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Home My WebLink About2009 Eider Oil PoolDate: 03/3112010 Attn: AOGCC BPXA Well DATA TRANSMITTAL RECEIVED HAR ' 2010 Enclosed is the 2009 Duck Island Unit, Eider Oil Pool Annual Reservoir Surveillance Report. If you have any questions or concerns, please contact John Garing (564-5167) or Travis Peltier (564-4511). Please Sign and Return one copy of this transmittal. M _ David J. Szabo Head of Resource Management Alaska Consolidated Team (ACT) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 31, 2010 Phone: (907) 564-4788 Fax: (907) 564-4440 Email SzaboDJObp.com Web: www.bp.com Mr. Dan Seamount Commissioner and Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Duck Island Unit, Eider Oil Pool Annual Reservoir Surveillance Report Dear Mr. Seamount: BP Exploration (Alaska) Inc., as operator of the Duck Island Unit, hereby submits the attached Annual Reservoir Surveillance Report in accordance with the requirements of Conservation Order 449. This report covers the period January 1 through December 31, 2009. The report is organized according to the outline provided in Rule 12 of the conservation order. A shut-in well list addressing 20 AAC 25.115 has been included in the Endicott Oil Pool Reservoir Surveillance Report submitted in a separate filing. BP reserves the right to alter the content of the analyses contained in this report at any time based upon the most recent surveillance information obtained. Should you have any questions please contact John Garing (564-5167) or Travis Peltier (564- 4511). S' cerely, David Szabo cc: Kevin Banks, DNR R. L. Skillern, BP Eider File Annual Reservol rSurvell lance Report Duck island Unit Elder Oil Pool January 2009,through lDecamibar 200001 by 0 March, 2010 Table of Contents A. Progress of Enhanced Recovery Project implementation and Reservoir Management summary B. Voidage Balance by Month of Produced Fluids and Injected Fluids and cumulative status C. Analysis of reservoir pressure surveys within the pool D. Results and Analysis of Production and Injection Log surveys, tracer surveys and observation well surveys E. Review of pool production allocation factors and issues over the prior year F. Future Development Plans K A) Progress of Enhanced Recovery Project implementation and Reservoir Management summary BPXA drilled two wells into the Eider reservoir: 2-56A/EI 01 ("Eider 1 ") and 2- 30A/EI 02 ("Eider 2"). The Eider 2 well was shut in May 1999 at the end of the approved test period, and the Eider 1 well was shut in September 1999. BPXA converted the Eider 1 well to water injection in June 2000 after receiving the proper Endicott partner approval. Production from Eider 2 well recommenced in June 2000 with the start of water injection. Over the next couple of years, static bottomhole pressure ("SBHP") measurements were obtained in both Eider wells to determine the extent of pressure support. With SBHP's rising in the Eider 1 well and falling in the Eider 2 well, there was a clear indication that the producer / injector pair were not in pressure communication with one another. BPXA converted the Eider 1 well back to production in July 2004 and subsequently perforated shallower sands in both wells. The Eider 2 well was sidetracked (2-30B/ME-01) in 2009 to the Minke target, a Sag River/Ivishak formation satellite prospect. Producer 2-56A/E101 was brought online once in 2009 to conduct a well test which indicated that the production characteristics of the well had not changed. (1 bopd, watercut — 100%). Otherwise this well was not online in 2009 due to its uncompetitive watercut. There were 5 days of production from the Ivishak formation for the time period of January 2009 through December 2009, with 5 bbls oil, 5 mscf of gas and 19.15 mstb water. Cumulative production through December 2009 was 2.75 mmstb oil, 26.52 bscf gas, and 5.52 mmstb water. There was no injection into the Ivishak formation for the time period of January 2009 through December 2009. Cumulative injection through December 2009 was 4.33 mmstb water. All produced fluids have been processed through the Endicott facility as stipulated under conditions within the Endicott Facility Sharing Agreement. Produced gas, other than that used for fuel, has been re -injected into the Endicott reservoir gas cap. 3 B) Voidage Balance by Month of Produced Fluids and Injected Fluids and Cumulative status Eider M116111 IN ...l..�a.._s OMMLWOMOMMOMMI OMM MMMMMMMM, OMMM MMOMMMI nmmm�wmmmwml MMMMwOT",=_wMMM1 11 C) Analysis of reservoir pressure surveys within the pool One pressure survey was complete! in January 2009 in 2-30A/E102. Extrapolated Pressure at -9700 TVDss Datum, Well Date psia 2-30A/E102 1/4/2009 4187 Data Source SBHP Pressure data since startup are graphically represented in the next figure that is a plot of pressure versus time. These data indicate pressures have not changed significantly in the past year. 5 3 0 cn R F- 0 0 ti Cd m u) L 3 cn a� L CL Eider Pressure Data Region: Eider Zone: Ivishak Pressure vs. Time 5500 5000 4500 4000 3500 3000 2500 2000 98 99 00 01 02 03 04 05 06 07 08 09 ■ 2-30A o 2-56 13 2-56A BP Exploration, Endicott D) Results and Analysis of Production and Injection Log surveys, tracer surveys and observation well surveys No production, injection logging or tracer surveys were performed during 2009 on wells in the Eider Pool E) Review of pool production allocation factors and issues over the prior year The allocation factor for Eider well has been set at 1.0 when the wells are producing. F) Future Development Plans Reservoir characterization work on the Eider reservoir will continue. Upon identification of any potential targets, BPXA will evaluate sidetracking existing wells in order to increase recovery from the Eider reservoir. The potential to redeploy the remaining Eider well to targets outside the Eider Participating Area will also be considered. 7