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Home My WebLink About2009 Prudhoe Oil and Put River Oil Pools ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL JANUARY THROUGH DECEMBER 2009 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT CONTENTS SECTION PAGE 1.0 INTRODUCTION 4 2.0 OVERVIEW 5 3.0 PRESSURE UPDATE 6 3.1 Pressure Monitoring 6 3.2 Pressure Plan 6 4.0 PROJECT SUMMARIES 7 4.1 Flow Station Two Water / MI Flood Project 7 4.2 Eastern Peripheral Wedge Zone Water / MI Project 8 4.3 Western Peripheral Wedge Zone Water / MI Project 9 4.4 Northwest Fault Block Water / MI Project 10 4.5 Eileen West End Waterflood Project 11 4.6 Gas Cap Water Injection Project 12 4.6.1 Observation Well RST Surveys and Zonal Conformance 4.6.2 Reservoir Evaluation 4.6.3 2009 Surveillance Plans 4.6.4 Plans for Change in Project Operation 4.7 Put River Pool 15 5.0 GAS MOVEMENT SURVEILLANCE 16 5.1 Gas Movement Summary 16 Page 2 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT LIST OF EXHIBITS 1-A Prudhoe Bay Unit Field Schematic 1-B PBU Well Statistics 1-C PBU Production / Injection Statistics 1-D PBU Pressure Map 1-E Areally Weighted Average Pressure Plot 1-F Areally Weighted Pressure Data 1-G Average Monthly CGF MI Rates and Compositions 2 Fieldwide Reservoir Balance 3-A FS-2 Base Flood Map 3-B FS-2 Reservoir Balance 3-C FS-2 Areal Average Reservoir Pressure 3-D FS-2 Daily Average RMI 4-A EPWZ Base Flood Map 4-B EPWZ Reservoir Balance 4-C EPWZ Areal Average Reservoir Pressure 4-D EPWZ Daily Average RMI 5-A WPWZ Water / MI Flood Base Map 5-B WPWZ Reservoir Balance 5-C WPWZ Areal Average Reservoir Pressure 5-D WPWZ Daily Average RMI 6-A NWFB Base Flood Map 6-B NWFB Reservoir Balance 6-C NWFB Areal Average Reservoir Pressure 6-D NWFB Daily Average RMI 7-A EWE Base Flood Map 7-B EWE Reservoir Balance 7-C EWE Daily Average RMI 8 Wells Surveyed for Gas Movement 9 Pressure Surveys 10 SI Well List 11-1 Flood Front and Well Locator Map 11-2 Water Bank Cross-section Interpretation - 2009 12 Put River Lobe Map Page 3 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 1.0 INTRODUCTION As required by Conservation Orders 341C (Approved June 12th, 1997), 341D (Approved November 30th, 2001) and 559 (Approved November 22, 2005) this report provides a consolidated waterflood and gas oil contact report summary of the surveillance activities for the Waterflood Project, Miscible Gas and Gas Cap injection projects, and the Gravity Drainage Area within the Prudhoe Oil Pool plus a section for the Put River Pool. The time period covered is January through December of 2009. In keeping with the requirements of the Conservation Order the report format provides information for each of the five major flood projects and the gravity drainage project in the field, where applicable, as follows: • Analysis of reservoir pressure surveys and trends • Progress of the enhanced recovery projects, including the gas cap water injection project • Voidage balance by month of produced and injected fluids • Data on Minimum Miscibility Pressure (MMP) of injected miscible gas • Summary of Returned Miscible Injectant (RMI) volumes • Results of gas movement and gas-oil contact surveillance efforts. • Results of pressure monitoring efforts • Table of wells shut-in throughout the 2009 calendar year Separate sections are provided for the five major flood areas: Flow Station 2 (FS-2), Eastern Peripheral Wedge Zone (EPWZ), Western Peripheral Wedge Zone (WPWZ), North West Fault Block (NWFB), and Eileen West End (EWE) along with information on the GCWI in the Gravity Drainage region and the Put River Pool. Water and miscible gas floods are described in each section. A separate section has been provided with detailed information on gas-oil contact surveillance. As agreed in 2004 with the Commission, the discussion of Gas Production Mechanisms was not included in the report. Page 4 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 2.0 OVERVIEW Exhibit 1A identifies the five flood areas and gravity drainage areas in the Prudhoe Oil Pool as follows: FS-2, EPWZ, WPWZ, NWFB, EWE, and GD. The Waterflood Project encompasses all five flood areas. The Prudhoe Bay Miscible Gas Project (PBMGP) is currently active throughout the waterflood areas. The Eileen West End waterflood pilot concluded in March 1999, after successfully establishing EWE injection potential. EWE information since waterflood startup in September 2001 is included in this report. Exhibits 1-B and 1-C provide well, production, and injection statistics for the major project areas included in this report. As in last years’ report, wells do not share project boundaries, but belong to a single project area. The well counts therefore reflect the total number of wells actually contributing to production and injection. Similar to last year, only wells that actually produced or injected during the year are included. During the report period of January through December 2009, field production averaged 252.0 MBOD, 7,161 MMSCFD (GOR 28,413 SCF/STB), and 893 MBWD (water-cut 78.0%). Waterflood project injection during this period averaged 897 MBWD with 140 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2009 was 10,785 MMSTB, while cumulative MI injection was 2,878 BCF. Cumulative production since waterflood startup was 2,766 MMSTB oil, 10,122 BCF gas, and 7,227 MMSTB water. As of December 31, 2009, cumulative production exceeded injection by 5,347 MMRB compared to 4,972 MMRB at the end of 2008. Similar to last year, production and injection values have been calculated based upon the waterflood start-up dates for the project areas rather than for each injection pattern. Exhibit 1-D provides analysis of pressure static, buildup, and falloff data that was collected from 2007 through 2009 at a datum of 8,800 ft, subsea for the Full Field Dominant Zone. Using the three year rolling technique improves the statistical validity of the pressure distribution since it roughly triples the number of data points employed versus only using the current year static pressures. As in the past, abnormal pressures, such as pressures taken in fault compartments and in the Sag Formation have been removed. As shown in Exhibit 1E, the historic pressure decline appears to have stabilized due to gas-cap water injection with 55% of repeat 2009 pressure surveys found equal to or greater than their 2007 or 2008 pressure measurements. For 2009, average pressure in the PBMGP project areas using three years of pressure static measurements was calculated to be 3,315 psia by areal weighting, as compared to 3,299 in 2008 (Exhibit 1F). The GD area pressure was stable rising four psi from 3,244 psia in 2008 to 3,248 in 2009. This subtle pressure increase is within the expected statistical variation with a different annual pressure sampling data sets. The methodology for calculation of the average pressure is explained further on page 7. Confirmed MI breakthrough has occurred in 140 wells during the reporting period. RMI production is an indicator of EOR pattern performance and the presence of RMI is determined by gas sample analyses that show a separator gas composition richer in intermediate range hydrocarbon components. MI breakthrough in a well is considered to have occurred when the average RMI rate over the number of producing days in a well exceeds 200 mcf/d. The previous Page 5 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT year showed MI breakthrough in 128 wells. The increase in RMI can be attributed to maturing of MI injection patterns in the PBMGP areas. Exhibit 1-G shows the 2009 average monthly CGF MI rates and compositions for the field. 3.0 PRESSURE UPDATE 3.1 Pressure Monitoring Exhibit 9 provides pressure, buildup, and falloff data collected in 2009 at a datum of 8,800 ft, subsea used for the Full Field Dominant Zone. For this report, as in the past, pressures taken in fault compartments, the Sag River Formation, and in Zone 1 of the G-Pad LPA (Low Pressure Area), which don’t appear to be in good communication with the rest of the reservoir, have been excluded from Exhibit 1-D. Also excluded were wells shut-in less than a week that obviously had not stabilized as compared to offsetting statics. Other wells completed in Zone 1 and Zone 4B, which are in poor communication with the rest of the reservoir and therefore have lower pressures, were still included in the map and calculations if their shut-in times were deemed long enough. The excluded pressure measurements are listed separately in Exhibit 9. Unless otherwise noted, all pressure calculations are areally weighted, bound by the main field original 50' LOC contour, and are referenced to a pressure datum of 8,800' SS. It was agreed with the commission that the polygon pressures would be calculated differently starting with the 2005 than it had in past reports due to the advent of pressure response to gas- cap water injection. That methodology consisted of utilizing only the pressure gathered during the reporting period. Starting with the 2008 report, since the field pressure has stabilized, pressure points from a rolling three year period will be used to construct the pressure map so as to reduce the statistical variation induced by changing year-to-year well sets. Exhibit 1-D illustrates the 2009 pressure map using 2007 through 2009 data points. 3.2 Pressure Plan Per C. O. 341C, Rule 6b, a pressure plan containing the number of proposed surveys for the next calendar year is required to be filed with this report. Prudhoe Bay reservoir depletion strategies are defined, and the goal of the pressure program is to optimize areal coverage and provide sufficient data for well safety. The proposed plan for 2009 calls for collection of 90 pressure surveys fieldwide. The number of surveys proposed is similar to last year. Per administrative approval 341C.01, dated June 22, 1999, a summary of pressure surveys run during 2009 is presented in Exhibit 9. Page 6 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 4.0 PROJECT SUMMARIES 4.1 Flow Station Two Water / MI Flood Project The Flow Station Two area (FS-2), which comprises the eastern third of the Eastern Operating Area, is shown in Exhibit 3-A. The locations of production and injection wells are shown with the EOR injection patterns identified. There were 115 producing wells and 58 injection wells that contributed to production/injection during 2009 within the FS-2 flood area. Production/injection data was calculated with the polygon boundaries as in last year’s report. The FS-2 waterflood area oil production averaged 27 MBOD for 2009 compared to 33 MBOD in 2008. Cumulative production since waterflood start-up through the end of 2009 is 1,035 MMSTB of oil, 4,530 BCF of gas, and 3,704 MMSTB of water. Injection rates averaged 440 MBWD and 49 MMSCFD in 2009. Since 12/31/08, the waterflood imbalance has increased from a cumulative under injection of 1,807 MMRB to 1,965 MMRB under injected. During the report period, production exceeded injection by 189 MMRB. Under- injection is related to production of free gas influxing from the gravity drainage region which should not be replaced so as to maintain a steady declining gas contact. Waterflood strategy is to replace voidage on a zonal basis after accounting for the free gas influx. Cumulative water injection since waterflood start-up through the end of 2009 is 5,654 MMSTB. The flood area's GOR increased from an average of 20,218 SCF/STB in 2008 to an average of 20,574 SCF/STB in 2009. Gas influx continues along the FS-2/GD GDWFI area, and in the high permeability conglomerates in the Updip Victor area. Water-cut was up 1% to 94% in 2009. A breakdown of the production and injection data is provided in Exhibit 3-B for the report period. See Exhibit 1-C for a comparison of the cumulative figures with last year’s AOGCC report. Exhibit 3-C presents the areal average waterflood pressure decline over time. The pressure in the FS-2 area was 3,348 psia in 2009. This is an increase of 32 psi over the 2008 pressure. This variation in pressure was likely caused by the 2006 data points dropping out of the three year rolling average since that year included points that had relatively low bottom-hole pressure values such as 04-29AL1 which was 3,184 psi. Exhibit 3-D is a presentation of 2009 average returned MI (RMI) rates. Miscible gas return has been confirmed in 37 wells by gas compositional analysis (RMI>200 MSCFD). Page 7 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 4.2 Eastern Peripheral Wedge Zone Water / MI Flood Project The Eastern Peripheral Wedge Zone (EPWZ) water and miscible gas (MI) flood area is shown in Exhibit 4-A. In 2009, oil production averaged 18.9 MBOD, as compared to 20.4 MBOD in 2008, with an average 89% water cut and 19,045 SCF/STB Gas Oil Ratio. Injection averaged 203 MBWD and 16 MMSCFD of miscible injectant (MI). There are a total of 77 producers and 29 injectors in the flood area that contributed to production/injection during 2009. Of the 29 injectors, 6 injected miscible gas at some point throughout the year, while the remaining wells injected water only. Production and injection values have been calculated using polygon boundaries the same as last year’s report. Two waterflood start-up dates have been used, 12/30/82 for the DS13 flood and 8/20/84 for the down-dip sections, rather than the start-up dates of each injection pattern. A total of 608 MMSTB of oil, 2,607 BSCF of gas, and 1,416 MMSTB of water have been produced with 1,924 MMSTB of water and 640 BSCF of miscible gas injected. Exhibit 4-B shows the monthly injected and produced volumes on a reservoir barrel basis during 2009 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 134 MMRB. Exhibit 4-C shows the trend of reservoir pressure decline in the EPWZ flood area with time. The area receives pressure support from pattern injection, some aquifer influx, and GCWI. Faulting and out of conformance injection can impair flood performance in some areas. Areas of low pressure are being addressed by flood management strategies designed to increase voidage replacement. The EPWZ pressure was 3,310 psia in 2009. This is an increase of 11 psi as compared to 2008. Much of the increase in pressure can be attributed to the elimination of lower pressure 2006 data points. Exhibit 4-D shows the 2009 average of estimated RMI rates in producers, as calculated from well tests and from numerous produced gas sample analyses. Miscible gas returns have been confirmed in 36 wells (RMI <200 MSCFD). Page 8 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 4.3 Western Peripheral Wedge Zone Water / MI Flood Project Exhibit 5-A is a map of the Western Peripheral Wedge Zone (WPWZ) water and miscible gas (MI) flood areas. During the report period oil production averaged 22.1 MBOD, as compared to 21.1 MBOD in 2008, with a gas/oil ratio of 10,484 SCF/STB and a watercut of 85%. Injection averaged 96 MBWD of water and 37 MMSCFD of miscible injectant. For the WPWZ project, 42 injectors (10 WAG injectors and 32 water injectors), and 97 producers contributed to the production and injection during 2009. The well counts reflect only the active wells for the year. The waterflood startup date for the WPWZ project area was September 1985, corresponding to the start of injection in the Main Pattern Area (MPA). The production and injection data for the project reflect this startup date. Consistent with last year, production and injection data are calculated on the single area basis. Cumulative water injection from waterflood start-up through December 2009 was 1,557 MMSTB while cumulative MI injection was 559 BSCF. Cumulative production since waterflood start-up is 492 MMSTB oil, 1,524 BSCF gas, and 1089 MMSTB water. As of December 31, 2009 cumulative production exceeded injection by 860 MMRB. Exhibit 5-B provides the monthly injection and production data from 01/09 through 12/09. During the report period, production exceeded injection by 83 MMRB. The reservoir balance in Exhibit 5-B doesn’t identify support from the aquifer, thereby understating voidage replacement nor does it capture the production of gas-cap-gas which needs not be replaced. During 2006 a produced water tie- line was installed connecting two GC-1 slug catchers to GC-3 produced water tanks. This allowed up-dip Zone 4 waterflood expansion and should allow ideal voidage replacement in the eastern half of the WPWZ area. Exhibit 5-C shows that the pressure in the WPWZ was 3,308 psia in 2009. This is an increase of 11 psi over the pressure reported in 2008 which appears to be due to adding higher 2009 pressures than those dropped from 2006. Exhibit 5-D indicates wells with MI breakthrough and the 12-month averaged returned MI rates. Miscible gas breakthrough has been confirmed in 32 wells by gas compositional analysis. Page 9 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 4.4 Northwest Fault Block Water / MI Flood Project Exhibit 6-A is a map of the Northwest Fault Block (NWFB) water and miscible gas (MI) flood areas. During the report period, oil production averaged 9.9 MBOD, as compared to 11.0 MBOD in 2008, with a gas/oil ratio of 6,716 SCF/STB and a watercut of 84%. Injection averaged 67.4 MBWD and 0.4 MMSCFD of miscible injectant. For the NWFB project, 29 injectors (1 WAG injectors and 28 water injectors), and 61 producers contributed to the production and injection during 2009. The well counts reflect the number of wells actually contributing to production/injection during the reporting period. Production and injection values have been calculated based upon the start-up date for the project area, 8/13/84. Consistent with last year, production and injection data are calculated on the single area basis. Cumulative water injection from waterflood start-up in August 1984 through December 2009 was 1,557 MMSTB while cumulative MI injection was 665 BCF as detailed in Exhibit 61-C. Cumulative production since waterflood start-up was 582 MMSTB oil, 1,241 BSCF gas, and 918 MMSTB water. As of December 31, 2009 cumulative production exceeded injection by 402 MMRB. Exhibit 6-B provides the monthly injection and production data from 01/09 through 12/09. During the report period, production exceeded injection by 20 MMRB. However, this does not include support obtained from aquifer influx or gas cap expansion. The areally weighted pressure in the NWFB area was 3,271 psia in 2009. This is an increase of 2 psi over last year. The historical pressure trend can be seen in exhibit 6-C. The increase in 2004 was largely due to the fact that this polygon’s boundaries were expanded to the northwest with the presence of aquifer area affecting the overall pressure of the northwest fault block. Exhibit 6-D indicates wells with MI breakthrough and the 12-month average returned MI rates. Miscible gas breakthrough has been confirmed in 23 wells by gas compositional analysis. Page 10 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 4.5 Eileen West End Waterflood Project Exhibit 7-A is a map of the Eileen West End (EWE) waterflood area and miscible gas (MI) flood area. During the report period, oil production averaged 13.0 MBOD, as compared to 14.4 MBOD in 2008, with a gas/oil ratio of 5,113 SCF/STB and water cut of 69%. Injection averaged 36.6 MBWD and 18.1 MMSCFD of miscible gas injectant. For the EWE project, 17 injectors (10 WAG injector, 7 water injectors), and 62 producers contributed to the production and injection during 2009. The well counts reflect only the active wells for the year. Cumulative water injection from waterflood start-up in September 2001 through December 2009 was 93 MMSTB and cumulative MI injection was 62 BCF. Cumulative production since waterflood start-up was 48 MMSTB oil, 220 BCF gas, and 99 MMSTB water. As of December 31, 2009 cumulative production exceeded injection by 178 MMRB. Exhibit 7-B provides the monthly injection and production data from January 1, 2009 through December 31, 2009. During the report period, production exceeded injection by 16 MMRB. The EWE pressure was 3,663 psia in 2009 representing an average pressure increase of 37 psi for this area from 2008. This increase is principally due to dropping twenty-six 2006 pressures that averaged 3560 psi while adding thirty-two 2009 pressures that average 3619. Exhibit 7-D indicates wells with MI breakthrough and the 12-month average returned MI rates. Miscible gas breakthrough has been confirmed in 12 wells by gas compositional analysis. Page 11 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 4.6 Gas Cap Water Injection Project Details of the Volume of Water Injected during 2009 are detailed below; units in thousands of barrels of seawater injected per month (MBWM): Date PSI-01 PSI-05 PSI-06 PSI-07 PSI-08 PSI-09 PSI-10 Monthly Total 1/1/2009 2,892 2,877 2,858 2,881 2,867 2,931 2,897 20,203 2/1/2009 2,574 2,594 2,620 2,614 2,623 2,650 2,603 18,278 3/1/2009 2,957 2,956 2,975 2,911 2,924 3,044 2,914 20,680 4/1/2009 2,746 2,825 2,818 2,792 2,802 2,822 2,776 19,581 5/1/2009 2,563 2,494 2,573 2,551 2,609 2,554 2,530 17,874 6/1/2009 2,133 2,040 1,998 1,984 2,217 2,053 2,064 14,489 7/1/2009 2,536 2,631 2,656 2,621 2,387 2,651 2,502 17,984 8/1/2009 2,835 2,900 2,874 2,896 2,393 2,909 2,804 19,610 9/1/2009 1,579 1,639 1,564 1,244 1,503 1,314 1,205 10,048 10/1/2009 1,320 1,176 1,176 865 1,208 1,187 1,140 8,072 11/1/2009 3,091 2,908 3,020 2,894 3,014 3,014 3,033 20,974 12/1/2009 2,821 2,730 2,797 2,676 2,773 2,837 2,761 19,395 2009 Total 30,047 29,770 29,929 28,929 29,320 29,966 29,229 207,188 The 2009 volume of sea water injected in the PSI area was 207 million barrels. The cumulative volume injected at the end of 2009 was 1,200 million barrels of sea water. 4.6.1 Observation Well RST Surveys and Zonal Conformance The RST surveys run in offset producers continue to be the primary method of monitoring water movement from the Gas Cap Water Injection project. These wells have been logged repeatedly since injection began at intervals of 4-6 months to monitor water movement. By comparing the RST logs with the baseline and previous logs, the presence of water can be readily observed. This procedure has provided a very clear picture of water in the Ivishak formation and allows the monitoring of vertical and lateral movement of the waterfront. Exhibit 11-1 is the locator map for the GCWI area and shows the PSI injectors along with the observation wells. This map shows the current interpretation of the shape of the waterfront in map view. The estimates of the waterfront shape for the March 2005 and the March 2008 time periods are also shown for comparison. The information from the RST logging program was also used to develop the updated cross section (Exhibit 11-2) showing the interpretation of the surveillance data for the current time period. The incremental movement in 2009 is shown as the lighter blue colored areas of the cross section. RST logging in 2009 has shown a continued advancement of the water front with respect to its position in 2008, primarily seen as a building of water thickness of 10-15 feet in Zone 2C, Zone 3 or Zone 4 There was no detection of advancement or column building in Zone 1 or Zone 2A in any of the surveillance logs in 2009. The most recent round of surveillance was done in October, 2009, and included the L1-14, L2-07A, L2-18A, L2-24, L2-32, L3-11, L5-15, 04-21, 11-10, 11-27 and 18-15B wells. As the size of the water mass becomes larger in areal extent, the rate of incremental advancement both laterally and vertically has become noticeably slower. At Page 12 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT this point, the changes in the waterfront have followed a predictable pattern established in recent surveillance, where most incremental waterfront changes are seen in Zone 2C, with less additional water logged in lower zones. RST logs in the L1-14 well, which is just to the southeast of the AGI gas injectors, show that water first reached this area in the fall of 2009, when 10 feet of water was detected in Zone 2C. No water was detected in the L2-07A and 18- 26B wells, which are to the south of L1-14, and provide a good definition of the extent of westerly movement of the PSI waterfront. Water continued to build to the south, as seen by observation wells 18-15B, 11-27, 11-10 and 04-21, where additional water column was logged in Zone 2C. An additional surveillance point was acquired during the drilling of the 18-29C rotary sidetrack, where 39 feet of water was detected in Zone 2C. No PSI injected water has been detected below Zone 2C south of the main east-west trending fault near the L2-18A well. To the east of the PSI injectors, an October RST in L5-15 logged an additional 6 feet of Zone 2 water after detecting the first water breakthrough just last year. Zone 2C is truncated in this well, and no water was detected in Zone 2A. There have been no deviations from the past RST surveillance which has shown that water first appears on top of a major shale then builds height with time. The 24N shale, which forms the base of Zone 2C, is clearly the most prominent unit controlling the lateral progression of the flood front. There continues to be no indications of water running down thief zones or high perm intervals in the middle of sand units. The flood front continues to maintain a sloped aspect indicating that gravity has a strong influence on the process. 4.6.2 2010 Surveillance Plans GCWI Injectors Injection pressures, rates, and temperatures are recorded for each well every day. Pressure-rate plots will be routinely monitored for changes in injectivity of the wells. Observation Well RST’s This program will continue as it has in the past by running RST’s every 6-8 months with the final timing and locations determined based on the results to date. Gravity Survey A gravity survey is not planned for 2010 due to the slowing of the flood front advance. The flood front has slowed enough to be within the uncertainty of the gravity survey. 4.6.3 Plans for Change in Project Operation No changes to the Gas Cap Water Injection plan are expected in 2010. Page 13 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 4.7 Put River Oil Pool On November 22, 2005 the AOGCC ruled in Conservation Order 559 that the Western, Central and Southern Lobes of hydrocarbon bearing Put River sands would be defined as the Put River Pool and that the Northern lobe would be included in the Prudhoe Oil Pool. Exhibit 12 displays all four lobes which are in pressure isolation from each other. Additional technical information was previously supplied with the application which led to Conservation order 559. 2009 Production For the year 2009, all of the production and injection in the Put River Pool occurred in the Southern Lobe. Production from the Put River Oil Pool in 2009 averaged 2325 BOPD for the days the reservoir was in production. The first Put River Pool producer, well 02-23A produced full year in 2009 and a second producer, well 02-27A was put on production into the Put River Pool on August 2nd, 2009. Injection in the Southern Lobe of the Put River averaged 3758 bwpd. Dedicated injector well 01-08Ai was shut in from August 24th to October 23rd 2009 for a planned flow line upgrade. In the month previous to the repair, the injection rate was raised from average 3500 bwpd to 4500 bwpd in preparation for the down time. The 2009 cumulative production for the Put River Oil Pool was 848 MBO and 575 MMscf gas. The full life cumulative production for the Put River Oil Pool through December 31, 2009 is 1.5 MMBO and 2 Bscf gas 2009 Pressures Put River Pressures taken during 2009 are listed in Exhibit 9. The Southern Lobe pressure obtained in 02-23A measured 3440 psi at 8,100’ SSTVD in August 2009. 2010 Surveillance Plan Southern Lobe –Production will continue from wells 02-23A and 02-27A at around 2000 BOPD to achieve a voidage replacement ratio of approximately 1.0. Static pressures will be taken periodically through the year to confirm volumetric calculations. Western Lobe - No 2009 production or surveillance planned. Central Lobe - No 2009 production or surveillance planned. Page 14 2009 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 15 5.0 GAS MOVEMENT SURVEILLANCE The report on gas movement surveillance activities and interpretations provides an overall summary of gas influx movement and summarizes the 2009 gas-monitoring logging program. 5.1 Gas Movement Summary Fieldwide GOC surveillance continues with collection of open-hole and cased-hole logs and monitoring of well performance. In order to monitor gas movement in the reservoir, GOC estimates are made across the field and are based upon the ongoing monitoring program and historical well performance. The central portion of the field, the gravity drainage area (GD) exhibits in some areas almost total influx of the LOC (Light Oil Column). Gas influx is essentially absent in the southern peripheral regions as a result of water and WAG injection in the waterflood areas. It has become difficult in most parts of the field to define a single current GOC as the surface is commonly broken into a series of oil lenses and gas underruns beneath the shales. The reservoir is better characterized by a description of remaining oil targets. The targets within the GD occur within three general regions; the basal Romeo (Zones 1 & 2A) sands, the inter-underrun sands, and oil lenses within the expanded GOC. Production from the Romeo (Zones 1 & 2A) sands has historically been low compared to the more prolific upper zones. This interval has a lower net to gross, lower permeability and more limited sand connectivity than the rest of the reservoir. These factors impede gas expansion into the Romeo. Underruns beneath shales within the Romeo sands are likely to be local. The inter-underrun sands occur throughout the GD and are characterized by one or more underruns or solution gas pockets segmenting the remaining oil pad. Gas underruns are observed beneath the top of the Sadlerochit reservoir, under Zone 4 shales, and the most regional persistent underruns have developed under the mappable floodplain shales of Tango or Zone 2B. Oil within the expanded GOC occurs in lenses above regionally continuous shales. Such lenses have been identified from neutron logs. Many lenses continue to exhibit oil drainage over time, while others appear isolated. Exhibit 8 lists the open and cased-hole neutron logs, as well as RST logs, run in the Prudhoe Bay Unit during the gas-influx reporting period from January 2009 through December 2009. A total of 98 gas-monitoring logs were run in the PBU of which 53 were cased-hole. Exhibit 1-BPBU Well StatisticsWELL COUNT BY FIELD AREAWPWZNWFBEWEFS2EPWZGD2008 AOGCC ReportProducers92 59 62 109 68 478Injectors40 27 18 61 24 47 -WAG531591 -Water Only35 24 14 53 14 13 -Gas00331332009Producers97 61 62 115 77 480Injectors42 29 17 58 29 52 -WAG8110532 -Water Only32 28 7 52 26 17 -Gas2001033Production Well Status in 2009 -Newly Drilled011000 -Sidetracked or Redrilled3215641Gas Injection Well Status in 2009 -Newly Drilled000000 -Sidetracked or Redrilled000000WAG Injection Well Status in 2009 -Newly Drilled000001 -Sidetracked or Redrilled000000Water Injection Well Status in 2009 -Newly Drilled000000 -Sidetracked or Redrilled100000NOTES:(1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year.(2) Project boundaries were simplified in 1998. Wells no longer share project boundaries, but belong to a single project area. (3) EOA GD and WOA GD have been combined. Exhibit 1-C2009 PBU Production/Injection StatisticsWaterflood TotalWPWZNWFBFS-2EPWZEWECumulative Production from WF Start-Up through 12/31/09Oil (MMSTB)492 582 1035 608 48 2766Gas (BCF)1524 1241 4530 2607 220 10122Water (MMSTB)1089 918 3704 1416 99 7227Cumulative Injection from WF Start-Up through 12/31/09Water (MMSTB)1557 1557 5654 1924 93 10785MI (BCF)559 665 952 640 62 2878Cumulative Balance from WF Start-Up through 12/31/08Cum Production (MMRB) 2728 2334 8054 4189 283 17588Cum Injection (MMRB) 1951 1952 6246 2347 120 12616Over/Under (MMRB) -778 -382 -1807 -1842 -162 -4972Cumulative Balance from WF Start-Up through 12/31/09Cum Production (MMRB) 2857 2379 8391 4369 317 18313Cum Injection (MMRB) 1996 1977 6426 2428 139 12967Over/Under (MMRB) -860 -402 -1965 -1941 -178 -5347MI Breakthrough in Producing Wells> 200 mcfd32 23 37 36 12140AVERAGE RATE DATA 2009ProductionOil (MBD)22.1 9.9 27.4 18.9 13.0 91.3Gas (MMSCFD)232.2 66.2 563.8 359.8 66.6 1288.5Water (MBD)127.0 51.1 402.6 157.9 29.7 768.3InjectionWater (MBD)95.8 67.4 440.0 202.6 36.6 842.4Gas (MMSCFD)36.6 0.4 49.1 15.7 18.1 119.8AVERAGE RESERVOIR PRESSURE (psia)GDWPWZNWFBFS-2EPWZEWEPBMGPPrevious report period: 20083244 3298 3269 3317 3299 3626 3299Current report period: 20093248 3308 3271 3348 3310 3663 3315Estimated Annual Change (psi/yr) 4 11 2 32 11 37 16Waterflood Project Area Exhibit 1-EAreal Average Pressure3000310032003300340035003600370038003900Dec-82 Jan-87 Jan-91 Jan-95 Jan-99 Jan-03 Jan-07PSIAPBMGP areal avg PGravity Drainage Exhibit 1-F Areally Weighted Average Pressure Table DATE FS2 EPWZ WPWZ NWFB GD EWE PBMGP Dec-77 3935 4005 4016 3944 3999 3968 Jul-78 3870 3967 3978 3909 3963 3914 Dec-78 3832 3930 3944 3875 3933 3873 Jul-79 3813 3895 3911 3843 3901 3844 Dec-79 3791 3861 3879 3799 3871 3816 Jul-80 3799 3831 3848 3770 3856 3798 Dec-80 3852 3819 3822 3781 3823 3818 Jul-81 3881 3821 3799 3814 3809 3840 Dec-81 3880 3815 3799 3820 3793 3842 Jul-82 3872 3806 3800 3812 3778 3833 Dec-82 3850 3795 3797 3804 3762 3818 Jul-83 3831 3784 3792 3787 3745 3804 Jan-84 3814 3771 3783 3772 3728 3790 Jul-84 3796 3758 3777 3756 3711 3774 Jan-89 3779 3743 3771 3736 3695 3755 Jul-89 3760 3730 3763 3723 3678 3740 Jan-90 3732 3708 3731 3704 3658 3713 Jul-90 3708 3693 3716 3687 3641 3695 Jan-91 3680 3676 3694 3655 3623 3666 Jul-91 3642 3657 3673 3628 3605 3635 Jan-92 3617 3641 3652 3602 3588 3615 Jul-92 3591 3626 3632 3577 3570 3593 Jan-93 3561 3600 3619 3544 3549 3582 Jul-93 3543 3595 3598 3515 3531 3565 Jan-94 3539 3555 3578 3483 3512 3537 Jul-94 3523 3536 3555 3456 3492 3516 Jan-95 3496 3524 3555 3507 3482 3506 Jul-95 3473 3507 3536 3489 3466 3486 Jan-96 3466 3485 3497 3478 3446 3463 Jul-96 3450 3467 3472 3461 3430 3443 Jan-97 3446 3484 3460 3444 3404 3441 Jul-97 3429 3467 3438 3427 3387 3421 Jan-98 3452 3417 3417 3421 3379 3430 Jul-98 3435 3409 3394 3402 3363 3415 Jan-99 3445 3391 3382 3343 3339 3443 Jul-99 3429 3378 3360 3317 3323 3426 Jan-00 3406 3361 3372 3268 3294 3418 Jul-00 3390 3351 3353 3240 3273 3395 Jan-01 3366 3325 3325 3225 3274 3358 Jul-01 3360 3310 3309 3205 3257 3347 Jan-02 3325 3334 3289 3163 3270 3358 Jul-02 3312 3324 3273 3144 3245 3347 Jan-03 3299 3316 3262 3121 3236 3696 3297 Jul-03 3285 3306 3245 3118 3223 3659 3283 Jan-04 3271 3296 3228 3116 3211 3645 3272 Jul-04 3277 3324 3281 3296 3239 3614 3290 Jul-05 3338 3344 3282 3289 3250 3542 3314 Jul-06 3304 3296 3276 3296 3233 3536 3293 Jul-07 3357 3339 3275 3248 3243 3618 3310 Jul-08 3317 3299 3298 3269 3244 3626 3299 Jul-09 3348 3310 3308 3271 3248 3663 3315 Exhibit 1-G2009 Average Monthly CGF MI Rates and CompositionsEOA MI Rate *MMP MWMCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/09 115,692 3,214 32.32 20.72% 32.14% 21.01% 24.68% 0.94% 0.49% 0.02%02/09 124,394 3,223 32.34 21.20% 31.65% 21.11% 25.32% 0.51% 0.19% 0.02%03/09 123,807 3,216 32.35 21.03% 31.73% 21.19% 25.04% 0.68% 0.30% 0.02%04/09 68,418 3,149 32.36 19.45% 33.02% 20.34% 24.40% 1.58% 1.20% 0.02%05/09 89,574 3,055 32.74 19.70% 31.90% 20.49% 24.50% 1.83% 1.56% 0.02%06/09 82,996 3,084 32.57 19.45% 32.33% 20.38% 24.83% 1.63% 1.36% 0.01%07/09 76,108 3,107 32.48 19.24% 32.94% 20.24% 24.12% 1.70% 1.74% 0.02%08/09 10,213 3,179 32.24 19.39% 33.46% 20.00% 24.64% 1.07% 1.44% 0.01%09/09 17,200 3,222 31.97 18.87% 33.91% 20.51% 24.74% 1.18% 0.77% 0.02%10/09 22,916 3,166 32.29 19.49% 33.11% 20.24% 24.73% 1.29% 1.12% 0.02%11/09 26,966 3,153 32.35 19.66% 32.66% 20.48% 25.02% 1.40% 0.75% 0.02%12/09 25,174 3,232 32.27 20.54% 33.17% 19.57% 25.00% 1.18% 0.52% 0.02%Average 64,982 3,166 32.36 19.89% 32.67% 20.46% 24.75% 1.25% 0.96% 0.02%WOAMI Rate *MMP MWMCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/09 136,984 3,222 32.28 20.69% 32.23% 21.02% 24.70% 0.91% 0.44% 0.02%02/09 145,342 3,233 32.29 21.10% 31.82% 21.14% 25.20% 0.52% 0.20% 0.02%03/09 142,999 3,219 32.32 20.98% 31.74% 21.30% 25.00% 0.66% 0.30% 0.02%04/09 99,565 3,136 32.39 19.39% 33.01% 20.24% 24.41% 1.62% 1.31% 0.02%05/09 153,436 3,055 32.73 19.69% 31.92% 20.47% 24.50% 1.83% 1.57% 0.02%06/09 71,484 3,083 32.58 19.46% 32.31% 20.38% 24.88% 1.62% 1.34% 0.02%07/09 55,560 3,151 32.33 19.23% 33.47% 20.00% 24.09% 1.59% 1.59% 0.02%08/09 29,596 3,132 32.19 17.92% 34.67% 19.48% 23.89% 1.67% 2.36% 0.01%09/09 135,560 3,193 32.08 19.03% 33.39% 20.77% 24.79% 1.14% 0.87% 0.02%10/09 171,289 3,174 32.26 19.50% 33.13% 20.30% 24.77% 1.23% 1.05% 0.02%11/09 181,289 3,114 32.49 19.76% 32.12% 20.65% 25.20% 1.45% 0.80% 0.02%12/09 163,842 3,285 32.12 20.58% 33.80% 19.45% 24.34% 1.24% 0.56% 0.02%Average 123,757 3,166 32.34 19.77% 32.81% 20.43% 24.64% 1.30% 1.04% 0.02%* MMP data from 1986 Zick CorrelationAverage Monthly Mole%Average Monthly Mole% Exhibit 2Fieldwide Reservoir BalanceJanuary - December 2009Produced Fluids (MMRB)January February March April May JuneOil 10.8 10.1 11.6 10.4 11.1 8.3Free Gas 206.1 205.3 222.9 202.0 199.9 174.7Water 31.9 29.1 30.8 28.6 32.9 24.1TOTAL 248.7 244.5 265.3 241.0 243.8 207.1Injected Fluids(MMRB)Water 52.8 48.5 52.4 50.1 51.9 39.3Gas 195.2 195.6 212.4 191.7 188.5 166.3TOTAL 247.9 244.1 264.8 241.8 240.5 205.6Net Injection Volumes = Injection - Production (MMRB)TOTAL -0.8 -0.4 -0.5 0.8 -3.4 -1.6Produced Fluids1/1/2009 -(MMRB)July August September October November December 12/31/2009Oil 8.3 7.6 10.5 10.9 10.9 10.9 121.2Free Gas 171.3 140.7 182.4 168.6 198.5 192.1 2,264.4Water 11.9 16.9 30.5 33.5 32.5 36.1 338.8TOTAL 191.5 165.2 223.4 212.9 241.9 239.0 2,724.4Injected Fluids(MMRB)Water 32.4 39.1 39.8 39.8 54.1 55.4 555.8Gas 164.0 136.6 175.3 181.3 188.4 183.2 2,178.6TOTAL 196.4 175.8 215.2 221.2 242.5 238.7 2,734.4Net Injection Volumes = Injection - Production (MMRB)TOTAL 4.9 10.6 -8.2 8.3 0.6 -0.4 10.0 Exhibit 3-A2009 FS-2 Base Flood Area MapFlowing Oil ProducerGas-Lifted Oil ProducerShut-In Oil ProducerActive Water InjectorShut-In Water InjectorActive MI Injector 01-01B01-05B01-081-09A03-0103-0203-0303-0403-0503 0603-07A 03-0803-0903-1003-1103-1203-1303-1403-14A03-1 B03-14BL103 5A03-15AL103-16A03-1703-18A03-1903-20A03-2103-2203-2303-2403-25A03-2603-2703-2803-2903-3003-3103-32A03-32B03-3 A03-33B03 34B03-3503-3603-36A04-0104-01A04-02A04-0304-04A04-05A04-0604-0704-0804-0904-1004-11A04-1304-1404-1504-16A04-1704-1804-1904-19A04-2004-2104-22A04-23A04-2404-2504-2604-2704-2804-29A04-29AL104-3004-304-32A04-3304-33A04-34A04-3504-35A04-3604-3704-3804-3904-4004-41A04-4204-4304-4404-4504-4604-4704-4804-4905-02A05-05B05-13B05-24A0 -32A09-0109-0209-0309-04A09-05A09-060 -07A09-0809-0909-1009-1109-1209-1309-109-1509-15A09-1609-1709-1809-1909-2009-2109-2209-23A09-2409-2509-2609-2709-28A09-2909-3009-31C09-3209-33 09-33A09-34A09-35A09-36C09-3709-3809-3909-4009-4109-42A09-4309-4409-4509-4609-4709-4809-4909-5009-5111-01A11-0211-04A11-05A11-06A11-0711-0811-09A11-1011-1111-1211-13A11-1611-17A11-1811-22AL111-23A11-24A11-25A1 -2611-2711-28A11-2911-31A11-3211-3311-3411-3511-3611-3711-38A12-06A12-3216-0116-0216-0316-04A16-0516-05A16-0616-06A16-06B16-0716-08A16-09A16-10A16-1116-12A16-1316-14A16-14B16-1516-1616-1716-1816-1916-2016-2116-2216-23A16-2416-2516-26A16-27A16-2816-29A16-3016-3117-01A17-03A17-04B17-0517-0617-07A17- 7B17-0817-0917-09A17-10A17-1117-1217-12A17-1417-15A17-1617-2017-2117-22 Exhibit 3-BFS-2 Reservoir BalanceProduced Fluids Cumulative(MMRB)12/31/2008 January February March April May JuneFluid Properties Used Oil 1,345.1 1.206 1.147 1.177 1.279 1.317 1.212 Bo (rb/stb) 1.322Free Gas 3,027.6 15.342 17.044 17.040 17.562 15.900 15.706 Bg (rb/mscf) 0.869Water 3,681.1 15.264 14.006 13.749 14.247 15.192 12.590 *Bw (rb/stb) 1.040TOTAL 8,053.7 31.812 32.197 31.966 33.088 32.409 29.508 Bmi (rb/mscf) 0.700Rs (scf/stb) 615.8Injected Fluids(MMRB)Water 5,619.6 16.150 15.035 14.534 15.164 16.696 14.656Gas 626.9 1.720 1.796 2.203 0.967 1.436 1.228TOTAL 6,246.5 17.870 16.831 16.737 16.130 18.131 15.884Net Injection Volumes = Injection - Production (MMRB)TOTAL -1,618.2 -13.9 -15.4 -15.2 -17.0 -14.3 -13.6Produced FluidsCumulative(MMRB)July August September October November December 12/31/2009Oil 0.289 0.599 1.148 1.259 1.237 1.352 1,358.3Free Gas 3.950 8.211 13.842 13.857 16.091 16.886 3,199.0Water 2.500 5.701 13.900 15.330 14.337 15.999 3,833.9TOTAL 6.739 14.510 28.891 30.445 31.665 34.237 8,391.2Injected Fluids(MMRB)Water 2.856 7.588 15.176 15.756 16.207 17.213 5,786.6Gas 1.265 0.102 0.206 0.497 0.566 0.546 639.5TOTAL 4.122 7.690 15.382 16.254 16.773 17.760 6,426.0Net Injection Volumes = Injection - Production (MMRB)TOTAL -2.6 -6.8 -13.5 -14.2 -14.9 -16.5 -1,965.2 Exhibit 3-CFS-2 Areal Average Reservoir Pressure3000310032003300340035003600370038003900Jan-87 Jan-91 Jan-95 Jan-99 Jan-03 Jan-07Reservoir Pressure @ 8800' SSTVD (psia) Daily RMI< 200 mscf/d=> 200 & < 2000 mscf/d>= 2000 mscf/dExhibit 3-D2009 FS-2 Average Daily RMI Map01-01B01-05B01-081-09A03-0103-0203-0303-0403 503 0603 07A 03-0803 0903-1003-1103-1203-1303-1403-14A03-1 B03-14BL103 5A03-15AL103-16A03 1703-18A03-1903-20A03-2103-2203-2303-2403-25A03-2603-2703-2803-2903-3003-3103-32A03-32B03-3 A03-33B03-34B03-3503-3603-36A04-0104-01A04-02A04-0304-04A04-05A04 0604-0704-0804-0904-1004-11A04-1304 1404-1504-16A04-1704-1804-1904-19A04-2004-2104-22A04-23A04-2404-2504-2604-2704-2804-29A04-29AL104-3004-304-32A04-3304-33A04-34A04-3504-35A04-3604-3704-3804-3904-4004-4104 4204-4304-4404-4504-4604-4704-4804-4905-02A05-05B05-13B05-24A0 -32A09-0109-0209-0309-04A09-05A09-060 -07A09-0809-0909-1009-1109-1209-1309-109-1509-15A09-1609-1709-1809-1909-2009-2109-2209-23A09-2409-2509-2609-2709-28A09-2909-3009-31C09-3209-33 09-33A09-34A09-35A09-36C09-3709-3809-3909-4009-4109-42A09-4309-4409-4509-4609-4709-4809-4909-5009-5111-01A11 0211-04A11- 5A11-06A11-0711-0811-09A11-1011-1111-1211-13A11-1611- 7A11-1811-22AL111-23A11-24A11-25A1 -2611-2711-28A11-2911-31A11-3211-3311-3411-3511-3611-3711-38A12 06A12-3216-0116-0216-0316-04A16-0516-05A16-0616-06A16-06B16-0716-08A16-09A16-10A16-1116-12A16-1316-14A16-14B16-1516-1616-1716-1816 1916-2016-2116-2216-23A16-2416-2516-26A16-27A16-2816-29A16-3016-3117-01A17-03 17-04B17-0517-0617 07A17- 7B17-08 17-0917-09A17-10A17-1117-1217-12A17-1417-15A17-1617-2017-2117-22 01-0201-07A01-1001-1101-1301-15A01-1801-18A01-24A01-2501-26A01-3001-3101-34A03 15AL103-24A06-04A6-06B06-08A06-0906-10A06-1106-12A06-1306-13A06-14A06-14B06-1706-1806 8A07-2412-0112-012-0312-04A12-0512-05A12-05AL112-06A12-07A12-08C12-0912-10A12-1112-1212-12A12-13B12-14A12-14AL112-1512-16A12-1712-1812-1912-20A12-2112-2212-2312-2512-2612-27A12-28A12-2912-3012-3112-3212-3312-3412-3512-3612 713-0113- 2B13-02BL113-0313-03A13-0413-0513-06A13-0713-08A13-0913-1013-1113-1213-13A13-1413-1513-1613-1713-1813-1913-2013-2113-2213-23A13-24A13-2513-2613-27A13-2813-2913-29L113-30A13-30C13-3113-31A13-3213-32A13-3313-3413-3513-3614-01A14-02B14 2C14-05A14-06A14-0714-08A14- 8AL114-09B14-1014-11A14-1214-1314-1414-1514-16A14-17A14-18A14-18B14-1914-2014-21A14-22A14-2314-2414-2514-2614-2714-2814-2914-30A14-3214-3414-3514-3614-3714-3814-3914-40A14-4114-4314-44A17-0217-03A17-04B17-0517-1217-13A17-19AX-03AX-07X-08AX-09BX-15AX-16X-16AFlowing Oil ProducerGas-Lifted Oil ProducerShut-In Oil ProducerActive Water InjectorShut-In Water InjectorActive MI Injector Exhibit 4-A2009 EPWZ Base Flood Area Map Exhibit 4-BEPWZ Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2008 January February March April May JuneOil 789.7 0.804 0.645 0.920 0.880 0.868 0.821 Bo (rb/stb) 1.319Free Gas 1,805.3 10.697 8.592 11.370 10.350 10.236 9.705 Bg (rb/mscf) 0.880Water 1,594.3 4.634 4.131 5.370 5.447 5.912 6.476 Bw (rb/stb) 1.040TOTAL 4,189.3 16.135 13.368 17.660 16.677 17.016 17.002 Bmi (rb/mscf) 0.700Rs (scf/stb) 608.8Injected Fluids(MMRB)Water 1,924.3 5.809 5.964 6.610 6.340 6.764 6.122Gas 422.9 0.791 0.642 0.484 0.470 0.508 0.515TOTAL 2,347.3 6.600 6.606 7.094 6.810 7.272 6.637Net Injection Volumes = Injection - Production (MMRB)TOTAL -1708.4 -9.5 -6.8 -10.6 -9.9 -9.7 -10.4Produced FluidsCumulative(MMRB)July August September October November December 12/31/2009Oil 0.384 0.533 0.727 0.774 0.893 0.846 798.8Free Gas 7.297 7.223 8.427 6.554 9.883 10.616 1,916.2Water 1.936 3.414 5.084 5.784 5.765 5.986 1,654.2TOTAL 9.617 11.170 14.238 13.112 16.541 17.448 4,369.3Injected Fluids(MMRB)Water 5.155 5.890 6.298 6.628 7.355 7.961 2,001.2Gas 0.386 0.119 0.091 0.000 0.000 0.000 426.9TOTAL 5.542 6.009 6.389 6.628 7.355 7.961 2,428.2Net Injection Volumes = Injection - Production (MMRB)TOTAL -4.1 -5.2 -7.8 -6.5 -9.2 -9.5 -1941.1Fluid Properties Used Exhibit 4-CEPWZ Areal Average Reservoir Pressure3000310032003300340035003600370038003900Jan-87 Jan-91 Jan-95 Jan-99 Jan-03 Jan-07Reservoir Pressure @ 8800' SSTVD (psia) Daily RMI< 200 mscf/d>= 200 & < 2000 mscf/d>= 2000 mscf/dExhibit 4-D2009 EPWZ Average Daily RMI Map01-0201-07A01-1001-1101-1301 15A01-1801-18A01-24A01-2501-26A01-3001-3101-34A03-1503 15AL103-24A06-04A6-06B06-08A06-0906-1006-1106-12A06-1306-13A06-14A06-14B06-1706-1806- 8A07-2412-0112-0212 0312-04A12-051 -05A12-05AL112-06A12-07A12-08C12 0912-10A12-1112-1212-12A12-13B12-14A12-14AL112-1512-16A12-1712-181 -1912-20A12-2112-2212-2312-2512-2612-27A12-28A12-2912-3012-3112-3212-3312-3412-3512-3612 713-0113-0 B13-02BL113-0313-03A13-0413-0513-06A13-0713-08A13-0913-1013-1113-1213-13A13-1413-1513-1613-1713-1813-1913-2013-2113-2213-23A13-24A13-2513-2613-27A13-2813-2913-29L113-3013-30C13-313-31A13-3213-32A13-3313-3413-3513-3614-01A14-02B1 2C14-05A14-06A14-0714-08A14-08AL114-09B14-1014-11A14-1214-1314-1414-1514-16A14-17A14-18A14-18B14- 914-2014-21A14-22A14-2314-2414 2514-2614-2714-2814-2914-30A14-3214-3414-3514-3614-3714-3814-3914-40A14-4114-4314-44A17-0217-03A 17-04B17-0517-0617-1217-13A17-19AX-03AX-07X-08AX-09BX-15AX-16X-16A Flowing Oil ProducerGas-Lifted Oil ProducerShut-In Oil ProducerActive Water InjectorShut-In Water InjectorActive MI Injector Exhibit 5-A2009 WPWZ Base Flood Area Map07-2614-06A14-23A14-3714-38A-01AA-02A-03A-04A-05A-05AA-06A-07A-08A-09AA-10A-11A-12A-12AA-13A-14A-15A-16AA-17A-17AA-18AA-19A-20A-21A-22A-23A-24A-25AA 26A-26L1A-27AA-28A-29A-30AA-31AA-32AA-33A-34AA-35A-37A-38A-38L1A-38L2A-39A-40A-41A-42A 42AA-43A-44B-01B-02AB-03BB-06B-09B-10B-10AB-11B 12AB-13AB- 4B-14AB-15B-16AB-17B-18B 19AB-21B-22AB-23AB-2B-25B-26BB-29AB-31B-32AB-33AB-34B-35B-37D-01AD-08AD-16AH-01AH-02AH-06H-09H-10AH-11H-21H-22AH-23AH-24H-31H-32H 34H-37H-37AM-17AN-03P-01P-02AP-03AP-04P-04L1P-05AP-06AP-06BP-08AP-09P-09L1P-10P-11P-12BP-13P-14P-15P-15L1P-16P-17P-18P-18L1P-19P-22P 23P-24P-25P-2 L1P-26U-02AU-03U-04AU-05U-06BU-07U-08AU-09AU-10U-11BU-13U-14U-15BX-01X-02X-03AX-04X-05X-06X-07X-08AX-09BX-10X-11AX-12X-13AX-14AX-15AX-16AX-17X-18X-19BX-19BL1X-20X-20AX-21AX-22AX-23X 24AX-25X-26X-27X-28X-29X-30X 30AX-3131L1X-32X-33X-34X-3X-35L1X-36Y-01BY-02AY-03AY-04Y-05AY-05BY 06AY-07Y-07AY-08AY-09AY-09AL1Y-09AL1-01Y-10Y-10AY-11BY-11CY-12Y-13Y-14BY-15AY-16Y-17BY-18Y-19Y-20AY-20AL1Y-20AL2Y-21AY-23BY-24Y-25Y-25AY-26AY-27Y-28Y-29AY-30Y-30L1Y-3Y- 2Y-32L1Y-33Y-34AY-35AY-36Y-37AY-38 Exhibit 5-BWPWZ Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2008 January February March April May JuneOil 643.6 0.829 0.933 1.181 0.830 1.074 0.400 Bo (rb/stb) 1.318Free Gas 999.7 5.496 5.089 5.321 4.833 5.255 3.381 Bg (rb/mscf) 0.883Water 1,085.0 4.656 4.587 4.679 3.476 4.579 1.451 Bw (rb/stb) 1.040TOTAL 2,728.3 10.981 10.609 11.181 9.139 10.908 5.233 Bmi (rb/mscf) 0.700Rs (scf/stb) 606.5Injected Fluids(MMRB)Water 1,582.9 4.348 3.491 3.788 2.928 3.356 1.670Gas 367.7 0.439 0.427 0.645 0.363 0.774 0.899TOTAL 1,950.6 4.788 3.919 4.432 3.291 4.130 2.569Net Injection Volumes = Injection - Production (MMRB)TOTAL -705.6 -6.2 -6.7 -6.7 -5.8 -6.8 -2.7Produced FluidsCumulative(MMRB)July August September October November December 12/31/2009Oil 0.693 0.568 0.945 1.101 1.023 1.076 654.2Free Gas 3.305 6.378 6.173 6.842 8.335 9.205 1,069.3Water 2.743 2.657 4.593 4.639 4.741 5.415 1,133.2TOTAL 6.742 9.603 11.711 12.582 14.100 15.695 2,856.8Injected Fluids(MMRB)Water 2.040 1.734 2.926 3.426 2.997 3.673 1,619.3Gas 0.397 0.231 0.886 1.705 1.494 1.088 377.0TOTAL 2.437 1.966 3.812 5.132 4.492 4.761 1,996.3Net Injection Volumes = Injection - Production (MMRB)TOTAL -4.3 -7.6 -7.9 -7.5 -9.6 -10.9 -860.4Fluid Properties Used Exhibit 5-CWPWZ Average Reservoir Pressure3000310032003300340035003600370038003900Jan-87 Jan-91 Jan-95 Jan-99 Jan-03 Jan-07Reservoir Pressure @ 8800' SSTVD (psia) 07-2614-06A14-23A14-3714 38A-01AA-02A 3A-04A-05A-05AA-06A-07A-08A-09AA-10A-11A-12A-12AA-13A-14A-15A-16AA-17A-17AA 18AA-19A-20A 21A 22A-23A-24A-25AA 26A-26L1A-27AA-28A-29A 30AA-31AA 32AA-33A-34AA 35A-37A-38A-38L1A-38L2A-39A-40A 41A-4A 42AA-43A-44B 01B-02AB-03BB-06B-09B-10B-10AB-11B 12AB-13AB- 4B-14AB-15B-16AB-17B-1819AB 21B-22AB-23AB-2B-25B-26BB-29AB-31B-32AB-33AB-34B-35B-37D-01AD-08AD-16AH-01AH-02AH-06H-09H-10AH-11H-21H-22AH-23AH-24H-31H-32H 34H-37H-37AM-17AN-03P-01P-02AP-03AP 04P-04L1P-05AP-06AP-06BP-08AP-09P-09L1P-10P-11P-12BP-13P-14P-15P-15L1P-16P-17P-18P-18L1P-19P-22P 23P-24P-25P-2 L1P-26U-02AU-03U-04AU-05U-06BU-07U-08AU-09AU-10U-11BU-13U-14U-15BX-01X-02X-03AX-04X-05X-06X-07X-08AX-09BX-10X-11AX-12X-13AX-14AX 15AX-16AX-1X-18X-19BX-19BL1X-20X-20AX-21AX-22AX-23X 24AX-25X-26X-27X-28X 29X-30X-30AX-3131L1X-32X-33X-34X-3X 35L1X-36Y-01BY-02AY-03AY 04Y-05AY-05BY 06AY-07Y-07AY-08AY-09AY-09AL1Y-09AL1-01Y-10Y-10AY11BY-11CY-12Y-13Y-14BY-15AY-16Y-17BY-18Y-19Y-20AY-20AL1Y-20AL2Y-21AY-23BY-24Y-25Y-25AY-26AY 27Y-28Y-29AY-30Y-30L1Y-3Y-32Y-32L1Y 33Y-34AY-35AY-36Y-37AY-38Daily RMI< 200 mscf/d>= 200 & < 2000 mscf/d>= 2000 mscf/dExhibit 5-D2009 WPWZ Average Daily RMI Map Flowing Oil ProducerGas-Lifted Oil ProducerShut-In Oil ProducerActive Water InjectorShut-In Water InjectorActive MI Injector Exhibit 6-A2009 NWFB Base Flood Area MapF-21F-24F-30F-37F-39F-41F-43F-43L1F-48J-06J-07AJ-26J-28M 01M-03AM-04M-05AM-06AM-07M-08M-09BM-10M-11M-12AM-13AM-14M-15M-1M-18BM-19AM-19BM-20AM-21AM-22M-23M-24AM-25M-26AM-27AM-28M-29AM-30M-31M-32M-33M-34M-38AN-06N-08AN-13N-14AN-15N-17N-18N-19N-23AN-25N-26R-01R-02R-03AR-04R-05AR-06AR-07AR-08R-09AR-10R-11AR-12R-13R-14AR-15AR-16R-17AR-18BR-19AR-20AR-21R-21L1R-21L1-01R-22R-23AR-24R-25AR-26AR-27R-28R-29AR-30R-3 AR-32AR-34R-35R 39AR-40R-41S-01BS-02AS-04S-05AS-06S-07AS-08BS-09S-11BS-12AS-13S-14AS-15S-16S-17CS-18AS-19S-20AS-21S-22BS-23S-24BS-25AS-26S-27BS-28BS-29AS-29AL1S-30S-31AS-32S-33S-34S-35S-36S-37S-38S-40AS-41S-41L1S-42S-43S-43L1S-44S-44L1T-01T-07U-12A Exhibit 6-BNWFB Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2008 January February March April May JuneOil 726.7 0.422 0.366 0.561 0.300 0.495 0.079 Bo (rb/stb) 1.316Free Gas 718.9 1.654 1.556 1.667 1.411 1.822 0.260 Bg (rb/mscf) 0.890Water 888.5 2.060 1.740 2.025 1.044 2.113 0.313 Bw (rb/stb) 1.040TOTAL 2,334.1 4.137 3.662 4.253 2.755 4.430 0.651 Bmi (rb/mscf) 0.700Rs (scf/stb) 601.6Injected Fluids(MMRB)Water 1,517.0 2.598 2.531 3.023 2.202 2.925 0.412Gas 418.3 0.000 0.000 0.001 0.006 0.030 0.006TOTAL 1,951.8 2.598 2.531 3.023 2.208 2.954 0.418Net Injection Volumes = Injection - Production (MMRB)TOTAL -360.5 -1.5 -1.1 -1.2 -0.5 -1.5 -0.2Produced FluidsCumulative(MMRB)July August September October November December 12/31/2009Oil 0.331 0.252 0.404 0.479 0.485 0.557 731.5Free Gas 2.003 1.449 2.372 1.486 3.560 1.949 740.1Water 1.205 0.804 1.608 1.926 2.004 2.568 907.9TOTAL 3.539 2.506 4.383 3.891 6.049 5.074 2,379.5Injected Fluids(MMRB)Water 1.936 1.618 2.109 2.233 1.682 2.311 1,539.6Gas 0.005 0.002 0.000 0.000 0.009 0.051 418.4TOTAL 1.940 1.620 2.109 2.233 1.691 2.362 1,977.5Net Injection Volumes = Injection - Production (MMRB)TOTAL -1.6 -0.9 -2.3 -1.7 -4.4 -2.7 -402.0Fluid Properties Exhibit 6-CNWFB Areal Average Reservoir Pressure3000310032003300340035003600370038003900Jan-87 Jan-91 Jan-95 Jan-99 Jan-03 Jan-07Reservoir Pressure @ 8800' SSTVD (psia) Exhibit 6-D2009 NWFB Average Daily RMI MapDaily RMI< 200 mscf/d>= 200 & < 2000 mscf/d>= 2000 mscf/dF-21F-24F-30F-37F-39F-41F-43F-43L1F-48J-06J-07AJ-26J-28M 01M-03AM-04M-05AM-06AM-07M-08M-09BM-10M-11M-12AM-13AM-14M-15M-1M-18BM-19AM-19BM-20AM-21AM-22M-23M-24AM-25M-26AM-27AM-28M-29AM-30M-31M-32M-33M-34M-38AN-06N-08AN-13N-14AN-15N-17N 18N-19N-23AN-25N-26R-01R-02R-03AR-04R-05AR-06AR-07AR-08R-09AR-10R-11AR-12R-13R-14AR-15AR-16R-17AR-18BR-19AR-20AR 21R-21L1R-21L1-01R-22R 23AR-24R-25AR-26AR-27R-28R-29AR-30R-3 AR-32AR-34R-35R 39AR-40R-41S-01BS-02AS-04S-05AS-06S-07AS-08BS-09S-11BS-12AS-13S-14AS-15S-16S-17CS-18AS-19S-20AS-21S-22BS-23S-24BS-25AS-26S-27BS-28BS-29AS-29AL1S-30S-31AS-32S-33S-34S-35S-36S-37S-38S-40AS-41S-41L1S-42S-43S-43L1S-44S-44L1T-01T-07U-12A Exhibit 7-A2009 EWE Base Flood Area MapFlowing Oil ProducerGas-Lifted Oil ProducerShut-In Oil ProducerActive Water InjectorShut-In Water InjectorActive MI Injector L-01L-02AL-03L-04L-50U-05AU-06BV-01V-02V-03V-04V-05V-07W-01AW-02AW-03AW-04W-05AW-06AW-07W-07AW-08AW-09AW-10AW-11W-12AW-15W-15AW-16AW-17AW-18W-19AW-19AL1W-20W-21AW-22W-23AW-24W-25W-25AW 26AW-27AW-29W-30W-31W-31AW-32AW-34AW-35W-36W-37AW-38AW-39W-39AW-40W-42W-44W-45W-56Z-01Z-01AZ-01BZ-02AZ-03Z-04AZ-05Z-06Z-07AZ-08AZ-09Z-09AZ-10Z-11Z-11AZ-12Z-13AZ-14AZ-14BZ-15Z-16Z-17Z-18Z-19Z-19AZ-20Z-21AZ-22BZ-23BZ-24Z-25Z-26Z-26AZ-27Z-28Z-29Z-30Z-30AZ-31Z-32BZ-32BL1Z-33AZ-35Z-38Z-39Z-39AZ-46A Exhibit 7-BEWE Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2008 January February March April May JuneOil 57.1 0.608 0.508 0.499 0.347 0.606 0.105 Bo (rb/stb) 1.346Free Gas 134.8 1.368 1.274 1.351 1.275 1.594 0.270 Bg (rb/mscf) 0.793Water 90.8 1.011 0.830 0.824 0.576 1.093 0.181 Bw (rb/stb) 1.040TOTAL 282.6 2.986 2.612 2.674 2.198 3.293 0.555 Bmi (rb/mscf) 0.700Rs (scf/stb) 673.6Injected Fluids(MMRB)Water 75.6 1.373 1.064 1.136 1.321 1.743 0.339Gas 38.3 0.512 0.463 0.305 0.338 0.228 0.021TOTAL 120.3 1.885 1.527 1.441 1.659 1.972 0.360Net Injection Volumes = Injection - Production (MMRB)TOTAL -154.0 -1.1 -1.1 -1.2 -0.5 -1.3 -0.2Produced FluidsCumulative(MMRB)July August September October November December 12/31/2009Oil 0.380 0.587 0.638 0.789 0.663 0.671 63.5Free Gas 0.831 1.570 1.758 1.402 1.644 2.038 151.2Water 0.576 0.844 1.214 1.490 1.232 1.388 102.0TOTAL 1.788 3.000 3.611 3.680 3.540 4.097 316.7Injected Fluids(MMRB)Water 0.619 0.703 1.285 1.222 1.346 1.732 87.7Gas 0.072 0.078 0.488 0.517 0.850 0.745 42.9TOTAL 0.692 0.781 1.774 1.739 2.196 2.476 138.8Net Injection Volumes = Injection - Production (MMRB)TOTAL -1.1 -2.2 -1.8 -1.9 -1.3 -1.6 -177.9Fluid Properties Used L-01L-02AL-03L-04L-50U-05AU-06BV-01V-02V-03V-04V-05V-07W 01AW-02AW-03AW-04W-05AW-06AW-07W-07AW-08AW-09AW-10AW-11W-12AW-15W-15AW-16AW-17AW-18W-19AW-19AL1W-20W-21AW-22W-23AW-24W-25W-25AW 26AW 27AW-29W-30W-31W-31AW-32AW-34AW-35W-36W-37AW-38AW-39W-39AW-40W-42W-44W-45W-56Z-01Z 01AZ-01BZ-02AZ-03Z-04AZ-05Z-06Z-07AZ-08AZ 09Z-09AZ-10Z-11Z-11AZ-12Z-13AZ-14AZ-14BZ-15Z-16Z-17Z-18Z-19Z-19AZ-20Z-21AZ-22BZ-23BZ-24Z-25Z-26Z-26AZ 27Z-28Z-29Z-30Z-30AZ-31Z-32BZ-32BL1Z-33AZ-35Z-38Z-39Z-39AZ 46AExhibit 7-C2009 EWE Average Daily RMI MapDaily RMI< 200 mscf/d>= 200 & < 2000 mscf/d>= 2000 mscf/d Exhibit 8 2009 Wells Surveyed for Gas Movement Well Log Date OH / CH GOC (MD)Well Log Date OH / CH GOC (MD) 01-05B 1/18/09 OH Sag-na 01-10 8/11/09 CH 9488 01-18A 9/1/09 OH Sag-na 01-29 8/12/09 CH 9320 01-19B 12/3/09 OH 10310 02-13B 3/25/09 CH 9800 01-28A 12/18/09 OH 10094 04-21 10/27/09 CH 12705 02-33B 6/8/09 OH 10566 04-26 9/26/09 CH 10596-10720 03-14B 4/14/09 OH no GOC 06-04A 8/23/09 CH 9144 03-14BL1 4/14/09 OH no GOC 07-10A 5/25/09 CH 10485 03-32B 3/8/09 OH -8575 07-19A 12/25/09 CH 11464 04-33A 9/24/09 OH no GOC 07-21 9/17/09 CH 9094 04-35A 5/14/09 OH no GOC 07-26 12/8/09 CH 10728 06-14B 4/4/09 OH no GOC 11-10 11/1/09 CH 11200 06-18A 10/12/09 OH 11554 11-18 3/2/09 CH 9240 07-02B 2/14/09 OH 11068 11-27 11/5/09 CH 11760 07-14C 8/5/09 OH 11348 12-01 6/2/09 CH 10808 07-20B 3/2/09 OH 10779 12-07A 5/17/09 CH no GOC 07-29D 3/19/09 OH 11229 15-15C 3/15/09 CH 10961 09-33A 4/4/09 OH no GOC 15-15C 1/1/09 CH 10961 12-05AL1 10/2/09 OH Sag-na 15-34A 4/19/09 CH 11240 13-03A 7/15/09 OH no GOC 15-42B 8/3/09 CH 9830 14-23A 5/16/09 OH Sag-na 15-49B 7/13/09 CH 10036 15-29B 5/30/09 OH 12445 18-02B 8/17/09 CH 10728 18-29C 6/6/09 OH 12708 18-11A 11/6/09 CH 12404 A-44 4/26/09 OH 12547 18-15B 10/31/09 CH 9266 B-10A 2/25/09 OH 10836 18-18B 6/7/09 CH 11175 C-12B 9/21/09 OH 11907 18-26B 4/1/09 CH 9961 C-15A 6/27/09 OH 9710 A-04 7/7/09 CH 10762 C-18B 8/12/09 OH 12863 B-14A 9/1/09 CH 11975 D-16A 9/7/09 OH 9911 B-16A 8/3/09 CH 11408 E-05B 3/26/09 OH 9840 C-03B 5/5/09 CH 10091 E-34L1 2/8/09 OH 9954 C-10A 12/28/09 CH 11089 E-36A 1/14/09 OH 9912 D-14A 11/15/09 CH 9567 F-18A 3/20/09 OH Sag-na D-24 9/27/09 CH 10824 F-19A 2/17/09 OH Sag-na D-28B 10/2/09 CH 10524 F-33A 1/29/09 OH 11269 E-09C 11/21/09 CH 10802 F-45B 6/10/09 OH 9452 E-36A 5/17/09 CH 9912 G-14B 7/24/09 OH 9650 F-03A 8/29/09 CH no pick-na G-16A 39982 OH 9934 F-08A 7/1/09 CH 11200 G-31B 39933 OH 9057 F-15A 9/3/09 CH 9484 H-05B 40109 OH 11441 F-45A 4/16/09 CH use F-45B-na H-13A 39982 OH 9333 G-01A 4/1/09 CH 9978 J-05C 39845 OH Sag-na H-14B 2/1/09 CH 10100 J-05CL1 39845 OH Sag-na H-19B 5/5/09 CH 11601 M-19B 39842 OH no GOC H-29A 5/19/09 CH 9490 Q-04B 40123 OH 9332 J-09A 3/22/09 CH 9809 R-41 39817 OH no GOC J-20B 39915 CH 11958 K-06B 39841 CH 9231 K-16AL2 39822 CH 9860 L2-07A 40115 CH 11228 L2-13A 39980 CH 10383 L2-18A 40115 CH 11768 R-27 39981 CH 9469 W-06A 39949 CH 13090 Z-21A 39868 CH 10820 OH - Open Hole Log CH - Cased Hole Log Exhibit 92009 Prudhoe1. Operator:2. Address:BP Exploration (Alaska) Inc.P.O. Box 196612, 900 E. Benson Blvd., Anchorage, AK 99519-66123. Unit or Lease Name:6. Oil Gravity:Prudhoe Bay Unit0.9 SG/27 API8. Well Name and Number:9. API Number 50XXXXXXXXXXXX NO DASHES10. Type See Instructions11. AOGCC Pool Code12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date15. Shut-In Time, Hours16. Press. Surv. Type (see instructions for codes)17. B.H. Temp.18. Depth Tool TVDSS19. Final Observed Pressure at Tool Depth20. Datum TVDSS (input)21. Pressure Gradient, psi/ft.22. Pressure at Datum (cal)01-02 50029200530000 O 6401508677-8686, 8742-8752, 8766-8793, 8803-8830, 8849-8877, 8886-8915, 8925-8955, 8955-8956, 8956-8968, 8968-8969, 8983-8984, 8984-8999, 8999-90009/20/2009 484 SBHP 193 8,800 3,2718,800 0.30 3,26701-07A 50029201570100O 6401508761-8789, 8794-8815, 8818-8826, 8831-8844, 8874-88927/6/2009 617 SBHP 201 8800.17 32818800 0.42 3,28001-13 50029202700000O 6401508811-8837, 8854-8857, 8857-8863, 8863-8866, 8866-8877, 8877-8880, 8880-8886, 8886-8891, 8891-8892, 8892-8897, 8928-8945, 9110-9144, 9152-9167, 9179-9203, 9215-92642/16/2009 568 SBHP 200 8800.19 32678800 0.10 3,26602-06B 50029200860200O 6401508946-8948, 8948-8953, 8990-899811/24/2009 10897 SBHP 203 8800.03 32018800 0.41 3,20102-27A 50029219940100O 6401508143-81628/31/2009 126 SBHP 181 8199.74 31208800 0.35 3,33503-08 50029202310000O 6401508636-8662, 8743-8776, 8778-8790, 8791-8794, 8803-8820, 8820-8824, 8826-8835, 8842-8850, 8859-8863, 8892-8893, 8893-8896, 8896-8901, 8901-8909, 8909-8923, 8934-8949, 8949-89515/15/2009 7271 SBHP 189 8599.61 31878800 0.30 3,24703-09 50029203620000O 6401508602-8605, 8605-8606, 8606-8615, 8618-8628, 8628-8632, 8643-86537/29/2009 554.5 SBHP 178 8595.85 32418800 0.11 3,25803-28 50029211140000O 6401508644-8648, 8648-8651, 8658-8661, 8661-8665, 8665-8666, 8666-8670, 8670-8671, 8684-8689, 8689-86987/12/2009 130 SBHP 182 8691.79 32548800 0.42 3,29903-34B 50029211320200O 6401508676-86994/23/2009 2075 SBHP 187 8600.02 31898800 0.43 3,27504-02A 50029200880100O 6401508611-8627, 8637-8641, 8647-8651, 8657-8667, 8746-8762, 8777-87979/11/2009 29.63 SBHP 181 8800.22 32898800 0.28 3,28904-03 50029200920000O 6401508597-8598, 8598-8603, 8616-8617, 8617-8619, 8619-8634, 8634-8634, 8634-8639, 8639-8646, 8646-8650, 8650-8650, 8664-8673, 8681-8688, 8757-8776, 8804-8839, 8852-8862, 8862-8871, 8871-8885, 8892-8897, 8897-891311/6/2009 330 SBHP 183 8799.7 33418800 0.43 3,34104-22A 50029214540100O 6401508681-8673, 8669-8663, 8660-8659, 8658-86427/7/2009 6428 SBHP 165 8600.17 33288800 0.43 3,41305-02A 50029201440100O 6401508814-87837/28/2009 265 SBHP 178 8699.68 32368800 0.29 3,26505-09A 50029202540100O 6401508897-8887, 8886-8891, 8893-8940, 8939-89341/1/2009 237 SBHP 188 8800.22 32438800 0.33 3,24305-10C 50029202630300O 6401508938-8938, 8937-8934, 8933-8933, 8932-8929, 8927-8926, 8923-8916, 8913-89045/27/2009 384 SBHP 186 8799.89 31668800 0.34 3,16605-25B 50029219880200O 6401508961-8967, 8967-8972, 8974-8979, 8972-8959, 8952-8956, 8955-8969, 8971-8973, 8974-8976, 8978-89726/12/2009 170 SBHP 182.5 8700.7 32508800 0.44 3,29306-04A 50029201790100O 6401508831-8845, 8845-88548/19/2009 263 SBHP 206 8800.18 32588800 0.42 3,25807-06B 50029202940200O 6401508884-8890, 8967-8970, 8969-89666/26/2009 654 SBHP 198.7 8799.76 32008800 0.08 3,20007-12 50029203370000O 6401508902-8905, 8905-8907, 8907-8912, 8930-8941, 8951-8952, 8952-8957, 8957-8961, 8961-8965, 8965-8981, 8981-8982, 8982-89857/10/2009 6100 SBHP 210 8800.51 32408800 0.34 3,23907-28AL1 50029217706000O 6401508954-8957, 8948-8945, 8944-8941, 8936-8939, 8939-8929, 8929-89142/14/2009 29.06 SBHP 204 8800.1 32498800 0.08 3,24909-03 50029202090000O 6401508636-8645, 8645-8660, 8660-8688, 8688-8693, 8703-8705, 8714-8716, 8731-8732, 8732-8742, 8742-8744, 8758-8766, 8766-8786, 8786-8787, 8797-8800, 8800-88195/28/2009 2372 SBHP 190 8699.61 32808800 0.29 3,30909-16 50029202570000WI 6401508595-8631, 8631-8638, 8638-8645, 8645-86667/13/2009 151 SBHP 146 8600.28 32058800 0.45 3,29509-28A 50029212920100O 6401508560-8570, 8574-8587, 8594-8597, 8597-8605, 8631-8632, 8632-8644, 8644-8657, 8657-8658, 8676-8679, 8679-8683, 8822-8836, 8866-8875, 8960-90113/14/20091513 SBHP 163 8800.17 33308800 0.44 3,33009-35A 50029213140100O 6401508662-8668, 8668-8674, 8674-8678, 8679-8682, 8682-86945/28/2009 6646 SBHP 191 8800.13 33668800 0.45 3,36509-36C 50029214290300WI 6401508678-8683, 8683-8688, 8780-8785, 8819-8830, 8836-8844, 8862-88787/13/2009 43391 SBHP 156 8800.07 33508800 0.44 3,35011-04A 50029204800100O 6401508757-8773, 8785-8795, 8805-8816, 8816-88256/3/2009 6341 SBHP 174 8799.72 32778800 0.43 3,27711-10 50029213940000WI 6401508652-8667, 8667-86819/9/2009 31846 SBHP 120 8600.32 32638800 0.43 3,34811-12 50029212120000O 6401508629-8633, 8768-8787, 8810-8823, 8844-8852, 8883-8901, 8912-8917, 8917-8918, 8928-8990 7/16/2009 227 SBHP 186 8799.76 32788800 0.08 3,27811-13A 50029212290100O 6401508652-8657, 8699-8707, 8736-8744, 8817-8833, 8838-8843, 8854-88707/16/2009 240 SBHP 179 8799.77 3294.88800 0.24 3,29511-17A 50029215980100O 6401508669-86746/13/2009 1112 SBHP 182 8699.96 32888800 0.23 3,31012-03 50029203770000O 6401508682-8690, 8690-8702, 8702-8707, 8784-8804, 8804-8814, 8821-8858, 8878-8917, 8927-8940, 8994-89966/15/2009 320 SBHP 190 8800.34 33558800 0.17 3,35512-07A 50029204090100O 6401508712-8727, 8754-8760, 8804-8821, 8821-8828, 8828-88385/19/2009 72 SBHP 154 8799.98 32878800 0.44 3,28712-23 50029211050000WI 6401508722-8745, 8821-8861, 8873-8913, 8927-8965, 8965-89855/30/2009 18244 SBHP 116 8800.49 32588800 0.40 3,25812-37 50029233980000O 6401508658-8675, 8762-8774, 8785-8795, 8829-8834, 8845-8852, 8856-8859, 8903-8912, 8920-8926 1/4/2009SBHP 202 8800.15 33118800 0.43 3,31013-24A 50029207390100 WAG 6401508847-8849, 8844-8843, 8844-88454/21/2009 2218 SBHP 153 8800.03 32588800 0.45 3,25814-11A 50029205290100O 6401508803-8918, 8935-88384/21/2009 3303 SBHP 228 8799.73 32968800 0.42 3,29614-24 50029209700000O 6401508587-8596, 8767-8776, 8793-8802, 8804-88137/29/2009 545 SBHP 214 8727.63 32348800 0.42 3,26414-28 50029207080000O 6401508781-8786, 8786-8788, 8788-8796, 8806-8829, 8842-8848, 8879-8899, 8914-8934, 8935-8945 6/30/2009 31813 SBHP 222 8800.17 32838800 0.42 3,28214-41 50029222900000O 6401508840-8845, 8845-8863, 8866-8874, 8887-8896, 8970-89896/30/2009 104 SBHP 218 8799.91 32668800 0.43 3,26614-43 50029222960000O 6401508788-8799, 8811-8826, 8830-88347/12/2009 148 SBHP 218 8799.96 32698800 0.43 3,26914-44A 50029225730100O 6401508982-8963, 8968-8969, 8973-899210/7/2009 230 SBHP 220 8699.97 32748800 0.43 3,31615-15C 50029206910300O 6401508866-8865, 8861-8861, 8864-8864, 8864-88618/7/2009 2987 SBHP 188 8700.08 32288800 0.32 3,26015-18A 50029222740100O 6401508747-8739, 8743-874811/3/2009 166 SICP 186 8699.83 32688800 0.36 3,30415-30A 50029222820100O 6401508718-8717, 8714-8708, 8710-87098/8/2009 1151 SBHP 178 8599.96 32788800 0.35 3,348RESERVOIR PRESSURE REPORT7. Gas Gravity:Prudhoe Bay Field, Prudhoe Oil Pool 8800 TVDss0.854. Field and Pool:5. Datum Reference:Page 20 of 31 Exhibit 92009 Prudhoe1. Operator:2. Address:BP Exploration (Alaska) Inc.P.O. Box 196612, 900 E. Benson Blvd., Anchorage, AK 99519-66123. Unit or Lease Name:6. Oil Gravity:Prudhoe Bay Unit0.9 SG/27 API8. Well Name and Number:9. API Number 50XXXXXXXXXXXX NO DASHES10. Type See Instructions11. AOGCC Pool Code12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date15. Shut-In Time, Hours16. Press. Surv. Type (see instructions for codes)17. B.H. Temp.18. Depth Tool TVDSS19. Final Observed Pressure at Tool Depth20. Datum TVDSS (input)21. Pressure Gradient, psi/ft.22. Pressure at Datum (cal)RESERVOIR PRESSURE REPORT7. Gas Gravity:Prudhoe Bay Field, Prudhoe Oil Pool 8800 TVDss0.854. Field and Pool:5. Datum Reference:16-05A 50029205740100 WAG 6401509001-8999, 8998-8979, 8960-8958, 8952-8951, 8948-8946, 8935-8935, 8933-8933, 8933-8934, 8934-8935, 8944-8945, 8953-8954, 8954-8956, 8956-8957, 8974-8974, 8974-8978, 8978-89786/6/2009 19921 SBHP 170 8799.74 35058800 0.44 3,50516-07 50029214300000O 6401508731-8749, 8759-8762, 8772-8778, 8803-8810, 8821-8847, 8847-8865, 8865-8883, 8892-8904, 8904-8921, 8921-8944, 8950-8959, 8959-896812/6/2009 307 SBHP 187 8799.57 37238800 0.43 3,72316-11 50029205160000WI 6401508852-8869, 8874-8884, 8894-8924, 8940-8970, 9011-9011, 9011-9012, 9012-9013, 9013-9014, 9014-9015, 9015-9016, 9016-9017, 9017-9018, 9018-9019, 9019-9020, 9020-9021, 9021-9022, 9022-90237/14/2009 188 SBHP 149 8800.22 38888800 0.50 3,88816-15 50029214740000O 6401508753-8763, 8767-8782, 8785-8797, 8799-8809, 8817-8855, 8887-8899, 8899-8903, 8903-8904, 8911-8915, 8915-89287/14/2009 190 SBHP 188 8799.92 34208800 0.43 3,42016-20 50029214930000O 6401508755-8761, 8761-8814, 8814-8820, 8856-8870, 8880-88877/17/2009 247.3 SBHP 184 8800.01 3256.88800 0.30 3,25716-29A 50029222720100O 6401508825-8841, 8841-8847, 8923-8930, 8930-8936, 8936-8943, 8950-89606/7/2009 16329 SBHP 201 8800.06 36828800 0.32 3,68216-30 50029222810000O 6401508918-8929, 8929-8941, 8957-8969, 8993-8995, 8995-8999, 8999-900112/8/2009 359 SBHP 191 8799.89 32708800 0.44 3,27017-01A 50029204760100O 6401508812-8996, 9001-89756/11/2009 1564 SBHP 202 8799.84 37278800 0.42 3,72717-02 50029204860000O 6401508748-8757, 8850-8859, 8866-8871, 8881-8889, 8895-8920, 8932-8949, 8963-89818/13/2009 894 SBHP 202.3 8799.94 3316.48800 0.43 3,31617-04B 50029204980200O 6401508827-89548/12/2009 47 SBHP 203.7 8800.11 33918800 0.44 3,39017-07B 50029205960200O 6401508786-8794, 8801-8808, 8816-8838, 8929-8946, 8952-8963, 8973-89806/11/2009 4387 SBHP 190 8600.2 31708800 0.45 3,25917-08 50029206020000 WAG 6401508764-8786, 8867-8894, 8913-8940, 8953-8963, 8963-8987, 9086-9105, 9165-9185, 9188-9210 2/24/2009 2563 SBHP 154 8799.93 35028800 0.43 3,50217-20 50029223000000O 6401508734-8752, 8830-8843, 8843-8849, 8869-8882, 8979-8989, 9002-90167/30/2009 573 SBHP 196 8773.13 34618800 0.43 3,47218-04B 50029208750200O 6401508748-8773, 8773-8788, 8788-8810, 8810-8816, 8825-88438/6/2009 11919 SBHP 189 8800.21 33068800 0.36 3,30518-12B 50029216150200O 6401508714-8695, 8693-8687, 8684-8683, 8681-86818/5/2009 8119 SBHP 174 8199.76 32218800 0.09 3,275A-12A 50029205150200O 6401508769-8750, 8748-8727, 8717-8703, 8698-8689, 8685-8718, 8729-87607/4/2009 236 SBHP 217 8700.53 32268800 0.42 3,268A-2050029207090000O 6401508738-8751, 8836-8851, 8851-8869, 8869-8872, 8880-8882, 8882-8883, 8883-8889, 8896-8925, 8925-8927, 8931-8944, 8951-89587/7/2009 1165 SBHP 222.5 8749.89 3334.88800 0.42 3,355A-2350029207160000O 6401508760-8761, 8761-88027/3/2009 221 SBHP 219.5 8800.11 32658800 0.21 3,265A-4050029223370000O 6401508743-8759, 8834-8870, 8949-89648/7/2009 236 SBHP 225 8800.11 33158800 0.44 3,315AGI-01 50029223070000GI 6401507026-7029, 8066-8078, 8089-8252, 8262-8270, 8310-8352, 8366-8391, 8398-8423, 8432-8448 12/13/2009 2763 SBHP 132.1 8254.91 3393.18800 0.15 3,478B-0450029200720000O 6401508850-8855, 8855-8857, 8857-8858, 8858-8862, 8892-8901, 8901-8907, 8907-8913, 8913-8914, 8914-8915, 8915-8918, 8918-89246/15/2009 8983 SBHP 208 8800.16 32558800 0.07 3,254B-0650029202790000O 6401508852-8872, 8872-8880, 8880-8882, 8898-8900, 8900-8911, 8911-8913, 8913-8915, 8928-8930, 8930-8938, 8938-8940, 8940-8948, 8948-8949, 8949-8958, 8958-89596/15/2009 3254 SBHP 214 8800.2 32388800 0.33 3,238B-12A 50029203320100O 6401508576-85936/15/2009 1368 SBHP 215 8800.16 32548800 0.15 3,254B-13A 50029203410100WI 6401508779-8780, 8783-8784, 8820-8826, 8837-88448/1/2009 13933 SBHP 169 8799.85 32908800 0.31 3,290C-03B 50029201240200O 6401508938-8942, 8942-8945, 8947-89504/16/2009 3139 SBHP 204 8800.2 32338800 0.31 3,232C-25B 50029208190200O 6401508968-89617/8/2009 332.38 SBHP 197 8800.09 32198800 0.33 3,219D-07B 50029201620200O 6401508960-8964, 8964-8966, 8966-8967, 8969-8968, 8967-8967, 8963-8964, 8965-8963, 8963-8961, 8961-8963, 8963-8964, 8964-8964, 8964-8964, 8964-89686/19/2009 2072 SBHP 207 8899.95 32088800 0.07 3,200D-2050029207800000O 6401508839-8856, 8870-8880, 8880-8883, 8883-8887, 8894-8904, 8904-8907, 8907-8916, 8925-8939, 8939-89416/19/2009 2509 SBHP 213 8800.06 32028800 0.19 3,202E-03A 50029201810100O 6401508991-8995, 8999-90005/27/2009 742 SBHP 185 8800 32918800 0.33 3,291E-04A 50029201840100O 6401508984-8984, 8982-8982, 8988-8990, 8990-89884/20/2009 593 SBHP 195 8800.03 32248800 0.35 3,223E-21B 50029205770200O 6401508934-8944, 8945-8951, 8955-8951, 8944-8939, 8940-8941, 8942-89425/4/2009 284 SBHP 192 8799.55 32468800 0.07 3,246E-24B 50029217690200O 6401508838-8851, 8859-8866, 8867-8867, 8859-8851, 8844-8848, 8848-8848, 8851-8849, 8842-8832, 8833-8830, 8835-8836, 8837-88404/20/2009 601 SBHP 197 8800.11 32538800 0.09 3,253F-18A 50029206360100O 6401508672-87344/8/2009SBHP 190 8600.13 32438800 0.41 3,325G-30B 50029216130200O 6401508892-8906, 8925-8939, 8955-8961, 8961-8958, 8953-8964, 8964-8957, 8957-8958, 8959-8958, 8957-8956, 8962-8955, 8955-89599/4/2009 1091 SBHP 200 8799.9 31968800 0.08 3,196H-05A 50029201060100O 6401508955-8954, 8953-8952, 8950-89442/15/2009 2070 SBHP 224 8800.18 31248800 0.44 3,124H-07A 50029202420100O 6401508864-8867, 8884-8897, 8897-89017/1/2009 617 SBHP 216 8800.21 31928800 0.34 3,192H-0850029202470000O 6401508639-8643, 8882-8886, 8886-8888, 8888-8892, 8892-8902, 8902-8905, 8905-8912, 8912-8913, 8913-8914, 8914-8922, 8922-89317/3/2009 670 SBHP 217 8799.76 32168800 0.30 3,216H-1150029204850000O 6401508672-8682, 8691-8726, 8739-8776, 8786-8796, 8817-88347/4/2009 676 SBHP 225 8699.96 32078800 0.42 3,249H-19B 50029208830200O 6401508935-8937, 8937-8936, 8936-8936, 8934-89367/3/2009 662 SBHP 211.7 8699.85 32098800 0.09 3,217H-24A 50029215120100O 6401508771-8736, 8734-8727, 8722-8697, 8702-88057/3/2009 658 SBHP 222 8699.92 31908800 0.43 3,233H-2850029218060000O 6401508787-8790, 8790-8791, 8791-8792, 8856-8857, 8908-8914, 8914-8926, 8926-8934, 8937-8948 7/3/2009 72001 SBHP 208 8599.79 31778800 0.29 3,235H-37A 50029227720100O 6401508867-8883, 8889-8882, 8883-89034/17/2009 15457 SBHP 232 8823.74 31878800 0.32 3,179J-10A 50029204440100O 6401508954-8954, 8955-89556/14/2009 2701 SBHP 205 8800.13 31488800 0.36 3,147J-1350029204970000O 6401508816-8835, 8843-8860, 8868-8893, 8901-8927, 8931-8939, 8939-8952, 8952-89545/3/2009 15004 SBHP 209 8799.84 32208800 0.31 3,220J-2850029217210000O 6401508874-8881, 8902-8931, 8931-8948, 8948-89557/9/2009 792 SBHP 208 8799.95 32178800 0.26 3,217Page 21 of 31 Exhibit 92009 Prudhoe1. Operator:2. Address:BP Exploration (Alaska) Inc.P.O. Box 196612, 900 E. Benson Blvd., Anchorage, AK 99519-66123. Unit or Lease Name:6. Oil Gravity:Prudhoe Bay Unit0.9 SG/27 API8. Well Name and Number:9. API Number 50XXXXXXXXXXXX NO DASHES10. Type See Instructions11. AOGCC Pool Code12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date15. Shut-In Time, Hours16. Press. Surv. Type (see instructions for codes)17. B.H. Temp.18. Depth Tool TVDSS19. Final Observed Pressure at Tool Depth20. Datum TVDSS (input)21. Pressure Gradient, psi/ft.22. Pressure at Datum (cal)RESERVOIR PRESSURE REPORT7. Gas Gravity:Prudhoe Bay Field, Prudhoe Oil Pool 8800 TVDss0.854. Field and Pool:5. Datum Reference:K-0150029209980000O 6401508871-8872, 8872-89063/7/2009 310 SBHP 187 8800.2 33688800 0.09 3,368K-05C 50029214180300O 6401508758-8769, 8773-8781, 8789-87867/9/2009 678 SBHP 188 8750.14 32998800 0.36 3,317K-1150029217650000O 6401508919-8919, 8919-8938, 8938-89769/12/2009 4254 SBHP 188.3 8799.99 3330.68800 0.31 3,330L-0350029232690000O 6401508834-8885, 8877-8872, 8871-88867/1/2009 604 SBHP 235 8799.9 37638800 0.23 3,763L2-07A 50029229100100O 6401508615-8623, 8628-8633, 8635-8637, 8638-8633, 8633-86358/22/2009 1731.84 SBHP 142 8500.24 32908800 0.33 3,388M-17A 50029206280100O 6401508747-8780, 8879-8890, 8890-8892, 8892-88986/28/2009 545 SBHP 220 8525.17 31758800 0.42 3,289M-2250029209360000O 6401508637-8654, 8654-8665, 8665-8688, 8688-8708, 8718-8752, 8757-8786, 8796-8804, 8804-8822 6/29/2009 563 SBHP 224 8700.17 32048800 0.44 3,247M-3450029225140000O 6401508592-8620, 8920-89305/28/2009 10797 SBHP 223 8800.05 32068800 0.42 3,206N-04A 50029213920000O 6401508755-8771, 8788-8804, 8921-8937, 8937-8950, 8950-89635/24/2009 4597 SBHP 214 8683.23 31678800 0.08 3,176N-07A 50029201370100O 6401508857-8866, 8871-8881, 8898-89006/17/2009 265 SBHP 218 8800.13 31858800 0.39 3,185N-10A 50029205070100O 6401508672-8677, 8684-8686, 8693-8695, 8703-8706, 8724-8723, 8709-8705, 8694-8688, 8680-8678, 8677-8676, 8673-86727/8/2009 772 SBHP 221 8500.06 31148800 0.42 3,240N-11C 50029213750200O 6401508631-8667, 8667-8686, 8695-8714, 8714-8732, 8753-87866/16/2009 5647 SBHP 221 8599.91 31468800 0.43 3,232N-1550029206070000O 6401508666-8672, 8676-8682, 8750-87565/20/2009 4114 SBHP 208 8599.97 31408800 0.09 3,158N-1650029208860000O 6401508721-8729, 8729-8737, 8737-87466/16/2009 255 SBHP 216 8699.81 31668800 0.42 3,208N-21A 50029213420100O 6401508934-8935, 8937-8939, 8939-8937, 8937-8938, 8937-8938, 8942-8945, 8946-8946, 8942-8939 6/18/2009 308 SBHP 219 8799.84 31728800 0.43 3,172P-04L1 50029221806000O 6401508926-8926, 8926-8967, 8967-89594/7/2009 1192 SITP 234 8799.5 33198800 0.42 3,319P-05A 50029225450100O 6401508818-8831, 8919-8920, 8920-8921, 8921-8922, 8923-8924, 8924-8925, 8926-8927, 8927-8929, 8930-8926, 8926-8923, 8923-8912, 8912-8912, 8912-89812/26/2009 3576 PFO8793.03 34308800 0.29 3,432P-09L1 50029223626000O 6401508839-8917, 8901-88658/15/2009 355 SBHP 231 8799.94 34268800 0.43 3,426P-12B 50029221360200O 6401508892-8901, 8901-8904, 8904-8910, 8912-8915, 8915-8916, 8917-8919, 8920-8924, 8924-8924, 8924-8925, 8925-8929, 8929-89463/4/2009PFO6658.98 26508800 0.33 3,347R-06A 50029203880100 WAG 6401508740-8765, 8912-89216/19/2009 17091 SBHP 152.1 8799.82 3137.38800 0.43 3,137R-1650029206860000O 6401508758-8776, 8776-8777, 8777-87966/17/2009 426 SBHP 206 8699.98 30718800 0.42 3,113R-2150029209970000O 6401508645-8648, 8648-86667/24/2009 109 SBHP 204.6 8649.79 2959.28800 0.33 3,008R-2450029212320000O 6401508642-8671, 8751-8757, 8757-87802/27/2009 14708 SBHP 155 8800.34 31938800 0.29 3,193R-39A 50029225260100O 6401508673-8758, 8758-88416/18/2009 316 SBHP 215 8657.31 31348800 0.42 3,193R-4150029233990000O 6401508707-8719, 8722-8726, 8729-8725, 8717-8713, 8690-8677, 8671-86842/25/2009 1124 SBHP 211 8699.74 34218800 0.42 3,463S-01B 50029207170200O 6401508680-8695, 8695-8710, 8809-8831, 8831-8850, 8857-8872, 8878-88937/1/2009 626 SBHP 226.7 8799.74 33038800 0.43 3,303S-0450029209590000 WAG 6401508644-8684, 8788-8905, 8905-8906, 8919-893411/2/2009 744 SBHP 152 8800.28 37898800 0.44 3,789S-05A 50029208690100O 6401508649-8654, 8654-8658, 8659-87175/12/2009 2256PP8528.62 31578800 0.43 3,274S-18A 50029211560100O 6401508934-8908, 8900-8885, 8936-896211/24/2009 15297 SBHP 232 8800.12 34298800 0.39 3,429S-20A 50029216370100 WAG 6401508665-8665, 8667-8670, 8890-89312/8/2009 1188.15 SBHP 175 8650.04 33778800 0.44 3,443S-2150029220360000O 6401508639-8643, 8650-8667, 8777-8797, 8797-88072/25/2009 1800 SBHP 214 8400.02 32778800 0.32 3,405S-28B 50029220950200O 6401508811-8815, 8822-8826, 8850-8850, 8862-8859, 8859-8858, 8857-88517/2/2009 11805 SBHP 226 8699.81 33948800 0.43 3,437S-3250029220990000O 6401508750-8780, 8876-8896, 8896-8927, 8935-89663/8/2009 40918.5 SBHP 217.23 8800.34 3365.18800 0.25 3,365S-3550029223240000O 6401508732-8769, 8856-8884, 8884-894812/23/2009 17366 SBHP 222 8799.76 33838800 0.42 3,383S-43L1 50029227546000O 6401508821-87742/15/2009 3279 SBHP 199 8425 31368800 0.33 3,259U-05A 50029211920100WI 6401508975-8946, 8948-89778/29/2009SBHP 214 8799.79 36468800 0.37 3,646U-06B 50029211170200O 6401508903-8946, 8948-8950, 8952-8952, 8953-8952, 8951-8949, 8939-8906, 8905-8900, 8898-8902, 8904-8915, 8915-8928, 8932-8937, 8938-8948, 8944-8937, 8936-8915, 8909-88876/27/2009 523 SBHP 229 8800.26 33258800 0.42 3,325U-0750029211270000O 6401508676-8694, 8766-8828, 8836-8863, 8872-88924/18/2009 235 SBHP 239 8800.01 30518800 0.43 3,051V-0250029232090000O 6401508898-8887, 8884-8876, 8881-8888, 8890-8890, 8890-8886, 8886-8884, 8895-8893, 8892-8894, 8892-8889, 8874-8872, 8869-88666/30/2009 582 SBHP 236 8800.62 36258800 0.41 3,625V-0350029231240000O 6401508810-8900, 8907-8913, 8926-8886, 8871-8839, 8865-8874, 8874-8881, 8886-8894, 8902-8924 7/7/2009 749 SBHP 234 8800.15 34128800 0.33 3,412V-0450029233220000O 6401508733-8770, 8777-8790, 8794-8797, 8828-8849, 8844-8842, 8831-8820, 8816-8810, 8804-8737 6/29/2009 562.96 SBHP 235 8699.89 38028800 0.42 3,844V-0750029233720000O 6401508867-8864, 8851-8831, 8827-8775, 8799-8851, 8863-88986/30/2009 591 SBHP 236 8800.45 38178800 0.43 3,817W-01A 50029218660100O 6401508811-8839, 8839-88536/28/2009 540 SBHP 220 8399.1 31108800 0.32 3,239W-10A 50029218930100O 6401508816-8824, 8830-8832, 8832-8829, 8829-8835, 8838-8841, 8844-8845, 8843-8840, 8821-8816, 8812-8814, 8817-8819, 8814-8812, 8812-8818, 8821-8825, 8836-88506/29/2009 559 SBHP 230 8699.51 35258800 0.41 3,566W-15A 50029220420100O 6401508880-89027/3/2009 696 SBHP 212 8365.47 33108800 0.40 3,484W-16A 50029220450100O 6401508833-8844, 8848-8855, 8862-8874, 8902-8901, 8881-8869, 8838-8825, 8821-8813, 8812-8814, 8816-8848, 8852-8856, 8859-88566/29/2009 566 SBHP 231 8699.85 33198800 0.42 3,361W-22 50029218690000O 6401508782-8790, 8795-8803, 8811-8816, 8820-8826, 8826-8843, 8843-8844, 8848-8858, 8864-8869, 8869-8874, 8874-88997/11/2009 888 SBHP 211 8336.26 34868800 0.40 3,672W-26A 50029219640100O 6401508744-8764, 8767-8783, 8802-8818, 8824-8834, 8842-8853, 8891-8905, 8909-8909, 8905-8899, 8808-8806, 8806-87966/29/2009 575 SBHP 236 8799.91 35788800 0.44 3,578Page 22 of 31 Exhibit 92009 Prudhoe1. Operator:2. Address:BP Exploration (Alaska) Inc.P.O. Box 196612, 900 E. Benson Blvd., Anchorage, AK 99519-66123. Unit or Lease Name:6. Oil Gravity:Prudhoe Bay Unit0.9 SG/27 API8. Well Name and Number:9. API Number 50XXXXXXXXXXXX NO DASHES10. Type See Instructions11. AOGCC Pool Code12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date15. Shut-In Time, Hours16. Press. Surv. Type (see instructions for codes)17. B.H. Temp.18. Depth Tool TVDSS19. Final Observed Pressure at Tool Depth20. Datum TVDSS (input)21. Pressure Gradient, psi/ft.22. Pressure at Datum (cal)RESERVOIR PRESSURE REPORT7. Gas Gravity:Prudhoe Bay Field, Prudhoe Oil Pool 8800 TVDss0.854. Field and Pool:5. Datum Reference:W-27A 50029218940100O 6401508783-8784, 8793-8796, 8801-8804, 8805-8810, 8819-8829, 8844-88712/13/2009 23957 SBHP 228 8650.2 35868800 0.34 3,636W-34A 50029218670100O 6401508859-8859, 8859-8859, 8858-8858, 8857-8855, 8853-8855, 8857-8862, 8863-8874, 8901-8899, 8890-88846/26/2009 497 SBHP 234 8799.82 36408800 0.40 3,640W-39A 50029217840100O 6401508886-8888, 8889-8890, 8888-8887, 8883-8881, 8877-88756/26/2009 482 SBHP 229 8806.28 35528800 0.44 3,549W-40 50029217760000O 6401508880-8888, 8895-89076/27/2009 517 SBHP 170 8800.16 35608800 0.34 3,559X-03A 50029204050100O 6401508767-8765, 8765-8764, 8763-8763, 8763-8764, 8818-8821, 8850-8851, 8836-88317/7/2009 324 SBHP 216 8699.82 32298800 0.41 3,270X-1250029204680000O 6401508765-8789, 8811-8825, 8831-8845, 8845-8851, 8861-8865, 8865-8883, 8883-8893, 8893-8915, 8925-8936, 8952-8958, 8959-8963, 8966-89747/7/2009 769 SBHP 214 8799.53 31888800 0.41 3,188X-1750029206810000O 6401508593-8617, 8753-8763, 8772-88157/5/2009 541 SBHP 222 8799.57 32738800 0.30 3,273X-21A 50029223920100O 6401508818-8797, 8797-87987/6/2009 743 SBHP 223 8800.18 32998800 0.42 3,299X-30A 50029225500100O 6401508968-8968, 8969-89847/7/2009 752 SBHP 224 8799.71 33348800 0.31 3,334Y-05B 50029204360200 WAG 6401508951-89676/16/2009 36 SBHP 181 8800.06 35678800 0.45 3,566Y-08A 50029205720100O 6401508891-89586/16/2009 137809 SBHP 224 8800.08 33568800 0.41 3,355Y-20A 50029215870100O 6401508959-8961, 8963-8968, 8975-8975, 8975-8975, 8967-8966, 8960-8960, 8958-8955, 8941-8940, 8920-8918, 8917-8915, 8913-8912, 8908-8907, 8906-8905, 8895-8894, 8892-8891, 8890-8891, 8894-8896, 8905-8907, 8911-8913, 8915-8918, 8922-8924, 8926-8927, 8942-8943, 8946-8947, 8948-8950, 8951-8953, 8954-8956, 8961-8964, 8969-8971, 8973-8972, 8960-8959, 8956-8955, 8927-8926, 8924-8923, 8922-8920, 8915-8915, 8917-8918, 8925-8928, 8933-8934, 8936-8938, 8942-8944, 8948-8950, 8953-8955, 8957-8958, 8965-8966, 8970-8970, 8974-8976, 8979-89816/16/2009 263 SBHP 231 8800.19 32998800 0.32 3,299Y-23B 50029215900200O 6401508963-8955, 8950-8940, 8940-8943, 8942-8938, 8933-89266/14/2009 218 SBHP 225 8,600 3,1268,800 0.42 3,209Y-26A 50029221910100O 6401508916-8931, 8951-8965, 8984-891612/5/2009 10380 SBHP 227 8800.14 33698800 0.32 3,369Y-2850029221690000O 6401508773-8786, 8866-8874, 8874-8891, 8891-8914, 8914-8921, 8921-8952, 8961-898311/13/2009 54,969 SBHP 225 8,800 3,3248,800 0.33 3,324Z-0550029220560000O 6401508760-8793, 8803-8817, 8825-8839, 8847-8862, 8871-8916, 8926-8944, 8957-89767/18/2009 6824 SBHP 229 8,800 3,6978800 0.42 3696Z-09A 50029219670100O 6401508757-8769, 8777-8812, 8820-88306/29/2009 572 SBHP 225 8,600 3,1718,800 0.43 3,256Z-13A 50029220690100O 6401508869-8868, 8866-8865, 8862-8861, 8861-8861, 8861-8860, 8859-8859, 8858-8857, 8858-8865, 8871-8875, 8877-8907, 8914-8920, 8951-8960, 8970-89761/21/2009 1356 SBHP 198 7,675 3,2148,800 0.45 3,720Z-14B 50029218440200O 6401508788-8792, 8808-8820, 8829-8843, 8854-88596/23/2009 432 SBHP 231 8799.14 36508800 0.44 3,650Z-1650029222450000O 6401508787-8792, 8792-8805, 8805-8808, 8808-8816, 8816-8824, 8841-8857, 8865-8882, 8882-8898, 8906-8914, 8914-89316/29/2009 565 SBHP 229 8,800 3,7008,800 0.42 3,700Z-1750029220010000O 6401508787-8800, 8800-8813, 8818-881912/29/2009 5429 SBHP 231 8,800 3,7018,800 0.30 3,701Z-2050029218590000O 6401508780-8781, 8785-8789, 8789-8797, 8805-8813, 8833-8845, 8876-8884, 8917-8925, 8925-8935, 8935-89416/17/2009 271 SBHP 231 8799.79 36468800 0.44 3646Z-21A 50029219380100O 6401508764-8772, 8780-8789, 8797-8805, 8805-8812, 8822-8837, 8852-88606/21/2009 370 SBHP 232 8800.26 37088800 0.44 3,708Z-22B 50029220370200O 6401508835-8836, 8838-88386/29/2009 558 SBHP 232 8799.93 35058800 0.33 3,505Z-2550029219020000 WAG 6401508796-8820, 8837-8841, 8841-8847, 8847-8849, 8849-8850, 8850-8852, 8852-8853, 8853-8856, 8856-8859, 8859-8867, 8867-8878, 8878-8879, 8879-8887, 8887-8893, 8893-8894, 8894-89258/12/2009 1601.85 SBHP 193 8,800 3,6628800 0.43 3662Z-2950029219540000O 6401508769-8772, 8777-8780, 8791-8799, 8806-8808, 8808-8811, 8818-8834, 8838-8846, 8852-8877, 8882-8882, 8882-8893, 8893-8898, 8898-88997/3/2009 674 SBHP 233 8799.93 37168800 0.41 3,717Z-2950029219540000O 6401508769-8772, 8777-8780, 8791-8799, 8806-8808, 8808-8811, 8818-8834, 8838-8846, 8852-8877, 8882-8882, 8882-8893, 8893-8898, 8898-88997/4/2009 698 SBHP 233 8,800 3,7168800 0.41 3,717Z-30A 50029220130100O 6401508784-88149/26/2009 3089 SBHP 220 8,500 3,4578800 0.32 3,552Z-32BL1 50029219246000O 6401508866-87997/2/2009 9882 SBHP 232 8,800 3,7638800 0.42 3,763Z-3550029228840000O 6401508876-8926, 8929-8924, 8923-8907, 8923-8930, 8933-89356/29/2009 20523 SBHP 212 8,393 3,5948800 0.41 3,761Z-39A 50029229950100O 6401508871-8872, 8886-89024/10/2009 7899.8 SBHP 239 8,700 3,6258800 0.43 3,668Z-46A 50029232800100O 6401508867-8858, 8852-88413/24/2009 5029 SBHP8,435 3,4868800 0.45 3,650Omitted from Pressure Map03-15AL1 50029204146000O 6401508633-8634, 8634-8681, 8682-86768/31/2009 422 SBHP 197 8,700 2,2738800 0.46 2,31903-32B 50029211410200O 6401508586-8589, 8593-8600, 8598-8585, 8585-8590, 8590-8588, 8595-8591, 8592-85897/29/2009 543 SBHP 184 8,600 2,6628800 0.18 2,69803-36A 50029223400100 WAG 6401508990-8990, 8990-8990, 8990-89902/8/2009 18 PBU8,991 3,0008800 0.44 2,91607-05 50029202930000O 6401508956-8961, 8961-8965, 8965-8970, 8970-8973, 8973-899410/28/2009SBHP 184 8,800 3,0178800 0.14 3,01713-14 50029208450000O 6401508813-8827, 8878-8883, 8883-8888, 8888-8897, 8897-8909, 8909-8914, 8923-8940, 8940-8953, 8953-89547/13/2009 160 SBHP 219 8,800 2,7158800 0.11 2,71513-30C 50029207680300O 6401508823-8825, 8827-8818, 8819-8827, 8826-88268/23/2009 1699 PBU 210.28 8,632 2,3348800 0.05 2,34213-30C 50029207680300O 6401508823-8825, 8827-8818, 8819-8827, 8826-88263/6/2009 1346 SBHP 223 8,800 2,2358800 0.05 2,23413-30C 50029207680300O 6401508823-8825, 8827-8818, 8819-8827, 8826-88262/5/2009 638 SBHP 213 8,800 2,0638800 0.05 2,063A-2650029207940000O 6401508643-865112/22/2009FBHP 229 8,683 9878800 0.11 1,000F-19A 50029206290100O 6401508591-86233/30/2009SBHP 188 8,600 2,8338800 0.46 2,975F-45B 50029221420200O 6401508994-8993, 8993-8992, 8993-89936/15/2009SBHP 192 8,800 3,4918800 0.44 3,490Page 23 of 31 Exhibit 92009 Prudhoe1. Operator:2. Address:BP Exploration (Alaska) Inc.P.O. Box 196612, 900 E. Benson Blvd., Anchorage, AK 99519-66123. Unit or Lease Name:6. Oil Gravity:Prudhoe Bay Unit0.9 SG/27 API8. Well Name and Number:9. API Number 50XXXXXXXXXXXX NO DASHES10. Type See Instructions11. AOGCC Pool Code12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date15. Shut-In Time, Hours16. Press. Surv. Type (see instructions for codes)17. B.H. Temp.18. Depth Tool TVDSS19. Final Observed Pressure at Tool Depth20. Datum TVDSS (input)21. Pressure Gradient, psi/ft.22. Pressure at Datum (cal)RESERVOIR PRESSURE REPORT7. Gas Gravity:Prudhoe Bay Field, Prudhoe Oil Pool 8800 TVDss0.854. Field and Pool:5. Datum Reference:R-2150029209970000O 6401508645-8648, 8648-86666/14/2009 1319 SBHP 199 8,650 3,9468800 0.44 4,012R-31A 50029222770100O 6401508691-8668, 8668-86442/18/2009 1762 SBHP 211 8,700 2,5038800 0.34 2,537R-3550029224240000O 6401508811-8848, 8929-89666/17/2009 279 SBHP 185 8,646 2,3978,800 0.22 2,430Put River02-23A 50029207950100O 6401828175-82008/31/2009 118 SBHP 183 8,199 3,4738,100 0.33 3,440Page 24 of 31 Exhibit 10 2009 Shut In Wells # Sw Name Field API Number SI Date Reason for Well Shut- InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 1 01-04A Prudhoe 029200700100 May-04 6 3 IAxOAxOOA comm - RWO failed in May 06. Will be evaluate for RST 2 01-09A Prudhoe 029201640100 Mar-07 7 6 SI due to prod casing leak, planning potential RWO 3 01-12A Prudhoe 029202690100 Oct-05 1 3 Evaluating RST 4 02-02A Prudhoe 029200740100 Jun-06 6 5 TxIA leak, well to be suspended, flowline used for 02-40 5 02-06B Prudhoe 029200860200 Aug-08 6 7 PC leak. RWO done. POP'd 2/15/10 6 02-11A Prudhoe 029202730100 Nov-07 1 1 Squeeze in the WBL 7 02-12B Prudhoe 029202770200 Feb-08 1 3 W/O to install lateral valve . CST candidate 8 02-22A Prudhoe 029207400100 Jul-08 1 3 Rig sidetrack issued. 9 02-26C Prudhoe 029207740300 Apr-07 6 2 Coiled + Candidate 10 02-39L1 Prudhoe 029227216000 Oct-07 1 3 Can't pull LTP. Sidetrack candidate. 11 03-08 Prudhoe 029202310000 Jul-08 6 2 SI for high OAP. Trouble shoo ing OA hydrate problem. 12 03-12 Prudhoe 029203920000 Feb-08 6 1 IAxOA comm. Potential fix with Sealtite. Contingency RWO package approved. 13 03-29 Prudhoe 029211180000 Mar-06 6 2 IA x OA Comm lab tests show IA and OA gas have different composition. Evaluating if this could be external gas source (similar to 03-08) 14 04-07 Prudhoe 029201890000 Jan-97 2 5 High WC, looking at adperf. 15 04-29AL1 Prudhoe 029214536000 Sep-05 6 7 PC and Tbg leak. Low IOR due to high GOR. Evaluating RWO. 16 04-34A Prudhoe 029221600100 Nov-97 2 5 High WC. Low IOR. Try to POP 17 04-36 Prudhoe 029221620000 Nov-01 2 5 High WC. Low IOR. Try to POP 18 04-39 Prudhoe 029221810000 Apr-98 2 3 High WC. Low IOR. No Flowline. Evaluating sidetrack as Lisburne injection well 19 04-47 Prudhoe 029224390000 Feb-03 6 5 High WC, Low IOR, PC Leak, Collapsed tubing, flowine is not fit for service. 20 05-07 Prudhoe 029202430000 Jan-08 6 7 SI for casing leak, RWO package prepared. 21 05-12B Prudhoe 029202440200 Mar-05 6 5 WH leak, evaluating sealtite job 22 05-17B Prudhoe 029202710200 Nov-02 6 5 Low existing value - collapsed tbg 23 05-30 Prudhoe 029222130000 Feb-06 6 7 SI for tubing leak,RWO package prepared. 24 05-31A Prudhoe 029221590100 Jul-08 6 7 Evaluating RST potential. 25 05-33A Prudhoe 029221680100 Jan-08 6 3 SI for csg leak 26 05-40 Prudhoe 029227070000 Nov-02 6 5 Failed RWO - stuck CT during cleanout 27 05-41A Prudhoe 029226960100 Jun-07 6 7 Tbg leaks, RWO package prepared. 28 06-17 Prudhoe 029207600000 May-04 6 5 TxIAxOA communication 29 07-16A Prudhoe 029208560100 Mar-07 6 2 SI for SC leak & IAxOA comm. 30 07-34A Prudhoe 029218120100 Apr-05 6 3 IAxOA; Stuck IBP fish in tubing. Rig ST candidate. 31 09-23A Prudhoe 029210660100 Jul-08 6 2 IAxOA after RWO cemented OA to surface, high OAP due to external gas, working on solutions 32 09-25 Prudhoe 029210830000 Aug-07 6 7 TxIA. RWO possibly in 2010 33 09-42A Prudhoe 029220590100 Dec-02 6 5 2008 RWO failed. Now possible SC leak. RST Candidate. 34 09-44 Prudhoe 029220870000 Oct-08 2 3 Planning on RST 2010 35 09-46 Prudhoe 029220920000 Nov-08 7 6 Actuator installed, but now broken choke. WR written. 36 09-47 Prudhoe 029220980000 Aug-08 7 6 Actuator installed, but now broken choke. WR written.Shut in for high WC 37 09-48 Prudhoe 029221280000 Aug-04 6 5 IAxOA, low IOR. Evaluating non-rig fix. May have sidetrack potential. 38 11-01A Prudhoe 029206440100 Nov-06 6 2 IAxOA no longer manageble by bleeds. Trying Sealtite. 39 11-02 Prudhoe 029206490000 Nov-06 7 6 Water injec ion line inoperable, replacement to occur in 2010. MI line okay and used occassionally 40 11-07 Prudhoe 029206870000 Nov-08 7 6 Water injection line inoperable, Replacement to occur in 2010. 41 11-08 Prudhoe 029212450000 Nov-08 7 6 Water injection line inoperable, Replacement to occur in 2010. 42 11-10 Prudhoe 029213940000 Jan-06 7 6 Water injec ion line inoperable, Replacement to occur inm 2010. AnnCom, RWO completed. 43 11-23A Prudhoe 029216100100 Feb-04 2 5 High WC. Low IOR. Possible sidetrack option 44 11-25A Prudhoe 029204880200 Feb-02 6 2 PC Leak and IAxOA Communication. Evaluating for RWO 45 11-26 Prudhoe 029216280000 May-06 7 6 Water injection line inoperable, Replacement to occur in 2010. 46 11-29 Prudhoe 029224660000 May-06 7 6 Water injection line inoperable, Replacement to occur in 2010. 47 11-35 Prudhoe 029224760000 Sep-05 7 6 SWI line inoperable, Replacement to occur in 2010. Slight TxIA comm, TTP set. Passes MIT-T and MIT-IA. 48 11-38A Prudhoe 029227230100 Nov-08 7 6 Water injection line inoperable, waiting on funds for repair 49 12-11 Prudhoe 029206010000 Feb-00 6 5 LTSI. High TGOR, low oil rate. Stole 12-11's surface facili ies for new grass roots well 12- 37. 50 13-01 Prudhoe 029203230000 Jul-06 6 5 SC leak & leak outside wellhouse; well likely not operable per WI group even if RWO completed given high risk in operating well! No plans at this time. 51 13-04 Prudhoe 029203260000 Oct-03 6 5 TxIAxOA; produces rocks, sand screen installed. 52 13-05 Prudhoe 029206260000 Nov-97 6 5 TxIAxOA; replaced by 13-06Ai MI injector. FL decommissioned 8/09. No plans at this time. 53 13-07 Prudhoe 029206500000 Jul-91 6 5 TxIA w/ significant surface facility issues. Future RST plans on hold. 54 13-09 Prudhoe 029206710000 Aug-03 6 2 TxIA & PC leak; currently evaluating for RWO. 55 13-10 Prudhoe 029206780000 Jun-94 6 5 IAxOA on GL: high WC. No plans at this time. 56 13-11 Prudhoe 029206040000 Dec-05 6 5 TxIA & possible packer or PC leak. No plans at this time. 57 13-12 Prudhoe 029205380000 Dec-07 6 5 TxIA; 58 13-15 Prudhoe 029208310000 Jul-06 6 5 TxIA & slow IAxOA, non-rig wellwork not a viable option given minimum 2 slicks ick patches (5-1/2" tbg) and a successful sealtite job would be required. No current plans. 59 13-18 Prudhoe 029207240000 Jun-06 7 6 Needs flowline replacement; sleeving not an op ion. full line replacemen anticipated in 2010 60 13-22 Prudhoe 029207490000 Nov-07 6 7 RWO done to repair PC leak, new 4-1/2"x5-1/2" L-80 TCII tubing, Online 1/24/10 61 13-25 Prudhoe 029207610000 Oct-07 6 2 TxIA; low priority given minimal offtake in area 62 13-26 Prudhoe 029207460000 Feb-97 6 5 IAxOA & possible Cretaceous leak. High WC. No plans at this time. 63 13-27A Prudhoe 029209490100 Aug-02 6 7 TxIA, PC leak, SC leak. Further review justified RWO. RWO started 12/30/09. Page 25 of 31 Exhibit 10 2009 Shut In Wells # Sw Name Field API Number SI Date Reason for Well Shut- InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 64 13-28 Prudhoe 029209420000 May-94 6 5 PC leak & bubbles in the cellar. Replaced by 13-13A 65 13-33 Prudhoe 029207730000 Dec-94 6 5 TxIAxOA. No plans at his time 66 14-14 Prudhoe 029206250000 Aug-06 7 5 IAxOA and flowline. Flowline replacement not planned due to lack justification for entire project. 67 14-27 Prudhoe 029210460000 Nov-04 7 6 Flowline repair needed. 68 14-31 Prudhoe 029209890000 Jul-07 6 5 TxIA poor tubing, low rate for the last 6 months of life. Possible future UZI injector. 69 14-38 Prudhoe 029218620000 Nov-94 3 5 TxIA and low PI (SI 11/94). No flowline. 70 14-39 Prudhoe 029218880000 Jun-94 6 5 IAxOAxForm. Leak @ 81'. Flowline is corroded and not fit for service. Considering permanent P&A op ions. 71 15-03 Prudhoe 029207220000 Jun-94 6 5 Cret leak, leaking sqz perfs, major fish in tubing; surface facilities given to another well 72 15-10A Prudhoe 029205010100 Jan-91 6 5 Major leaks and a channel; no surface facilities; bottom hole location developed by 15-49 73 15-24 Prudhoe 029222230000 Mar-95 6 5 Collapsed tubing, cret leak, no surface facilities 74 15-27 Prudhoe 029222430000 Nov-08 6 3 Well tested high GOR. MITIA failed on 9/19/09 as part of RST screening. Rig ST pkg is out and on 2010 Rig Schedule. 75 15-35 Prudhoe 029224880000 Sep-03 6 5 Cret leak, dumpflooded Ivishak, TxIA and PC leak 76 15-41B Prudhoe 029224920000 Feb-07 7 5 Put Appraisal well, needs expensive cmt sqz before returning to Ivishak prod. No sidetrack target 77 15-43 Prudhoe 029226760000 Dec-09 6 2 SC leak at the wellhead. Evaluating fixing via surface excavation. 78 15-47 Prudhoe 029226170000 Oct-02 6 5 Tbg very rotten, IA cemented. Well secured w/ sand plug--chunks of tbg falling down on plug. 79 16-01 Prudhoe 029205330000 Jul-08 6 7 TxIAxOA comm. RWO possible in 2010 80 16-03 Prudhoe 029205540000 Nov-06 6 7 TxIA comm, RWO possibly in 2010. 81 16-09A Prudhoe 029205580100 Jul-07 6 2 Fish in the hole. Will need a RWO to fix. Current plan is to reach 16-09A target with 17-09A ST. 82 16-24 Prudhoe 029215360000 Jul-06 2 2 100% WC. Sidetrack candidate. Try POP for MIST from 16-14Bi. 83 16-25 Prudhoe 029222700000 Nov-06 7 6 SI due to 16/17 Commonline. Low PI due to heavier oil in the SE DS 16 area - need plan for low API gravity oil. 84 16-28 Prudhoe 029222760000 Oct-05 6 2 SC leak, low PI, but has much larger potential IOR from MIST and BW, offset to BW inj 16- 16i. WIE looking into Furmanite composite patch. Potential CST if workover not an option. 85 16-31 Prudhoe 029222800000 Apr-95 7 5 SI due to 16/17 Commonline out of service, TxIA to gas only, low PI, maybe pull IBP, POP and evaluate, esp when 16-03i BOI. High WC.Try stimulation for asphaltenes. 86 17-07B Prudhoe 029205960200 Dec-08 7 6 Expect oil rate to improve with future MIST response. Also may find that coil PPROF (or follow up FCO if needed) cleans out 2-3/8" completion and improves flow. 87 17-09 Prudhoe 029206170000 Dec-06 6 3 PC Leak, RST candidate for 2010 88 18-04B Prudhoe 029208750200 Jan-07 1 2 GOC at top perf. Evaluating graben sidetrack target. 89 18-19 Prudhoe 029215960000 Sep-03 6 5 RWO package tabled - target more attractive with CST from another well 90 18-20 Prudhoe 029218900000 Jan-07 3 2 PC leak @ 7900' & 8100' md 91 18-22A Prudhoe 029223030100 Aug-02 3 5 High GOR 92 18-23A Prudhoe 029218980100 Feb-04 1 2 May be upstructure ST target. 93 18-25A Prudhoe 029219480100 May-03 3 5 Cretaceous leak. No future utility. FL was donated to well 18-15. 94 18-28 Prudhoe 029225640000 Nov-00 6 5 Hole in tbg and csg. CTU fish in well. Low remaining value and very high risk WW opportunity. 95 18-33A Prudhoe 029225980100 Dec-05 6 2 TxIAxOA, Also has starting head leak. Evaluating RWO or non-rig fix 96 18-34 Prudhoe 029226110000 Oct-00 6 5 Hole in tbg and casing. Cement in tbg and IA. Multiple plugs in tbg. Remaining value very low. 97 A-18A Prudhoe 029206300100 Jun-03 6 5 LTSI Low IOR and AC. No Flowline 98 A-21 Prudhoe 029207100000 Jun-04 8 3 AC and bad injector. A-17A sidetracked to replace both A-17 and A-21. Facilities used for the grassroots well A-44i 99 A-41 Prudhoe 029225300000 Sep-00 6 5 LTSI - cretaceous leak. Evaluating RST. 100 B-01 Prudhoe 029200590000 Jul-06 6 7 SI TxIA. Cal shows no hole. LDL indicated PC leak. 101 B-02A Prudhoe 029200660100 Jul-04 6 5 Failed RWO 9/23/06. Drainage area taken by B-37 new drill. 102 B-08 Prudhoe 029203140000 Dec-08 1 2 High GOR that no longer heals. GSO hampered by 3 1/2" tbg in 9 5/8 liner so difficult to cleanout after GSO. Potential CST away from parent gas cone. 103 B-09 Prudhoe 029203160000 Sep-95 5 5 Injects into fault. Used for pit dewatering. 104 B-11 Prudhoe 029203310000 Jan-91 2 5 LTSI - No FL ; surface facilities given to B-35 105 B-13A Prudhoe 500292034101 Dec-07 6 2 PC leaks at 3002' and 3700'. RST planned. 106 B-24 Prudhoe 029208150000 Jan-93 6 5 LTSI. Replaced by B-13. No FL. 107 B-28 Prudhoe 029215100000 Feb-00 5 2 GD MI pilot. Eval conv back to prod. Tested high GOR. Eval if lowest perfs have lower GOR 108 B-30A Prudhoe 029215420100 Dec-08 1 2 Very mature cycle well, no longer heals. Twinned with more competitive B-21. Share common choke and don't flow simutaneously due to velocity issues. 109 C-27B Prudhoe 029208430200 Nov-08 6 3 Packer leak. Rig ST candidate. 110 C-28A Prudhoe 029208670100 Dec-07 6 3 TxIA wi h patch in hole. Rig ST candidate. 111 C-38 Prudhoe 029215710000 Nov-97 6 5 Cretaceous leak, flowline taken, evaluated CST, but add'l facility costs makes it prohibitive. No current wellbore utilization; recovery captured by offset wells. 112 CC-02A Prudhoe 029220160000 May-96 5 5 LTSI Cretaceous Disposal Well, will need MITIA test when returned to service 113 E-14A Prudhoe 029207840100 Sep-07 6 2 TxIA Comm & surface csg leak 114 E-20A Prudhoe 029205760100 Jun-05 6 5 Surface Casing Leak, waiver canceled 115 E-33A Prudhoe 029224220100 Jan-08 6 3 TTP stuck post-RWO. On 2010 Rig Schedule 116 E-39A Prudhoe 029225870100 Sep-05 6 5 IBP fish stuck in hole. 117 F-16A Prudhoe 029206610100 Jan-07 6 5 SCMT on WBL to eval for CTD. AMS - moved to under evaluation due to comment 118 F-22 Prudhoe 029219510000 Apr-08 6 3 Evaluating Sidetrack. Page 26 of 31 Exhibit 10 2009 Shut In Wells # Sw Name Field API Number SI Date Reason for Well Shut- InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 119 F-23A Prudhoe 029216580100 Jul-08 6 3 Evaluating Sidetrack. 120 F-26 Prudhoe 029219870200 Apr-08 1 2 Consider for Adperf. 121 F-27A Prudhoe 029216590100 Nov-08 1 2 High GOR 122 G-03A Prudhoe 029202210100 Dec-04 6 3 RWO suspended due to PC leak. Evaluating RST 123 G-23A Prudhoe 029216800100 Dec-06 6 3 High GC-1 MGOR might make patch viable. Evaluating RST 124 GC-2A Prudhoe 029201670000 Sep-95 6 5 LTSI Cretaceous Disposal Well, No Flowline, Repeated attempts to cleanout fialed, CT fish iin hole, no injectivity 125 GC-2C Prudhoe 029217740000 Sep-07 6 2 Monobore completion, OA valve gauge shows IAP, MITIA passed to 1700psi on 2/6/09 126 GC-3D Prudhoe 029203090000 May-03 4 5 LTSI Cretaceous Disposal Well - requires CT FCO 127 GNI-01 Prudhoe 029228450000 May-07 7 4 Replaced with GNI-04 for Class 1 Injection, Available for Class 2 Injection and Observation, Has no flowline 128 H-02 Prudhoe 029201000100 Feb-08 6 1 Furmanite repair complete - ready to POP 129 H-28 Prudhoe 029218060000 Apr-01 6 2 Pkr Sqz program risky; planned for 2010 130 H-34 Prudhoe 029228030000 Nov-04 6 7 TxIA, PC leak, eval for possible Sag ST/RWO 131 H-37 Prudhoe 029227720100 Jul-07 3 2 SI for low PI - needs acid/ADPERFS 132 J-01B Prudhoe 029200200200 Aug-08 7 2 Cellar is bubbling gas w/Ivishack characteristics 133 J-02B Prudhoe 029200230200 Dec-08 6 2 Evaluating OOOA cmt downsqueeze. 134 J-13 Prudhoe 029204970000 Aug-07 6 2 confirmed SC leak at 4' 3". 135 J-15B Prudhoe 029209610200 May-06 6 2 Small MITIA LLR, evaluating op ions to restore integrity. 136 J-20B Prudhoe 029217160200 Sep-06 6 2 5/09 RWO suspended. Notes state fish in hole that cannot be dressed or milled. Is his still be evaluated. 137 L-02a Prudhoe 029230480100 May-07 7 6 Available for production, inadequate gas lift supply 138 L2-08A Prudhoe 029217610100 Jul-99 6 2 Evaluating RWO feasibility & possible non-rig fix . Can't flow to LPC due to gas limitations. 139 L2-11 Prudhoe 029228850000 Nov-08 6 7 Began showing water in 7/08. October lab tests showed the produced water to be cretaceous. Potenial 2010 RWO. 140 L2-18A Prudhoe 029217660100 Sep-01 6 5 TxIAxOA 141 L-50 Prudhoe 029232770000 May-07 1 6 Available for production 142 L-51 Prudhoe 029233090000 Dec-07 6 7 Available for production, low PI 143 M-01 Prudhoe 029200420000 Aug-87 7 5 Suspended, replaced with M-28i 144 M-05A Prudhoe 029201940100 Dec-04 6 5 Gas lifted well TxIAxOA Communication, waiver cancelled. TTP stuck. 145 M-08 Prudhoe 029204990000 Dec-09 6 1 SI for high wc, otherwise an operable well. Tree repaired, integrity restored 8/30/09, WSO on WBL 146 M-13 Prudhoe 029205220000 Mar-05 7 6 PW inj line split, AFE in he works 147 M-24 Prudhoe 029209390100 Mar-08 2 6 Shut in due to GC2 water handling capacity otherwise an operable well. 148 M-27A Prudhoe 029219920100 Jul-97 3 5 LTSI, low rate. TxIA Communication 149 N-03 Prudhoe 029200870000 Jan-96 6 5 SC leak. No flowline. 150 N-06 Prudhoe 029200980000 Aug-05 6 5 Replaced with N-18A 151 N-11C Prudhoe 029213750200 Oct-08 3 6 SI for High GOR & Flow N-25 152 N-19 Prudhoe 029209220000 Sep-08 7 6 SI for velocity issues; evaluating debottlenecking 153 P-14 Prudhoe 029221290000 Mar-03 6 2 TxIA & possible packer failure. Eval RWO, or patch and cement packer to POI. 154 P-18L1 Prudhoe 029220976000 Jul-07 6 2 SC leak. RWO or ST? 155 P-22 Prudhoe 029223960000 Dec-96 6 5 TxIA comm, probable bad pkr, FTS.High risk Wellwork obs at 10500 that failed to be milled out. 156 P-23 Prudhoe 029223930000 Jun-02 6 7 Patch failed. RWO if recovery justifies. 157 PWDW1-1 Prudhoe 029202260000 Jul-07 6 5 SI due to poor injectivity resulting from a SSSV fish down-hole. 158 PWDW2-1 Prudhoe 029202270000 Feb-03 6 5 LTSI Cretaceous Disposal Well, PC Leak at 2992', would require redrill 159 Q-02A Prudhoe 029203330100 Dec-04 6 7 Ann Comm - MITOA passed, MIT-IA failed. RWO Pkg prepared. 160 R-01 Prudhoe 029203530000 Nov-93 6 5 Suspended with Ann Comm issues. No flowline or wellhouse. Replaced by R-39. 161 R-06A Prudhoe 029203880100 Jun-06 7 6 Flowline needs repair or replacing. 162 R-08 Prudhoe 029205480000 Dec-07 2 4 Looking for options with IBP, appears to have moved uphole 163 R-10 Prudhoe 029206180000 Mar-01 3 5 LTSI, low rate w/ Ann Comm. 164 R-17A Prudhoe 029206770100 Feb-05 7 5 Sag w/ Ivishak fault water, not competitive, waivered for TxIA. Eval CST. flowline needs repair. 165 R-20A Prudhoe 029206410100 Jun-06 6 2 Surface Casing Leaks 166 R-30 Prudhoe 029222790000 Sep-05 6 5 R-30 bottomhole target captured by R-41 grassroots well; R-30 could be Sag Coil Sidetrack candidate if excavation repairs SC. 167 S-13 Prudhoe 029208100000 Mar-01 6 5 SI for high WC, and TxIAxOA communication, ST candidate 168 S-15 Prudhoe 029211130000 Sep-08 5 4 SI due to all offset producers being SI for water handling. Will POI when some offsets online again. 169 S-16 Prudhoe 029211230000 Aug-04 6 2 SC leak and IAxOA. Marginal RWO candidate. Being eval for external SC repair. 170 S-17C Prudhoe 029211480300 Mar-08 2 6 SI for Low Rate, high wc, otherwise an operable well. 171 S-18A Prudhoe 029211560100 Feb-08 2 6 SI for Low Rate, high wc, otherwise operable. Last 2 tests obtained shortly after POP'ing. With sustained produc ion, rates listed are expected. 172 S-19 Prudhoe 029216110000 Mar-08 2 6 SI for Low Rate, high wc, otherwise an operable well. 173 S-23 Prudhoe 029220880000 Apr-04 6 5 SI for IAxOA Comm, Bradenhead leak, no tbg leak but in poor condition. Looking for ST opportunity. 174 S-27B Prudhoe 029220570200 Apr-07 2 6 SI for low rate, high wc, otherwise an operable well. BOL and retested w/ portable in 07-07 which confirmed last rate. 175 S-30 Prudhoe 029220510000 Aug-03 6 5 TxIA. Plan to request LDL and evaluate patch options or RWO. 176 S-35 Prudhoe 029223240000 Dec-07 6 1 Recent wellwork confirmed MIT-IA failed and tbg leak rate. Work on WBL to patch. 177 S-38 Prudhoe 029223100000 Mar-08 2 6 SI for Low Rate, high wc, otherwise an operable well. Upside when S-25A on MI inj. Also a flowline issue that is expected to be repaired during next SD. 178 S-400A Prudhoe 029232890100 Oct-08 3 2 ESP failed. Extra water not needed at the moment. Page 27 of 31 Exhibit 10 2009 Shut In Wells # Sw Name Field API Number SI Date Reason for Well Shut- InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 179 S-401 Prudhoe 029233130000 Oct-08 3 2 Low productivity. Extra water not needed at the moment. 180 S-40A Prudhoe 029224940100 Aug-06 6 5 SC Leak at 19' and TxIA. 181 S-41L1 Prudhoe 029226456000 Jan-05 6 5 SI due to TxIA and previously n-S pad velocity limit on flowline; Low Rate, high GOR. 182 S-42 Prudhoe 029226620000 Dec-06 6 5 SI TxIA and high wc. Looking for long patch or ST options. 183 S-44L1 Prudhoe 029227350000 Mar-08 2 6 SI for low rate, high wc, otherwise an operable well. Looking at ST options. 184 T-01 Prudhoe 029212410000 Jul-99 8 5 LTSI Injector, not an effective injector 185 T-07 Prudhoe 029207330000 Jul-99 8 5 LTSI Injector, not an effective injector 186 U-02A Prudhoe 029211700100 Dec-02 6 5 Hole in tubing and PC leak; TTP 187 U-08A Prudhoe 029211360100 Jan-02 2 5 High watercut, flowlines given to U-15A. 188 U-09A Prudhoe 029211440100 Feb-05 6 5 IAxOA. Too low remaining oil to justify a RWO. Avail for ST. 189 U-13 Prudhoe 029203550000 Jul-06 6 5 Low oil rate. Rock producer w/ fill. 190 U-14 Prudhoe 029223860000 Apr-07 3 5 high TGLR. Low oil rate & high WC. 191 U-15B Prudhoe 029225650200 Jul-06 3 5 Not producing; no FL 192 V-01 Prudhoe 029232100000 Dec-08 7 6 Operable producer, SI due to lack of gas lift in area. 193 W-12A Prudhoe 029220230100 Sep-06 2 2 Cement sqz performed w/ cmt left in wellbore, milling cleanout pending 194 W-19AL1 Prudhoe 029220060100 Jul-06 2 3 high watercut, operable 195 X-04 Prudhoe 029204120000 May-03 6 5 TxIAxOA; High WC 196 X-18 Prudhoe 029206750000 Sep-05 6 1 IAxOA on GL, low IOR and remaining recovery. Evaluating ST or Misted Seal ite fix. 197 X-22 Prudhoe 029223990100 Aug-08 6 1 SC Leak RWO on hold. External repair w/ Furmanite moving forward. 198 Y-02A Prudhoe 029203950100 Oct-05 6 3 TxIAxOA GL. Future offtake Y-03Ai.Diagnostic confirm comm is not thru theWH. Rapid OA repressurization. ST being evaluated. 199 Y-08A Prudhoe 029205720100 Sep-93 3 5 Limited remaingin recovery. Evaluating ST to southeast to support Y-09L1-L1-01 200 Y-12 Prudhoe 029205170000 May-99 6 5 TxIAxOA. FTS. Poor tbg condition. Secure for LTSI with CaCO3 L&K. Evaluating ST to east toward Y-34 201 Y-13 Prudhoe 029206340000 Feb-06 2 5 SI high WC. No short term plan. Long term ST candidate 202 Y-17B Prudhoe 029209200200 Jun-02 2 5 SI wet since the beginning. Plan to plugback to Y-17A perfs for Y-03i offtake. 203 Y-26A Prudhoe 029221910100 Jan-09 3 5 Low PI well. Poor rock quality in the area. 204 Y-31 Prudhoe 029221610000 Dec-07 2 5 SI for high WC. No obvious ST targets. 205 Y-32 Prudhoe 029221490000 Jan-09 2 5 SI for high WC. No obvious ST targets. 206 Y-34 Prudhoe 029221780100 Dec-07 2 5 SI for high WC. No obvious ST targets. 207 Y-38 Prudhoe 029225530000 Dec-02 6 5 TxIA. OAxCond. Collapsed tbg. Poten ial for Sidetrack candidate. 208 Z-03 Prudhoe 029227870000 Oct-07 6 3 RWO left multiple fish in well, CT sidetrack planned. 209 Z-05 Prudhoe 029220560000 Oct-08 2 4 High wC, low oil rate, POP after Z-09i on injection 210 Z-19A Prudhoe 029222510100 Jul-08 6 7 OA repressurization due to shallow gas, poor cement 211 Z-35 Prudhoe 029228840000 Apr-01 2 5 High WC, no current plans for well 212 Z-38 Prudhoe 029228730000 May-07 6 7 SI due to rock production 213 Z-46 Prudhoe 029232800100 Sep-08 7 6 Available for production, SI due to inadequate gas lift in area A. Reasons for Well Shut-In 1 High GOR, curently uncompetitive to produce due to facility constraints, no known mechanical problems 2 High water, currently uneconomic to produce, no known mechanical problems 3 Low production rate, no known mechanical problems 4 Wellwork 5 Reservoir Management 6 Mechanical Problem 7 Other (Specify under comments) B. Future Utility 1 Wellwork Planned 2 Under Evaluation 3 Sidetrack Planned 4 Reservoir Management 5 No Current Utilization 6 Surface Facilities 7 RWO Candidate Page 28 of 31 Flood Front and Well Locator Map Exhibit 11-1 Water Bank Cross-section Interpretation - 2009 Exhibit 11-2 Exhibit 12Put River Sandstone Distribution