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Supplemental Oil and Natural Gas Disclosures (Unaudited) (Tables)
 12 Months Ended
Dec. 31, 2011
Oil and Gas Exploration and Production Industries Disclosures [Abstract]  
Cost incurred in oil and natural gas activities

Costs incurred in oil and natural gas activities were as follows:

   Year Ended December 31,
In thousands  2011  2010  2009
Property acquisitions:         
 Proved  $ 86,465 $ 3,373,450 $ 585,637
 Unevaluated   17,858   1,297,695   104,772
Exploration   31,483   8,728   4,635
Development   1,144,243   658,758   292,545
  Total costs incurred (1) $ 1,280,049 $ 5,338,631 $ 987,589
            
(1)Capitalized general and administrative costs that directly relate to exploration and development activities were $35.0 million, $20.1 million and $14.0 million for the years ended December 31, 2011, 2010 and 2009, respectively.
Results of operations from oil and natural gas producing activities excluding corporate overhead and interest costs

Results of operations from oil and natural gas producing activities, excluding corporate overhead and interest costs, were as follows:

  Year Ended December 31,
In thousands, except per BOE data 2011 2010 2009
Oil, natural gas and related product sales $ 2,269,151 $ 1,793,292 $ 866,709
Lease operating costs   507,397   470,364   314,689
Marketing expenses   26,047   31,036   16,890
Taxes other than income   138,419   114,569   37,037
Depletion, depreciation and amortization   369,075   391,782   206,999
CO2 depletion, depreciation and amortization (1)   24,460   29,206   29,076
Commodity derivative expense (income)   (52,497)   (21,414)   236,226
 Net operating income   1,256,250   777,749   25,792
Income tax provision   477,375   295,545   9,927
  Results of operations from oil and natural gas producing activities $ 778,875 $ 482,204 $ 15,865
            
Depletion, depreciation and amortization per BOE $ 16.42 $ 15.82 $ 13.39
            
(1)Represents an allocation of the depletion, depreciation and amortization of our CO2 properties and pipelines associated with our tertiary oil producing activities.
Estimated quantities of reserves
   Year Ended December 31,
   2011 2010 2009
   Oil Gas Total Oil Gas Total Oil Gas Total
   (MBbl) (MMcf) (MBOE) (MBbl) (MMcf) (MBOE) (MBbl) (MMcf) (MBOE)
                    
Balance at beginning of year  338,276  357,893  397,925  192,879  87,975  207,542  179,126  427,955  250,452
Revisions of previous estimates  (4,478)  (14,058)  (6,821)  3,538  16,171  6,233  (69)  (1,298)  (285)
Revisions due to price changes  2,558  485  2,639  2,780  811  2,915  4,557  (2,079)  4,211
Extensions and discoveries  42,936  52,339  51,658  26,313  130,245  48,021  334  11,785  2,298
Improved recovery(1)  264  -  264  30,173  -  30,173  13,875  -  13,875
Production  (22,169)  (10,783)  (23,966)  (21,870)  (28,491)  (26,619)  (13,495)  (24,764)  (17,622)
Acquisition of minerals in place  346  239,332  40,235  155,021  622,984  258,852  28,379  2,317  28,765
Sales of minerals in place  -  -  -  (50,558)  (471,802)  (129,192)  (19,828)  (325,941)  (74,152)
Balance at end of year  357,733  625,208  461,934  338,276  357,893  397,925  192,879  87,975  207,542
                    
Proved Developed Reserves:                  
 Balance at beginning of year  219,077  110,516  237,496  116,192  69,513  127,778  96,746  298,114  146,432
 Balance at end of year  239,741  125,970  260,736  219,077  110,516  237,496  116,192  69,513  127,778
                    
(1) Improved recovery additions result from the application of secondary recovery methods such as water flooding, or tertiary recovery methods such as CO2 flooding.
Oil and natural gas prices

The following representative oil and natural gas prices were used in the Standardized Measure. These prices were adjusted by field to arrive at the appropriate corporate net price.

  December 31,
  2011 2010 2009
Oil (NYMEX) $ 96.19 $ 79.43 $ 61.18
Natural Gas (Henry Hub)   4.16   4.40   3.87
Discounted future net cash inflows after income taxes
  December 31,
In thousands 2011 2010 2009
           
Future cash inflows $ 38,165,122 $ 26,698,819 $ 11,579,159
Future production costs   (12,570,015)   (9,702,896)   (5,034,393)
Future development costs   (3,026,898)   (1,912,457)   (836,455)
Future income taxes   (7,379,972)   (4,700,023)   (1,257,844)
 Future net cash flows   15,188,237   10,383,443   4,450,467
10% annual discount for estimated timing of cash flows   (8,180,632)   (5,465,516)   (1,993,082)
 Standardized measure of discounted future net cash flows $ 7,007,605 $ 4,917,927 $ 2,457,385
Analysis of changes in the Standardized Measure of Discounted Future Net Cash Flows from proved oil and natural gas reserves

The following table sets forth an analysis of changes in the Standardized Measure of Discounted Future Net Cash Flows from proved oil and natural gas reserves:

   Year Ended December 31,
In thousands 2011 2010 2009
            
Beginning of year $ 4,917,927 $ 2,457,385 $ 1,415,498
Sales of oil and natural gas produced, net of production costs   (1,597,288)   (1,177,322)   (498,093)
Net changes in sales prices   4,646,086   2,062,181   1,263,346
Extensions and discoveries, less applicable future development and production costs   762,370   295,074   6,735
Improved recovery(1)   15,708   623,622   202,145
Previously estimated development costs incurred   354,228   193,947   98,659
Revisions of previous estimates, including revised estimates of development costs, reserves and rates of production   (1,673,283)   (285,158)   (63,044)
Accretion of discount   729,234   307,546   192,686
Acquisition of minerals in place   29,737   3,671,439   365,771
Sales of minerals in place   -   (1,474,443)   (419,601)
Net change in income taxes   (1,177,114)   (1,756,344)   (106,717)
End of year $ 7,007,605 $ 4,917,927 $ 2,457,385
            
(1)Improved recovery additions result from the application of secondary recovery methods such as water flooding or tertiary recovery methods such as CO2 flooding.