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Home My WebLink About2010 Prudhoe Oil and Put River Oil Pools ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL JANUARY THROUGH DECEMBER 2010 2010 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 2010 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 GCWI Flood Front and Well Locator Map 11-2 GCWI Water Bank Cross-section Interpretation - 2010 12 Put River Lobe Map Page 3 2010 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 2010. 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 2010 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 2010 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 2010, field production averaged 244.1 MBOD, 6898 MMSCFD (GOR 28,253 SCF/STB), and 879 MBWD (water-cut 78.3%). Waterflood project injection during this period averaged 886 MBWD with 136 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2010 was 11,085 MMSTB, while cumulative MI injection was 2,920 BCF. Cumulative production since waterflood startup was 2,802 MMSTB oil, 10,657 BCF gas, and 7,502 MMSTB water. As of December 31, 2010, cumulative production exceeded injection by 5,779 MMRB compared to 5,347 MMRB at the end of 2009. 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 2008 through 2010 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 69% of repeat 2010 pressure surveys found equal to or greater than their 2008 or 2009 pressure measurements. For 2010, average pressure in the PBMGP project areas using three years of pressure static measurements was calculated to be 3,339 psia by areal weighting, as compared to 3,315 in 2009 (Exhibit 1F). The GD area pressure was stable rising eleven psi from 3,248 psia in 2009 to 3,259 in 2010. 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 131 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 2010 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT year showed MI breakthrough in 140 wells. The increase in RMI can be attributed to maturing of MI injection patterns in the PBMGP areas. Exhibit 1-G shows the 2010 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 2010 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 2010 pressure map using 2008 through 2010 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 2010 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 2010 is presented in Exhibit 9. Page 6 2010 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 118 producing wells and 62 injection wells that contributed to production/injection during 2010 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 29 MBOD for 2010 compared to 27 MBOD in 2009. Cumulative production since waterflood start-up through the end of 2010 is 1,046 MMSTB of oil, 4,765 BCF of gas, and 3,839 MMSTB of water. Injection rates averaged 412 MBWD and 37 MMSCFD in 2010. Since 12/31/09, the waterflood imbalance has increased from a cumulative under injection of 1,965 MMRB to 2150 MMRB under injected. During the report period, production exceeded injection by 2,150 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 and MI injection since waterflood start-up, through the end of 2010, is 5,804 MMSTB and 966 BCF respectively. The flood area's GOR increased from an average of 20,574 SCF/STB in 2009 to an average of 21,494 SCF/STB in 2010. Gas influx continues along the FS-2/GD GDWFI area, and in the high permeability conglomerates in the Updip Victor area. Water-cut was down 1% to 93% in 2010. 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 3,367 psia in 2010. This is an increase of 18 psi over the 2009 pressure. Exhibit 3-D is a presentation of 2010 average returned MI (RMI) rates. Miscible gas return has been confirmed in 29 wells by gas compositional analysis (RMI>200 MSCFD). Page 7 2010 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 2010, oil production averaged 19.2 MBOD, as compared to 18.9 MBOD in 2009, with an average 90% water cut and 20,420 SCF/STB Gas Oil Ratio. Injection averaged 189 MBWD and 6 MMSCFD of miscible injectant (MI). There are a total of 77 producers and 30 injectors in the flood area that contributed to production/injection during 2010. Of the 30 injectors, 3 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 Cumulative total of 615 MMSTB of oil, 2,756 BSCF of gas, and 1,478 MMSTB of water have been produced with 1,993 MMSTB of water and 643 BSCF of miscible gas injected. Exhibit 4-B shows the monthly injected and produced volumes on a reservoir barrel basis during 2010 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 2066 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 3,329 psia in 2010. This is an increase of 19 psi as compared to 2009. Exhibit 4-D shows the 2010 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 30 wells (RMI >200 MSCFD). Page 8 2010 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 21.1 MBOD, as compared to 22.1 MBOD in 2009, with a gas/oil ratio of 12,418 SCF/STB and a watercut of 85%. Injection averaged 112 MBWD of water and 35 MMSCFD of miscible injectant. For the WPWZ project, 44 injectors (12 WAG injectors and 32 water injectors), and 94 producers contributed to the production and injection during 2010. 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 2010 was 1,598 MMSTB while cumulative MI injection was 572 BSCF. Cumulative production since waterflood start-up is 500 MMSTB oil, 1,620 BSCF gas, and 1134 MMSTB water. As of December 31, 2010 cumulative production exceeded injection by 944 MMRB. Exhibit 5-B provides the monthly injection and production data from 01/10 through 12/10. During the report period, production exceeded injection by 84 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 3,317 psia in 2010. This is an increase of 8 psi over the pressure reported in 2010. Exhibit 5-D indicates wells with MI breakthrough and the 12-month averaged returned MI rates. Miscible gas breakthrough has been confirmed in 34 wells by gas compositional analysis. Page 9 2010 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 10.5 MBOD, as compared to 9.9 MBOD in 2009, with a gas/oil ratio of 5,841 SCF/STB and a watercut of 84%. Injection averaged 65.8 MBWD and 1.6 MMSCFD of miscible injectant. For the NWFB project, 30 injectors (1 WAG injectors, 28 water injectors, and 1 gas injector), and 57 producers contributed to the production and injection during 2010. 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 2010 was 1,581 MMSTB while cumulative MI injection was 666 BCF as detailed in Exhibit 61-C. Cumulative production since waterflood start-up was 586 MMSTB oil, 1,266 BSCF gas, and 938 MMSTB water. As of December 31, 2010 cumulative production exceeded injection by 422 MMRB. Exhibit 6-B provides the monthly injection and production data from 01/10 through 12/10. 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 3,329 psia in 2010. This is an increase of 59 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 these 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 2010 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 18.6 MBOD, as compared to 13.0 MBOD in 2009, with a gas/oil ratio of 4,305 SCF/STB and water cut of 67%. Injection averaged 41.6 MBWD and 33.7 MMSCFD of miscible gas injectant. For the EWE project, 17 injectors (13 WAG injector, 4 water injectors), and 67 producers contributed to the production and injection during 2010. Of the 13 WAG injectors, 6 injected gas only, 5 injected water only and 2 injected both gas and water in 2010. The well counts reflect only the active wells for the year. Cumulative water injection from waterflood start-up in September 2001 through December 2010 was 108 MMSTB and cumulative MI injection was 74 BCF. Cumulative production since waterflood start-up was 55 MMSTB oil, 249 BCF gas, and 113 MMSTB water. As of December 31, 2010 cumulative production exceeded injection by 196 MMRB. Exhibit 7-B provides the monthly injection and production data from January 1, 2010 through December 31, 2010. During the report period, production exceeded injection by 18 MMRB. The EWE pressure was 3,666 psia in 2010 representing an average pressure increase of 4 psi for this area from 2010. Exhibit 7-C indicates wells with MI breakthrough and the 12-month average returned MI rates. Miscible gas breakthrough has been confirmed in 15 wells by gas compositional analysis. Page 11 2010 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 4.6 Gas Cap Water Injection Project Details of the Volume of Water Injected during 2010 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 1/1/10 3,109 3,091 3,060 3,003 3,063 3,167 3,103 21,597 2/1/10 2,181 2,112 2,144 1,940 2,127 2,045 2,053 14,602 3/1/10 2,978 2,942 2,909 2,810 2,936 2,951 2,928 20,455 4/1/10 3,059 2,993 3,006 2,977 3,009 2,986 2,961 20,990 5/1/10 3,223 3,177 3,163 3,165 3,184 3,185 3,187 22,285 6/1/10 2,388 2,403 2,401 2,069 2,390 2,377 2,297 16,325 7/1/10 3,034 2,996 3,004 2,892 2,994 3,025 2,961 20,906 8/1/10 1,145 1,128 1,138 908 1,019 1,025 1,018 7,381 9/1/10 270 294 28 206 112 26 28 964 10/1/10 1,828 1,698 1,646 1,214 1,543 1,504 1,588 11,021 11/1/10 2,096 2,025 2,162 2,185 2,089 2,159 2,048 14,763 12/1/10 2,141 2,280 2,117 2,164 2,127 2,035 2,117 14,981 2010 Total 27,453 27,139 26,779 25,533 26,594 26,484 26,289 186,270 The 2010 volume of sea water injected in the PSI wells was 186 million barrels. The cumulative volume injected at the end of 2010 was 1,407 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 once or twice a year since injection began 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. The red outline shows the current interpretation of the GCWI waterfront in map view. The lighter grey lines inside the red outline show the previous extent of the waterfront since the start of injection. The information from the RST logging program was also used to develop the updated west to east cross section (Exhibit 11-2) showing the interpretation of the surveillance data for the current time period. The most recent round of RST surveillance logs were completed in September and October of 2010 and included wells L2-07A, L2-16, L2-28, L2-33, L3-05, L3-08, L3-19, 04-20 and 11-28A. As the areal and vertical extent of the water mass becomes larger, the rate of incremental advancement both laterally and vertically has become noticeably slower. At this point, the Page 12 2010 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 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. The 2010 logs continued this pattern, showing a continued lateral advancement of the water front in Zone 2C with respect to its position in 2009, and a building of water thickness in Zone 2C and Zone 3. Also, there was some lateral advancement and column building in Zone 1 and Zone 2A . There was no additional lateral movement of water seen to west near the gas injectors. The RST log in the L2-07 well, which is just to the southeast of the NGI gas injectors, still does not show any water. Also, there has been no impact on the gas injection rates of the wells closest to GCWI wells. Water continued to build to the south, as seen by observation wells 04-20, 11-28A, L2-16, L3-08 and L3-19, where additional water column was logged in Zone 2C and Zone 3. The lateral extent of the water was extended south due to GCWI water observed in the 04-20 and 11-28A logs. Also, GCWI water has been detected below Zone 2C in wells L3-08, L3-19 and L2-16 south of the main east-west trending fault near the L2-18A well. To the east of the PSI injectors, there were no surveillance activities conducted. A RST log was attempted in L3-02 but subsurface safety valve issues prevented acquisition of the log. To the north, a RST log was planned for LGI-04 but could not be completed due to well issues. 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 as shown in Exhibit 11-2. 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 2011 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 year with the final timing and locations determined based on the results to date. Gravity Survey A gravity survey is not planned for 2011 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 Page 13 2010 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT No changes to the Gas Cap Water Injection plan are expected in 2011. Page 14 2010 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. 2010 Production For the year 2010, all of the production and injection in the Put River Pool occurred in the Southern Lobe. Production from the Put River Oil Pool in 2010 averaged 825 BOPD for the days the reservoir was in production. The total production of the Put River Pool is coming from the two Put River well producers, well 02-23A and 02-27A. Injection in the Southern Lobe of the Put River averaged 4029 bwpd. Dedicated injector well 01-08Ai was shut in from August 15th to September 26th 2010 for SIP/STP TAR. In the month following the shut-down, the injection rate was raised from average 4000 bwpd to 4500 bwpd. The 2010 cumulative production for the Put River Oil Pool was 553 MBO and 746 MMscf gas. The full life cumulative production for the Put River Oil Pool through December 31, 2010 is 2.0 MMBO and 2.7 Bscf gas 2010 Pressures Put River Pressures taken during 2010 are listed in Exhibit 9. The Southern Lobe pressure obtained in 02-23A measured 3,718 psi at 8,100’ SSTVD in April 2010 and in 02-27A measured 2,998 psi at 8,100’ SSTVD in August 2010. 2011 Surveillance Plan Southern Lobe –Production will continue from wells 02-23A and 02-27A at around 825 BOPD to achieve a voidage replacement ratio of approximately 1.0. Static pressures will be taken periodically through the year to confirm volumetric calculations. Additionally in 2011 a tracer study is planned to calculate sweep efficiency of the Southern Lobe. Western Lobe - No 2011 production or surveillance planned. Central Lobe - No 2011 production or surveillance planned. Page 15 2010 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 16 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 2010 through December 2010. A total of 113 gas-monitoring logs were run in the PBU of which 53 were cased-hole. Exhibit 1-BPBU Well StatisticsWELL COUNT BY FIELD AREAWPWZNWFBEWEFS2EPWZGD2009 AOGCC ReportProducers97 61 62 115 77 480Injectors42 29 17 58 29 52 -WAG8110532 -Water Only32 28 7 52 26 17 -Gas20010332010Producers94 57 67 118 77 472Injectors44 30 17 62 30 52 -WAG1212323 -Water Only32 28 9 55 27 18 -Gas0164131Production Well Status in 2010 -Newly Drilled001110 -Sidetracked or Redrilled2 2 3 3 (incl 1 fail) 2 42Gas Injection Well Status in 2010 -Newly Drilled000000 -Sidetracked or Redrilled000000WAG Injection Well Status in 2010 -Newly Drilled000000 -Sidetracked or Redrilled100000Water Injection Well Status in 2010 -Newly Drilled000010 -Sidetracked or Redrilled000000NOTES:(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 12/31/10Oil (MMSTB)500 586 1046 615 55 2802Gas (BCF)1620 1266 4765 2756 249 10657Water (MMSTB)1134 938 3839 1478 113 7502Cumulative Injection from WF Start-Up through 12/31/10Water (MMSTB)1598 1581 5804 1993 108 11085MI (BCF)572 666 966 643 74 2920Cumulative 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 -5347Cumulative Balance from WF Start-Up through 12/31/10Cum Production (MMRB) 2992 2425 8742 4568 359 19086Cum Injection (MMRB) 2048 2003 6592 2501 163 13308Over/Under (MMRB) -944 -422 -2150 -2067 -196 -5779MI Breakthrough in Producing Wells> 200 mcfd34 23 29 30 15131AVERAGE RATE DATA 2010ProductionOil (MBD)21.1 10.5 28.9 19.2 18.6 98.3Gas (MMSCFD)262.2 61.3 645.2 409.2 79.9 1457.7Water (MBD)121.3 56.3 370.2 169.5 37.4 754.8InjectionWater (MBD)112.9 65.8 412.1 189.0 41.6 821.4Gas (MMSCFD)35.3 1.6 36.8 5.9 33.7 113.4AVERAGE RESERVOIR PRESSURE (psia)GDWPWZNWFBFS-2EPWZEWEPBMGPPrevious report period: 20093248 3308 3271 3348 3310 3663 3315Current report period: 20103259 3317 3329 3367 3329 3666 3339Estimated Annual Change (psi/yr) 11 8 59 18 19 4 24Waterflood 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 Jul-10 3367 3329 3317 3329 3259 3666 3339 Exhibit 1-G2010 Average Monthly CGF MI Rates and CompositionsEOA MI Rate *MMP MWMCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/10 25,258 3,136 32.50 20.13% 32.17% 20.49% 24.94% 1.48% 0.77% 0.02%02/10 15,273 3,079 32.66 19.74% 32.22% 20.18% 24.64% 1.99% 1.20% 0.03%03/10 26,597 3,167 32.29 19.53% 33.02% 20.35% 24.78% 1.39% 0.90% 0.03%04/10 32,919 3,222 32.14 19.87% 33.20% 20.15% 25.35% 0.77% 0.65% 0.02%05/10 38,039 3,241 32.14 20.07% 33.20% 20.56% 24.35% 1.11% 0.68% 0.03%06/10 36,946 3,194 32.33 20.30% 32.49% 20.75% 24.48% 1.15% 0.80% 0.02%07/10 15,902 3,162 32.38 19.52% 33.66% 19.47% 23.95% 1.60% 1.77% 0.02%08/10 16,226 3,136 32.45 19.17% 34.12% 18.92% 23.55% 1.84% 2.39% 0.01%09/10 59,395 3,145 32.41 19.77% 32.57% 20.55% 24.61% 1.29% 1.19% 0.03%10/10 80,278 3,188 32.44 20.90% 31.88% 20.66% 25.14% 0.89% 0.51% 0.03%11/10 81,557 3,231 32.28 20.93% 32.03% 20.99% 25.17% 0.61% 0.26% 0.02%12/10 90,828 3,229 32.27 20.74% 32.33% 20.84% 24.80% 0.99% 0.30% 0.02%Average 43,395 3,178 32.36 20.06% 32.75% 20.32% 24.64% 1.26% 0.95% 0.02%WOAMI Rate *MMP MWMCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/10 188,939 3,139 32.49 20.14% 32.19% 20.47% 24.92% 1.48% 0.77% 0.02%02/10 202,588 3,075 32.67 19.74% 32.19% 20.19% 24.64% 2.00% 1.22% 0.03%03/10 160,565 3,162 32.31 19.55% 32.92% 20.41% 24.79% 1.39% 0.92% 0.03%04/10 68,575 3,250 32.12 20.20% 33.23% 20.27% 24.85% 0.87% 0.58% 0.02%05/10 125,209 3,203 32.24 20.02% 32.85% 20.53% 24.73% 1.14% 0.70% 0.02%06/10 94,998 3,171 32.43 20.44% 32.08% 20.92% 24.55% 1.18% 0.81% 0.03%07/10 43,047 3,143 32.36 19.10% 33.82% 19.33% 24.36% 1.85% 1.53% 0.02%08/10 79,423 3,125 32.38 18.61% 34.56% 18.54% 24.03% 2.17% 2.08% 0.01%09/10 136,143 3,144 32.42 19.77% 32.54% 20.56% 24.63% 1.29% 1.19% 0.02%10/10 160,192 3,188 32.42 20.81% 31.88% 20.79% 25.09% 0.89% 0.51% 0.03%11/10 128,812 3,238 32.26 20.97% 32.10% 20.93% 25.11% 0.61% 0.26% 0.02%12/10 132,829 3,218 32.32 20.79% 32.19% 20.85% 24.76% 1.09% 0.29% 0.02%Average 126,369 3,172 32.37 20.01% 32.72% 20.31% 24.70% 1.33% 0.90% 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 10.4 9.6 11.1 10.3 9.3 8.6Free Gas 194.7 187.9 213.4 186.9 167.1 159.9Water 31.9 26.0 30.0 29.8 26.6 23.5TOTAL 237.1 223.5 254.5 227.0 203.0 192.0Injected Fluids(MMRB)Water 55.0 41.2 52.1 52.1 51.2 41.5Gas 186.8 180.9 205.4 182.7 158.3 152.0TOTAL 241.8 222.1 257.4 234.8 209.4 193.5Net Injection Volumes = Injection - Production (MMRB)TOTAL 4.7 -1.5 3.0 7.8 6.4 1.5Produced Fluids1/1/2010 -(MMRB)July August September October November December 12/31/2010Oil 8.7 8.3 9.9 10.4 10.2 10.7 117.6Free Gas 137.9 140.4 180.6 178.5 201.1 219.2 2,167.7Water 26.1 21.5 26.5 29.7 31.0 30.9 333.7TOTAL 172.7 170.2 217.1 218.7 242.3 260.8 2,618.9Injected Fluids(MMRB)Water 49.0 29.6 24.1 39.9 46.8 47.6 529.9Gas 135.2 138.2 177.5 196.4 193.3 212.4 2,119.0TOTAL 184.2 167.8 201.6 236.3 240.1 260.0 2,648.9Net Injection Volumes = Injection - Production (MMRB)TOTAL 11.5 -2.4 -15.6 17.6 -2.3 -0.9 30.0 Exhibit 3-BFS-2 Reservoir BalanceProduced Fluids (MMRB)12/31/2009 January February March April May JuneFluid Properties Used Oil 1,358.3 1.338 1.169 1.340 1.309 1.070 0.906 Bo (rb/stb) 1.323Free Gas 3,199.0 17.388 18.765 19.752 17.535 13.403 10.935 Bg (rb/mscf) 0.865Water 3,833.9 14.487 10.459 12.566 12.929 10.474 9.324 *Bw (rb/stb) 1.040TOTAL 8,391.2 33.213 30.393 33.657 31.773 24.947 21.165 Bmi (rb/mscf) 0.700Rs (scf/stb) 619.2Injected Fluids(MMRB)Water 5,786.6 15.458 11.182 13.972 13.769 12.185 11.168Gas 639.5 0.548 0.299 0.533 0.663 0.756 0.675TOTAL 6,426.0 16.006 11.481 14.506 14.431 12.941 11.843Net Injection Volumes = Injection - Production (MMRB)TOTAL -1,618.2 -17.2 -18.9 -19.2 -17.3 -12.0 -9.3CumulativeProduced Fluids(MMRB)July August September October November December 12/31/2010Oil 1.086 0.948 1.054 1.133 1.227 1.365 1,372.2Free Gas 15.820 13.447 15.003 13.792 17.356 22.751 3,395.0Water 10.388 9.209 11.165 12.417 13.547 13.560 3,974.4TOTAL 27.294 23.604 27.222 27.341 32.129 37.676 8,741.6Injected Fluids(MMRB)Water 12.501 10.635 11.653 12.951 15.399 15.565 5,943.0Gas 0.341 0.274 1.159 1.607 1.204 1.340 648.9TOTAL 12.842 10.909 12.812 14.558 16.604 16.905 6,591.9Net Injection Volumes = Injection - Production (MMRB)TOTAL -14.5 -12.7 -14.4 -12.8 -15.5 -20.8 -2,149.7 Exhibit 3-CFS-2 Areal Average Reservoir Pressure3000310032003300340035003600370038003900Jan-87 Jan-91 Jan-95 Jan-99 Jan-03 Jan-07 Jan-11Reservoir Pressure @ 8800' SSTVD (psia) Exhibit 4-BEPWZ Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2009 January February March April May JuneOil 798.8 0.758 0.678 0.746 0.808 0.771 0.761 Bo (rb/stb) 1.320Free Gas 1,916.2 8.899 8.205 8.809 10.054 10.266 10.332 Bg (rb/mscf) 0.875Water 1,654.2 5.076 4.623 5.703 5.924 5.885 5.288 Bw (rb/stb) 1.040TOTAL 4,369.3 14.734 13.507 15.257 16.785 16.922 16.380 Bmi (rb/mscf) 0.700Rs (scf/stb) 612.2Injected Fluids(MMRB)Water 2,001.2 7.647 6.132 7.232 7.465 7.077 6.325Gas 426.9 0.000 0.000 0.000 0.010 0.052 0.042TOTAL 2,428.2 7.647 6.132 7.232 7.475 7.129 6.367Net Injection Volumes = Injection - Production (MMRB)TOTAL -1708.4 -7.1 -7.4 -8.0 -9.3 -9.8 -10.0Produced FluidsCumulative(MMRB)July August September October November December 12/31/2010Oil 0.810 0.540 0.689 0.819 0.957 0.929 808.1Free Gas 11.425 6.902 10.702 11.310 14.473 13.884 2,041.5Water 5.698 3.474 4.673 5.238 6.668 6.083 1,718.6TOTAL 17.933 10.916 16.065 17.366 22.098 20.896 4,568.2Injected Fluids(MMRB)Water 5.738 3.252 2.829 5.488 6.291 6.274 2,073.0Gas 0.000 0.052 0.084 0.135 0.507 0.630 428.5TOTAL 5.738 3.304 2.913 5.624 6.798 6.904 2,501.4Net Injection Volumes = Injection - Production (MMRB)TOTAL -12.2 -7.6 -13.2 -11.7 -15.3 -14.0 -2066.7Fluid Properties Used Exhibit 4-CEPWZ Areal Average Reservoir Pressure3000310032003300340035003600370038003900Jan-87 Jan-91 Jan-95 Jan-99 Jan-03 Jan-07 Jan-11Reservoir Pressure @ 8800' SSTVD (psia) Exhibit 5-BWPWZ Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2009 January February March April May JuneOil 654.2 1.009 0.962 0.939 0.900 0.814 0.718 Bo (rb/stb) 1.319Free Gas 1,069.3 8.483 7.419 7.053 7.376 6.178 6.572 Bg (rb/mscf) 0.878Water 1,133.2 4.709 4.015 3.887 3.987 3.624 3.377 Bw (rb/stb) 1.040TOTAL 2,856.8 14.201 12.396 11.880 12.264 10.616 10.667 Bmi (rb/mscf) 0.700Rs (scf/stb) 610.0Injected Fluids(MMRB)Water 1,619.3 4.077 3.778 3.812 3.494 3.442 2.813Gas 377.0 0.719 0.658 0.501 0.256 0.550 0.466TOTAL 1,996.3 4.796 4.436 4.314 3.750 3.991 3.279Net Injection Volumes = Injection - Production (MMRB)TOTAL -705.6 -9.4 -8.0 -7.6 -8.5 -6.6 -7.4Produced FluidsCumulative(MMRB)July August September October November December 12/31/20010Oil 0.820 0.691 0.854 0.873 0.819 0.764 664.4Free Gas 6.762 5.436 6.809 5.617 6.144 5.246 1,148.4Water 3.383 3.210 4.629 4.223 3.867 3.142 1,179.3TOTAL 10.965 9.337 12.292 10.713 10.830 9.153 2,992.1Injected Fluids(MMRB)Water 3.686 2.710 3.549 4.006 3.832 3.676 1,662.2Gas 0.187 0.422 1.372 1.753 1.091 1.056 386.1TOTAL 3.874 3.132 4.920 5.759 4.923 4.732 2,048.3Net Injection Volumes = Injection - Production (MMRB)TOTAL -7.1 -6.2 -7.4 -5.0 -5.9 -4.4 -943.8Fluid Properties Used Exhibit 5-CWPWZ Average Reservoir Pressure3000310032003300340035003600370038003900Jan-87 Jan-91 Jan-95 Jan-99 Jan-03 Jan-07 Jan-11Reservoir Pressure @ 8800' SSTVD (psia) Exhibit 6-BNWFB Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2009 January February March April May JuneOil 731.5 0.505 0.390 0.387 0.382 0.390 0.374 Bo (rb/stb) 1.320Free Gas 740.1 1.832 1.368 1.038 1.323 1.369 0.852 Bg (rb/mscf) 0.874Water 907.9 2.384 1.867 1.723 1.453 1.595 1.419 Bw (rb/stb) 1.040TOTAL 2,379.5 4.721 3.624 3.148 3.158 3.354 2.645 Bmi (rb/mscf) 0.700Rs (scf/stb) 612.4Injected Fluids(MMRB)Water 1,539.6 2.182 2.165 2.185 2.056 2.160 1.746Gas 418.4 0.069 0.067 0.072 0.034 0.070 0.083TOTAL 1,977.5 2.251 2.233 2.258 2.089 2.230 1.829Net Injection Volumes = Injection - Production (MMRB)TOTAL -360.5 -2.5 -1.4 -0.9 -1.1 -1.1 -0.8Produced FluidsCumulative(MMRB)July August September October November December 12/31/2010Oil 0.449 0.383 0.421 0.462 0.415 0.500 736.5Free Gas 1.388 1.391 1.896 1.737 3.522 1.653 759.5Water 1.883 1.553 1.531 2.040 1.589 2.350 929.3TOTAL 3.720 3.327 3.847 4.239 5.526 4.504 2,425.3Injected Fluids(MMRB)Water 2.040 1.801 1.936 2.060 2.135 2.498 1,562.4Gas 0.000 0.001 0.002 0.003 0.003 0.003 418.8TOTAL 2.040 1.802 1.938 2.063 2.138 2.501 2,002.9Net Injection Volumes = Injection - Production (MMRB)TOTAL -1.7 -1.5 -1.9 -2.2 -3.4 -2.0 -422.4Fluid Properties Exhibit 6-CNWFB Areal Average Reservoir Pressure3000310032003300340035003600370038003900Jan-87 Jan-91 Jan-95 Jan-99 Jan-03 Jan-07 Jan-11Reservoir Pressure @ 8800' SSTVD (psia)C Exhibit 7-BEWE Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2009 January February March April May JuneOil 63.5 0.638 0.628 0.799 0.832 0.750 0.487 Bo (rb/stb) 1.347Free Gas 151.2 2.209 1.994 2.036 1.815 1.481 0.586 Bg (rb/mscf) 0.792Water 102.0 1.224 1.220 1.280 1.227 1.200 0.697 Bw (rb/stb) 1.040TOTAL 316.7 4.071 3.842 4.115 3.874 3.431 1.770 Bmi (rb/mscf) 0.700Rs (scf/stb) 674.2Injected Fluids(MMRB)Water 87.7 1.299 1.279 1.337 1.300 0.867 0.445Gas 42.9 1.097 1.266 1.011 0.355 0.817 0.392TOTAL 138.8 2.396 2.545 2.348 1.655 1.684 0.837Net Injection Volumes = Injection - Production (MMRB)TOTAL -154.0 -1.7 -1.3 -1.8 -2.2 -1.7 -0.9Produced FluidsCumulative(MMRB)July August September October November December 12/31/2010Oil 0.876 0.728 0.884 0.849 0.817 0.832 72.6Free Gas 1.684 1.050 1.567 1.473 1.476 1.727 170.3Water 1.253 1.031 1.071 1.322 1.265 1.421 116.3TOTAL 3.812 2.810 3.522 3.644 3.557 3.979 359.1Injected Fluids(MMRB)Water 0.978 1.740 1.795 1.637 1.362 1.735 102.6Gas 0.229 0.511 0.730 0.433 0.882 0.886 51.5TOTAL 1.207 2.251 2.526 2.070 2.243 2.622 163.2Net Injection Volumes = Injection - Production (MMRB)TOTAL -2.6 -0.6 -1.0 -1.6 -1.3 -1.4 -195.9Fluid Properties Used Exhibit 8 2010 Wells Surveyed for Gas Movement Well Log Date OH / CH GOC (MD)GOC (SSTVD)Well Log Date OH / CH GOC (MD)GOC (SSTVD) 01-14A 1/1/10 CH 11910 8900 01-01C 6/9/10 CH 10173 8632 01-22B 5/18/10 CH 10668 8938 01-02 10/26/10 CH 9590 8890 02-22B 7/7/10 OH 9522 8876 01-06A 10/29/10 CH 11445 8762 02-34B 5/6/10 CH 10078 8910 02-10B 5/7/10 CH GOC not logged 02-36A 7/31/10 CH 11080 8633 02-20 11/19/10 CH 10206 8879 03-37i 1/28/10 GOC not logged 03-22 3/30/10 CH 12865 8767 04-22AL1 11/1/10 CH 11192 8575 04-03 9/28/2010 CH 10248 8649 05-08A 9/10/10 OH / CH 11538 8962 04-20 5/30/10 CH 11452 8447 05-25C 5/28/10 CH 9823 8926 04-24 12/5/10 CH 11128 8585 05-31B 8/31/10 OH 9200 8799 05-01C 1/16/10 CH 9968 8812 05-33B 8/9/10 OH 9494 8857 05-08 1/18/10 CH 11580 8980 07-09A 12/6/10 CH 10856 8916 05-19 3/14/10 CH 9816 8829 07-23B 1/14/10 CH 9635 8884 05-27B 9/18/10 CH 11,590 8980 09-44A (Fail) 3/30/10 OH not drilled not drilled 05-28B 1/18/10 CH 12268 8693 13-21Ai 8/29/10 OH GOC not logged 05-32A 5/20/10 CH 9962 8739 13-37 10/7/10 OH GOC not logged 06-24A 11/12/10 CH 9630 8844 14-11ALi 8/23/10 OH GOC not logged 07-23B 11/28/10 CH 9650 8898 15-07CL1 6/10/10 CH 12212 8647 11-04A 9/6/10 CH 8938 8616 15-16B 4/5/10 OH 13157 8586 11-12 12/7/10 CH 12349 8709 15-27A 5/14/10 OH 12178 8644 11-28A 6/1/10 CH 12013 8519 15-30B 5/24/10 CH 11370 8670 14-07 6/7/10 CH 10919 8739 15-32B 7/16/10 CH 8943 8775 18-12B 9/5/10 CH GOC not logged 15-37C 6/29/10 CH 10837 8708 A-06 2/9/10 CH 10815 8733 17-09A 2/12/10 OH GOC not logged A-28 2/16/10 CH 11934 8775 17-12A 3/10/10 OH GOC not logged B-12A 3/5/2010 CH 9118 8713 18-10C 9/28/10 CH 12549 8617 B-18 6/2/10 CH 9065 8832 18-30A 1/28/10 OH GOC not logged B-20 5/8/10 CH 9730 8868 AGI-01A 2/9/10 OH Gas in entire well 8408 (LKG) B-21 4/28/10 CH 9586 8737 B-04A 11/1/10 CH 11357 8937 C-13A 2/17/10 CH 11254 8876 B-08A 10/28/10 OH 9920 8904 C-15A 1/27/2010 CH 9710 8891 B-13Bi 6/19/10 OH GOC not logged D-13A 3/9/10 CH GOC not logged C-20C 3/4/10 CH 11979 8800 F-23A 2/17/10 CH 11180 8947 C-28B 7/26/10 OH 11199 8926 F-27A 3/17/10 CH 10480 8956 C-37B 9/9/10 CH 9732 8890 F-28A 3/20/10 CH 9232 8949 D-11B 7/19/10 OH 10600 8935 G-09B 9/20/10 CH 10260 8918 E-02B 6/25/10 OH 9902 8838 H-08 8/8/2010 CH 9362 8884 E-15D 3/1/10 CH 10512 8850 H-11 12/18/10 CH 9114 8651 E-33B 3/1/10 CH 9980 8872 H-23A 4/17/10 CH 10350 8726 E-35B 12/4/10 CH/OH 10968 8970 K-12B 11/22/10 CH 9246 8847 E-37AL1 7/9/10 OH GOC not logged L2-07A 9/28/10 CH 11228 8596 F-04B 8/18/10 CH 10400 8944 M-11 7/2/10 CH GOC not logged F-27B 12/28/10 OH GOC not logged N-09 7/6/10 CH 9095 8630 F-47B 8/3/10 CH 9724 8940 N-14B 7/1/10 CH 9760 8832 G-23B 8/14/10 OH 9298 8913 N-16 7/5/10 CH 9970 8705 G-29B 10/5/10 OH GOC not logged NGI-03 7/24/10 CH GOC not logged G-30C 4/20/10 CH 9495 8870 PWDW3-1 6/22/10 OH drilled to 5993' NA H-02B 7/17/10 OH 10646 8723 Y-36 1/14/10 CH 11580 8820 J-13A 7/8/10 OH 11276 8934 J-18A 4/17/10 CH 12500 8910 J-20C 11/27/10 OH 11130 8912 K-07E 2/15/10 CH 9979 8749 K-11A 10/16/10 CH 11890 8916 K-12B 5/14/10 OH 9234 8840 OH - Open Hole Log P-28 5/21/10 OH GOC not logged CH - Cased Hole Log R-26B 5/3/10 Sag Only GOC not logged R-26BL1 5/6/10 Sag Only GOC not logged S-41A 9/21/10 Sag Only GOC not logged S-41AL1 10/11/10 Sag Only GOC not logged W-19B 8/30/10 OH GOC not logged W-19BL1 9/23/10 OH GOC not logged X-19BL2 10/7/10 OH GOC not logged X-19BL2-01 10/13/10 OH GOC not logged Z-03A 3/24/10 OH GOC not logged Z-16A 4/5/10 OH GOC not logged W-25A 12/6/09 OH GOC not logged W-56 12/19/09 OH GOC not logged 2010 Drilling 2010 Surveillance Exhibit 92010 PrudhoeRESERVIOR PRESSURE REPORT1. 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)01-10 50029201690000O6401508831-8843, 8849-8862, 8862-8882, 8882-8903, 8903-8910, 8910-8915, 8915-8916, 8923-8932, 8943-8952, 8967-89871/14/2010 1241 SBHP 196 8,7993,261 8,800 0.32 3,26101-14A 50029202810100O6401508964-8956, 8953-89471/13/2010SBHP 188 8400.11 31328800 0.44 3,30601-23 50029208540000O6401508890-8898, 8921-8943, 8953-8958, 8962-8967, 8975-89829/29/2010 66 SBHP 197 2 8799.93 32848800 0.30 3,28402-12B 50029202770200O6401508958-89559/30/2010 1755 SBHP 190.7 8800.28 32218800 0.32 3,22102-20 50029207210000O6401508888-8900, 8900-8905, 8905-8906, 8925-8955, 8955-8970, 8970-8980, 8996-900810/10/2010 4960 8 SBHP 192 8800.42 32768800 0.08 3,27602-22B 50029207400200O6401508954-8949, 8948-896711/23/2010 975 SBHP 191 8800.24 32088800 0.42 3,20802-27A 50029219940100O6401508143-81628/11/2010 294 SBHP 183 8199.74 29988800 0.40 3,23702-31A 50029222270100O6401508883-8876, 8885-88829/20/2010 7431 SBHP 189 8800.25 32978800 0.08 3,29703-02 50029202030000O6401508726-87455/16/2010 2594 SBHP 183 8649.87 32098800 0.44 3,27503-03 50029202110000O6401508633-8657, 8657-8673, 8683-8697, 8697-8727, 8767-8769, 8769-87776/7/2010 310 SBHP 196 8699.89 32668800 0.43 3,30903-12 50029203920000WI6401508614-8633, 8637-8652, 8667-8683, 8687-8696, 8700-8710, 8731-8740, 8762-8776, 8776-8781, 8833-8846, 8856-8884, 8893-8906, 8923-8930, 8941-89484/2/2010 16184 SBHP 154 8690.67 31648800 0.46 3,21503-24A 50029210150100O6401508791-8811, 8821-88283/28/2010 937 SBHP 184 8600.03 31938800 0.44 3,28103-30 50029211220000O6401508701-8732, 8767-8776, 8788-8813, 8819-8830, 8927-8935, 8966-89745/25/2010 7738 SBHP 174 8799.58 33238800 0.30 3,32304-01A 50029200780100O6401508639-8641, 8645-8647, 8732-8734, 8751-8792, 8831-8840, 8862-89205/25/2010 230 SBHP 183 8701.17 33198800 0.34 3,35304-22A 50029214540100O6401508622-867912/2/2010 1046 SBHP 170 8600.17 336288003,43004-23A 50029214840100O6401508532-8540, 8540-8547, 8612-86225/16/2010 6253 SBHP 175 8 8700.27 3329.4 8800 0.45 3,37404-29A 50029214530100O6401508794-87975/16/2010 82089 SBHP 173 8800.14 34398800 0.43 3,43904-35A 50029221470100O6401508562-8568, 8575-8583, 8602-8607, 8613-8639, 8633-8625, 8609-86085/19/2010 1460 SBHP 167 8599.96 33238800 0.41 3,40505-10C 50029202630300O6401508938-8938, 8937-8934, 8933-8933, 8932-8929, 8927-8926, 8923-8916, 8913-89049/18/2010 50 SBHP 186 8799.89 32188800 0.31 3,21806-01 50029201720000O6401508944-8954, 8954-8955, 8955-8964, 8964-8967, 8967-8970, 8970-8972, 8972-89909/15/2010 0 SBHP 196 8799.73 32618800 0.25 3,26106-02 50029202820000O6401508929-8943, 8965-8972, 8972-89789/16/2010 785 SBHP 201 8813.43 31958800 0.09 3,19506-08A 50029203000100O6401508823-88379/14/2010 727 SBHP 203 8799.98 32838800 0.43 3,28306-21B 50029208020200O6401508875-8878, 8859-88569/13/2010 1998 SBHP 207 8799.88 32798800 0.43 3,27906-23C 50029208080300O6401508977-8965, 8967-89669/15/2010 6690 SBHP 198 8800.03 32258800 0.36 3,22507-22 50029209250000O6401508911-8914, 8914-8929, 8932-8942, 8942-8943, 8943-8950, 8950-895210/16/2010 453 SBHP 201 8794.85 32808800 0.08 3,28007-23B 50029216350200O6401508927-8936, 8946-8963, 8963-898211/6/2010 1750 SBHP 207 8799.98 32398800 0.34 3,23907-33B 50029218090200O6401508833-8845, 8851-8862, 8869-88804/12/2010 3797 SITP 192 8800.03 32848800 0.07 3,29409-24 50029214280000O6401508781-8784, 8787-8793, 8793-88068/10/2010 281 SBHP 185 8800.27 33928800 0.43 3,39209-33A 50029213650100O6401508681-8693, 8760-8768, 8782-8787, 8812-8822, 8844-8856, 8867-88888/4/2010 121 SBHP 173 8699 5 33158800 0.37 3,35211-17A 50029215980100O6401508669-86745/15/2010 5748 SBHP 185873033058800 0.40 3,33311-26 50029216280000WI6401508719-8738, 8744-8746, 8746-8761, 8761-876212/9/2010 39829 SBHP 129 8788.61 33158800 0.44 3,32011-30 50029224840000O6401508629-8629, 8684-8686, 8689-8692, 8696-8697, 8697-8698, 8698-8698, 8698-8701, 8708-8710, 8710-8713, 8720-8722, 8722-8722, 8722-86985/16/2010 2146 SBHP 176.4 8600.06 3289.7 8800 0.09 3,30611-33 50029224900000O6401508575-8584, 8663-8689, 8698-871612/6/2010 6291 SBHP 175 8716.7 33058800 0.42 3,34012-03 50029203770000O6401508682-8690, 8690-8702, 8702-8707, 8784-8804, 8804-8814, 8821-8858, 8878-8917, 8927-8940, 8994-89966/8/2010 5359 SBHP 198 8800.34 34368800 0.33 3,43612-16A 50029208990100O6401508743-8761, 8833-8846, 8852-8869, 8874-8878, 8878-88965/31/2010 6480 SBHP 211 8799 8 33438800 0.40 3,34312-29 50029210870000O6401508797-8847, 8859-8868, 8875-8887, 8887-8889, 8889-8892, 8892-8896, 8896-8903, 8904-8911, 8911-891311/8/2010 3416 SBHP 193 8799.91 32868800 0.44 3,28613-22 50029207490000WI6401508689-8708, 8792-8812, 8817-8847, 8856-8882, 8886-8896, 8901-8911, 8915-8933, 8948-8965, 8977-89911/16/2010 18657 SBHP 154 8799.85 33438800 0.43 3,34313-23A 50029207150000WI6401508630-8645, 8727-8742, 8749-8771, 8777-8788, 8796-8825, 8837-8877, 8885-8888, 8894-8896, 8896-8903, 8903-8904, 8918-8928, 8936-8948, 8955-89627/26/2010 450 SBHP 155 8799.99 32638800 0.43 3,26313-26 50029207460000O6401508750-8765, 8786-8800, 8845-8853, 8859-8881, 8887-8894, 8903-8926, 8932-89392/10/2010 64947 SBHP 220.03 8799.67 3324.27 8800 0.20 3,32413-36 50029226130000WI6401508973-8974, 8975-8978, 8978-8977, 8976-8977, 8977-8980, 8980-8981, 8981-8982, 8982-8984, 8988-8993, 9000-900410/5/2010 330 SBHP 181 8799.89 35178800 0.42 3,51714-02C 50029203180300O6401508671-8650, 8633-8638, 8637-8632, 8630-8627, 8624-8621, 8619-86249/14/2010 390 SBHP 193 8599.77 31378800 0.43 3,22314-11A 50029205290100O6401508754-8756, 8756-8767, 8779-8783, 8803-8918, 8935-88388/31/2010 1150 SBHP 209 8800.87 33008800 0.42 3,30014-32 50029209990000O6401508730-8732, 8734-8761, 8764-8778, 8778-8782, 8782-8787, 8852-8861, 8870-8875, 8875-8888, 8888-8897, 8897-8902, 8902-8906, 8914-8923, 8923-89431/6/2010 260 SBHP 207.4 8799.57 3275 2 8800 0.12 3,27514-35 50029210180000WI6401508676-8694, 8703-8722, 8736-8754, 8764-8773, 8777-8779, 8779-87919/13/2010 382 SBHP 158 8800.22 33118800 0.41 3,31114-44A 50029225730100O6401508982-8963, 8968-8969, 8973-89929/13/2010 435 SBHP 221 8699.97 32798800 0.43 3,32215-22 50029205090000O6401508741-8744, 8748-8751, 8761-8778, 8778-8785, 8785-8785, 8789-8795, 8795-8796, 8796-8797, 8797-8798, 8798-8811, 8811-8813, 8813-8822, 8822-8826, 8826-8830, 8830-8833, 8837-88458/13/2010 138 SBHP 189 8787.78 33468800 0.16 3,34816-01 50029205330000WI6401508840-8866, 8880-8887, 8887-8901, 8901-8906, 8912-8914, 8914-8920, 8920-8923, 8923-8929, 8947-8954, 8954-8964, 8972-8978, 8978-8985, 8985-8987, 8987-89893/7/2010 14226 SBHP 169 8799.66 34248800 0.47 3,424Prudhoe Bay Field, Prudhoe Oil Pool8800 TVDss0.94. Field and Pool:5. Datum Reference:7. Gas Gravity:Page 20 of 32 Exhibit 92010 PrudhoeRESERVIOR PRESSURE REPORT1. 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)Prudhoe Bay Field, Prudhoe Oil Pool 8800 TVDss 0.94. Field and Pool: 5. Datum Reference: 7. Gas Gravity:16-03 50029205540000WI6401508890-8900, 8903-8907, 8907-8922, 8944-8958, 8977-8984, 8984-8999, 9014-9036, 9050-9065 2/6/2010 28195 SBHP 173 8799.94 33248800 0.44 3,32416-08A 50029205490100O6401508986-8935, 8949-89742/11/2010 2535 SBHP 198 8799.92 37928800 0.44 3,79216-13 50029205660000O6401508785-8810, 8844-8866, 8878-8882, 8882-8886, 8886-8907, 8935-8958, 8968-8979, 8991-8998, 9008-9012, 9018-90266/23/2010 115 SBHP 167 7300.09 28778800 0.14 3,08616-18 50029214610000O6401508799-8827, 8827-8915, 8955-8966, 8977-89841/14/2010 240 SBHP 201 8761.98 36968800 0.41 3,71116-21 50029215180000O6401508836-8851, 8861-8883, 8883-88846/23/2010 190 SBHP 189 8799.88 33198800 0.18 3,31916-22 50029220400000O6401508946-8947, 8947-8954, 8954-8961, 8964-8971, 8974-8975, 8975-8983, 8991-8998, 8998-9004 6/22/2010 105 SBHP 195 8800.13 32808800 0.43 3,28016-24 50029215360000O6401508863-8870, 8870-8877, 8877-8879, 8879-8884, 8884-8890, 8910-8924, 8924-8929, 8929-8931, 8931-8938, 8938-8939, 8939-8940, 8940-8943, 8960-8961, 8961-8961, 8961-8963, 8963-8966, 8966-8975, 8975-8977, 8977-8983, 8983-8984, 9003-9004, 9004-90165/31/2010 34090 SBHP 191 8799.74 3304 8800 0.44 3,30416-26A 50029222670100O6401508982-89931/18/2010 359 SBHP 197 8799.86 32698800 0.42 3,26917-05 50029205080000O6401508733-8751, 8830-8837, 8847-8855, 8868-8879, 8879-8887, 8893-8901, 8910-8915, 8915-8927, 8939-8952, 8964-8970, 8970-89776/21/2010 89 SBHP 206 8799.92 31868800 0.44 3,18617-09A 50029206170100O6401508888-8901, 8975-8977, 8992-8997, 8999-8991, 8989-8988, 8999-9004, 9014-9000, 8953-8964 2/23/2010SBHP 199 8799.86 38348800 0.40 3,82417-11 50029212590000O6401508935-8941, 8943-8949, 8974-89866/21/2010 76 SBHP 205 8799.89 31968800 0.43 3,19617-13A 50029212000100GI6401508718-8719, 8718-8716, 8713-8710, 8706-8704, 8701-8700, 8700-8704, 8706-87053/29/2010 18740 SBHP 192 8699.99 35198800 0.44 3,56317-14 50029211900000O6401508680-8699, 8774-8803, 8803-8838, 8846-8881, 8881-8895, 8925-8926, 8926-8927, 8927-8928, 8928-8930, 8930-8931, 8931-8933, 8933-8934, 8934-8937, 8937-8938, 8940-8944, 8968-8974, 8974-89765/16/2010 149 SBHP 196 8799.35 3305 8800 0.45 3,30517-20 50029223000000O6401508734-8752, 8830-8843, 8843-8849, 8869-8882, 8979-8989, 9002-90166/24/2010 169 SBHP 196 8800.23 34258800 0.43 3,42518-02B 50029207620200O6401508763-8764, 8782-8795, 8798-880111/6/2010 837 SBHP 182 8700.01 33068800 0.32 3,338A-04 50029201150000O6401508727-8732, 8732-8735, 8740-874811/26/2010 781 SBHP 214 8699.75 32418800 0.33 3,274A-13 50029206720000O6401508712-8720, 8728-8736, 8740-8748, 8748-8752, 8752-8753, 8753-8763, 8763-8766, 8772-8790, 8801-8821, 8821-8832, 8832-884211/29/2010 1019 SBHP 218 8699.92 32448800 0.43 3,287A-24 50029207430000O6401508749-87643/21/2010 153 SBHP 223 8600 3 31708800 0.42 3,254A-39 50029223440000O6401508663-8683, 8764-8801, 8801-8822, 8831-8889, 8899-891510/24/2010 5801 SBHP 225 8800.11 32818800 0.42 3,281A-42A 50029225420100O6401508928-8943, 8960-8968, 8976-8972, 8950-8949, 8949-8947, 8945-8942, 8932-8932, 8932-8930 3/31/2010 824 SBHP 225 8799.59 32208800 0.42 3,220A-43 50029226770000O6401508590-8599, 8599-8610, 8703-8713, 8720-8724, 8724-8751, 8751-8753, 8798-880312/1/2010 4281 SBHP 208 8699.65 32418800 0.21 3,262B-07 50029202850000O6401508848-8854, 8881-8886, 8886-8888, 8888-88896/25/2010 339 SBHP 208 8799.46 32478800 0.27 3,247B-12A 50029203320100O6401508576-8593, 8711-8715, 8715-8723, 8723-8734, 8759-8765, 8771-8777, 8779-8783, 8798-8817, 8817-8827, 8827-8830, 8841-8846, 8896-8908, 8909-8915, 8945-89536/22/2010 1009 SBHP 210 8599.44 33868800 0.23 3,432B-20 50029208420000O6401508836-8885, 8885-8889, 8889-8894, 8894-8895, 8907-8926, 8935-8953, 8959-89725/5/2010 263 SBHP 197 8799 6 32568800 0.08 3,256B-21 50029208500000O6401508760-8762, 8765-8773, 8777-8778, 8778-8784, 8789-87984/25/2010 932 SBHP 216 8700.46 32458800 0.15 3,260C-41A 50029223850100O6401508936-8936, 8929-8930, 8930-8933, 8943-8946, 8950-8951, 8953-8955, 8959-8962, 8961-8958, 8957-8960, 8961-89574/14/2010 3443 SBHP 204 8799.74 32548800 0.29 3,254D-05 50029200580000O6401508916-8925, 8932-8945, 8945-89611/12/2010 5173 SBHP 210 8799.95 32288800 0.08 3,228D-16A 50029206830100O6401508817-88216/24/2010 125 SBHP 217 8799.91 32388800 0.42 3,238D-22C 50029207370300O6401508958-8957, 8956-8956, 8956-8953, 8953-89529/23/2010 667 SBHP 210 8799.92 32038800 0.31 3,203E-05B 50029201970200O6401509016-9011, 9007-90025/5/2010 174 SBHP 193 8800.16 32718800 0.36 3,270E-11B 50029204750200O6401508967-8974, 8974-8981, 8981-90123/17/2010SITP 199 8800.18 25708800 0.35 2,569E-11B 50029204750200O6401508967-8974, 8974-8981, 8981-90124/2/2010 1481 5 SBHP 193 8800.18 27828800 0.11 2,782E-19B 50029205710200O6401508786-8798, 8798-8801, 8814-8818, 8822-8815, 8810-8806, 8810-88154/3/2010 777.2 SBHP 191 8822.78 32968800 0.32 3,296E-28A 50029217530100O6401508913-8918, 8918-8913, 8911-8909, 8940-8938, 8935-8932, 8927-8926, 8927-89275/30/2010 848 SBHP 194 8800.19 32418800 0.08 3,241F-12 50029204250000O6401508846-8872, 8880-8897, 8906-8931, 8952-8973, 8973-899012/7/2010 170 SBHP 193 8799 9 32358800 0.08 3,235F-19A 50029206290100O6401508591-862310/14/2010 262 SBHP 194 8600.19 26518800 0.34 2,719F-45B 50029221420200O6401508994-8993, 8993-8992, 8993-89934/13/2010 226 SBHP 199 8800.19 31918800 0.34 3,191G-09B 50029205820200O6401508964-8955, 8966-89609/15/2010 126 SBHP 198 8799.71 32178800 0.33 3,217G-14B 50029206460200O6401508971-8971, 8971-8972, 8972-897210/15/2010 3077 SBHP 195 8800.33 32148800 0.35 3,214GETTY-01 50029201770000T6401508614-8619, 9019-90293/13/2010SBHP 226 8829.09 33528800 0.29 3,343H-06 50029202380000O6401508579-8609, 8698-8722, 8730-8746, 8746-8789, 8797-8804, 8813-88151/26/2010 5624 SBHP 222 8699 9 31938800 0.18 3,211H-14B 50029205800300O6401508923-8911, 8910-8910, 8907-8904, 8904-89025/3/2010 386 SBHP 216 8800.08 31448800 0.44 3,144H-21 50029215750000O6401508171-8173, 8715-8719, 8727-8740, 8748-8756, 8756-8762, 8762-8764, 8767-8775, 8787-8795, 8803-8820, 8880-89148/1/2010 197 SBHP 216 8800.22 32488800 0.20 3,248Page 21 of 32 Exhibit 92010 PrudhoeRESERVIOR PRESSURE REPORT1. 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)Prudhoe Bay Field, Prudhoe Oil Pool 8800 TVDss 0.94. Field and Pool: 5. Datum Reference: 7. Gas Gravity:H-26 50029214870000O6401508856-8866, 8866-8874, 8874-8878, 8878-8884, 8894-8898, 8898-8903, 8903-8906, 8906-8909, 8909-8916, 8916-8918, 8918-8923, 8923-8926, 8926-8936, 8936-8942, 8942-8946, 8946-8952, 8952-8962, 8962-8972, 8972-89844/12/2010 784 SBHP 220 8800.26 3171 8800 0.43 3,170H-29A 50029218130100O6401508848-8859, 8863-88661/25/2010 1941 SBHP 223 8599 9 31118800 0.34 3,178H-30 50029218000000O6401508920-8936, 8943-89528/12/2010 298 SBHP 216 8800.08 32318800 0.07 3,231H-33 50029224580000O6401508692-8704, 8704-8709, 8709-8712, 8712-8719, 8724-8730, 8730-8734, 8734-8740, 8740-8759 1/25/2010 6558 SBHP 224 8799.85 32198800 0.43 3,219H-35 50029226000000O6401508739-8740, 8740-8754, 8754-8758, 8758-87696/28/2010 136 SBHP 224 8699.87 31978800 0.09 3,206H-38 50029234020000O6401508770-8767, 8761-8730, 8723-8702, 8705-8710, 8749-87558/17/2010 385 SBHP 216 8500.05 31218800 0.43 3,250J-01B 50029200200200O6401508943-89474/6/2010 14548 SBHP 123 5999.42 23568800 0.43 3,586J-13A 50029204970100O6401508944-89538/7/2010 187 SBHP 200 8802.37 32038800 0.43 3,203J-18A 50029209860100O6401508957-8957, 8958-8959, 8958-8959, 8955-8951, 8950-89405/4/2010SBHP 199 8799.69 29168800 0.44 2,916K-02D 50029210140300O6401508942-8950, 8941-89202/23/2010 167 SBHP 181 8799.82 33698800 0.09 3,369K-08B 50029214080200O6401508988-8984, 8985-89904/20/2010 785 SBHP 186 8799.84 33498800 0.09 3,349K-12B 50029217590200O6401508849-8769, 8767-87578/17/2010 1502 SBHP 189 8799.85 31728800 0.45 3,172M-12A 50029205930100O6401508747-8731, 8731-8729, 8729-8744, 8748-8757, 8761-87628/13/2010 944 SBHP 179 8699.85 32118800 0.44 3,255M-13A 50029205220100WAG6401508655-8656, 8659-86639/7/2010 33294 SBHP 197 8350.71 30708800 0.36 3,230M-14 50029205120000WI6401508684-8723, 8723-8727, 8734-8764, 8764-8768, 8775-8776, 8776-8788, 8876-8897, 8897-8931, 8931-8934, 8947-897412/17/2010 3666 SBHP 122 8666 8 31888800 0.42 3,245M-34 50029225140000O6401508592-8620, 8920-893012/18/2010 10652 SBHP 222 9 8800.05 31938800 0.58 3,193N-11C 50029213750200O6401508631-8667, 8667-8686, 8695-8714, 8714-8732, 8753-878610/27/2010 17592 SBHP 223 8599.91 31578800 0.43 3,243N-18A 50029209060100O6401508683-869010/29/2010 14566 SBHP 211 8650.03 31828800 0.10 3,197N-20A 50029213200100O6401508961-8960, 8950-8946, 8944-8935, 8927-8921, 8912-8909, 8909-8909, 8909-89098/11/2010 223 SBHP 213 8799.72 31928800 0.42 3,192N-24 50029222710000O6401508696-8702, 8702-8707, 8707-8710, 8734-8735, 8735-8742, 8742-8749, 8749-87626/24/2010 206 SBHP 223 8499.79 31058800 0.35 3,220N-26 50029224830000O6401508616-8620, 8620-8624, 8624-8638, 8638-86461/26/2010 4516 SBHP 225 8600.49 31378800 0.43 3,222NGI-14 50029203480000O6401507176-7180, 7996-8014, 8014-8021, 8021-8039, 8039-8046, 8046-8064, 8064-8078, 8078-8096, 8096-8107, 8107-8134, 8134-8148, 8148-8174, 8174-8188, 8188-8214, 8214-8229, 8229-8256, 8272-8290, 8322-836710/2/2010 151 SBHP 130 8344.31 3356 8800 0.07 3,387P-05A 50029225450100O6401508818-8831, 8919-8920, 8920-8921, 8921-8922, 8923-8924, 8924-8925, 8926-8927, 8927-8929, 8930-8926, 8926-8923, 8923-8912, 8912-8912, 8912-89816/27/2010 263 SBHP 235 8800.29 27408800 0.34 2,740P-08A 50029223770100O6401508890-8946, 8946-8948, 8949-8935, 8936-8931, 8931-8934, 8935-8935, 8939-8954, 8954-8956, 8953-8949, 8945-8945, 8944-8941, 8940-89396/29/2010 240 SBHP 229 8799.96 33208800 0.31 3,320P-17 50029221050000O6401508843-8856, 8856-8862, 8862-8864, 8864-8872, 8872-8874, 8874-8882, 8890-8894, 8904-8947, 8955-89698/20/2010 197 SBHP 231 8799.82 32548800 0.43 3,254P-21B 50029221480200O6401508870-8874, 8878-8911, 8911-8933, 8935-8950, 8953-8944, 8941-8927, 8922-8910, 8908-8885 6/29/2010 250 SBHP 226 8699.89 33788800 0.42 3,420P-28 50029234250000O6401508938-8934, 8933-8921, 8907-8912, 8917-8927, 8932-89337/8/2010SBHP 225 8793.07 35838800 0.41 3,586Q-02A 50029203330100O6401508946-8941, 8933-8936, 8938-8940, 8941-8952, 8958-89638/15/2010 49848 SBHP 181 8269.22 31438800 0.34 3,322Q-05B 50029203440200O6401508950-8946, 8945-8941, 8941-8944, 8945-894510/3/2010 683.17 SBHP 203.15 8800.05 31828800 0.32 3,182R-03A 50029203640100WI6401508644-8660, 8660-8675, 8816-881610/1/2010 2843 SBHP 152 8800.01 32428800 0.45 3,242R-08 50029205480000O6401508683-8730, 8802-8827, 8827-8840, 8849-88824/5/2010 20221 SBHP 213 8700.27 31938800 0.42 3,235R-12 50029209210000O6401508696-8701, 8790-8835, 8835-8844, 8852-8853, 8853-8863, 8863-8870, 8870-8890, 8890-8917, 8937-8950, 8950-8953, 8953-8971, 8971-898212/14/2010 9624 SBHP 206 8455.78 30978800 0.55 3,287R-20A 50029206410100WI6401508919-88654/7/2010 32675 SBHP 175 8799.78 32138800 0.38 3,213R-25A 50029222780100WI6401508769-8765, 8758-8755, 8772-8774, 8789-8793, 8808-8806, 8788-8785, 8775-8772, 8772-8771, 8771-8769, 8764-87611/26/2010 2891 SBHP 171 8750.19 32258800 0.42 3,245R-26B 50029215470100O6401508782-8773, 8781-88065/28/2010 68 SBHP 207 8799.85 28228800 0.43 2,822R-35 50029224240000O6401508811-8848, 8929-89664/5/2010 2175.13 SBHP 207 8800.35 30758800 0.32 3,075S-31A 50029221090100GI640150#N/A1/5/2010 44184 SBHP 206 8535.32 340088003,517S-31A 50029221090100GI640150#N/A7/24/2010 325 SBHP 128 6700.13 36008800 0.20 3,600S-31A 50029221090100GI640150#N/A8/25/2010 166 SBHP 132 6700.13 34218800 0.20 3,421S-31A 50029221090100GI640150#N/A8/26/2010 200 SBHP 200 8449.78 38688800 0.18 3,932S-44 50029227350000O6401508921-89024/14/2010 18024 SBHP 221 8649.81 34198800 0.36 3,473U-03 50029211730000WI6401508734-8762, 8846-8873, 8882-889911/8/2010 244 SBHP 126 8800.44 33488800 0.46 3,348U-04A 50029211910100WI6401508709-8743, 8836-8900, 8910-89505/18/2010 5349 SBHP 158 8800.39 33788800 0.41 3,378U-11B 50029214200200O6401508652-8679, 8762-8783, 8783-8797, 8797-8804, 8804-8807, 8814-88215/8/2010 1639 SBHP 226 8749.85 32978800 0.44 3,319V-01 50029232100000O6401508904-8888, 8891-8897, 8903-8911, 8910-8905, 8899-8896, 8895-88886/18/2010 13087 SBHP 234 8800.08 37888800 0.42 3,788W-01A 50029218660100O6401508811-8839, 8839-88532/16/2010 2542 SBHP 229 8799.87 33868800 0.34 3,386W-02A 50029227930100O6401508879-8905, 8906-8905, 8904-8902, 8905-8907, 8909-89254/8/2010 5882.62 SBHP 234 8799.89 35998800 0.42 3,599Page 22 of 32 Exhibit 92010 PrudhoeRESERVIOR PRESSURE REPORT1. 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)Prudhoe Bay Field, Prudhoe Oil Pool 8800 TVDss 0.94. Field and Pool: 5. Datum Reference: 7. Gas Gravity:W-03A 50029219530100GI6401508850-8867, 8867-8885, 8885-888810/8/2010 15 SBHP 180 8799.82 35268800 0.15 3,526W-07A 50029219180100O6401508867-8877, 8884-8897, 8901-8909, 8914-8915, 8889-8887, 8867-8857, 8853-8842, 8887-8896, 8901-8913, 8939-8938, 8936-8934, 8934-8933, 8926-89258/18/2010 454 SBHP 231 8800 2 34528800 0.43 3,452W-16A 50029220450100O6401508833-8844, 8848-8855, 8862-8874, 8902-8901, 8881-8869, 8838-8825, 8821-8813, 8812-8814, 8816-8848, 8852-8856, 8859-88563/3/2010 2644 SBHP 235 8699.85 34588800 0.43 3,500W-17A 50029218560100GI6401508935-8856, 8855-88953/4/2010 27925 SBHP 231 8799.86 34978800 0.14 3,497W-19A 50029220060100O6401508820-8847, 8855-8862, 8869-8911, 8921-8927, 8925-8917, 8912-8905, 8898-8897, 8897-8896, 8896-8895, 8895-8898, 8928-8932, 8934-8938, 8946-8942, 8932-8930, 8930-8925, 8912-8916, 8919-8921, 8923-8924, 8927-8932, 8932-89324/12/2010 21232 SBHP 235 8800.07 3599 8800 0.31 3,599W-19B 50029220060200O6401508866-8863, 8861-8855, 8846-8835, 8832-8842, 8844-8867, 8879-8882, 8894-889810/20/2010SBHP 213 8699.83 39848800 0.49 4,033W-19B 50029220060200O6401508866-8863, 8861-8855, 8846-8835, 8832-8842, 8844-8867, 8879-8882, 8894-889811/25/2010 214 SBHP 226 8699.83 33708800 0.33 3,403W-22 50029218690000O6401508782-8790, 8795-8803, 8811-8816, 8820-8826, 8826-8843, 8843-8844, 8848-8858, 8864-8869, 8869-8874, 8874-88991/6/2010 550 SBHP8353.57 33108800 0.40 3,500W-22 50029218690000O6401508782-8790, 8795-8803, 8811-8816, 8820-8826, 8826-8843, 8843-8844, 8848-8858, 8864-8869, 8869-8874, 8874-88998/17/2010 552 SBHP8336.26 32478800 0.40 3,432W-22 50029218690000O6401508782-8790, 8795-8803, 8811-8816, 8820-8826, 8826-8843, 8843-8844, 8848-8858, 8864-8869, 8869-8874, 8874-889910/6/2010 1680 SBHP 211 8336.26 32948800 0.40 3,468W-29 50029218340000GI6401504734-4747, 4747-4750, 4750-4982, 4982-4984, 4984-5087, 5087-5115, 5115-5122, 8787-8806, 8813-882410/9/2010 552 SBHP 157 8799.73 36248800 0.17 3,624W-30 50029218870000O6401508819-8829, 8837-8847, 8854-8856, 8856-888110/15/2010 510 SBHP 222 8800.06 35688800 0.10 3,568W-35 50029217990000GI6401508292-829510/10/2010 576 SBHP 190 8,2503,514 8,800 0.16 3,602W-37A 50029218550100O6401508860-8881, 8885-8908, 8922-8947, 8957-89676/19/2010 590 SBHP 228 8800.04 35518800 0.45 3,551W-38A 50029218070100O6401508787-8844, 8848-8829, 8827-88906/20/2010 612 SBHP 221 8,4003,434 8,800 0.17 3,502W-56 50029234230000O6401508831-8852, 8857-8864, 8876-8890, 8892-8901, 8897-8894, 8890-8850, 8849-8820, 8823-8901, 8904-8899, 8896-8884, 8879-8875, 8872-8869, 8864-8855, 8853-88503/20/2010SBHP 230 8,5282,850 88003544WGI-04 50029203860000GI6401508027-8053, 8053-8055, 8055-8072, 8074-8100, 8100-8102, 8102-8119, 8129-8146, 8146-8148, 8148-8165, 8167-8184, 8184-8185, 8185-8199, 8201-8218, 8218-8219, 8219-8246, 8248-8274, 8274-8276, 8276-8285, 8297-8324, 8324-8325, 8325-8335, 8341-8348, 8348-8350, 8350-8352, 8365-8375, 8388-8407, 8419-843812/7/2010 0.5 SBHP 134 8,0273,347 8,800 0.44 3,687X-02 50029203970000O6401508616-86423/22/2010 125 SBHP 216 8,5993,187 8,800 0.31 3,250X-07 50029204410000O6401508728-8750, 8820-8832, 8832-88453/26/2010 275 SBHP 233 8799.36 32688800 0.44 3,268X-19B 50029206760200O6401508928-8936, 8936-8934, 8931-8931, 8931-8933, 8935-8939, 8940-8940, 8939-8952, 8954-8954, 8954-8957, 8962-8966, 8970-897111/7/2010 2123 SBHP 219 8,8003,365 8,800 0.33 3,365X-27 50029211120000O6401508810-8818, 8818-8822, 8822-8841, 8841-8863, 8871-88883/27/2010 300 SBHP 225 8,7993,261 8,800 0.43 3,261Y-04 50029204230000O6401508728-8754, 8834-8845, 8845-8858, 8858-8862, 8862-8871, 8871-8873, 8882-8892, 8900-8909, 8909-89408/6/2010 167 SBHP 228 8799.98 32808800 0.42 3280Y-09A 50029205790100O6401508943-8952, 8951-8950, 8949-8949, 8951-8958, 8957-8954, 8951-8945, 8945-8946, 8948-8947, 8947-8947, 8951-8957, 8957-8957, 8957-8960, 8962-8972, 8964-8963, 8946-8935, 8935-8951, 8951-8950, 8950-8950, 8951-8951, 8952-8950, 8947-89456/28/2010 221 SBHP 229 8800.09 3090 8800 0.43 3,090Y-14B 50029218320200O6401508793-8810, 8894-8901, 8902-8900, 8902-8912, 8912-8915, 8915-89531/27/2010 339 SBHP 228 8800 3 32278800 0.33 3,227Y-20A 50029215870100O6401508891-8891, 8962-89631/9/2010 5238 SBHP 234 8,8003,406 8800 0.42 3406Y-23B 50029215900200O6401508963-8955, 8950-8940, 8940-8943, 8942-8938, 8933-89266/28/2010 230 SBHP 223 8600.26 31378800 0.42 3,220Y-29A 50029221230100O6401508909-8905, 8910-8920, 8918-8924, 8931-8931, 8928-89274/22/2010 1411 SBHP 234 8,8003,386 8800 0.35 3,386Z-01B 50029218300200O6401508852-8860, 8860-8862, 8868-8877, 8877-8881, 8881-8888, 8893-8896, 8901-8903, 8903-8906 1/6/2010 3300 SBHP8,2303,582 8800 0.40 3,810Z-01B 50029218300200O6401508852-8860, 8860-8862, 8868-8877, 8877-8881, 8881-8888, 8893-8896, 8901-8903, 8903-8906 10/6/2010 432 SBHP 210 8,2303,486 8800 0.42 3,727Z-06 50029217980000O6401508770-8778, 8786-8801, 8801-8815, 8819-8822, 8825-8831, 8840-8842, 8842-8857, 8873-8878, 8878-8885, 8885-8894, 8894-8896, 8896-8909, 8918-89356/19/2010 9668 SBHP 232 8,8003,685 8800 0.37 3,685Z-07A 50029220460100O6401508805-8815, 8815-8826, 8826-8826, 8826-8837, 8839-8850, 8850-8852, 8854-8856, 8856-8861, 8861-8864, 8864-8869, 8872-8880, 8880-8891, 8894-8905, 8922-8933, 8935-894210/10/2010 914 SBHP 234 8,7963,768 8800 0.44 3,770Z-08A 50029217870100O6401508717-8730, 8734-8755, 8764-8781, 8790-8803, 8803-8806, 8806-8807, 8807-8812, 8812-8832, 8844-8855 8856-8869 8874-887810/6/2010 2040 SBHP 197 7,7683,310 8800 0.43 3,750Z-15 50029218490000O6401508818-8831, 8849-8870, 8927-89582/6/2010 3348 SBHP 237 8,8003,608 8800 0.43 3,608Z-46A 50029232800100O6401508867-8858, 8852-88411/6/2010 10000 SBHP8,4353,695 8800 0.35 3,820Z-46A 50029232800100O6401508867-8858, 8852-884110/6/2010 672 SBHP 220 8,4353,390 8800 0.40 3,537Omitted from pressure map01-05B 50029200760200O6401508530-86448/7/2010178 SBHP 186 8,599 69 2,324 8,8000.072338Page 23 of 32 Exhibit 92010 PrudhoeRESERVIOR PRESSURE REPORT1. 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)Prudhoe Bay Field, Prudhoe Oil Pool 8800 TVDss 0.94. Field and Pool: 5. Datum Reference: 7. Gas Gravity:03-15A 50029204140100O6401508648-8659, 8659-8664, 8664-8673, 8759-8779, 8784-8795, 8795-8800, 8800-8807, 8812-8823 10/16/20105,838 SBHP 188 8,599 37 2,130 8,8000.35220103-37 50029234210000GI6401508635-8654, 8750-8762, 8768-8777, 8785-8806, 8816-8833, 8833-88494/24/2010SBHP 156 8,799.75 3,794 8,8000.47379409-13 50029202400000O6401508864-8874, 8874-8879, 8879-8903, 8915-8923, 8936-89418/3/20101,055 SBHP 191 8,799.45 3,312 8,8000.44406812-12A 50029206100100O6401508663-8629, 8628-86298/6/10171 SBHP 175 8,600 20 1,524 8,8000.04153213-02B 50029203240200O6401508328-8650, 8650-86623/26/10510 SBHP 196 8,600.17 1,367 8,8000.04137413-30C 50029207680300O6401508823-8825, 8827-8818, 8819-8827, 8826-88268/9/10246 SBHP 215 8,800 38 1,499 8,8000.04149913-37 50029234280000O6401508809-8805, 8798-8785, 8773-877010/26/2010SBHP 200.6 8,800 35 3,762 8,8000.43376217-10A 50029206220100WI6401508836-8849, 8978-8977, 8976-8975, 8973-8971, 8969-8966, 8936-8968, 8975-90096/21/201083 SBHP 164 8,799 93 4,085 8,8000.41408517-15A 50029222920100WI6401508993-8989, 8988-8985, 8983-8981, 8969-8965, 8964-89586/22/201098 SBHP 165 8,799 82 4,067 8,8000.414067A-26 50029207940000O6401508643-86516/20/20101,250 SBHP 218 8,599.70 2,801 8,8000.092819B-14A 50029203490100O6401508918-89238/9/20101,804 SBHP 208 8,799 86 3,267 8,8000.423792C-08B 50029201290200O6401508956-8960, 8966-8958, 8958-8963, 8963-8962, 8962-8949, 8944-8943, 8943-8942, 8942-8895 2/16/10756 SBHP 194 8,711 95 1,549 8,8000.251571C-08B 50029201290200O6401508956-8960, 8966-8958, 8958-8963, 8963-8962, 8962-8949, 8944-8943, 8943-8942, 8942-8895 4/14/102 128 SBHP 204 8 699 95 1 455 8 8000.051460E-11B 50029204750200O6401508967-8974, 8974-8981, 8981-90122/10/10270 SBHP 197 8,800.18 1,901 8,8000.351901E-11B 50029204750200O6401508967-8974, 8974-8981, 8981-90123/17/10SITP 199 8,800.18 2,570 8,8000.352569E-11B 50029204750200O6401508967-8974, 8974-8981, 8981-90124/2/101,482 SBHP 193 8,800.18 2,782 8,8000.112782G-07 50029203590000O6401508905-8906, 8906-8911, 8911-8915, 8915-8918, 8918-8920, 8923-8933, 8936-8954 10/15/2010760 SBHP 193 8,778 51 2,763 8,8000.072764J-01B50029200200200O 6401508943-89474/6/201014 548 SBHP 123 5 999.42 2 356 8 8000.433 586J-05C 50029201200300O6401508588-8620, 8620-86427/9/2010494 SBHP 192.8 8,400.18 2,536 8,8000.302655K-09C 50029217360300O6401508954-8953, 8952-8953, 8953-8953, 8959-8957, 8959-8956, 8958-89562/26/20105,041 SBHP 198 8,799 81 3,288 8,8000.335041P-05A50029225450100O 6401508818-8831, 8919-8920, 8920-8921, 8921-8922, 8923-8924, 8924-8925, 8926-8927, 8927-8929, 8930-8926, 8926-8923, 8923-8912, 8912-8912, 8912-89816/27/2010263 SBHP 235 8,800 29 2,740 8,8000.342,740R-19A 50029206370100O6401508911-88778/8/1042 SBHP 207 8,756 58 1,455 8,8000.041456R-22 50029210050000WI6401508761-8764, 8764-8772, 8772-8796, 8796-8805, 8805-88078/9/20101,055 SBHP 151 8,764 01 3,777 8,8000.444068R-22 50029210050000WI6401508761-8764, 8764-8772, 8772-8796, 8796-8805, 8805-88078/9/101 055 SBHP 151 8 764 01 3 777 8 8000.444068S-41A 50029226450100O6401508874-8867, 8870-8887, 8886-8886, 8893-8900, 8884-887210/25/2010SBHP 195 8,799 87 3,739 8,8000.433739X-28 50029223940000WI6401508488-849010/10/10PFO8,649 94 3,331 8,8003397Put River01-08A 50029201600100 WI 6401828275-82696/27/2010 212 SBHP 135 8,1003,844 8100 0.44 3,84423. All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission.I hereby certify that the foregoing is true and correct to the best of my knowledge.SignatureTitlePrinted DateNamePage 24 of 32 Exhibit 10 2010 IPA Shut In Well Report # 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 evaluated for RST. On GD Hopper. 2 01-09A Prudhoe 029201640100 Mar-07 7 5 SI due to prod casing leak, & flow line repairs needed. Not economic to repair flowline at this stage. Also needs RWO. Flowline 3 01-12A Prudhoe 029202690100 Oct-05 1 3 Evaluating RST. Listed on Waiting on TP Hopper on Rig Schedule (Jan 2010) 4 02-01B Prudhoe 029204420100 Jul-09 1 3 High GOR well. No more wellwork options.Well requires a RST 5 02-02A Prudhoe 029200740100 Jun-06 6 5 Well suspended. Flowline & slot used for 02-40 6 02-05A Prudhoe 029200810100 Jan-09 6 2 Evaluating poss bilies to repair TxIA. Extended Patch stuck on well 7 02-07A Prudhoe 029201540100 Jul-09 6 7 RWO Completed on March 2011. Post-Rig WW on progress 8 02-12B Prudhoe 029202770200 Feb-08 1 3 CTD Package Ready 9 02-26C Prudhoe 029207740300 Apr-07 6 7 RWO cancelled. Rig Sidetrack Candidate 10 02-31A Prudhoe 029222270100 Oct-09 1 1 High GOR. Drift well with bailer. Poss bility to POP well during winter months 11 02-39A Prudhoe 029227216000 Oct-07 1 3 Can't pull LTP. D&T fish and welltest to evaluate healing after being SI for 3 year. Need to SI 02-40 to POP this well. Sidetrack candidate. 12 03-26 Prudhoe 029210270000 Jul-09 2 4 Cannot access wellbore due to fish. Shut-in until MI from 03-33 gets close enough to POP and look for benefits. 13 03-29 Prudhoe 029211180000 Mar-06 6 2 IAxOA comm lab tests show IA and OA gas have different composition, not similar to 03-08. Starting head leak found February 2009 - evaluating RWO 14 04-07 Prudhoe 029201890000 Jan-97 7 5 Originally SI for high WC; well slot/piping in manifold has been removed so unable to pursue wellwork options. Well does not justify surface repair. 15 04-20 Prudhoe 0292099600 Aug-09 7 6 Water injection line inoperable, waiting on funds for repair. 16 04-34A Prudhoe 029221600100 Nov-97 2 2 High WC, low IOR. Planning to pursue POP. 17 04-39 Prudhoe 029221810000 Apr-98 2 5 High WC, low IOR. No Flowline. 18 04-41A Prudhoe 0292223701 Sep-09 2 2 High WC. Evaluating wellwork options. 19 04-47 Prudhoe 029224390000 Feb-03 6 5 PC leak & collapsed tubing, FL not fit for service. High WC, low IOR. 20 05-07 Prudhoe 029202430000 Jan-08 6 7 SI for casing leak, RWO package submitted though listed in Hopper as on hold due to high GOR/economics 21 05-12B Prudhoe 029202440200 Mar-05 6 5 WH leak, evaluating sealtite job or CTD 22 05-17B Prudhoe 029202710200 Nov-02 6 5 Low existing value - collapsed tbg 23 05-18A Prudhoe 029219600100 Feb-03 1 3 Casing Leak. Slimhole. Listed on Waiting on TP Hopper on Rig Schedule (Jan 2010) 24 05-19 Prudhoe 029219620000 May-09 7 6 Well POP'd in Feb 2011 after choke repair. 25 05-40 Prudhoe 029227070000 Nov-02 6 5 Failed RWO - stuck CT during cleanout 26 06-15 Prudhoe 029204590000 Jul-06 6 5 Surface casing leak, Integrity team suggests P&A 27 06-17 Prudhoe 029207600000 May-04 6 5 TxIAxOA communication - RWO cancelled due to cret damage 28 07-16A Prudhoe 029208560100 Mar-07 6 2 SI for SC leak & IAxOA comm. LP access only. 29 07-34A Prudhoe 029218120100 Apr-05 6 3 IAxOA; Stuck IBP fish in tubing. Rig ST candidate, but LP access only. 30 09-05A Prudhoe 029202150100 Nov-09 2 2 SI for high WC and H2S. 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. On WBL for gel treatemnt. Not on WBL as of 10/18/10 32 09-28A Prudhoe 029212920100 Aug-09 2 2 Shut in for high WC. Having injection issues at FS2, lots of inj in area, currently rebalancing inj with worked over inj, try WSO, adperfs for 09-15Ai, POP when 09-15Ai MIST gets close 33 09-42A Prudhoe 029220590100 Dec-02 6 5 2008 RWO failed. Now possible SC leak. Sidetrack candidate. 34 09-47 Prudhoe 029220980000 Aug-08 7 6 Actuator installed, but now broken choke. WR written.Shut in for high WC 35 09-48 Prudhoe 029221280000 Aug-04 6 2 Waiting on POP under eval. IAxOA to gas- may be manageable by bleeds. 36 11-02 Prudhoe 029206490000 Nov-06 7 6 Water injection line inoperable, waiting on repair. MI line okay and used occassionally. 37 11-07 Prudhoe 029206870000 Nov-08 7 6 Water injection line inoperable, waiting on funds for repair. 38 11-08 Prudhoe 029212450000 Nov-08 7 6 Water injection line inoperable, waiting on funds for repair. Well used for pit dewatering in 2010. 39 11-10 Prudhoe 029213940000 Jan-06 7 6 Water injection line inoperable, waiting on repair. RWO completed. 40 11-16 Prudhoe 029215810000 Sep-09 1 6 High GOR due to shut-in injector; waiting on injection 41 11-17A Prudhoe 029215980100 Sep-09 1 6 High GOR due to shut-in injector, waiting on injection 42 11-25A Prudhoe 029204880200 Feb-02 6 5 PC Leak and IAxOA Communication. No current plans. Exhibit 10 2010 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 43 11-26 Prudhoe 029216280000 May-06 7 6 Water injection line inoperable, waiting on funds for repair. RWO completed 12/2010. 44 11-28A Prudhoe 029219580100 Apr-09 1 6 High GOR due to shut-in injector; waiting on injection 45 11-29 Prudhoe 029224660000 May-06 7 6 Water injection line inoperable, waiting on funds for repair. MIT-IA for AA needed post-flowline repair. 46 11-35 Prudhoe 029224760000 Sep-05 7 6 Water injection line inoperable, waiting on repair. Slight TxIA comm, hot MIT-IA to confirm integrity post-flowline repair planned. 47 11-38A Prudhoe 029227230100 Nov-08 7 6 Water injection line inoperable, waiting on funds for repair. SC leak poss ble, but plan to address post-FL repair for testing while online. 48 12-03 Prudhoe 029203770000 Jan-09 6 2 High OA pressure post RWO that cemented OA, Seal-Tite tried twice but failed. Working on another fix (maybe a cement top job or a permanent OA vent). 49 12-07A Prudhoe 029204090100 May-09 6 2 High OA pressure post RWO that cemented OA. Working on a fix (maybe Seal-Tite, cement top job, or a permanent OA vent). On WBL. 50 12-11 Prudhoe 029206010000 Feb-00 6 5 LTSI. High TGOR, low oil rate. Stole 12-11's surface facilities for new grass roots well 12-37. 51 12-30 Prudhoe 029218910000 Dec-09 6 2 POGLM leaking.Work incomplete needs coil for fishing. Progarm on WWBL. 52 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. 53 13-04 Prudhoe 029203260000 Oct-03 6 5 TxIAxOA; produces rocks, sand screen installed, swiss cheese tubing.. Plans to further diagnose 54 13-05 Prudhoe 029206260000 Nov-97 6 5 TxIAxOA; replaced by 13-06Ai MI injector. FL decommissioned 8/09. No plans at this time. 55 13-07 Prudhoe 029206500000 Jul-91 6 5 TxIA w/ significant surface facility issues that would add ~$1MM to package. NWD screening for ST. 56 13-09 Prudhoe 029206710000 Aug-03 6 2 TxIA & PC leak; currently evaluating for RWO economics. 57 13-10 Prudhoe 029206780000 Jun-94 6 5 IAxOA on GL: uneconomic RWO (high WC). No plans at this time. 58 13-11 Prudhoe 029206040000 Dec-05 6 5 TxIA & possible packer or PC leak.NWD screening for ST 59 13-12 Prudhoe 029205380000 Dec-07 6 5 TxIA;NWD screening for ST. 60 13-15 Prudhoe 029208310000 Jul-06 6 5 TxIA & slow IAxOA. NWD screening for ST. 61 13-18 Prudhoe 029207240000 Jun-06 7 6 Needs flowline replacement; FS3 decided sleeving not an option. Waiting for O&M funding for full line replacement. 2010 line repair anticipated. Flowline 62 13-25 Prudhoe 029207610000 Oct-07 6 2 TxIA 63 13-28 Prudhoe 029209420000 May-94 6 5 PC leak & bubbles in the cellar. Replaced by 13-13A. 64 13-33 Prudhoe 029207730000 Dec-94 6 5 TxIAxOA; Plans to further diagnose. 65 14-03A Prudhoe 029203190000 Aug-09 6 2 TxIA; uneconomic RWO. Evaluating sealtite repair 66 14-14 Prudhoe 029206250000 Aug-06 7 5 IAxOA and flowline; uneconomic RWO. Flowline replacement not planned due to lack of reserves to justify entire project. Flowline 67 14-16A Prudhoe 029206080100 Oct-09 6 2 Was SI for choke repairs. Choke repairs complete and now awaiting POP 68 14-27 Prudhoe 029210460000 Nov-04 7 6 Flowline repair needed. Reserves ranked high. Flowline 69 14-31 Prudhoe 029209890000 Jul-07 6 7 TxIA poor tubing, low rate for the last 6 months of life. Previously considered for UZI, but project on hold due to FS3 projected water limitations. RWO package has been issued. 70 14-37 Prudhoe 029218100000 Sep-05 6 2 TxIAxOA; extended patch program with Wells Group for revision. RWO planned for November 2010 71 14-38 Prudhoe 029218620000 Nov-94 3 5 TxIA and low PI (SI 11/94). No flowline. 72 14-39 Prudhoe 029218880000 Jun-94 6 5 IAxOAxForm. Leak @ 81'. Flowline is corroded and not fit for service. Considering permanent P&A options. P&A progarm done & aspproved by XOM, waiting for COPs approval 73 15-03 Prudhoe 029207220000 Jun-94 6 5 Cret leak, leaking sqz perfs, major fish in tubing; surface facilities given to another well 74 15-10A Prudhoe 029205010100 Jan-91 6 5 Major leaks and a channel; no surface facilities; bottom hole location developed by 15-49 75 15-19A Prudhoe 029218290100 Oct-06 6 2 Pulled leaking patch over parted tubing @ ~ 3000' MD & Liner Top Packer, calipered liner, logged SCMT, set WRP then performed passing CMITxIA to 2500 psi before securing. Re-set the LTP in 9/08 and well tested all gas. LTP pulled & re-set with CTU in July 76 15-24 Prudhoe 029222230000 Mar-95 6 5 Collapsed tubing, cret leak, no surface facilities 77 15-28A Prudhoe 029222470100 Mar-04 6 3 MITOA fails, has cretaceous leak. Twinned with 15-22 78 15-35 Prudhoe 029224880000 Sep-03 6 5 Cret leak, dumpflooded Ivishak, TxIA and PC leak 79 15-38A Prudhoe 029224960100 Jul-09 1 2 High GOR. Sidetrack candidate. Exhibit 10 2010 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 80 15-41B Prudhoe 029224920000 Feb-07 6 5 Put/Ivishak comingling issue & already swept Ivishak zone makes wellwork unattractive. No sidetrack target. 81 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. 82 16-05A Prudhoe 029205740100 Mar-07 6 5 Low injectivity. Failed CMIT-IA 83 16-09A Prudhoe 029205580100 Jul-07 6 7 Considering for RWO EoS 2011. 84 16-24 Prudhoe 029215360000 Jul-06 6 2 Failed TIFL. 85 16-28 Prudhoe 029222760000 Oct-05 6 2 SI for high WC. SC leak. 86 16-29A Prudhoe 029222720100 Nov-06 3 2 High WC 87 16-31 Prudhoe 029222800000 Apr-95 3 2 SI for low PI. TxIA to gas only, low PI, maybe pull IBP, POP and evaluate, esp when 16-03i BOI. High WC.Try stimulation for asphaltenes. 88 18-04B Prudhoe 029208750200 Jan-07 1 3 sidetrack in 2011 89 18-08A Prudhoe 029215770100 Aug-08 1 3 ready for sidetrack 90 18-12B Prudhoe 029216150200 Jun-08 1 3 RST planned for 2011 91 18-19 Prudhoe 029215960000 Sep-03 6 7 AnnComm, preparing RWO package 92 18-20 Prudhoe 029218900000 Jan-07 6 2 PC leak @ 7900' & 8100' md. Possible RST 93 18-25A Prudhoe 029219480100 May-03 3 5 Cretaceous leak. No future utility. FL was donated to well 18-15. 94 18-28B Prudhoe 029225640000 Nov-00 6 7 Hole in tbg and casing. CTU fish in well. Preparing RWO package 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. No way to recover this well Remaining value very low anyway97A-01A Prudhoe 029201080100 Dec-09 2 5 SI for high WC. Considering Brightwater in pattern. 98 A-06 Prudhoe 029201180000 Nov-09 7 6 SI for GC3 H2S limits and A-pad header velocity constraints. 99 A-18A Prudhoe 029206300100 Jun-03 6 5 LTSI, Low IOR, SC leak & TxIA communication 100 A-21 Prudhoe 029207100000 Jun-04 8 5 LTSI. A-17 Sidetrack replaced A-21. A-44 using A-21 Facilities. 101 A-34A Prudhoe 029213390100 Mar-09 6 2 RWO 6/08 but now external gas souce causing high OAP 102 A-40 Prudhoe 029223370000 Sep-09 6 5 SC leak, TxIA comm 103 A-41 Prudhoe 029225300000 Sep-00 6 5 LTSI - cretaceous leak, TxIAxOAxSC. P&A planned. 104 B-01 Prudhoe 029200590000 Jul-06 6 7 SI TxIA. Cal shows no hole. LDL indicated PC leak. Might get UZI benefit. RWO complete Jan 2011. Waiting for surface tie-in. 105 B-02A Prudhoe 029200660100 Jul-04 6 5 T&A 9/23/06. Failed RWO. 106 B-09 Prudhoe 029203160000 Sep-95 5 5 Injects into fault. Used for pit dewatering. 107 B-11 Prudhoe 029203310000 Jan-91 2 5 T&A. LTSI - No FL ; surface facilities given to B-35 108 B-19A Prudhoe 029207030100 Oct-09 6 2 TxI com. Possible tbg patch. Coiled tubing scale milling failed. Revisit scale milling, Integrity work up next. 109 B-24 Prudhoe 029208150000 Jan-93 6 5 LTSI. Replaced by B-13. No FL. 110 B-26B Prudhoe 029209760200 Nov-09 6 2 Tbg failure during P/T for tree change out. Wells grp was working on NRWO fix. Need to look at reserves for RWO. 111 B-28 Prudhoe 029215100000 Feb-00 5 2 Injector used for GD MI pilot. Tested with ASRC in 2008 for producer conversion ~ well was HGOR. Evaluating well for ST to another location. 112 B-30A Prudhoe 029215420100 Dec-08 1 5 High GOR well. Does not heal. No remaining cycle value. 113 C-14 Prudhoe 029204130000 May-91 7 5 Well was P&A'd in 1991 and has no facilities. Reserves captured by offset wells 114 C-23C Prudhoe 029207750300 Mar-09 1 2 Recent CTD reservoir failure. 115 C-27B Prudhoe 029208430200 Nov-08 6 1 Packer leak. Working on the Packer squeeze procedure to set up the well for a CTST. NOT ON WBL 116 C-29A Prudhoe 029214720100 Nov-09 1 2 SI for high GOR. Did APF in May. No longer on WBL 117 C-32C Prudhoe 029215590300 Nov-09 1 2 Eval GSO/APF. Program is written and waiting on Wells group approval. NOT on WBL yet. 118 C-33A Prudhoe 029223730100 Aug-09 7 2 Flowline velocity constraint. Velocity 119 C-34A Prudhoe 029217850100 Nov-09 1 2 SI for high GOR. Evaluating mill/GSO/APF. NOT on WBL. 120 C-38 Prudhoe 029215710000 Nov-97 6 5 Cretaceous leak, flowline taken, evaluated CST, but add'l facility costs makes it cost proh bitive. No current wellbore utilization; reserves captured by offset wells. 121 C-41A Prudhoe 029223850100 Nov-09 1 1 SI for high GOR. On WBL. 122 CC-02A Prudhoe 029220160000 May-96 5 5 LTSI Cretaceous Disposal Well, will need MITIA test when returned to service 123 D-05 Prudhoe 029200580000 Jan-08 1 2 Low priority as a CTD sidetrack due to underruns in area. Continuing to evaluate options. ResMan working area. 124 E-14A Prudhoe 029207840100 Sep-07 6 5 TxIA Comm & surface csg leak 125 E-23B Prudhoe 029217630200 Jul-09 1 3 WID signed and package is out. 126 E-39A Prudhoe 029225870100 Sep-05 6 5 IBP fish stuck in hole. 127 F-11B Prudhoe 029204240200 Nov-09 6 5 Non Operable. TxIA communication - collapsed tubing at 8180' Exhibit 10 2010 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 128 F-13A Prudhoe 029204340100 Aug-08 1 2 Considering for Sidetrack to GDWFI. Doubtful will do anytime soon 129 F-16A Prudhoe 029206610100 Jan-07 6 5 No forward plans for this well. 130 F-22 Prudhoe 029219510000 Apr-08 6 2 Well Not Operable. Potential Rig Sidetrack Opportunity in 2011. Confirmed by PE Jan 2010 131 F-23A Prudhoe 029216580100 Jul-08 6 3 Planning to Sidetrack. Confirmed by PE Jan 2010 132 F-26B Prudhoe 029219870200 Apr-08 1 2 Consider for Adperf. (Feb 2010) 133 F-31 Prudhoe 029216470000 Jun-09 1 2 Considering Acid Job, or potential RST. (Feb 2010). 134 F-37 Prudhoe 029219740000 Jun-08 1 2 Considering for Sidetrack. Listed in the GD West Rig Hopper. (Feb 2010) 135 F-41 Prudhoe 029222030000 Sep-08 1 2 Considering for Sidetrack. Listed in the GD West Rig Hopper. (Feb 2010). Well does not exh bit signs of healing. 136 G-03A Prudhoe 029202210100 Dec-04 6 5 Notes indicate BHL replaced with G-31B. 137 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 138 GC-2C Prudhoe 029217740000 Sep-07 6 2 Monobore completion, OA valve gauge shows IAP, MITIA passed to 1700psi on 2/6/09 139 GC-3D Prudhoe 029203090000 May-03 4 5 LTSI Cretaceous Disposal Well - requires CT FCO 140 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 141 H-03 Prudhoe 029201030100 Jul-09 7 5 SI Operable disposal well in the Cretaceous. Only used for pit dewtaering and has no flowline. 142 H-16B Prudhoe 029205920200 Mar-09 6 2 NOT OPERABLE, FAILED MITOA w/N2, working SC leak repair, top job is high risk, RWO likely. POP UE for well tests. 143 H-22A Prudhoe 029215880100 Mar-09 3 1 OPERABLE. SI for low PI/high WC. Mill, set CIBP for WSO, add perfs on WBL. 144 H-28 Prudhoe 029218060000 Apr-01 6 2 NOT OPERABLE. Pkr Sqz program, reserves look okay, but thin oil column and GOC may have moved further down; needs WH choke. May decide to repair packer and then sidetrack. 145 H-34 Prudhoe 029228030000 Nov-04 6 7 NOT OPERABLE TxIA, PC leak. Repair with RWO and get Z4B well back with acid job or possible RWO and Sag ST. 146 H-37A Prudhoe 029227720100 Jul-07 3 2 OPERABLE. SI for low PI. Possible frac or add perfs. Need U Pad injector. 147 J-01B Prudhoe 029200200200 Aug-08 6 2 Cellar is bubbling gas w/Ivishack characteristics 148 J-03 Prudhoe 029200250000 Nov-04 6 2 Wellhead leak, uncertain about future fix (either RWO or SH repair) 149 J-15B Prudhoe 029209610200 May-06 6 2 Small MITIA LLR, evaluating options to restore integrity. 5/10 sent request to WBL to set LTP - will troubleshoot after setting. 150 J-17C Prudhoe 029209690300 Oct-09 1 1 HGOR. On WBL Mar 10 for Plug GSO. GSO executed and well POP 2/2011, now fulltime. 151 J-22A Prudhoe 029216980100 Nov-09 1 2 HGOR. Well POP 2/20/11, work on WBL to execute GSO. 152 K-09C Prudhoe 029217360300 Feb-09 6 5 Sealtite failed. Will eval other optioins. 153 K-10B Prudhoe 029217620200 Jan-04 1 3 RST planned for 2Q 2011. 154 K-19A Prudhoe 029225310100 Apr-09 6 5 Has a PC leak w/ a LLR of 3 bpm. Currently there are no future plans for this well. 155 L-02a Prudhoe 029230480100 May-07 7 6 Available for production, inadequate gas lift supply 156 L-03 Prudhoe 0292326900 Nov-09 7 6 Available for production, inadequate gas lift supply, low PI/ oil rate 157 L2-08A Prudhoe 029217610100 Jul-99 6 2 Evaluating RWO feasibility & poss ble non-rig fix . Can't flow to LPC due to gas limitations. 158 L2-11 Prudhoe 029228850000 Nov-08 6 7 Began showing water in 7/08. October lab tests showed the produced water to be cretaceous. RWO pkg is out. Was on Rig Schedule for 2010 - looks like it was dropped from schedule due to economics. 159 L2-18A Prudhoe 029217660100 Sep-01 6 3 Tbg and casing damaged. Evaluating repair options and TT CTD options. 160 L-50 Prudhoe 029232770000 May-07 1 6 No flowline 161 M-01 Prudhoe 029200420000 Aug-87 7 5 Suspended, replaced with M-28i 162 M-05A Prudhoe 029201940100 Dec-04 6 5 Gas lifted well TxIAxOA Communication, waiver cancelled. TTP stuck. 163 M-08 Prudhoe 029204990000 Dec-09 2 2 SI for high wc, otherwise an operable well. Tree repaired, integrity restored 8/30/09, WSO attempted but not complete. No longer on WBL 164 M-13A Prudhoe 029205220100 Mar-05 7 6 PW inj line split, AFE approved. Twin w/ M-14. 165 M-24 Prudhoe 029209390100 Mar-08 2 6 Shut in due to GC2 water handling capacity otherwise an operable well. 166 M-27A Prudhoe 029219920100 Jul-97 3 5 LTSI, low rate, money pit. Also TxIA Communication 167 M-34 Prudhoe 029225140000 Oct-09 2 6 SI for GC-2 facility constraints (high wc), otherwise an operable well. 168 N-02 Prudhoe 029200830000 Jul-88 6 5 SUSPENDED. N-24 replaced this well. SC and PC leaks. No flowline. Exhibit 10 2010 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 169 N-03 Prudhoe 029200870000 Jan-96 7 6 OPERABLE. Resurrected from P&A pile by WIC. Well has no flowline. Run DHPG for PBU testing, would need PBGL and flow through ASRC for a week of testing to build case for surface equipment purchase. Or good ST candidate. Flowline 170 N-06 Prudhoe 029200980000 Aug-05 6 5 NOT OPERABLE. Work to P&A. Too many integrity issues. Replaced with N-18A. No flowline. 171 N-07A Prudhoe 029201370100 Jul-09 1 2 OPERABLE. SI for high GOR. GSO pgm on the WBL. 172 N-11C Prudhoe 029213750200 Oct-08 6 2 NOT OPERABLE. SI for SH leak. Had been SI for High GOR. Will POP UE to get well test to evaluate for Furmanite repair. 173 N-26 Prudhoe 029224830000 Jul-09 2 2 OPERABLE. SI for high water. Eval WSO options; lab WC @ 73%. High water. 174 P-15 Prudhoe 029221200000 Feb-09 6 2 SC leak. RWO option to be explored 175 P-18 Prudhoe 029220976000 Jul-07 6 2 SC leak. RWO or ST? 176 P-22 Prudhoe 029223960000 Dec-96 6 5 TxIA comm, probable bad packer, FTS.High risk Wellwork considering obs at 10500 that failed to be milled out. 177 P-23 Prudhoe 029223930000 Jun-02 6 5 Injection lines given to P-28 178 PWDW1-1 Prudhoe 029202260000 Jul-07 6 5 SI due to poor injectivity resulting from a SSSV fish down-hole. 179 PWDW2-1 Prudhoe 029202270000 Feb-03 6 5 LTSI Cretaceous Disposal Well, PC Leak at 2992', would require redrill 180 R-01 Prudhoe 029203530000 Nov-93 6 5 Suspended with Ann Comm issues. No flowline or wellhouse. Replaced by R-39. To be used for J-Pad UZI 181 R-06A Prudhoe 029203880100 Jun-06 7 6 Corroded Flowline on 7-24-06. Flowline 182 R-08 Prudhoe 029205480000 Dec-07 2 4 Looking for options with IBP, appears to have moved uphole - operable well 183 R-10 Prudhoe 029206180000 Mar-01 3 5 LTSI, low rate (also has Ann Comm issues), Have approved CTST but needs RWO also and can't afford. To be used for J-Pad UZI 184 R-12 Prudhoe 029209210000 Nov-09 7 4 SI for GC-2 facility constraints, high GOR, high WC, high volume - operable well. Facilities 185 R-14A Prudhoe 029209090100 Sep-09 2 4 SI for GC-2 facility constraints - operable well. 186 R-17A Prudhoe 029206770100 Feb-05 7 2 Sag well with Ivishak fault water. Not competitive to flow, waivered for TxIA. Looking at CTST. Now has condemned flowline that needs major repair. Well to be visited for Sag development late 2010 or early 2011. 187 R-20A Prudhoe 029206410100 Jun-06 6 2 Surface Casing Leaks 188 R-24 Prudhoe 029212320000 Oct-09 6 2 OA repressurization - external gas source. On WBL for Gel Treatment. NOT on WBL as of 10/18/10 189 R-30 Prudhoe 029222790000 Sep-05 6 5 R-30 bottomhole reserves captured by R-41 grassroots well; however, R-30 is an excellent excavation and Sag Coil Sidetrack candidate when SC is repaired 190 S-05A Prudhoe 029208690100 Mar-09 2 9 SI for high wc, otherwise an operable well. Planning to convert to injection, glm's dummied for MIT-IA which passed. Tech package out to partners. Waiting on electrical work should be on 1Q 2011. 191 S-07A Prudhoe 029208290100 Mar-09 2 6 SI for high wc, otherwise an operable well. 192 S-116 Prudhoe 029231830000 Feb-09 5 4 Currently, no nearby producers. Plan to drill new producer, S-129, into fault block 4Q 2010. 193 S-12A Prudhoe 029214190000 Aug-09 2 6 Well has been SI for high wc until 3/5/11. Well has been POP'd to evaluate for ~1 month to get welltests and GeoChem sample and use that data to determine if there are potential Sag Adperfs. Once this one month evaluation period ends and the well once again is not competitive at GC-2, it will be shut in. The well is operable! 194 S-13 Prudhoe 029208100000 Mar-01 6 5 SI for high WC, and TxIAxOA communication, ST candidate 195 S-16 Prudhoe 029211230000 Aug-04 6 7 SC leak and IAxOA. Water handling limitations at GC2, currently impacting the IOR. When GC2 can handle more water, reconsider a RWO. Being eval for external SC repair. 196 S-17C Prudhoe 029211480300 Mar-08 2 6 SI for Low Rate, high wc, otherwise an operable well. 197 S-19 Prudhoe 029216110000 Mar-08 2 6 SI for Low Rate, high wc, otherwise an operable well. 198 S-200 Prudhoe 029228460000 Oct-01 6 5 Collapsed liner. Poss ble ST in future 199 S-216 Prudhoe 029229890000 Jul-06 8 5 Plan is to use surface hole + slot for future producer. Replaced DH location with new well S-217. 200 S-23 Prudhoe 029220880000 Apr-04 6 5 SI for IAxOA Comm, Bradenhead leak, no tbg leak but in poor condition. 201 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. 202 S-29A Prudhoe 029220820100 Sep-09 5 4 SI for reservoir management -all offset producers SI. Trying to get offsets POP'd then will return to inj. Also eval redevelopment plans in area. Exhibit 10 2010 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 203 S-30 Prudhoe 029220510000 Aug-03 6 5 TxIA. Plan to request LDL and evaluate patch options or RWO. High wc so may not have high on-time even if repair. 204 S-38 Prudhoe 029223100000 Mar-08 7 6 SI for a corrosion related line issue which is in the works to be sleeved. Previously SI for Low Rate, high wc, otherwise an operable well. Upside of +150 IOR when S-25A put on MI inj. Also a flowline issue that is expected to be repaired during next SD. 205 S-400A Prudhoe 029232890100 Oct-08 3 2 ESP failed. Extra water not needed at the moment. 206 S-401 Prudhoe 029233130000 Oct-08 3 2 Low productivity. Extra water not needed at the moment. 207 S-40A Prudhoe 029224940100 Aug-06 6 2 SC Leak. Plan to POP under eval since repaired TxIA in 4/10 to better determine SC leak depth and consider repair options. 208 S-42 Prudhoe 029226620000 Dec-06 6 5 SI for low rate. Need to investigate cause of rate drop. Also has leak. 209 T-01 Prudhoe 029212410000 Jul-99 8 5 LTSI Injector, not an effective injector 210 T-07 Prudhoe 029207330000 Jul-99 8 5 LTSI Injector, not an effective injector 211 U-02A Prudhoe 029211700100 Dec-02 6 5 Hole in tubing and PC leak; TTP 212 U-04A Prudhoe 029211910100 Feb-09 6 1 SH leak. External casing wrap on WBL. Pending other successes. 213 U-07 Prudhoe 029211270000 Dec-09 2 2 With separator back at U-Pad, POP well for further evaluation of WC. 214 U-08A Prudhoe 029211360100 Jan-02 2 5 High watercut, flowlines given to U-15A. 215 U-13 Prudhoe 029203550000 Jul-06 6 5 Low oil rate. Rock producer w/ fill. 216 U-15B Prudhoe 029225650200 Jul-06 3 5 Not producing; no FL 217 V-01 Prudhoe 029232100000 Dec-08 7 6 Operable producer, SI due to lack of gas lift in area. 218 V-201 Prudhoe 029230540000 Mar-05 8 5 Aborted RST due to surface casing leak. No planned future utilization. BHL replaced with new injector 219 W-02A Prudhoe 0292279301 Mar-07 7 7 Low PI and no area pressure support. 220 W-12A Prudhoe 029220230100 Sep-06 2 3 Cleanout of liner cement, laterals planned with Nordic CTD rig 221 X-04 Prudhoe 029204120000 May-03 6 2 LDL run ~ found 2 leaks. IAxOA comm history is barrier to NRWO. 222 X-18 Prudhoe 029206750000 Sep-05 6 1 Identified IAxOA in wellhead. Possible downhole TxIA. Sealtite on wbl. 223 X-22A Prudhoe 029223990100 Aug-08 6 7 Furmanite wrap failed. RWO waiting approval. 224 X-34 Prudhoe 029224170000 Jan-09 6 5 SC leak. Low IOR. Can't justify RWO. Eval RST. POP'd and tested 1/2009. Still uncompetitive. 225 Y-02A Prudhoe 029203950100 Oct-05 6 3 TxIAxOA GL. Future offtake Y-03Ai.Diagnostic confirm comm is not thru theWH. Rapid OA repressurization. Plan is to ST away from a fault. On long term list of candidates but not actively workinng yet. 226 Y-08A Prudhoe 029205720100 Sep-93 3 5 Limited reserve. Conv/CRWO pkg submitted for approval 5/25/06. Should be done simultant w/ Y-07Ai RST/MI fac upgrade. Declined by Partner due to uneconomic. ST to southeast Y-09 area to support Y-09L1-L1-01 227 Y-12 Prudhoe 029205170000 May-99 6 5 TxIAxOA. FTS. Poor tbg condition. - will secure for LTSI with CaCO3 L&K. ST to east toward Y-34 candidate. 228 Y-13 Prudhoe 029206340000 Feb-06 2 5 SI high WC. No short term plan. Long term ST candidate 229 Y-17B Prudhoe 029209200200 Jun-02 2 5 SC Leak; SI wet since the beginning. Plan to plugback to Y-17A perfs for Y- 03i offtake. 230 Y-26A Prudhoe 029221910100 Jan-09 3 5 Low PI well. Poor rock quality in the area. Mechanically Operable well 231 Y-30 Prudhoe 029221350000 Jan-09 2 5 This area is swept. Mechanically operable well 232 Y-31 Prudhoe 029221610000 Dec-07 2 5 SI for high WC. No obvious ST targets. Mechanically operable well 233 Y-32 Prudhoe 029221490000 Jan-09 2 5 SI for high WC. No obvious ST targets. Mechanically operable well 234 Y-34A Prudhoe 029221780100 Dec-07 2 5 SI for high WC. No obvious ST targets. 235 Y-38 Prudhoe 029225530000 Dec-02 6 5 TxIA. OAxCond. Collapsed tbg. Potential for Sidetrack candidate. 236 Z-06 Prudhoe 0292179800 Aug-08 6 3 Slow Tx IA communication, ST package approved for 2011 237 Z-19A Prudhoe 029222510100 Jul-08 6 6 OA repressurization due to shallow gas, poor cement, waiting on decision on annular vent system 238 Z-32B Prudhoe 0292192460 Feb-07 2 5 High WC, no current plans for well 239 Z-35 Prudhoe 029228840000 Apr-01 2 5 High WC, no current plans for well A. Reasons for Well Shut-In 1. High GOR, currently uncompetative 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 (Specified under comments) B. Future utility 1. Wellwork Planned Exhibit 10 2010 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 2. Under Evaluation 3. Sidetrack Planned 4. Reservoir Management 5. No Current Utilization 6. Surface Facilities 7. RWO Candidate 8. Waiting on Waiver 9. Conversion Exhibit 12Put River Sandstone Distribution