662

Proved undeveloped reserves:
 
 
 
 
 
 
 
 
Beginning of year
 
225

 
24.2

 
20.3

 
492

End of year
 
428

 
53.4

 
31.0

 
935

The tables above include changes in estimated quantities of oil and NGL reserves shown in Mcf equivalents at a rate of one barrel per six Mcf.
Standardized Measure of Discounted Future Net Cash Flows and Changes Therein Relating to Proved Reserves  
Information with respect to the standardized measure of discounted future net cash flows relating to proved reserves is summarized below. Future cash inflows are computed by applying applicable prices relating to the Company’s proved reserves to the year-end quantities of those reserves. Future production, development, site restoration and abandonment costs are derived based on current costs assuming continuation of existing economic conditions. There are no future income tax expenses because the Company is not subject to federal income taxes. Limited liability companies are subject to Texas margin tax. Limited liabilities companies were also subject to state income taxes in the state of Michigan during 2011 and 2010; however, these amounts are not material. See Note 14 for additional information about income taxes.
 
 
December 31,
 
 
2012
 
2011
 
2010
 
 
(in thousands)
 
 
 
 
 
 
 
Future estimated revenues
 
$
30,374,380

 
$
29,319,369

 
$
20,160,275

Future estimated production costs
 
(11,460,854
)
 
(9,464,319
)
 
(6,825,147
)
Future estimated development costs
 
(3,574,058
)
 
(2,848,497
)
 
(1,733,929
)
Future net cash flows
 
15,339,468

 
17,006,553

 
11,601,199

10% annual discount for estimated timing of cash flows
 
(9,266,487
)
 
(10,391,693
)
 
(7,377,667
)
Standardized measure of discounted future net cash flows
 
$
6,072,981

 
$
6,614,860

 
$
4,223,532

 
 
 
 
 
 
 
Representative NYMEX prices: (1)
 
 
 
 
 
 
Natural gas (MMBtu)
 
$
2.76

 
$
4.12

 
$
4.38

Oil (Bbl)
 
$
94.64

 
$
95.84

 
$
79.29

(1) 
In accordance with SEC regulations, reserves at December 31, 2012, December 31, 2011, and December 31, 2010, were estimated using the average price during the 12-month period, determined as an unweighted average of the first-day-of-the-month price for each month, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions. The price used to estimate reserves is held constant over the life of the reserves.
Principal Sources of Change in Standardized Measure of Discounted Future Net Cash Flow  
The following summarizes the principal sources of change in the standardized measure of discounted future net cash flows:
 
 
Year Ended December 31,
 
 
2012
 
2011
 
2010
 
 
(in thousands)
Sales and transfers of oil, natural gas and NGL produced during the period
 
$
(1,075,354
)
 
$
(822,602
)
 
$
(466,964
)
Changes in estimated future development costs
 
289,762

 
27,236

 
(56,001
)
Net change in sales and transfer prices and production costs related to future production
 
(1,463,820
)
 
784,308

 
886,438

Purchase of minerals in place
 
2,153,651

 
1,452,169

 
1,277,134

Extensions, discoveries, and improved recovery
 
413,702

 
552,704

 
329,642

Previously estimated development costs incurred during the period
 
442,322

 
306,827

 
42,947

Net change due to revisions in quantity estimates
 
(1,595,302
)
 
(292,343
)
 
164,999

Accretion of discount
 
661,486

 
422,353

 
172,328

Changes in production rates and other
 
(368,326
)
 
(39,324
)
 
149,727

 
 
$
(541,879
)
 
$
2,391,328

 
$
2,500,250