EOG Resources reported second quarter 2010 net income of $59.9 million, or $0.24 per share. This compares to a second quarter 2009 net loss of $16.7 million, or $0.07 per share.
The results for the second quarter 2010 included a $2.5 million ($1.4 million after tax, or $0.01 per share) revision in the estimated fair value of a contingent consideration liability associated with a previously disclosed acquisition of unproved acreage and a previously disclosed non-cash net gain of $37.0 million ($23.7 million after tax, or $0.09 per share) on the mark-to-market of financial commodity transactions. During the quarter, the net cash inflow related to financial commodity contracts was $15.9 million ($10.1 million after tax, or $0.04 per share). Consistent with some analysts' practice of matching realizations to settlement months, and making certain other adjustments in order to exclude one-time items, adjusted non-GAAP net income for the quarter was $44.9 million, or $0.18 per share. Adjusted non-GAAP net income for the second quarter 2009 was $183.6 million, or $0.73 per share. (Please refer to the attached tables for the reconciliation of adjusted non-GAAP net income to GAAP net income.)
Operational Highlights and Targets
During the second quarter, total company crude oil and condensate production increased 43 percent over the same period in 2009. Production increases were greatest from the North Dakota Williston Basin where drilling and production results have proven consistent. In the Bakken Core, the Van-Hook 7-23H and Fertile 37-07H came on-line at 2,525 and 1,654 barrels of crude oil per day (Bopd), respectively. EOG has 99 and 81 percent working interest, respectively in these Mountrail County wells. EOG is drilling development prospects in the Bakken Core, Bakken Lite and Three Forks Formations with a 12-rig program.
EOG announced success from a portion of its acreage tested in the Leonard Shale, a horizontal crude oil play in southeastern New Mexico. The four vertical and seven horizontal wells that EOG has completed in this new area have production characteristics similar to the Barnett Shale Combo - crude oil with a liquids rich natural gas stream contributing to strong well economics. Initial production rates from the Lomas Rojas 26 #1H and #2H were 710 Bopd with 1.7 million cubic feet per day (MMcfd) of liquids rich natural gas and 800 Bopd with 1.5 MMcfd of liquids rich natural gas, respectively. EOG has 100 percent working interest in these two horizontal wells. Based on drilling results to date and other industry data points, EOG estimates the likely reserves on 31,000 of its 120,000 net acres in the play are approximately 65 million barrels of crude oil equivalent, net after royalty.
The Barnett Shale Combo, where EOG is operating a 14-rig drilling program, also continues to add to EOG's crude oil production profile. In Montague County, EOG reported strong results from three horizontal wells. The King #1H began production at 344 Bopd with 2.5 MMcfd of natural gas, the Olden B#1H was completed at 323 Bopd with 1.7 MMcfd of natural gas and the Alamo B#6H commenced production at 500 Bopd. EOG has 98 percent, 97 percent and 96 percent working interest in the wells, respectively. To further test the concept of horizontal drilling in an area previously designated for vertical wells, EOG completed the Richardson #3H in far western Cooke County. The well, in which EOG has a 92 percent working interest, began production at 325 Bopd and is still cleaning up after frac treatment. These Combo wells are producing at restricted rates to minimize frac sand flowback.
In the Eagle Ford horizontal crude oil shale play in South Texas, EOG also reported consistent production results. The Darlene #2H, in which EOG has 50 percent working interest, commenced production at 1,033 Bopd with 423 thousand cubic feet per day (Mcfd) of natural gas. Recently, EOG completed its first two wells in Wilson County. The Borgfeld #1H and #2H began production at 707 and 836 Bopd, respectively. EOG has 100 percent working interest in the wells. As previously reported, EOG is operating a modest five-rig drilling program while gathering and interpreting additional 3D seismic data. To date, EOG has drilled and completed 31 wells and has 25 wells awaiting completion across its 505,000 net acre position in the Eagle Ford trend's mature crude oil window. Toward year-end, EOG plans to ramp up drilling activity to a 12-rig program and operate an average of 14 rigs during 2011.
In the Haynesville, EOG drilled two wells that may be among the industry's most prolific to date in the entire play. Due to pipeline constraints, the 30-day average restricted flow rates from the Crane #26-1H and Murray #1H were 27 and 25 MMcfd of natural gas at 7,800 and 8,100 psi flowing pressure, respectively. The wells had initial production rates of 32 and 30 MMcfd at 9,700 and 9,200 psi flowing pressure, respectively. EOG has 96 percent working interest in these Texas core area wells. Extending the boundary of the sweet spot further east into San Augustine County, Texas, the Walters #1H was completed with a restricted initial production rate of 21 MMcfd of natural gas. EOG has 49 percent working interest in this well. EOG confirmed success from the Bossier Formation in DeSoto Parish, Louisiana with the Red River 5#3H. EOG has a 100 percent working interest in the well, which began production at over 15 MMcfd of natural gas.
In the Niobrara Formation in Colorado, EOG is operating a four-rig exploratory drilling program currently concentrating on 100,000 of its 400,000 total net acre position. During the second quarter, EOG drilled and completed the Critter Creek #02-03H and Critter Creek #04-09H, which are producing at managed restricted rates of 570 and 600 Bopd, respectively. EOG has 100 percent working interest in these wells.
"For the first time in EOG's history, during the second quarter total revenues generated from crude oil, condensate and natural gas liquids production exceeded those from natural gas. This mix is in-line with EOG's target to organically evolve toward a predominantly liquids weighted portfolio in North America by 2011 to 2012," said Mark G. Papa, Chairman and Chief Executive Officer.
At June 30, 2010, EOG's total debt was $3,734 million for a debt-to-total capitalization ratio of 27 percent. Taking into account cash on the balance sheet of $650 million, at the end of the quarter EOG's net debt was $3,084 million and the net debt-to-total capitalization ratio was 23 percent.
As EOG continues to pursue its extensive organic high rate-of-return horizontal crude oil and liquids rich investment opportunities, it is making incremental capital expenditures for crude oil related facilities and infrastructure. To maximize long-term project economics on crude oil developments such as the Eagle Ford, EOG is raising its 2010 capital expenditure program by $500 million from previous estimates. The increase will be offset by a greater amount of acreage sales than previously anticipated.
"We plan to sell certain non-core North American producing natural gas assets, as well as acreage in both natural gas and liquids plays, to execute the drilling and development of our suite of outstanding horizontal oil drilling opportunities. The cash generated will partially fund our capex program in 2010 and 2011,” Mr. Papa said. “In addition, we are focused on maintaining a strong balance sheet, while on track to deliver 13 percent total company organic production growth this year."
Most Popular Articles
From the Career Center
Jobs that may interest you