TransAtlantic provided an operational update for the year ended December 31, 2010.
Selected Production Highlights
Net oil and gas production, after royalty, for the fourth quarter of 2010 increased 171% to approximately 344,000 barrels of oil equivalent ("boe") compared to approximately 127,000 boe for the fourth quarter of 2009. For the fourth quarter of 2010, net oil production, after royalty, in the Company's Selmo oil field increased 45% to approximately 180,000 barrels of oil from approximately 124,000 barrels of oil in the fourth quarter of 2009. For 2010, net oil and gas production, after royalty, increased 133% to approximately 974,000 boe compared to approximately 417,000 boe in 2009. The increase in 2010 was the result of a full year of production in the Selmo oil field, additional production in the Arpatepe oil field and new production in the Thrace Basin gas fields.
For the fourth quarter of 2010, the Company's average realized oil price was approximately $92.00 per barrel, and the Company's average realized natural gas price was approximately $8.00 per thousand cubic feet ("Mcf").
Summary of Net Reserves
DeGolyer and MacNaughton evaluated the Company's reserves as of December 31, 2010 in accordance with the reserves definitions of Rule 4-10(a) (1)-(32) of Regulation S-X of the Securities and Exchange Commission ("SEC") and in accordance with National Instrument 51-101 ("NI 51-101") and the Canadian Oil and Gas Evaluators Handbook ("COGEH"). DeGoyler and MacNaughton evaluated reserves at the Company's Selmo oil field, Arpatepe oil field, Bakuk license, and Thrace Basin gas fields, all of which are located in Turkey.
"We expect to achieve a production rate from our properties in Turkey of at least 10,000 boe per day by the end of 2011," said Malone Mitchell, the Company's Chairman. He added, "All of our actions are directed toward this near-term goal, at which point we will largely be able to fund our capital expenditure program out of cash flow." For 2011, the Company anticipates non-acquisition capital expenditures of between $125 million and $150 million, with the overwhelming majority directed towards Turkey.
Turkey Operations -- Thrace Basin
More than half of the Company's capital expenditures in 2011 are planned for properties in the Thrace Basin. The capital will be expended in the expectation of considerably growing gas production from the current base of approximately 10.0 million net cubic feet per day ("Mmcfpd"). The program for 2011 will focus on developing shallow gas prospects and reserves (conventional gas) and fracture stimulating the deeper pay (unconventional gas). The Company expects net gas production at year end of approximately 35 to 40 Mmcfpd.
On the Company's northern licenses (3839 and 4037) production growth is expected from receipt of a wholesale gas license, which will permit sales from wells that are currently shut-in, and the drilling of 15 to 20 wells on structures identified on recently processed 3D seismic data.
On the Company's central licenses, considerable production growth is expected from the Alpullu gas field and the adjoining exploration license, where the Company plans to drill between five and eight wells to further develop the Alpullu field and test structures on the exploration license. The Alpullu field is currently producing at a constrained rate through a small pipeline to the north. The Company is currently constructing a pipeline to the south, which would connect the field to the gas distribution system operated by Thrace Basin Natural Gas. The Company plans to build gathering lines to connect the structures to the east and west of the new pipeline.
The Company plans to be quite active on the southern licenses that it expects to acquire upon the acquisition of Thrace Basin Natural Gas, currently expected to close in the second quarter of 2011. The Company expects to drill approximately 20 wells on these licenses in 2011, targeting shallow conventional targets, and re-enter and fracture stimulate approximately eight wells in the Mezardere formation, which is behind pipe.
Turkey Operations -- Southeastern Turkey
Selmo Oil Field
In January 2011, the Company began conducting a series of small fracture stimulations and gelled acid jobs on wells in the Selmo oil field. As a result of those operations, daily average production increased from approximately 2,400 bopd at year end 2010 to an average of 2,766 bopd for the month of February 2011, reaching a peak production of over 3,000 bopd. Current production from the field is approximately 3,000 bopd. The Company plans to drill and complete at least 24 wells in the field during 2011. As a result of the planned drilling activity, the Company expects production to grow to approximately 4,000 bopd. "In addition to the active drilling program, we are also reviewing all current and lower rate wells as candidates for fracture stimulated or gelled acid stimulation, as our results to date have been very good," said Gary Mize, the Company's President.
Last year the Company acquired 252 square kilometers of 3D seismic data around the Arpatepe field area on License 3118, in which the Company holds a 50% working interest. Last week, the Company received brute stack processing of the data and expects to receive final migrated data by the end of March 2011. "This is the highest priority 3D seismic data we are working with right now. We are pleased with the leads we see on the brute stack data," said Mr. Mize. The Company expects to drill three exploration wells and two development wells at Arpatepe in 2011. In addition, plans have been approved to put the Arpatepe-1 well on pump, which is still flowing, but at declining rates. The Company anticipates that the pump should increase production from the well by about 300 bopd gross. The Company expects its year end 2011 net production from License 3118 will be approximately 600 bopd.
Syrian Trend -- Bakuk
The Company and its partner have completed and tested the Bakuk Camurlu Pipeline, a 23 kilometer, six-inch pipeline that runs from the Bakuk-101 gas discovery well to the south. Limited gas sales are anticipated to commence by the end of March 2011 and build gradually over the coming months. The Company has a 50% working interest on the Bakuk license and is evaluating prospect proposals for a well on the South Bakuk area, where the Company acquired 3D seismic data last year. In addition, the Company is working with its partner to plan another well to further delineate the Bakuk-101 discovery. That well could help justify the construction of a larger pipeline approximately 50 miles to the north, which would access markets with greater demand for gas. If that pipeline were constructed it would not come into service until 2012.
Bulgaria and Romania Operations
The Company is planning wells in Bulgaria to appraise the Deventci R-1 gas discovery and to test the Etropole shale. In Romania the Company plans to drill a well to test the Silurian aged shale. The wells are likely to be drilled in succession, beginning in late Spring.
The Company has drilled the GRB-1 well to a total depth of 8,120 feet (2,475 meters) and expects to reach total depth in the next few days. The GRB-1 well is located near the Atlantic coast approximately 30 kilometers south of Tangiers and 3.5 kilometers from the Maghreb-Europe gas pipeline.
The GRB-1 well was the first well drilled on the Asilah exploration permits and has targeted Tertiary age reservoirs. The Company plans to test numerous intervals that had gas shows while drilling.
The GRB-1 well was drilled using the Company's Viking I-8 rig. Upon completion of testing, the rig will move to the Tselfat exploration permit and drill the planned TKN-1 well on the Tekna Jurassic oil prospect, 3.5 kilometers north of the Haricha oil field.
The HR-33bis appraisal well, drilled in the Haricha oil field by the Company in 2009, tested 100 bfpd with 50% water cut from Jurassic and Tertiary age reservoirs at a subsea depth of approximately 2,802 feet (854 metres). The field had an estimated 15 million barrels of oil originally in place, and oil production ceased in 1972 after production of approximately 2.8 million barrels of oil. The HR-33bis location was recently enlarged, and specialized testing equipment was installed. An extended well test will start soon to give a more complete estimation of the remaining reserves and determine the feasibility of field redevelopment.
Most Popular Articles
From the Career Center
Jobs that may interest you