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Home My WebLink About2011 Prudhoe Oil and Put River Oil PoolsMarch 15, 2012 Mr. Daniel Seamount, Chairman Alaska Oil & Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 BP Exploration (Alaska)Inc 900 East Benson Boulevard PO, Be. 196612 Anchorage, Alaska 99519-6612 1907) 561-6111 RECEIVED MAR 13 2012 Alaska Oil & AGas nchorage Commission n Ko Re: ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL and PUT RIVER OIL POOL - 2011 Dear Chairman Seamount, BP Exploration (Alaska) Inc., as the Operator of the Prudhoe Bay Unit, submits herewith a consolidated Surveillance Report for the Prudhoe Bay Waterflood Project, Miscible Gas Project, Gas Cap Water Injection Project, Field Gravity Drainage Area and Put River Oil Pool in accordance with the requirements of Conservation Orders 341C (originally CO 279), 341D and 559. This report covers the time period of January 1 through December 31, 2011. The Operators of the Prudhoe Bay Field reserve the right to alter the content of the analyses contained in this report at any time based upon the most recent surveillance information obtained. Any questions can be directed to the undersigned or to Michael Husband at 564-4618, michael.husband@bp.com. Sincerely, I Emeka Emembolu Head of Base Management Alaska Resource, BPXA 564-5536 Attachments: Exhibits 1 through 12 Cc: S. Digert, BPXA M. Agnew, ExxonMobil Alaska, Production Inc. J. Schultz, CPAI P. Ayers, Chevron USA D. Roby, AOGCC P. Bettis, DNR W. Montague, BPXA K. Cooper, BPXA M. Vandergon, BPXA J. Starck, BPXA J. Dean, BPXA E. Apolianto, BPXA T. Rome, BPXA R. Skillem, BPXA M. Husband, BPXA March 15, 2012 This letter is to confirm that the office of the Alaska Oil and Gas Conservation Commission, has received a copy of the ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL and PUT RIVER OIL POOL - 2010 Received by: Alaska Oil & Gas Conservation Commission Employee Date March 15, 2012 Mr. Daniel Seamount, Chairman Alaska Oil & Gas Conservation Commission 333 West 7h Avenue, Suite 100 Anchorage, AK 99501 Re: ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL and PUT RIVER OIL POOL - 2011 Dear Chairman Seamount, BP Exploration (Alaska) Inc., as the Operator of the Prudhoe Bay Unit, submits herewith a consolidated Surveillance Report for the Prudhoe Bay Waterflood Project, Miscible Gas Project, Gas Cap Water Injection Project, Field Gravity Drainage Area and Put River Oil Pool in accordance with the requirements of Conservation Orders 341C (originally CO 279), 341D and 559. This report covers the time period of January 1 through December 31, 2011. The Operators of the Prudhoe Bay Field reserve the right to alter the content of the analyses contained in this report at any time based upon the most recent surveillance information obtained. Any questions can be directed to the undersigned or to David Lenig at 564-5301, david.lenig@bp.com. Sincerely, Emeka Emembolu Head of Base Management Alaska Resource, BPXA 564-5536 Attachments: Exhibits 1 through 12 Cc: S. Digert, BPXA M. Agnew, ExxonMobil Alaska, Production Inc. J. Schultz, CPAI P. Ayers, Chevron USA D. Roby, AOGCC P. Bettis, DNR W. Montague, BPXA K. Cooper, BPXA M. Vandergon, BPXA J. Starck, BPXA J. Dean, BPXA E. Apolianto, BPXA T. Rome, BPXA R. Skillern, BPXA D. Lenig, BPXA March 15, 2012 This letter is to confirm that the office of the Alaska Oil and Gas Conservation Commission, has received a copy of the ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL and PUT RIVER OIL POOL - 2010 Received by: Alaska Oil & Gas Conservation Commission Employee Date ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL JANUARY THROUGH DECEMBER 2011 2011 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT CONTENTS SECTION 1.0 INTRODUCTION 2.0 OVERVIEW PAGE M �41 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 14 5.0 GAS MOVEMENT SURVEILLANCE 15 5.1 Gas Movement Summary 15 Page 2 2011 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 WPWZReservoir 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 - 2011 12 Put River Lobe Map Page 3 2011 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 2011. 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 2011 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 2011 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 2.0 OVERVIEW Exhibit 1 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 2011, field production averaged 231.1 MBOD, 6894 MMSCFD (GOR 29,835 SCF/STB), and 888.5 MBWD (water -cut 79.4%). Waterflood project injection during this period averaged 1,411 MBWD with 131.3 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2011 was 11,376 MMSTB, while cumulative MI injection was 2,967 BCF. Cumulative production since waterflood startup was 2,835 MMSTB oil, 11,199 BCF gas, and 7,782 MMSTB water. As of December 31, 2011, cumulative production exceeded injection by 6,224 MMRB compared to 5,779 MMRB at the end of 2010. 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 2009 through 2011 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 IE, the historic pressure decline appears to have stabilized due to gas -cap water injection with 61% of repeat 2011 pressure surveys found equal to or greater than their 2009 or 2010 pressure measurements. For 2011, average pressure in the PBMGP project areas using three years of pressure static measurements was calculated to be 3,340 psia by areal weighting, as compared to 3,339 in 2010 (Exhibit IF). The GD area pressure was stable rising eleven psi from 3,265 psia in 2010 to 3,274 in 2011. 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 111 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 Page 5 2011 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT average RMI rate over the number of producing days in a well exceeds 200 MCF/D. The previous year showed MI breakthrough in 131 wells. The increase in RMI can be attributed to maturing of MI injection patterns in the PBMGP areas. Exhibit 1-G shows the 2011 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 2011 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 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 2009 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 2011 pressure map using 2009 through 2011 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 2012 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 2011 is presented in Exhibit 9. Page 6 2011 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 105 producing wells and 64 injection wells that contributed to production/injection during 2011 within the FS -2 flood area. Production/injection data was calculated with the polygon boundaries as in last year's report. The FS -2 waterflood area oil production averaged 27.6 MBOD for 2011 compared to 28.9 MBOD in 2010. Cumulative production since waterflood start-up through the end of 2011 is 1,056 MMSTB of oil 5,020 BCF of gas, and 3,979 MMSTB of water. Injection rates averaged 411 MBWD and 62.9 MMSCFD in 2011. Since 12/31/10, the waterflood imbalance has increased from a cumulative under injection of 2,150 MMRB to 2,349 MMRB under injected. During the report period, production exceeded injection by 199 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 2011, is 5,954 MMSTB and 988 BCF respectively. The flood area's GOR increased from an average of 22,341 SCF/STB in 2010 to an average of 25,298 SCF/STB in 2011. Gas influx continues along the FS-2/GD GDWFI area, and in the high permeability conglomerates in the Updip Victor area. Water -cut is 93% in 2011 and remains unchanged from 2010. A breakdown of the production and injection data is provided in Exhibit 3-13 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 3,369 psia in 2011. This is an increase of 2 psi over the 2010 pressure. Exhibit 3-D is a presentation of 2011 average returned MI (RMI) rates. Miscible gas return has been confirmed in 24 wells by gas compositional analysis (RMI>200 MSCFD). Page 7 2011 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 2011, oil production averaged 17.6 MBOD, as compared to 19.2 MBOD in 2010, with an average 90% water cut and 22,714 SCF/STB Gas Oil Ratio. Injection averaged 160.7 MBWD and 8.1 MMSCFD of miscible injectant (MI). There are a total of 79 producers and 30 injectors in the flood area that contributed to production/injection during 2011. 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 621 MMSTB of oil, 2,902 BSCF of gas, and 1,537 MMSTB of water have been produced with 2,052 MMSTB of water and 646 BSCF of miscible gas injected. Exhibit 4-B shows the monthly injected and produced volumes on a reservoir barrel basis during 2011 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 129 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 3,345 psia in 2011. This is an increase of 16 psi as compared to 2010. Exhibit 4-13 shows the 2011 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 19 wells (RMI >200 MSCFD). Page 8 2011 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 20.6 MBOD, as compared to 21.1 MBOD in 2010, with a gas/oil ratio of 12,249 SCF/STB and a watercut of 86%. Injection averaged 121.5 MBWD of water and 38.2 MMSCFD of miscible injectant. For the WPWZ project, 45 injectors (7 WAG injectors and 36 water injectors, 2 gas injectors), and 98 producers contributed to the production and injection during 2011. 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 2011 was 1,642 MMSTB while cumulative MI injection was 586 BSCF. Cumulative production since waterflood start-up is 508 MMSTB oil, 1,712 BSCF gas, and 1181 MMSTB water. As of December 31, 2011 cumulative production exceeded injection by 1024 MMRB. Exhibit 5-13 provides the monthly injection and production data from 01/11 through 12/11. During the report period, production exceeded injection by 80 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 -I slug catchers to GC -3 produced water tanks. This allowed up -dip Zone 4 waterflood expansion and should allow ideal voidage replacement in the eastern half of the WPWZ area. Exhibit 5-C shows that the pressure in the WPWZ was 3,308 psia in 2011. This is a decrease of 9 psi over the pressure reported in 2011. Exhibit 5-D indicates wells with MI breakthrough and the 12 -month averaged returned MI rates. Miscible gas breakthrough has been confirmed in 32 wells by gas compositional analysis. Page 9 2011 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 10.1 MBOD, as compared to 10.5 MBOD in 2010, with a gas/oil ratio of 6,517 SCF/STB and a watercut of 84%. Injection averaged 52.3 MBWD and 8 MMSCFD of miscible injectant. For the NWFB project, 28 injectors (3 WAG injectors, 25 water injectors, and 0 gas injector), and 63 producers contributed to the production and injection during 2011. 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 2011 was 1,600 MMSTB while cumulative MI injection was 668 BCF as detailed in Exhibit 61-C. Cumulative production since waterflood start-up was 590 MMSTB oil, 1,293 BSCF gas, and 958 MMSTB water. As of December 31, 2011 cumulative production exceeded injection by 427 MMRB. Exhibit 6-B provides the monthly injection and production data from 01/11 through 12/11. During the report period, production exceeded injection by 25 MMRB. However, this does not include support obtained from aquifer influx or gas cap expansion. The areally weighted pressure in the NWFB area was 3,322 psia in 2011. This is a decrease of 7 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 17 wells by gas compositional analysis. Page 10 2011 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 16.3 MBOD, as compared to 18.6 MBOD in 2010, with a gas/oil ratio of 3,700 SCF/STB and water cut of 69%. Injection averaged 52.1 MBWD and 13.4 MMSCFD of miscible gas injectant. For the EWE project, 17 injectors (13 WAG injector, 4 water injectors), and 64 producers contributed to the production and injection during 2011. Of the 13 WAG injectors, 0 injected gas only, 6 injected water only and 7 injected both gas and water in 2011. The well counts reflect only the active wells for the year. Cumulative water injection from waterflood start-up in September 2001 through December 2011 was 127 MMSTB and cumulative MI injection was 79 BCF. Cumulative production since waterflood start-up was 61 MMSTB oil, 271 BCF gas, and 127 MMSTB water. As of December 31, 2011 cumulative production exceeded injection by 209 MMRB. Exhibit 7-B provides the monthly injection and production data from January 1, 2010 through December 31, 2011. During the report period, production exceeded injection by 13 MMRB. The EWE pressure was 3,642 psia in 2011 representing an average pressure decrease of 25 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 19 wells by gas compositional analysis. Page 11 2011 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 4.6 Gas Cap Water Injection Project Details of the volume of water injected into the Gas Cap during 2011 are shown below; units in thnmands of barrels of seawater iniected ner month (000 BWM): The 2011 volume of sea water injected in the PSI wells was 154.8 million barrels. The cumulative volume injected at the end of 2011 was 1.56 billion barrels of sea water since the project startup in 2002. 4.6.1 Observation Well RST Surveys and Zonal Conformance The RST (Reservoir Saturation Tool) 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. By comparing the latest RST logs with the baseline and previous logs, the presence of injected 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 dashed green outline shows the current interpretation of the GCWI waterfront in map view. The lines inside the green outline show the previous extent of the waterfront in 2009, 2008, and 2005. 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 October of 2011 and included wells L1-02, L2 -07A, L2-24, L2-32, L3-11, L3-12, L5-05, 04-20, 11-28A, 11-32, 18-06B, and 18-12C. 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 Page 12 PSI -01 PSI -05 PSI -06 PSI -07 PSI -08 PSI -09 PSI -10 Monthly Totals 1/1/2011 2,203 2,243 2,112 2,243 2,228 2,171 2,156 15,354 2/1/2011 2,309 2,341 2,358 2,346 2,353 2,354 2,324 16,386 3/1/2011 3,177 3,164 3,138 3,172 3,134 3,169 3,145 22,099 4/1/2011 3,181 3,133 3,144 3,151 3,188 3,171 3,168 22,136 5/1/2011 3,082 3,063 3,085 3,049 3,098 2,409 3,091 20,877 6/11/2011 1,282 1,198 1,168 1,554 1,597 1,729 1,877 10,406 7/1/2011 0 0 0 0 0 0 0 0 8/1/2011 0 0 0 0 0 0 0 0 9/1/2011 335 398 176 401 348 277 31 1,965 10/1/2011 1,551 1,347 1,481 1,493 1,533 1,279 1,466 10,151 11/1/2011 2,821 2,836 2,830 1 2,822 1 2,817 2,8141 2,829 19,769 12/1/2011 2,198 2,200 2,280 2,302 2,226 1 2,2391 2,216 15,661 2011 Totals 22,139 21,922 21,771 22,532 22,522 1 21,612 1 22,304 154,803 The 2011 volume of sea water injected in the PSI wells was 154.8 million barrels. The cumulative volume injected at the end of 2011 was 1.56 billion barrels of sea water since the project startup in 2002. 4.6.1 Observation Well RST Surveys and Zonal Conformance The RST (Reservoir Saturation Tool) 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. By comparing the latest RST logs with the baseline and previous logs, the presence of injected 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 dashed green outline shows the current interpretation of the GCWI waterfront in map view. The lines inside the green outline show the previous extent of the waterfront in 2009, 2008, and 2005. 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 October of 2011 and included wells L1-02, L2 -07A, L2-24, L2-32, L3-11, L3-12, L5-05, 04-20, 11-28A, 11-32, 18-06B, and 18-12C. 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 Page 12 2011 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT point, the changes in the waterfront have followed a predictable pattern established in recent surveillance, where most incremental waterfront changes are seen in Zone 2C, with less additional water logged in lower zones. The 2011 logs continued this pattern, showing a continued lateral advancement of the water front in Zone 2C with respect to its position in 2010, 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 slight lateral movement of water seen to west near the gas injectors. The RST log in the L2-07 well, located slightly southeast of the NGI gas injectors, showed water for the first time in 2011. However, 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, and 11-32 where additional water column was logged in Zone 2C and Zone 3. There was lateral movement of water to the east of the PSI injectors. Surveillance was conducted in L5-05 and water was seen in Zone 3 and Zone 4. 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 2012 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 2012. 4.6.3 Plans for Change in Project Operation No changes to the Gas Cap Water Injection operation are planned for 2012. Page 13 G @ i— :: / co, , m , 2mm �2f%¥9 kIL \ r, „ :, :, _ E_ , N , t6\ !) 6) ]f! ƒf) J0 )M) & «f@ EL.) �f1 w M U)U. [, ,_ :, 00 00 , k §— m= ,, „ ,: , )/ e— ,_ k LL Gm, :: 00 _, ,o m, § § 222G: W®w:, „ , „ _, „ 00 G 0 / 2mm �2f%¥9 kIL \ \ 0 « E_ kdt t6\ !) 6) ]f! ƒf) J0 )M) #f@ «f@ EL.) �f1 o O h mmN mhcomm Mm O M r m4z M N a Nqm Om �9mm N IM N N M NN m n N�h �N mmtn (O ��t0 � N m m M mph h� amm N m 3~ N h N m M't m mom m M m rp N N h h h m m m m w m m m N m- V IM N N M NN N m m m M m N m M M N m top N w oo N h N m M't m mom m M m rp N N h N m 0 m mNOM N m N m m N N dh' N N h d0' tN0 M m W 0 �m0 N m �a0 m m NNO N 0� m O MOO 0, NI h m M M N O O m MM m mo' h m mmN h m mmN N h W m Nmm N It m wmm o m m m O m O m m N N O N N t h h N � m UO m N m m NN N M N M MM V O p NN 7 0 N N O M m m m m 3 Mo. Z MM NM N W4 M M 0 h M. N m� m M, m o m --0 N 0 m N N Mom m - M N N NN. 3 N O m Cm�l Ol minim � M M r r o a r M OI O O r O1 r OI w � � > O > O a f4 w LL N N y 3 N EE 3 3 3 c rc O Q w C EE w O m E O m a O r Q a LL' N N l o w jrQ w a F cc d d Ir CO m Cc cIr V o d =� c c? rn F N a s IL Fm- c fm- m e m c? o Q O O K n o c >F'LL� >� >� m d >'00 t 'O d nQ '� v o W O. -.mm mN w m m v)U� m _ALL U o d� -> A o d c7 E m O�� cgg m c .d C7 ¢ d o c m d m grL `d >a` o m `m _> m E E N E «' E E E E E E m w m w O= N N w U O C7 U ?i 7> U 0 U 0 >>>> U U 0 0 E N n > N d Q a 0 C7 3 c 3 (7 > 6 E O N a U w L- ------------------- i; s ' + + m -03 Cap NI] V030 0=]!t ypF of^_ O ]eL 2011 ' �1 zasu q at 8800' SS Datum • 201' " 1]-09A 1 A1A 1"M IB?28� ' 3,050 - 3,150 g • 201 0 • lB i 1>.33 ]]e3BJA 3000 3•A I i L:M 2 31 • SDAB 33,9 i »^9 y aB 3,150 - 3,225 psi - Pru, �— 3,225 -3,300 psi L-._, Uni! z e • I0 :l.1 3,300 - 3,420 psi Q Depl O B ]Sq -a 11 3J- F.]L •I -']A V, ---------_� 1 •T-�1° ' ]''' '-.A use NOTE: En -- 3,680 - 3,790 psi points havi I - D♦193 3391 3,790 - 3,890 psi 3 w.zoA • BeP xsv wx .v�9 I______ ISq%I —IA • 3,890 - 4,000 psi a more ace I Z�T3A OB-S1A 0 5,000 3� \ ! II-:MII 300 om Ga. F 2 I B IO ewJ 1 &Iwn 1. 10'10 B19B ' 11 I•1415 I�SSt19#�� IB.F$ O O •,L� 3.]] • I ]Sim ...0 -050i[jpB Jy� ]]IIB -11 1}0! 2011 Reservior Pressure O 20 at 8800' SS Datum • 201' " 1]-09A 1 A1A 1"M IB?28� ' 3,050 - 3,150 g • 201 0 • lB i 1>.33 ]]e3BJA 3000 3•A I psi • SDAB 33,9 i 3,150 - 3,225 psi - Pru, �— 3,225 -3,300 psi L-._, Uni! 3,300 - 3,420 psi Q Depl 3,420 -3.550 psi —---------------- ---------_� 3,550 - 3,680 psi NOTE: En -- 3,680 - 3,790 psi points havi 3,790 - 3,890 psi the field pe 3,890 - 4,000 psi a more ace 0 5,000 10.000 20,003 300 I El P, 0 P 4 en R R 7 n W C R 7 N OP V m O n M M M M M M M M M P, 0 P 4 en R R 7 n W C R 7 N OP V m O 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 Jul -11 3368 1 3345 1 3308 1 3322 1 3265 1 3640 1 3338 N c O N O CQ G O U R N d r r _ r d LL L � L) :E W t i O m CD m L r. 0 N 0 0 0 0 0 o a o 0 0 a o 0 0 0 0 0 0 0 0 0 0 0 } 0 0 0 0 0 0 0 0 0 V o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a o 0 0 0 0 0 0 0 0 o e o 0 V m'v� mvvv r.N(nm o ZM (n (nrr-� mrnrnm (u 0000.-0000�� o o a o 0 0 0 0 0 0 0 0 0 0 p m (O r M m m m N m m M � 'd d'mg 000MM N O 0 >, a. o 00 0 0 0 0 0 0 0 o e o t 0 0 0 0 0 0 0 0 0 0 0 0 0 O V 9 m m r r m v M M M r p V 0 o r o rn M o 0 o m m r r M d N N N N N N N N N N N N N d m L o 0 0 0 0 0 0 0 0 0 o s o > 00000e000000 0 QNrn vorr-r `0)m m V m000M (n m(n (0 OO N N N N N N- - -- 0 o e o 0 0 0 0 0 0 0 0 0 0 0 0 o e o 0 0 0 0 0 0 0 V m m o rn 7 7 0 m m � rn V r M m v 7 7 m m m m M M M M N (V M M M N M M M M M M M M M M M M M M M M M 0000000000eo 0 0 N N 000N n((p((0 � U o o c o of of of ai o of of of of 33rm�,ommrmi we owarow 3 rn m �i rov M noi(O+I N U ( 9 N 1 O r O m N O M O m r 0I m m N IL rmM(0 V?mNmOO O) H mm v- m m m o 0 0 o m C N_ M N_ N _ -1-1 N_ _ «pm('�(n(�im(�+�oomv(Moamo i M M M M M M M M M M M M M co m LL �1r NNMM D7 N �N N KN V O r ( Ln m M r m O O m r m O ��v(n (nm ui mr�Oi V'N Mr (orrnvvrmmrnm n d $�amaa(or- Was a�a w r 000000000 0 0 0 0 0 0 0 0 0 Q o 0 0 0 0 0 o e o 0 o a o } o 0 0 0 0 0 0 0 0 V 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ego 0 0 0 0 0 0 0 0 0 o e o �"tUn((9 n Z r- m cl cl 0000.-0000�� o o 0 0 0 0 0 0 0 0 0 0 0 0 a U D 7 m m m N r M N N (o (n m m o m ((� ((� (r� (n (q M � 'd O a >, t o 00 0 0 0 0 0 0 0 o e o �Mrfl. mrmMr MO)mm O V r 0) m N N N O "77 N N N N N N N N N N N N N d m > o 0 0 0 0 0 0 0 0 0 o s o Q N m m O CO r r 0 r O N N O Umr rnMMrnr.M Oo r Of O 0 0 0 m m CD m m m m N N N N N- - -- 0 o e o 0 0 0 0 0 0 0 0 0 m v m m m r m m rn V m (O O M O r m m N 0 0 0 V M 00000000000e o iOr�M 0 N N 000N n((p((0 � m 33rm�,ommrmi we owarow 1 O r O m N O M O m r 0I m m N r N m r r m 0 0 0 N N N N M N M M M N N N N � M (") (•1 ("1 M M M M M M M M M «pm('�(n(�im(�+�oomv(Moamo dLLrnMmmromv(°�'N�ra co m O N(NO�,NY m i r 000000000 Q O_ co (D d Cl) ai �* V n CO N N ntOnrn m 00 coN .1CMi r N - a) M M N co V N N O D) co M r N M N n (D O Cl) O co M N I N rn m rn m n (OD N T V (D r Cl) CO r r N ,r N V CO L N N t.: LO LO r M a N C r N M(D ro N N � r � r N CO r N N N y CIS 0) N r o N N X W 0ca y E r) (0 ca a LL coco r N G � 7 C ai vi of (o 9 r C 3 o O N N LO _3 T O m Z U ccld LL V. co (D d Cl) ai �* V n CO N N ntOnrn m 00 coN .1CMi r N - a) M M N co V N N O D) co M r N M N n (D O Cl) O co M N I N rn m rn m n (OD N T V (D r Cl) CO r r N ,r N V CO n N N LO LO r M a N C7 r N M(D N N O (O D) V E r N O _TvZ•Z4=41 co tO Cl(OD n N N v v n yr do co N N r N 0] N O co N V n V V I m my 0 m co to N r r 00 O ,r V r (D N N M tD O a U) C7 V LO N N 0) Cl) N E O V O L N N y CIS 0) N r o N �O tD COId m H r N G � co co (D � ai vi of (o 9 r C r LL O N N LO _3 T O m D U ccld LL 'O a) o v n r N C r+H a a` 0 L r N �� 0 �i(7� Z� 7 N E N U N N E ro O z ro a O U O `m E ro d O m cm a _T Cl) V Cl) O r (6rl: L6 r (D Cl) r M to N N (O Co V N O D)N N r N Cl) N r O Cl) to O N M N a m rn n n v (D N N M O r V aiorm CO N N n r r rn n m N (0 (0 nvr-m (0 n r LO C\j N T N N V co to N r r 00 O V r (D N N M tD O a N C7 V LO N N 0) Cl) N c0 O V O L N N y CIS 0) N r o 00 tD COId m r N 0) co co (D rn ai vi of (o N r D) r O OR 0? r cucamo � �H O N N LO T 0 m v n r 0 n CO N a V r N () r 7 ' 0 N D N O > � � C LL 3 O y CIS LL V 0¢ .0 c 0) -j02' ++ d� m ¢ NH .(D 2 a`'o —0 — � LL cucamo � �H c� 3: 0 / ( � � ( N I{ § - ..\/�� `, / ( d N N d CL O IL LL CO (VD V O M CO O f- r U o E E N in E�� concw I-, O c! r O Cl) ^ N cher, V O O r� O co p N 0 V O O m m I, N CO N V CO N 3 m N M M 9 m clV Oi Cl) m Ea N N N r� O co n N ce ce m r N ,-- Cb c6 r o (i r C) C) W :E cc, N r CD N � U - 2 o 0LL�: - IL V co o �C7F I,(c77 m 1, C N m N V r w N CO O Z N m OD (D V m N ((D O N (mo r C) (D -0 r (D N N - (f7 r (LJ U Q - M M ` N n O E O N r r CO d O m LO co .0 Qi ,� M M m O N CO rNr (6r� W(6 c�j N Ch vO7vo ItU)0) LL ca T (D V N r m 0 �coTCi uio(o CO r LL LL 00 co qt CD to in 0 N O T O NCD co C N p N 0 V O O m m N (� 3 m N M M 9 m clV Oi Cl) m Ea r N ce ce m r m coV(mO O O O (i r C) C) W (O O V N N I N V (D (n (D n N O CD r, 3 m N M M 9 m clV Oi Cl) m Ea T U UO 00 m n O O (i N V O C) C) I, 'p O` r V N N � U - 2 o 0LL�: - IL OLL�F co o �C7F r (D (n (D n (n r CD N O CD r, CV7 N M M N V I�- clV Oi Cl) m Ea T U UO 00 m n O O (i N J V O C) C) I, 'p O` r V N N � U - 2 o 0LL�: - Ol (p 0 3:17F - I,(c77 m 1, N m N V r w N CO O Z OD (D V m N (D O m O r C) (D -0 r (D N N O U O N n O E D ci N r r CO d O m LO V O O V N O N co r O) r N W V V (n n o V (O co O r m N N (O h m O T 1� m N C) r V (O O cor O m V co 00 j m OD(pgv ol� r T Y 1 V co r � (D CO V C r N O O C N O CD r, CV7 (D (D N N V I�- r N O m n Om Vh N UO 00 m n m (i N J V O ' N (O h m O T 1� m N C) r V (O O cor O m V co 00 j m OD(pgv ol� r T Y 1 V co r � (D CO V C r N O O C N 7 m 9 m LL Q 7 R (i N J N J 'p O` Q N N cu V N Q NN F- 0 IL - 2 o 0LL�: - E (p 0 3:17F - M co O M M Cl) m M Cl) (eisd) 4AM,0088 @ sinssaJd JionJasaa )_ Cl 2 f<§ ` \ LLL j )) A 3� 11 CN 00 \- ` ! �® $ CL <]] �E< - ; )I\ § LL ! ) k { ! i . i \ ! ^! , ,.,««« ! } , IL /\)4u! z` <q< T O m r n > O m O ro(�I CMO � (OD mrr,- r� Cl) N r d' Ea m 4) NO O 0, COLO m N CV N V OD �o N N r V O E 0T(om a) U �M0001n - a) (a 0 O m a (D V a) U) O r 0 co L N. CO LO (D E o o Lri co a) N z E V a) r- CV LO LO L O m d V O U O CL U a) N jo CD LO m E o6vLo p N L^ L r (L a) E IL w E E 42 M LO N O LO N 00 (O y M O m co o V CV n LL O T ? E U m m m m m N00 O co O r N co M N O COO 000 000 V C:5 vr-� (Dor- � r r O) c0 O LO O N O co n(hcv �v0 D iv C o .= LO r r` o c6 C r L v i m rCO T LO NCl) r� r N m m coco co co 'Q O N (O m V' CO r Q O CDD O co ui n LO (NM\l COO i y L co co V m N r M 01 O T (6 06 O r ' WN� ca IL N : r n LO co m (D N M IL ` m V LO co LO N (V CO co m (D r CO W Or LO CD (DOco T U- C C O n LO V r N CO 04 COO M CR n n N m C r coN O m Cl) Cl) LO O O ' N L O O r LO O CV O IO V ar- 'gip N co O r- LOO O V LOO _O O N r V C\ N �'' N E c) 4) •C U ,- II d E N O 9 •� m 'NO m C ILL 0 a O 4f 7v v C a)CD LQ r LQ (A r LQ V r a.` 0 L 3:(D z� a T O m r n > O co O ro(�I CMO � (OD mrr,- r� Cl) N r d' Ea m U T COLO m N CV N V OD �o aoLf) OrO E 0T(om a) U N - a) (a 0 O m a (D V a) CO CD CO m L N. CO LO (D E o o Lri co a) 'o z N cm O V a) r- CV LO LO L O m d V O U O 0) 00 a) N jo CD LO m E o6vLo a r (L a) M LO N O LO N 00 (O y M O m co o V CV n OT m O LO O co 00 V r m LO LO N LO r CO r, OD � m V O 4 T O r m CO O co @=:=i O m a0) m rn T � LO M N CV CV m - CO m OV COLO m LO r CO r, OD � m V O 4 T O r m CO O co @=:=i O co m O c m M P m LL O m C0 CIS C� cC C O r - a) (a 0 O m a CD In 0 Ln �C71- O O O r ND O (( ( D () N r m o C7 O o m P m LL O C0 CIS o - a) (a 0 m m m 0 a OIL 3: �C71- O o 0 0 0 0 0 0 0 0 0 0 O o7 r V' co N O M M co M M Cl) M M Cl) co (eisd) Ug1SS .0088 @@ a tnssald 110AIGsOd N W G f6 T rn C: w r ro c m a� rn Q 4 4 Q C rt - ww �N r r � N � - a K 4 "a h p R + yp i q S i0 r 4 h 4 i 4 w a V N E a N U � < 4 N U �Vy E C 1y Q < A Q T - C O _ O O N O N R ry N T V ^ n K a n �1 oo 00 � X01 o' a) 0 LO nim 6 0 COm O n o M V T O T O O N TTM d O L' CL In V T O N Il) n _ U ILE\ 00 Cl) V O E p;E w V' o (n 7 M LL O rn 3 E w OMD mmmmQ 41 O V' O) -L co U] n LO V n n to co O N M -q- ride 0 o (, V M 7 r N m co N O V z Cl) co N co riov d v CD V N cO C� r r U O O m m Cl) Cl) 2 m n o Q o (O V ¢ v Ed(ovr (n(nnn R 00 V N L OR mm T i o (D V N (p r a N n N It NCO r� L r co 9 d l(i ri d o r Tc n (O a (n L 0 00 (O In v N Z co Co N ro dvri06 0 m 0 O r O V V M r >M It c N tooanm (o r r m j r r N co (O O O nim CO O .w r N N M V co N N T MW co TTM N O N co m v o v In V T O N Il) n O N n O 00 Cl) V O E onc(�i V' o (n N Cl) M N h J OMD J N 41 O V' O) -L co U] n O to co IL ride o(ov� lr m N m z 000 (00 CO riov LO m W CD V N v u) 00 r r U Cl) C 2 M N OMD LO m v Ed(ovr R r OL F- a) 0 a N N r M (V (D 00co mo 00 co 9 C o T C\i Tc n (O a (n N M CD N 07 (n co O .w r N N N co N N T N TTM Ea O U r `y In V T O OnN(O O co 00 Cl) V O E onc(�i U 3 m J d J N II o O) -L F¢- U N F - mp IL 0L o(ov� lr C7F- 1a 0 F- r M CD N 07 (n co O .w r N N N co N N T N TTM Ea O U r `y In V T O OnN(O O co 00 Cl) V O E onc(�i U m O m co n m (O n co O N p OD OD 00 E o(ov� lr T N O z 000 (00 CO riov LO m W nn v u) 00 U O In Cl) D) U 0 000 N ¢ a co N N OMD LO m M IT O co Ed(ovr R r OL F- a) LO N N ( LO OD N M O n mo corio m In In O o T O (n n (O a (n 0 00 (O In v n M O n 7 O O M o M O T (n co IT II m O m O N n M r O r N � O co 0 cl) v r Iri O m co n m 'NO m n m W) IL Q M O q: lr n O co N N 000 (00 n riov 0 N ca co W 000 N ¢ a U °' riov C ¢ F- 2 a _ O(i�� m0 D0 F- d0 Zi F- M n r 00 Lo. In In O o T O (n i+ v V 0 0 O r a r rn n co (D C n N ci c6 .21 II m 0 N •� m 'NO m C IL Q lr 'p r2 _7 0 N ca N ¢ a U °' ¢ m C ¢ F- 2 a _ O(i�� m0 D0 F- d0 Zi F- M G 0) c (DD N It O N O co M M M M co co M M M (eisd) aAISS.0088 N7 amssaad 110/uGsaa N W C R <j] \§\ ] /7 CA /<:< ! : { ! . < y ' . 2L ; § ! \ 4 ; ( . ; ( !� : J•• r V (D (D IC) O ra m m w E N r V O O O V CD m 1 N •� D r O r O (D UOD V O V j N r N 'y0 m d C li Ce CL 7 W O U — CL N N LO [Y D) ca r .0 1E 2 N r N C) r v n _¢ y LL C\im ror j 3:o O •C N 0 m 3 E n O U m m m m ¢ O) m (l N O N r D) U) N P� V 00 O O '- U C O r r M O (D r- CV O N 4 7 CO N O N. ID N N E o ri L6 r C5 r O) n a) c co (OD V M M N O I[) V N N N V Z O N N (n N O N co co m Ln r^ r V n N IOD m � V N N m ED Cl) , �o O Lf) 0) (D r O r 07 O N 'Q o N r V' r C7 N Q Cl) C LO O CO N N m m M CS] � M N L t m N r Un N N O O , E O r N Ni ror N O N m m N It O m Cl) r) d' Cl) Cn r O VN m m N co O D O r N V W O r O r O y (DD Om) 0 m O O O r O O ci ' ¢ g i Om 0 f� N r r) V N ID C) N UD O m Om O O O = OCU r , O co co O r r C6 O UD CC) c0 m N m C N r O N � C m ?` c r O N r O r O 0 0 d O a) U) U) co co (D m m UD v co m N O N -r N M N^ r m -q-- I(°n V O O V jCV r N V E a d II N 0 E 3 _ O 9 li O O v u g L) ca d C LJ IJ- LJ co 3tj :0 CL O(L3: E ZO r V (D (D IC) O ra m m w E O m O O V CD m 1 N •� ,y N n r rn V UOD V O V j N r N 'y0 m Or) E C li Ce N 7 W O U — (D N O It LO [Y D) ca r _ CO N O r N r N C) r v n _¢ y E C\im ror j 3:o O •C N z O U O) CO V CO CD O (D r- 4 CO N O N. 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'& N y� 1 H N a 1n • N Q � Q Nµ NN m R t -N .,m N N J m N M Qd n n epy w Q nj • � Q n n O � Y N O y o V i E E o u v E E 0 o N N p�p Ir y n %'��f\ N J .� 00 O 4 J Exhibit 8 2010 Wells Surveyed for Gas Movement 2011 Drilling Well Louate OH ICH GOC MD GOC (NDSS) 02-21B 5/13/11 CH 11546 8942 06-02A 5/4/11 CH 10426 8852 GOC 07-13C 817/11 CH 11543 8907 14-33A 4/6/2011 CH 11857 BB39 15-05B 6/26/11 CH 10128 8688 15-11C 1/6111 CH 11040 8721 1548C 5131/11 CH 9179 8745 GOC 18-03C 11/3/11 CH 9510 8695 GOC 18-12C 9/20/11 OH 14160 8568 18-12C 9120111 OH 16560 8566 18-13C 1 2/101111 CH 9757 8626 A-258 10/81111 OH 11173 8668 A -39A 2/6/11 OH DidnoLlogGOC Didnotla GOC C-108 9/26111 CH 11112 8938 GOC C -42A 5/25111 CH 9843 8926 E -19C 7/6/11 CH 11739 8758 E -23C 3/15/11 CH 10952 8743 H -04B 10/6111 CH 11699 8825 GOC K -05D 8/26/11 CH 9700 8718 GOC K -10C 8/16/11 OH 11083 8597 K -10C 8/16/11 OH 14778 8596 PAm 1/17/12 OH Did not log GOC Did not log GOC MM 11/191111 OH Did not log GOC Did not log GOC R -12A 10!7/11 OH 10766 8708 S -01C 3121/11 OH Did not log GOC Did not log GOC S-188 2128/11 OH Did not log GOC Did not log GOC U-12AL1 12!7/11 OH Did not log GOC Did not log GOC W-21ALl 12/19/11 OH Did not log GOC Did not log GOC W-21ALl-01 12/19/11 OH Did not log GOC Did not log GOC Z-65 10/23/11 OH Did not log GOC Did not log GOC Z-67 7/23111 OH 9992 8762 OH - Open Hole Log CH - Cased Hole Log 2011 Surveillance Welt Loa Date OH / CH GOC (MD) GOC (NDS_S) 01-02 915/11 CH 9590 8890 01-13 7/12/11 CH Did not too GOC Did not log GOC Oi-16 3112/11 CH 10240 8854 01-20 3/5/11 CH 11524 8979 01-31 3/17/11 CH 9483 8897 01-3 AA 5/29/11 CH 9123 8817 02-03B 6/1/11 CH Did not log GOC Did not I GOC 03-30 11/16/11 CH Did not log GOC Did not log GOC 04-20 9/25/2011 CH 11607 8562 04-23 8/26/2011 CH 9450 8511 05-35A 1 713/20111 CH 10546 8843 06-01 7123/11 CH 9714 8924 0&08A 3/6111 CH Did not log GOC I Did not log GOC 06-09 10/22/11 CH Did not log GOC Did not [w GOC 06-11 7/5111 CH 10160 8775 06-16 3/8/11 CH 9755 8869 06-20A 2/17/11 CH 9983 8903 09-02 2/17/11 CH Did not log GOC Did not log GOC 0946 3/2/11 CH Did not log GOC Did not log GOC 11-2 AA 9/17/2011 CH 12194 8649 11-32 10/1/2011 CH 10667 8543 15-026 1 4/11111 CH 10737 8875 15-09A 3/15/11 CH 1 10476 B722 15-17 9/29/11 CH 10603 8715 18-06B 8/29/11 CH 8886 8582 A43 9/10/11 CH Did not log GOC Did not log GOC B -16A 6/30/11 CH 11290 8811 C -03B 8/19/11 CH 10114 8914 C -12B 3/9111 CH 11937 8947 C -22A 3/11/11 CH 9972 1 8910 C -32C 716111 CH 10332 8929 D -06A 6/25/11 CH 9566 8899 D -16A 2/19/11 CH 9966 8814 E -14A 3151111 CH 11589 8828 E-358 1 2J7/111 CH 10972 1 8972 F -01A 1 715/111 CH 9150 1 8955 F -06A 7/2/111 CH Did not log GOC Did not log GOC F-12 1/5120111 CH 9550 8922 F-30 7/4/11 CH Did not log GOC Did not log GOC F-35 2/23/11 CH 11727 8919 F44A 6/20/11 CH 9816 8971 F48 7/10/11 CH Did not log GOC Did not log GOC G-118 7/7111 CH 10915 8911 G-21 8/6/11 CH 10155 8825 1-1-198 6/13111 CH 11640 8907 H-20 2/13/11 OH 10018 8886 H-26 8/23/11 CH 9747 8843 J -17C 2/9/11 CH 11105 8903 J-19 8/13/11 CH 10010 8930 J-21 10/4/11 CH 9482 8935 J -22A 7/6/11 CH 10182 8864 J-28 4/30/11 CH 10795 8834 M -21A 6/6/11 CH Did not log GOC Did not log GOC N -04A 9/28/11 CH 10056 8703 N -11C 4/21/11 CH Didnollo GOC Didnotl GOC W -39A 3/14/2011 CH 9552 8807 X-17 2/10/11 CH 9641 8713 Z -21A 10/13/2011 CH 10715 8683 `o FIE E- r m 8 - m R io P 8 8^ . 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U'UU' U i $$ 2` a rc m w w rc rc di rli > rA $ N N NN .-mm a2 9-0 !| �( $ /E` ■ ! wR ••w�,. f!`j.E |! § § § § §2/ § )/) / �§ / ! 6d.6 § ` \ ] #; ` E! \)�� (t!|! {( . . m &I 00 o °! §/ § ! !f { | g &I § | § |\ )/ &| z -06 26 Exhibit 10 2011 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut- In Future Utility Plans & Possibilities" 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 02-02A Prudhoe 029200740100 Jun -06 6 5 Well suspended. Flowline & slot used for 02.40 3 02-05A Prudhoe 029200810100 Jan -09 6 2 Evaluating ibilies toreair TAX Extended Patch stuck on well 4 02-12B Prudhoe 029202770200 Feb -08 1 3 CTD Packatte Read 5 02-15A Prudhoe 029204470100 Dec -10 6 5 Well has a IAxOA communication managed by bleeds. 6 02-26C Prudhoe 029207740300 A r-07 6 7 RWO cancelled. Rig Sidetrack Candidate 7 02-30B Prudhoe 029222020200 Jun -07 6 5 Ann Comm Issues 8 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. 9 03-26 Prudhoe 029210270000 Jul -09 2 4 Cannot access wellbore due to fish. Shut-in until MI from 03-33 gets dose enough to POP and look for benefits. 10 04-04A Prudhoe 029200960100 Se 98 6 5 Suspended well. CTD BHA stuck in Window. No Flowline 11 04-05A Prudhoe 029201070100 Jan -10 6 2 IAxOA. Evaluatin options to POP Under Eva] for wellwork screening 12 04-07 Prudhoe 029201890000 Jan -97 7 5 Originally SI for high WC; well slol/piping in manifold has been removed so unable to Pursue wellwork options. Well does not usfify surface repair. 13 1 04-34A I Prudhoe 029221600100 Nov -97 2 2 High WC low IOR. Planning to pursue POP. 14 04-39 Prudhoe 029221810000 Apr -98 2 1 5 High WC low IOR. No Flowline, 15 04-40 Prudhoe 029222240000 Jul -10 7 1 2 Shut -In for velocity concerns. Currently evaluating WSOotions 16 04-41A Prudhoe 029222370100 Se 09 2 2 High WC. Evaluating wellwork options. 17 0447 Prudhoe 029224390000 Feb -03 5 5 PC leak & collapsed tubing,FL not fit for service. High WC low IOR. IS 05-12B Prudhoe 029202440200 Mar -05 6 5 WH leak evaluating sealtite'ob or CTD 19 05-13B Prudhoe 029202500200 Apr -10 6 7 WRP stuck Post RWO. No success as of 10 2012 removing WRP 20 05-16B Prudhoe 029202620200 Sep -10 6 1 Ann Comm Issues... Evaluating Well Work Options 21 05-17B Prudhoe 029202710200 Nov -02 6 5 Low existing value -colla setl 22 05-18A Prudhoe 029219600100 Feb -03 1 3 23 05-28 Prudhoe 029222080000 Oct -01 1 1 Shut in for High GOR.. led back on Feb 12 24 05-33B Prudhoe 029221680200 Oct -10 6 6 Choke Issues on Surface post sidetrack 25 05-39 Prudhoe 029227150000 Au -10 6 6 Ann Comm Issues 26 05-40 Prudhoe 029227070000 Nov -02 6 5 Failed RWO - stuck CT during cleanout 27 06-15 Prudhoe 029204590000 Jul -06 6 5 Surface casinq leak Integrity team suggests P&A 28 06-17 Prudhoe, 029207600000 May -04 6 5 TxIAxOA communication - RWO cancelled due to cret damage 29 07-21 Prudhoe 029209070000 Sep -10 6 1 Patch/integrity Patch/integritydiagnostics are in progress. 30 07-33B Prudhoe 029218090200 Sep -10 1 2 High GOR. LP access only. 31 07-34 Prudhoe 029218120000 Apr -00 6 2 IAxOA; Stuck IBP fish in tubing. Rig ST candidate but LP access only. 32 07-34A Prudhoe 029218120100 r-05 6 3 ACOA' Stuck IBP fish in tubing. Rig ST candidate but LP access only. 33 09-05A Prudhoe 029202150100 Nov -09 2 2 SI for high WC and H2S. 34 09-07A I Prudhoe 029202230100 Se 10 2 2 Cueenfiy looking a doing a cal intervention w/ adiperf 35 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 trealemnt. Not on WBL as of 10/18/10 36 09-27 Prudhoe 029212910000 Se 10 2 4 SI for high WC then VSM repairs. Currently scheduled to POP in March 2012 37 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 cats close 38 09-29 Prudhoe 029214220000 Sep -10 2 4 High WC. Possible LoSAL candidate 39 09-30 Prudhoe 029214110000 Dec -10 2 1 Hi h WC. Wellwork currently on the backlog 40 09-35A Prudhoe 029213140100 Nov -10 2 4 High WC. Will consider POP when 09-15 MIST well coes around the bend. 41 09424 Prudhoe 029220590100 Dec -02 6 5 2008 RWO failed. Now possible SC leak. Sidetrack candidate. 42 1 0945 1 Prudhoe 029220830000 Se 10 2 4 EoS sidetrack potential donorwellbore. 43 11-12 Prudhoe 029212120000 Deo -10 1 6 Hi h GOR due to shut-in injector, waiting on injection to lower GORs 44 11-16 Prudhoe 029215810000 Se 09 1 6 High GOR due to shut-in injector, waiting on injection 45 11-17A Prudhoe 029215980100 Sep-09 1 1 6 High GOR due to shut-in injector, wailing on infection 46 11-25A Prudhoe 029204880200 Feb -02 6 5 PC Leak and IAxOA Communication. No current plans. 47 11-28A Prudhoe 029219580100 Apr -09 1 6 High GOR due to shut-in injector' waiting on in' 'on 48 11-33 Prudhoe 029224900000 Mar -10 1 6 High GOR due to shut-in injector' waiting on injection to lower GORs 49 11-36 Prudhoe 029224770000 Sep -10 1 6 High GOR due to shut-in injector, waiting on Injection to lower GORs 50 12-11 Prudhoe 029206010000 Feb -00 6 5 LTSI, High TGOR, low oil rate. Utilized 12-11's surface facilities for new grew roots well 12-37. 51 13-01 Prudhoe 029203230000 Jul -06 6 5 SC leak & leak outside wellhouse; well likely not operable per WI group even'rf RWO completed given high risk in operating well! No plans at this time. 52 13-04 Prudhoe 029203260000 Oa -03 6 5 TxIAx0A; produces rocks, sand screen installed, poor tubing Condition. Plans to further diagnose 53 13 -OS Prudhoe 029206260000 Nov -97 6 5 TXAxOA; replaced by 13-05Ai MI injector. FL decommissioned 8/09. No plans at this time. 54 13-07 Prudhoe 029206500000 Jul -916 5 TxIA w/ significant surface facility issues that would add -$1 MM to package. NWD screening for ST. 55 13-10 Prudhoe 029206780000 Jun -94 6 5 IAxOA on GL: uneconomic RWO (high WC). No plains at this time. 56 13-11 Prudhoe 029206040000 Dec -05 6 5 TXIA& possible packer or PC leak.NWD screening for ST 57 13-12 Prudhoe 029205380000 Deo -07 6 5 Tx1A'NWD screening for ST. Exhibit 10 2011 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut- In Future Utility Plans & Possibilities Current Mechanical Condition / Additional Comments 58 13-28 Prudhoe 029209420000 Ma -94 6 1 6 PC leak & bubbles in the cellar. Replaced by 13-13A. 59 13-33 Prudhoe 029207730000 Dec -94 6 1 5 TxIAxOA; Plans to further tlia nose. 60 14-03A Prudhoe 029203190000 Aug -09 8 1 2 TxIA' uneconomic RWO. Evaluating sealtile repair 61 14-16A Prudhoe 029206080100 Oct -09 6 1 2 Was SI for choke repairs. Choke repairs complete and now awaiting POP 62 14-31 Prudhoe 029209890000 Jul -07 6 7 TAA poor tubing, low rale for the last 6 months of lite. Previously considered for UZI, but project on hold due to FS3 projected water limitations. RWO package has been issued. 63 14-37 Prudhoe 029218100000 Sep -05 1 6 2 TxIAxOA; extended patch program with Wells Group for revision. RWO planned for November 2010 64 14-38 Prudhoe 029218620000 Nov -94 3 5 TxIA and low PI SI 11/94. No bowline. 65 14-39 Prudhoe 029218880000 Jun -94 6 5 IAxOAxFonn. 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 66 15-03 Prudhoe 029207220000 Jun -94 6 5 Cret leak, leaking sqz parts, major fsh in tubing; surface facilities given to another well 67 15-t0A Prudhoe 029205010100 Jan -91 6 5 Major leaks and a channel; no surface facilities; bottom hole location developed by 15,19 68 15-12B Prudhoe 029206650200 Jul -10 1 2 Choke removed 8/1/10 (erosion). High GOR. Jul -10 Plug/perftested all gas. Sidetrack candidate, 69 15-13A Prudhoe 02 92064 501 00 Oct -10 1 2 High GOR. If CST, pursue de -twin as part of AFE. 70 15-15C Prudhoe 029206910300 May -10 1 2 High GOR. Big rig sidetrack candidate. 71 15-24 Pmtlhce 029222230000 Mar -95 6 5 Collapsed tubing, cret leak no surface facilities 72 15-28A Prudhoe 029222470100 Mar -04 6 3 MITOA fails has cretaceous leak. Twinned with 15-22 73 15-35 Prudhoe 029224880000 Se 03 6 5 Crel leak dum tootled Ivishak TXIA and PC leak 74 15-38A Prudhoe 029224960100 Jul -09 1 2 Hi h GOR. Sidetrack candidate. 75 15-41 B Prudhoe 029224920000 Feb -07 6 5 PuVivishak comingling issue & already swept Ivishak zone makes wellwork unattractive. No sidetrack target 76 15-428 Prudhoe 029225240200 Mar -10 1 6 Hi hGOR. Sidetrack candidate. 77 15-47 Prutlhce 029226170000 Oct -02 6 5 Poor tubing condition IA cemented. Well secured w/ send plug. 78 1 16-09A I Prudhoe 029205580100 Jul -07 6 7 Under evaluation for RWO 79 16-24 Prudhoe 029215360000 Jul -06 6 2 Failed TIFL. 80 16-25 Prudhoe 029222700000 Se 10 81 16-28 Prudhoe 029222760000 Oct -05 6 2 SI for hi h WC. SC leak. 82 16-29A Prudhoe 029222720100 Nov -06 3 2 High WC 83 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 SOL Hiah WC.Try stimulation for as haltenes. 84 18-02B Prudhoe Sep -10 1 2 Fill and AnnCom 85 18-046 Prudhoe 029208750200 Jan -07 1 5 sidetrack in 2011 86 1B -08A Prudhoe 029215770100 Aug -08 1 3 ready for sidetrack 87 18-098 Prudhoe 029215660200 May -10 1 2 High GOR 88 18-11A Prudhoe Jul -10 6 2 PC leak 89 18-19 Prudhoe 029215960000 Sep -03 1 6 1 7 AnnComm preparing RWO package 90 18-20 Prudhoe 029218900000 Jan -07 6 2 PC leak 7900'& 8100' md, Possible RST 91 18-25A Prudhoe 029219480100 May -03 3 5 Cretaceous leak. No future utility. FL was donated to well 18-15. 92 18-27D Prudhoe May -10 1 2 High GOR 93 18-288 Prudhoe 029225640000 Nov -00 6 7 Hole in thq and casing. CTU fish in well. Preparing RWO package 94 18-33A Prudhoe 029225980100 Dec -05 6 2 TxIAxOA Also has starting head leak. Evaluating RWO or non-rlq, fix. 95 18-34 Prudhoe 029226110000 Oct -00 6 5 Hole in tbg and casing. Cement in tbg and IA. Multiple plugs in Ihg. No way to recover this well. Remaining value very low an 96 1 A -01A I Prudhoe 029201080100 Dec -09 2 5 SI for high WC. Considering Brihtwater in pattern, A-06 Pmdhoe 029201180000 Nov -09 7 6 SI for GC3 H2S limits and A- ad header vel constraints. A-13 Pmdhce 029206720000 Dec -10 6 5 Removed from LTSI list. Failetl RWO. P&A candidate A -18A Pmdhoe 029206300100 Jun -03 6 5 LTSI Low IOR SC leak & TAA communication A -32A Pmdhce 029213950100 Feb -10 6 5 Low IOR. TAA. No current lans. [97 A-33 Prudhoe 029214100000 Feb -10 5 4 SI for GC3 H2S limits. A-40 Pmdhce 029223370000 Se 09 6 5 SC leak TxIA comm AAl Pmdhce 029225300000 Se 00 6 5 LTSI-cretaceous leak TxIAxOAxSC. P&A lanned. B -02A Pmdhce 029200660100 Jul -04 6 6 T&A 9/23106. Failed RWO. B-11 Prudhoe 029203310000 Jan -91 2 5 T&A. LTSI - No FL � surface facilities given to B-35 10fi B -19A Prudhoe 029207030100 Oct -09 6 p Txl com. Possible tbg patch. Coiled tubing scale milling failed. Revisit scale milling, Integrity work up next. 107 B-24 Prudhoe 029208150000 Jan -93 6 5 LTSI. Replaced bv B-13. No FL. 108 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. 109 B -29A Prudhoe 029215230100 Jan -10 1 7 GSO squeeze is being planned. 110 B -30A Prudhoe 029215420100Dec-08 1 5 Hi h GOR well. Does not heal. No remainingcycle value. 111 C -23C Pmtlhce 029207750300 Mar -09 1 1 2 Recent CTD reservoir failure. 112 C-38 Prudhoe 029215710000 Nov -97 6 5 Cretaceous leak, flowline taken, evaluated CST, but addl facility costs makes it cost prohibitive. No current wellbore utilization; reserves captured by offset wells. Will be P&A'd Exhibit 10 2011 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut- In Future Utility Plans & Possibllftiesa Current Mechanical Condition /Additional Comments 113 C-02 Prudhoe 029223570000 Oct -10 4 1 sidetrack in 2011 114 D-05 Prudhoe 029200580000 Jan -08 1 2 Low priority as a TO sidetrack due to underuns in area. Continuing to evaluate colons. ResMan workma area. 115 D -19A Prudhoe 029207070100 r-96 4 1 sidetracked 116 D -27A Prudhoe 029215430100 Apr -10 6 2 Not operable. Cannot flow. Evaluation of the 5/12/10 STP LDL indicates the well to have TxIA communication near 5,063' & 5,086' and a PC leak into formation near this de th also. 117 D -28A Prudhoe 029215560100 Jul -09 4 Sidetracked 118 E -14A Prudhoe 029207840100 Sep -07 6 5 TAA Comm & surface csq leak 119 E -18B Prudhoe 029206540200 Nov -04 6 1 5 Failed Coil ST. Secured w/ WRP. 120 E -39A Prudhoe 029225870100 Se -05 6 5 IBP fish stuck in hole. 121 F-11 B Prudhoe 029204240200 Nov -09 6 5 Non Operable. TXIA communication - collapsed tubing at 8180' 122 F -16A Prudhoe 029206610100 Jan -07 6 5 No forward Plans for this well. 123 F-22 Prudhoe 029219510000 r-08 6 2 Well Not Operable. No completion opportunities found. 124 F -23A Prudhoe 029216580100 Jul -08 6 3 Planning to Sidetrack. Confirmed by PE Jan 2010 125 F -26B Prudhoe 029219870200 Apr -08 1 2 Consider for Ad rf. Feb 2010 126 G -03A Prudhoe 029202210100 Dec -04 6 5 Failed RWO in 2006. SHL replaced with G-31 B. 127 GC -2A I Prudhoe 029201670000 Sep -95 6 5 LTSI Cretaceous Disposal Well, No Flowline, Repealed attempts to cleanout Haled, CT fish iin hole no injectivity 128 GC -2C Prudhoe 029217740000 Sep -07 6 2 Monobore completion, OA valve gauge shows IAP, MITIA passed to 1700psi on 2/6/09 129 GC -3D Prudhoe 029203090000 Ma -03 4 1 5 LTSI Cretaceous Disposal Well - requires CT FCO 130 G -13A Prudhoe 029206000100 Ma -07 6 5 Collapsed tubi 47'. 131 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 limline 132 H-12 Prudhoe 029204840000 May -91 6 5 Not Operable. Tubin collasped at 201 V, No flowline 133 H-15 Prudhoe 029205910000 May -03 6 5 Suspended and permanently P&A'd with cement to surface in 2/2011 due to collas / arted tog 2604'. 134 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. 135 H-34 Prudhoe 029228030000 Nov -04 8 7 NOT OPERABLE TXIA, PC leak. Repair with RWO and get Z4B well back with acid job or Possible RWO and Sag ST. 136 J -01B Prudhoe 029200200200 Aug -08 6 2 Cellar is bubbling sw/Ivishack characteristics 137 J-03 Prudhoe 029200250000 Nov -04 6 2 Wellhead leak and Ime growing, Planning for rig workover 138 J-158 Prudhoe 029209610200 May -06 6 2 There is a program on JMS for MIT -T, MIT -IA and MIT -OA for leak path detection 139 K -09C Prudhoe 029217360300 Feb -09 6 5 PC leak. Sealtite failed to repair. No current repair option, 140 K-13 Prudhoe 029217570000 Oct -97 T x IA x OA x conductor. Reservoir abandoned with 72 bbls of cement. 141 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. 142 L -02a Prudhoe 029230480100 May -07 7 6 Available for Production,inadequate as lift supply 143 L-03 Prudhoe 0292326900 Nov -09 7 6 Available for production,inadequate as lift supply, low PV oil rate 144 L-50 Prudhoe 029232770000 May -07 1 5 High GOR. No flowline now, no current utilization (no plans) 145 L 51 Prudhoe 029233090000 Nov -10 3 2 Low Pl, does not compete for limited supply of EWE gas lift. Possible slim candidate. Sagwell, lacks injection support. 146 L2 -08A Prudhoe 029217610100 Jul -99 6 2 Evaluating RWO feasibility & possible non -rig fix. Can't flow to LPC due to gas limitations. 147 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. 148 L2 -18A Prudhoe 029217660100 Sep -01 6 3 Tho and casing damaged. Evaluating repair options and TT CTD options. 149 M -05A Prudhoe 029201940100 Dec -04 6 5 Gas lifted well TXIAxOA Communication waiver cancelled. TTP stuck. 150 M-08 Prutlhce 029204990000 Dec -09 2 2 SI for high wc, otherwise an operable well. Time repaired, integrity restored 8/30/09, WSO attempted but not complete, No longer on WBL 151 M -24A I Prudhoe 029209390100 Mar -08 2 6 Shut in due to GC2 water handling capacity otherwise an operable well. 152 M -27A Prudhoe 029219920100 Jul -97 3 5 LTSI low rate, money k. Also TAA Communication 153 N-02 Prudhoe 029200830000 Jul -88 6 5 SUSPENDED. N-24 replaced this well. SC and PC leaks. No Howlin. 154 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 goad ST candidate. Flowline 155 N -O6 Prudhoe 029200980000 Aug -05 6 5 NOT OPERABLE- Work to P&A. Too many integrity issues. Replaced with N -1 8A. No 11mline. 156 N-1BA Prudhoe 029209060100 r-10 7other 2 Was shut m or velocity, ante L source we wen own. Plan to P since N Pad "Its currently Sl for PMPs (currently have mom) 157 P-15 I Prudhoe 029221200000 Feb -09 6 2 SC leak. RWO option to be explored 158 P-18 Prudhoe 029220976000 Jul -07 1 6 2 SC leak. RWO or ST? 159 P-22 Prudhoe 029223960000 Dec -96 6 5 TXIA comm, probable bad packer, FTS.High risk Wellwork considering abs at 10500 that failed to be milled out. 160 P-23 Prudhoe 029223930000 Jun -02 6 5 In ection lines given to P-28 1611 PWDW1-1 I Prudhoe 1 029202260000 Jul -07 6 5 Sl due to poor injectivity resulting from a SSSV fish down -hole. Exhibit 10 2011 IPA Shut In Well Report Reason for Future Utility Well Shut- Plans & # Sw Name Field API Number SI Date In Possibiiitles Current Mechanical Condition IAdditional Comments 162 PWDW2-1 Prudhoe 029202270000 Feb -03 6 5 LTSI Cretaceous Dispose[ Well PC Leak at 2992' would require redrill Suspended with Ann Comm issues. No flowline orwellhouse. Replaced by R-39. 163 R-01 Prudhoe 029203530000 Nov -93 6 5 To be used for J -Pad UZI LTSI, low rate (also has Ann Comm issues), Have approved CTST but needs RWO 164 R-10 Prudhoe 029205180000 Mar -o1 3 5 also and can't afford. To be used for J -Pad UZI SI for GC -2 facility constraints, high GOR, high WC, high volume - operable well. 165 R-12 Prudhoe 029209210000 Nov -09 7 4 Facilities Sag well with Ivishak fault water. Not competitive to flow, waivered for TXIA. Looking 166 R -17A Prudhoe 029206770100 Feb -05 7 2 at CTST. Now has condemned flowline that needs major repair. Well to be visited for Sag development. 167 R -20A Prudhoe 029206410100 Jun -06 6 2 Surface Casing Leaks OA repressurization - external gas source. On WBL for Gel Treatment. NOT on 168 R-24 Prudhoe 029212320000 Oct -09 6 2 WBL as of 10/18/10 R-30 boftomhole reserves captured by R41 grassroots well; however, R-30 is an 169 R-30 Prudhoe 029222790000 Sep -05 6 5 excellent excavation and Sag Coil Sidetrack candidate when SC is repaired SI for high wc, otherwise an operable well. Planning to convert to injection, glm's 170 Prudhoe 029208690100 Mar -09 2 9 dummied for MIT -IA which passed. Tech package out to partners. Waiting on S -05A electrical work should be on 1 O 2011. 171 5-116 I Prudhoe 029231830000 Feb -09 5 4 Currently, no nearby producers. Plan to drill new producer, 5-129 into fault. Well has been SI for high we 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 delennine if there 172 Prudhoe 029214190000 Aug -09 2 6 are potential Sag Adpeds. 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 operablel S 12A 173 S-13 Prudhoe 029208100000 Mar -01 6 5 SI for high WC and TxIAxOA communication ST candidate SC leak and IAxOA. Water handling limitations at GC2, currently impacting the IOR. 174 5-16 Prudhoe 029211230000 Aug -04 6 7 When GC2 can handle more water, reconsider a RWO. Being eval for external SC repair. 175 5-19 Prudhoe 029216110000 Mar -08 2 6 SI for Low Rate high we otherwise an operable well. 176 5-21 I Prudhoe 029220360000 Sep -10 6 2 IxO communication on list for Seabite 177 5-200 Prudhoe 029228460000 Oct -01 6 5 Collapsed liner. Possible ST in future Plan is to use surface hole +slot for future producer. Replaced DH location with new 178 5-216 Prudhoe 029229890000 Jul -06 8 5 well 5-217. 179 5-23 Prudhoe 029220880000 Apr -04 6 5 SI for IAxOA Comm Bradenhead leak no tbq leak but in poor condition. SI for low rate, high we, otherwise an operable well. BOL and retested wl portable in 180 S -27B Prudhoe 029220570200 Apr -07 2 6 07-07 which confirmed last rate. 181 S -28B Prudhoe 029220950200 Mar -10 7 4 LTSI for GC -2 water handling SI for reservoir management -all offset producers SI. Trying to get offsets POP'd then 182 Prudhoe 029220820100 Sep -09 5 4 S -29A will return to in . Also eval redevelopment plans in area. TAA. Plan to request LDL and evaluate patch options or RWO. High we so may not 183 5-30 Prudhoe 029220510000 Aug -03 6 5 have high on-fime even if repair. 184 5-32 Prudhoe 029220990000 r-10 2 2 High WC well need rock screen before POPin SI for a corrosion related line issue which is in the works to be sleeved. Previously SI for Low Rale, high wc, otherwise an operable well. Upside of +150 [OR when S - 185 5-38 Prudhoe 029223100000 Mar -08 7 6 25A put on MI mj. Also a flowline issue that is expected to be repaired during next SO. 186 5-400A Prudhoe 029232890100 Oct -08 3 2 ESP failed. Extra water not needed at the moment 187 S-401 Prudhoe 029233130000 Oct -08 3 2 Low productivity, Extra water not needed at the moment. SC Leak. Plan to POP under eval since repaired TAA in 4/10 to better determine SC 188 S40A Prudhoe 029224940100 Aug -06 6 2 leak depth and consider repair options. 189 S42 Prudhoe 029226620000 Dec -06 6 5 SI for low rate. Need to investigate cause of rate drop. Also has leak. 190 T-01 I Prudhoe 029212410000 Jul -99 8 5 LTSI Injector, not an effective injector 191 T-07 Prudhoe 029207330000 Jul -99 8 5 LTSI Injector, not an effective injector 192 U -02A Prudhoe 029211700100 Dac-02 6 5 Hole in tubinq and PC leak; TTP 193 U -08A Prudhoe 029211360100 Jan -02 2 5 High watercul fkiwlines given to U-1 5K 194 U-13 Prudhoe 029203550000 Jul -06 6 5 Low oil rate. Rock producer w/ fill. 195 U -15B Prudhoe 029225650200 Jul -06 3 5 Not roducin ' no FL Aborted RST due to surface casing leak. No planned future utilizaflon. BHL 186 Prudhoe 029230540000 Mar -05 8 5 V-201 replaced with new injector 197 W -02A Prudhoe 0292279301 Mar -07 6 2 Low PI and no area pressure support. Rock screen for hole in liner 188 Prudhoe 6 5 No access to liner to due damaged liner top, never perforated. Wet when drilled. W -09A 029219470100 JUI-041 199 W -12A I Prudhoe 029220230100 Se 06 2 3 Cleanout of liner cement laterals planned with Nordic CTD rig 200 W -27A Prudhoe 029218940100 Aug -10 1 2 High TGOR EWE LDF Velocity limits 201 X-04 Prudhoe 029204120000 May -03 6 2 Identified IAxOA in wellhead. Possible downhole TAA. Sealtite on wbl. TXIAxOA GL. Future offtake Y-03Ai.Diagnosfic confirm comm is not thm theWH. 202 Prudhoe 029224170000 Jan -09 6 5 Rapid OA repressurinton. Plan is to ST away from a fault. On long tens list of X-34 candidates but not actively workinng YeL Limited reserve. Conv/CRWO pkg submitted for approval 5/25/06. Should be done 203 Y -02A Prudhoe 029203950100 Oct -05 6 3 stimultant w/ Y -07A] RST/MI fac upgrade. Considering ST to southeast Y-09 area to support Y-09LI -LI -01. Exhibit 10 2011 IPA Shut In Well Report # Sw Name Field API Number SI Date Reason for Well Shut- In Future Utility Plans & Possibililiesa Current Mechanical Condition I Additional Comments 204 Y-0a.A Prudhoe 029205720100 Sep -93 3 5 TxIAxOA. FTS. Poor tbg condition. - will secure for LTSI with CaCO3 L&K. ST to east toward Y-34 candidate. 205 Y-12 Prudhoe 029205170000 May -99 6 5 SI high WC. No short term plan. Lon term ST candidate 206 Y-13 Prudhoe 029206340000 Feb -06 2 5 SC Leak; SI wet since the beginning. Plan to plugback to Y-1 7A Peds for Y-031 offtake. 207 Y -17B Prudhoe 029209200200 Jun -02 2 5 Low PI well. Poor rack quality in the area. Mechanically Operable well 208 Y-31 Prudhoe 029221610000 Dec -07 2 5 SI for high WC. No obvious ST tauqets. Mechanically operable well 209 Y-32 Prudhoe 029221490000 Jan -09 2 5 SI for high WC. No obvious ST to ets. 210 Y -34A Prudhoe 029221780100 Dec -07 2 5 TAA. OAxCond. Collapsed thq. Potential for Sidetrack candidate, 211 Y-38 Prudhoe 029225530000 Dec -02 6 5 Slow Tx IA communication ST package approved for 2011 212 Z-05 Prudhoe 029220560000 Jul -10 2 4 High WC low oil rate POP after Z -09i on injection 213 Z-06 Prudhoe 0292179800 Aug -08 6 3 Slow Tx lA communication ST packagea roved for 2011 214 Z -011A Prudhoe 029217870100 Jul -10 2 4 High WC post acid stimulation POP after Z -09i on injection 215 Z-15 Prudhoe 029218490000 Dec -10 1 2 High TGOR EWE LDF Velocity limits 216 Z -19A Prudhoe 029222510100 Jul -08 5 6 OA repressurization due to shallow gas, poor cement, waiting on decision on annular vents stem v system 217 Z -32B Prudhoe 0292192460 FeD-07 2 3 h Lookingat SToptions. 218 Z-35 Prudhoe 029228840000 A -01 2 5 High WCno current plans for well High GOR, currently uncompetafive to produce due to facility constraints, no known mechanical problems High water, currently uneconomic to produce, no known mechanical problems Low production rate, no known mechanical problems Wellwork Reservoir management Mechanical Problem Other (Specified under comments) B. 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