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2012 Prudhoe Oil and Put River Oil Pools
March 15, 2013 Cathy Foerster, Chair Alaska Oil & Gas Conservation Commission 333 West 7"' Avenue, Suite 100 Anchorage, AK 99501 Re: ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL and PUT RIVER OIL POOL - 2012 Dear Chair Foerster, 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, 2012. 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 Paulo Ballin at 564-4299, Paulo.Ballin@bp.com. Sincerely, �16"- 6nrj, Katrina Cooper Head of Base Management Alaska Resource, BPXA 564-4212 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 K. Smith, DNR W. Montague, BPXA K. Cooper, BPXA M. Vandergon, BPXA J. Starck, BPXA J. Dean, BPXA E. Apolianto, BPXA S. Kent, BPXA R. Skillern, BPXA P. Ballin, BPXA ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL JANUARY THROUGH DECEMBER 2012 2012 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 (includes previous section 4.6.2 used till 2007 report) 4.6.2 2013 Surveillance Plans 4.6.3 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 2012 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 - 2012 12 Put River Lobe Map Page 3 2012 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 2012. In keeping with the requirements of the Conservation Orders, 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 2012 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 2012 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 2.0 OVERVIEW Exhibit IA 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 2012, field production averaged 225.4 MBOD, 7035.8 MMSCFD (GOR 31,214 SCF/STB), and 927.2 MBWD (water -cut 80.4%). Waterflood project injection during this period averaged 1,588.9 MBWD with 144.5 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2012 was 11,684 MMSTB, while cumulative MI injection was 3,018 BCF. Cumulative production since waterflood startup was 2,870 MMSTB oil, 11,759 BCF gas, and 8,070 MMSTB water. As of December 31, 2012, cumulative production exceeded injection by 6,676 MMRB compared to 6,224 MMRB at the end of 2011. 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 2010 through 2012 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 65% of repeat 2012 pressure surveys found equal to or greater than their 2010 or 2011 pressure measurements. For 2012, average pressure in the PBMGP project areas using three years of pressure static measurements was calculated to be 3,348 psia by areal weighting, as compared to 3,338 in 2011 (Exhibit 1F). The GD area pressure was stable rising nine psi from 3,274 psia in 2011 to 3,283 in 2012. This subtle pressure increase is within the expected statistical variation with a different annual pressure sampling data sets. Confirmed MI breakthrough has occurred in 109 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 Page 5 2012 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT previous year showed MI breakthrough in 111 wells. This number is stable and inside expected variation considering that similar MI volume was injected in the PBMGP areas between the two years. Exhibit 1-G shows the 2012 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 2012 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 413, 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 2012 pressure map using 2010 through 2012 data points. 3.2 Pressure Plan Per C. O. 341 C, 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 2013 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 2012 is presented in Exhibit 9. Page 6 2012 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 97 producing wells and 61 injection wells that contributed to production/injection during 2012 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 27.1 MBOD for 2012 compared to 27.6 MBOD in 2011. Cumulative production since waterflood start-up through the end of 2012 is 1,066 MMSTB of oil 5,283 BCF of gas, and 4,124 MMSTB of water. Injection rates averaged 496 MBWD and 65.4 MMSCFD in 2012. Since 12/31/11, the waterflood imbalance has increased from a cumulative under injection of 2,349 MMRB to 2,526 MMRB under injected. During the report period, production exceeded injection by 177 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 2012, is 6,136 MMSTB and 1,012 BCF respectively. The flood area's GOR increased from an average of 25,298 SCF/STB in 2011 to an average of 26,522 SCF/STB in 2012. Gas influx continues along the FS-2/GD GDWFI area, and in the high permeability conglomerates in the Updip Victor area. Water -cut increased from 93% in 2011 to 94% in 2012. 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 3,375 psia in 2012. This is an increase of 6 psi over the 2011 pressure. Exhibit 3-1) is a presentation of 2012 average returned MI (RMI) rates. Miscible gas return has been confirmed in 26 wells by gas compositional analysis (RMI>200 MSCFD). Page 7 2012 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 2012, oil production averaged 17.1 MBOD, as compared to 17.6 MBOD in 2011, with an average 90% water cut and 23,935 SCF/STB Gas Oil Ratio. Injection averaged 139.6 MBWD and 13.5 MMSCFD of miscible injectant (MI). There are a total of 74 producers and 30 injectors in the flood area that contributed to production/injection during 2012. 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 DS 13 flood and 8/20/84 for the down -dip sections, rather than the start-up dates of each injection pattern. A Cumulative total of 627 MMSTB of oil, 3,052 BSCF of gas, and 1,595 MMSTB of water have been produced with 2,103 MMSTB of water and 650 BSCF of miscible gas injected. Exhibit 4-13 shows the monthly injected and produced volumes on a reservoir barrel basis during 2012 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 137 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 3,338 psia in 2012. This is a decrease of 7 psi as compared to 2011. Exhibit 4-D shows the 2012 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 20 wells (RMI >200 MSCFD). Page 8 2012 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 20.4 MBOD, as compared to 20.6 MBOD in 2011, with a gas/oil ratio of 12,658 SCF/STB and a watercut of 87%. Injection averaged 116.0 MBWD of water and 29.0 MMSCFD of miscible injectant. For the WPWZ project, 44 injectors (6 WAG injectors and 35 water injectors, 3 gas injectors), and 85 producers contributed to the production and injection during 2012. 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 2012 was 1,685 MMSTB while cumulative MI injection was 596 BSCF. Cumulative production since waterflood start-up is 515 MMSTB oil, 1,807 BSCF gas, and 1229 MMSTB water. As of December 31, 2012 cumulative production exceeded injection by 1109 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 86 MMRB. The reservoir balance in Exhibit 5-13 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 3,350 psia in 2012. This is an increase of 42 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 29 wells by gas compositional analysis. Page 9 2012 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 10.6 MBOD, as compared to 10.1 MBOD in 2011, with a gas/oil ratio of 7,277 SCF/STB and a watercut of 86%. Injection averaged 41.5 MBWD and 16.2 MMSCFD of miscible injectant. For the NWFB project, 23 injectors (6 WAG injectors, 17 water injectors, and 0 gas injector), and 69 producers contributed to the production and injection during 2012. 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 2012 was 1,615 MMSTB while cumulative MI injection was 674 BCF as detailed in Exhibit 61-C. Cumulative production since waterflood start-up was 594 MMSTB oil, 1,322 BSCF gas, and 981 MMSTB water. As of December 31, 2012 cumulative production exceeded injection by 479 MMRB. Exhibit 6-13 provides the monthly injection and production data from 01/12 through 12/12. During the report period, production exceeded injection by 32 MMRB. However, this does not include support obtained from aquifer influx or gas cap expansion. The areally weighted pressure in the NWFB area was 3,302 psia in 2012. This is a decrease of 20 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 19 wells by gas compositional analysis. Page 10 2012 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 19.5 MBOD, as compared to 16.3 MBOD in 2011, with a gas/oil ratio of 3347 SCF/STB and water cut of 68%. Injection averaged 47.2 MBWD and 13.5 MMSCFD of miscible gas injectant. For the EWE project, 17 injectors (13 WAG injector, 4 water injectors), and 66 producers contributed to the production and injection during 2012. Of the 13 WAG injectors, 1 injected gas only, 8 injected water only and 4 injected both gas and water in 2012. The well counts reflect only the active wells for the year. Cumulative water injection from waterflood start-up in September 2001 through December 2012 was 144.3 MMSTB and cumulative MI injection was 84 BCF. Cumulative production since waterflood start-up was 68 MMSTB oil, 295 BCF gas, and 142 MMSTB water. As of December 31, 2012 cumulative production exceeded injection by 228 MMRB. Exhibit 7-13 provides the monthly injection and production data from January 1, 2012 through December 31, 2012. During the report period, production exceeded injection by 19 MMRB. The EWE pressure was 3,632 psia in 2012 representing an average pressure decrease of 10 psi for this area from 2011. 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 2012 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 2012 are shown below; units in thousands of barrels of seawater injected per month (MBWPM): The 2012 volume of sea water injected in the PSI wells was 201.3 million barrels. The cumulative volume injected at the end of 2012 was 1.66 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 orange 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 2011, 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 included the following wells: 11-11, 11-33, 18- 05A, 18-06B, 18-08B, 18-12C, 18-15C, 18-17, L1-14, L2 -07A, L2 -21A, L2-24, L2-25, L2-28, L2-33 and L3-05. 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 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 2012 logs continued this pattern, showing a Page 12 PSI -01 PSI -05 PSI -06 PSI -07 PSI -08 PSI -09 PSI -10 Monthly Totals 1/1/2012 2,353 2,296 2,291 2,419 2,379 2,411 2,331 16,480 2/1/2012 2,596 2,600 2,599 2,612 2,574 2,581 2,563 18,125 3/1/2012 2,902 2,856 2,872 2,889 2,866 2,884 2,839 20,107 4/1/2012 2,758 1,360 2,740 2,750 2,751 2,735 2,725 17,820 5/1/2012 2,966 2,317 2,894 2,984 2,979 2,995 2,970 1 20,105 6/1/2012 2,730 2,851 2,784 2,801 2,819 2,794 2,771 19,551 7/1/2012 2,942 2,970 3,054 3,087 3,054 3,073 3,043 21,225 8/1/2012 1,163 1,097 1,136 1,165 1,091 1,055 1,075 7,781 9/1/2012 2,488 2,366 2,471 2,481 2,441 1,955 2,423 16,624 10/1/2012 2,702 2,618 2,727 2,780 2,718 2,702 2,704 18,950 11/1/2012 2,084 2,190 2,184 2,245 662 678 2,213 12,255 12/1/2012_ 1,889 1,585 1,785 1,658 1,755 1,823 1,750 12,245 2012 Totals 29,572 1 27,105 1 29,538 29,871 28,088 27,686 1 29.408 201,268 The 2012 volume of sea water injected in the PSI wells was 201.3 million barrels. The cumulative volume injected at the end of 2012 was 1.66 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 orange 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 2011, 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 included the following wells: 11-11, 11-33, 18- 05A, 18-06B, 18-08B, 18-12C, 18-15C, 18-17, L1-14, L2 -07A, L2 -21A, L2-24, L2-25, L2-28, L2-33 and L3-05. 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 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 2012 logs continued this pattern, showing a Page 12 2012 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT continued lateral advancement of the water front in Zone 2C with respect to its position in 2011, 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 and increased water column in 2012. 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 11-33, 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 L3-05 and water was seen in Zone 3 and Zone 4, up to the LCU. 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. There is evidence of GCWI production in 4 DS -18 wells (18-2613-18-1813, 18-12C and 18-15C) but the propagation of the water through the reservoir is still under evaluation. One possibility is that the water is slumping through fault; but this has not been confirmed. 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 2013. 4.6.3 Plans for Change in Project Operation No changes to the Gas Cap Water Injection operation are planned for 2013. Page 13 2012 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. 2012 Production For the year 2012, all of the production and injection in the Put River Pool occurred in the Southern Lobe. Production from the Put River Oil Pool in 2012 averaged 869 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 3797 BWPD. Dedicated injector well 01-08Ai was shut in periodically to maintain a VRR of 1 in the southern lobe. Cumulative Put River water injection was 6.41 MMBW through 2012, of which 1.38 MMBW was injected in 2012. The 2012 cumulative production for the Put River Oil Pool was 283 MBO, 1280 MBW and 739 MMSCF gas. The full life cumulative production for the Put River Oil Pool through December 31, 2012 is 2.56 MMBO and 3.4 BSCF gas. 02-27A did fail an integrity test in November of 2012, and a rig workover will be conducted in 2013 to repair the issue and restore production. 2012 Pressures Put River Pressures taken during 2012 are listed in Exhibit 9. The Southern Lobe pressure obtained in 02-23A measured 3,978 psi at 8,100' SSTVD in September 2012 and in 02-27A measured 3,730 psi at 8,100' SSTVD in September 2012. 2012 Surveillance Plan Southern Lobe —Production will continue from wells 02-23A and 02-27A at around 1000 BOPD to achieve a voidage replacement ratio of approximately 1.0. Static pressures will be taken periodically through the year to confirm volumetric calculations. No tracer breakthrough was observed in 2011 or 2012, but reservoir connection is evident through pressures. Western Lobe - No 2013 production or surveillance planned. Central Lobe - No 2013 production or surveillance planned. Page 14 2012 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT 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 2012 through December 2012. A total of 100 gas -monitoring logs were run in the PBU of which 82 were cased -hole Page 15 ■ k�& Q n n v � 2 0. :3CL C CL > � ; , ƒCD )U) .}/ G § CD / ) cr % C@ CO FO (D $E 20 § g CD CL to =r$ E k� Cr § ? g U) CL Ec EU2 (C a � 0 ( _ 2� � § ¢ n F z 6 $ $ 7 � E K> o a EV -5 ° m> a ® R - m / m CD * CD CD CD CL #o w Cl) mtq 0 | %9D %97 %9 o %9E CD 0 CD CD M CL ƒ k CL k 0 :3 CL k ■ , 0 0 E / / k ° k k , - . @ g . 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V 'o N O O V L a D CL N c co r' c N O N Cb .4 O V 4 0 Cn 91 CD CD N CD coCD O W N Cn V O - 0) 1 Y O 0 U1 O N CD co OCD CD 1 CD V 1 M OD N CD Z o O (o om (o 3 CD cr cNiiwo 1 W Cb CD CD cn Cn 1 N V co � CD CD n CD v 000 OD CA W " — Cy - N) 4�, W O CD V N 1 W 1 1 N O N N 1 N C) CO N 1 N CA U1 O O O O CA N 4 CD 1 4�-- (D 4�!. O O Olz M OQ)i W --I" -I V' m D 0 D r = r 3.. --i �m0 T CD CD M � O v a 'o L a CL N C r' O 7 91 � 0) 1 Y N V CD V U1 N OD U1 CD N = N CD v O V o (o om (o 3 1 N N V co � CD 1 W v 000 OD W O V N 00 1 O � CUn -N O � 00 0 00 � N " 0 �I 0 N v � O O V W 3.. --i �m0 T CD CD W � O v a L c CL N D O W N - CD W U1 c -J ? in � C) O 0) CC O N O l 0) W N N N O c N 1 W 1 W CC O N O -rh w ca CD CD O CD CD 1 - 0o CD N w co C- C: C CD T FF L Q D w 91 � m CD N = CD fD Q 3 cr O N CD N W 00 � N � N � 0 0 m C- C: C CD - O O N > -nD m W ca � � CD o� II o� c :3 0 (D D -SCD � D CD `' 0 --iCD -- O r C- r .-. CD 3a r °) _ c 3CD 4N, Y CO 00. A O W 3 M � ; W 3 a 00 OD CO O ' CD 0 c W O CD V V C) O � CO N SI T V oo CL CI) N O oo c O C „'� N V CL ... a C C c 3 N 3 1 1 N O N 1 1 -i fn O N v W N 0 0 0C: " 10 .�. � COO � oCD II 0 c :3 o�-° (D -I OD 1 OD -SCD � CO l 1 (n - ' CD C) CA �l W oi CD C- CD In 6 C. W 4N, Y CO O A O W 00 O -,< � ; W 3 00 OD CO Cn 4 CO CD 0 c W O CD V V C) O � CO N SI T V CD CI) N O C O O V CL O Ul N C D c 3 � rt 1 1 N O N 1 1 -i fn O N v W N 0 0 0C: " 10 .�. � COO � OD W CO O OD N 07 1 ic f J W 1 V CD l ic -N Cl) 1 MJ f OD f a) O CDW1 CVO 4 l N CD j (n CO1 J W� 00 O 1 4 W N W- 0 (rt N CO 1 1 U 1 M�M O 1 W 1 W 9 1 (T 1 W CD 1 4 W N 000 O N V U) -N V 1 Ui Z 0 1 1 W 1 1 CD A PO 1 V NN0) 3 -` W O N W 1 1 CO CT CA CO W N CO co O CD Ln W i CO O " N O CD W 1 " CD 1 CO i V W CO 3 1 O 1 " N W 6 Ul Ul W 00 O Ln N U) W Ln CD 1 n 1 W3 C N CA O O.06 W 1 1 co V W 0 C W COO O Ln OOD 1 CD N V -I W CO W CO -q N oCD N II 0 c :3 o�-° (D -I OD 1 OD -SCD � CO l 1 (n - ' CD C) CA �l W oi CD CO n 0 CD In 6 C. 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CD (D CA 0 1 0 1 0 O V O OD CO C V O 4�6 O -N W O00004 CD Exhibit 8 2012 Wells Surveyed for Gas Movement 2012 Drilling 2012 Surveillance Well Lad Data am I CH G0C IMDI 130C Magal Well Lon Orta 04 I CH lane imm W-12ALl 1/20/2012 OH N/A N/A 16-15C 21112012 CH 9290 -8634 13-12A 2/9/12 OH GOC Not intersected by well GOC Not intersected by well Z-40 2/26/2012 OH WA N/A F 29B 2127/2012 CH 10,014 -8,942 TB•0813 3/2/2012 CH 10105 1 -8639 D -19B 4/10/2012 CH 9188 -BB84 J-1613 4/2012012 CH 9764 -8915 Z-50 41.1881112 OH N/A N/A C -02A 5/3/2012 CH 10090 -8906 F -08B 5/13/2012 CH 11300 -8963 Z -06A 5/21/2012 OH I N/A NIA C•12C 5/308012 CH 11936 -8935 J -27B M112012 CH 946B3 -8923 13-15A 6/2/12 OH GOC Not intersected by well GOC Not intersected by well 8-20A 6170112 CH 9789 -8915 C -27C 6/22/2012 CH 11216 -8928 C-D1B 7/10/2012 CH 9090 -8910 07-35A 71138012 OH 9342 -8936 07-22A 7121%1012 CH 10025 -8919 C -09B 8/1412012 CH 9803 -8900 C-098 81168012 OH 9803 -8900 C -03C 8808012 CH 12240 -8894 C -03C 8/31/2012 CH 12240 -8894 S -37A 9/38012 ON i NIA N/A Z-34 9/138012 OH N/A N/A S -32A 9/16/2012 CH GOC Not intersected by well GOC Not intersected by well s -32A 9/18/2012 OH N/A N/A C -24B 8/208012 CH 10450 -8929 B -27B 10/28012 CH 11740 -8941 B -27B 10/3/2012 CH 11740 -8941 S -12B 10/312012 CH GOC Not intersected by well GOC Not intersected by well z-69 10/5/2012 CIH 10670 -8784 S -12B 1 0/712 01 2 OH N/A N/A 18'-27E 1 0/2 4120 12 CH 10630 -8524 P-191_1 10/26/2012 CH GOC Not intersected by well GOC Not intersected by well 06.16A 1177012012 CH 9736 -8859 Z -10A 1180/2012 OH 13963 -8728 Z -10A 118072012 off 14410 -8717 D -29A 11/21/2012 CH 9946 -8920 F -31A 11/21/2012 CH I 9323 -8925 E -20B 11130/2012 CH 10545 -8921 Y -19A 11/30/12 OH GOC Not intersected by well GOCNot intersected by wall Z-078 12/16/1012 OH 13095 -8826 W -02B 12/26/2012 OH N/A N/A P-171_1 1/2/13 CH GOC Not intersected by well I GOC Not intersected by well OH - Open Hale Log CH - Cased Hole Log 1 B -29A 2/2812 0 1 2 CH 9595 2 G -09B 3/2212012 CH 10105 3 N-17 3/26/2012 CH 8952 4 K -04C 4/5/2012 CH 8958 5 C -35B 4/7/2012 CH 9604 6 E -01A 418/2012 CH 9678 7 D -19B 4110!2012 CH 9188 B 15-09B 4/28/2012 CH 11044 9 A-213 SWO12 CH 11935 10 GABA 5/1B/2012 CH 10315 11 K -07E 5/2772D12 CH 10053 12 15.016 8/8/2012 CH 9666 13 C -17B 6/8/2012 CH 11028 14 18-06B 6/2412012 1 CH 8932 15 18-12C 6/24/2012 CH Not present over logged interval 16 18-17 6125/2012 CH 11007 17 18-05A 6/26/2012 CH Not present over logged interval 18 11-33 BT27/2012 CH 10179 19 04-30 7/1/2012 CH 9945 20 X-17 1 7/4%1012 CH 9637 21 G -22A 7/5/2012 CH 9984 22 D -16A 6!712012 CH 9969 23 J-28 7)812012 CH 10780 24 Z-1 3A 7/9/2012 CH GOC Not intersected by well 25 G -04B 7/1012012 CH 10402 26 E -09C 7/12/2012 CH 10858 27 N -21A 7/128012 CH 11077 28 H-20 7/16/2012 CH 10018 29 G -10C 7117/2012 CH 10338 30 N-12 7/2012012 GH 9620 31 G-258 785/2012 CH 10455 32 M-15 7/2612012 CH Did not log GOC over Ivishak 33 C -28B 8/312012 CH NIA 34 06-03A 8/9/2012 CH Not present over logged interval 35 W24A 8/142012 CH 9636 36 F-41 8/18/2012 CH 11414 37 C-21 819919 12 CH 9117 38 16-30 8/23/2012 CH Not present over logged interval 39 H -02B 8/25/2012 CH Did not lop GOC 40 N -22B 813072012 CH 10310 41 0-27A 9/5/2012 CH 9483 42 E-16 9/10/2012 CH 906& 43 N-27 9/15/2012 CH 9104 44 N-15 91178012 CH 9647 45 11-11 10/20/2012 CH Clear GOC not present over logged interval 46 F -47B 10/27/2012 CH 9763 47 07-03A 10872012 CH 10368 48 15-17 10/31/2012 CH 10612 49 01-20 11/22012 CH 11527 50 F -06A 1114/2012 CH 10658 51 H -17A llf612012 CH 10568 52 02-19 11/11/2012 CH 9451 53 N-24 17!2112012 CH 9909 54 09-11 11/30/2012 CH Not present over logged interval M m CO) m 5 TcnN cn n C C T: m m M O T4 9Y }� S+WwS° Rl 1 "P p 1G m v$m m O D am � 3m Er z m m N 1G N m IU W N V p N e� A N N N NV IV IV N N 1V U IN N N N IN N N N N N N �i Z N Z O r .N N A m _ A A wp mwp 8p8p hh!! 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D(1t W •m 'V W A < S= L T = m m m 2 2 T 3 9 'a 2 2 2 2 U 2 2 U m m P 9 2 1 L T P 2 2 TT 2 2 TA- o D p W 4 H INd eD V m + IV ID Ib 3 � ww•m II•aVP oe •J mm mmm m m .a mo_to liNam fI'niOa;n o m �Ovmi li? . ;J�V •mm AIn �8 in V--A+P+iND o m •_VAA DN VQ+1KW +m •mm 1A� ImV WmmO ? {0�0`rr0111 i�' -PppQ.+ll to Jmm 12 V. m Jbb I�O 9vm 8 A� +O�NA N tmjW.�e A$N$ee+..11 1 O b r W1 p A N W V 01 IJ W IT la W �ppp W yj� bO1biJJ '15 (J 41 w W 1y.�1 W N w 0IV I'v w +P w IA w m N+ �r{f W w 11 W. W A 1(�p m Nm 1p�0 W 1p� NAV NSD O" �p • m D �n ,01, N'J d1'D mQ! rL•A tN0 1'JV+ A -•J ON)-bN l� •OWuO VIV pl � ml� R. R.2Soo�� y • 3 n � aaa a a� 0 aa� 0 a�aaa 0 0 •n a 1;7 �z D • O a O a� a O a� a G7 L7 a�R 17 �� L] a y m yA n n o o m +I n OpOeOn NW u A n (d • O n n 0-0 NOW n r n n o WOP NN n n O•D O p N p •v •9 .p .N O[]tOf A+_In OO+O+uW No A771�OININJn 11 M DC n n 0.0 r l! [P�0yy W N:� n 11 01D N u OBD wIT pp Q Ia' � O I� J pQt - IP NO �ywWW m VVV W p�NW `t QI WWV r[ WSW of m�N E0 J iIT •N N .P �N T a m •+ m ZJ la m 10 N W W N N A :b W iA I't A W .Gl �U } .m w er �1 +1 eL N W !ice IJ W X m 5 O X O -cnN cn n C0 ;a T m m O M Exhibit 10 2012 IPA Shut In Well Remit: :sw name Field APl Number SI Date Reason for Well Shut4nA Future Utility Plans Possibilities" 1Current Mechanical Condition / Additional Comments 01-04A Prudhoe U292D0700100 May -04 6 5 IAxOAxOOA comm - RWO failed in May 06. Will be evahiated for RST. 01-09A Prudhoe 029201640100 Mar -07 6 5 SI due to prod casing leak, & flow line repairs needed. Not economic to repair towline at Ilhis stage Also needs RWO. 01.31 Prudhoe 029216260000 pec -11 5 2 Requires DH Screen. Investigate sand consolidation to mitigate solids producion. 02-019 Prudhoe 029204420100 -11 i 5 Couldn't mill CIBR Requires a RST 02-05A Prudhoe 02=0810100 Jan -09 1 6 2 Evaluating ossbTes to re airTxTA. Extended Patch stuck on well 02-13B Prudhoe D2920433020D Mar -11 6 3 RST 02-14A Prudhoe 029204460100 Jul -11 6 2 S z GSO & RWO needed to bring onTine 02-15A Prudhoe 029204470100 Dec -10 3 3 WBII is not showing any fluid. Looking at ST 02-17e Prudhoe 029204530200 Aug -1 1 7 6 Flowfine VSM issues plus hi h GOR well. On WBL for GSO. 02-188 Prudhoe D29204540200 Jul -11 S 5 TxIA .No more wellwork opportunities 02-20 Prudhoe 029207210000 Jul -11 6 2 TxIA. Also High GOR Well. 02-24A Prudhoe 029207440100 Sep -11 5 1 TxIA. Setting Patch to Fix - 02 -26C Prudhoe 029207740WO Apr -07 6 7 RWO package on progress p2 -39A Prudhoe 029227210100 Oct -07 1 1 5 Can't pull LTR 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. 03-12 Prudhoe 0292039200DO Jerl-10 1 6 7 PC leak 0 233W M0, RWO package Is OuL 03-15A Prudhoe 029204140100 Au -11 6 5 Has 1AxOA unmanageable by bleeds while using AL. Unstable producer because of low rate. 03-26 Prudhoe 029210270000 Jul -09 3 2 SI for high watercut and low oil rate" Evaulating GL optimization. Well has a lot ofjunk 'which prevents water shut off" 03-29 Prudhoe 029211180ODD Nov -11 6 1 On WBL for Bradenhead Weld. IAxOA comm lab tests show IA and OA gas have different composition, not similar to 03-08. Starting head leak found February 2009. Had Funnanite Clamp installed 10/11 to determine if the well will be operable after a ST If we ,03-348 Prudhoe 029211320200 Apr -1 1 6 5 Well was repaired with RWO EOS 2010 but funnanite wrap began leaking shortly after POP. Re -wrapped with Furmanie but it leaked again. When flowing after last wrap the production was very poor Not pursuing another repair. O4.05A Prudhoe 029201070100 Jan -10 6 2 IAxOA and hi h GOR WIC working on POP UNDER EVAL for diagnostics - 104-07 Prudhoe 029201890000 Jan -97 7 5 Ongmaly SI for high WC; well slot/piping in manifold has been removed so unable to pursue wellwork options. Well does not lomity surface re Ir '04-14 Prudhoe 029203100000 Dec -11 7 6 Flowline needs to be repaired. 04-26 Prudhoe 029215200000 Oct -11 6 5 Hiah WC, low oil/IOR. IAxOA. PC leak.. No current plans 04-28 Prudhoe 029214880000 Jul -10 1 6 1 TxIA. Tubing patch failed; considered pkr squeeze, however some uncertainty given FL lis slated for SI Dec 2012 due to wall loss and FL replacement will likely not compete for expense dollars. Pkr squeeze econ payout is 1 years, but would only have 18 mont 04.30 Prudhoe 029213450000 Apr -1 1 3 1 Oil column disappeareFCO/adpert program on WBL 104-32A Prudhoe 029213260100 Apr -11 2 2 Currently SI for high WC. Split in S -Riser Operations repaired S -riser 517/11 and now waiting on space at FS2 to return well to service - 04 -34A Prudhoe 0292216DO10D Nov -97 2 5 High WC low IOR Flowline not ft for servjce" 104-35A Prudhoe 029221470100 Jan -11 2 5 High WC, tow IOR. Wellbore previously planned to be used for Beach Boys target ZWID signed 2/3/11 " Higher risk ad erfs tables because flowiine not fit for service. 04-8 Prudhoe 029221620000 Jan -11 2 5 High WC low 1OR. 0439 Prudhoe 029221810D00 Feb -11 2 5 Hi h WC, low IOR, No Flowline. 04-40 Prudhoe 029222240000 Jul -10 7 2 S1 for velocity excursion Total gas rate needs to be below 6 MMCFO in LP119 MMCFD lin HIP Evalualin WS0 o tions 04A1A Prudhoe 029222 370100 Se -09 2 1 !Hi h WC. Mill CIBP on WBL 04.43 Prudhoe I 02922443DOOD Dec -11 5 4 Sl for Res M mt 04.46 Prudhoe 029224340000 Feb -11 2 2 IHi h WC" Evaluating wellwork options 04-07 Prudhoe 029224390000 Fab -03 6 2 IPC leak & collapsed tubing, FL not fit for service. High WC, low IOR" Reevaluating for IRWO reserves. 04-46 Prudhoe 029224980000 Dec -11 6 7 SC leak & TxIA. Secure program on WBL RWO pk intemall approved on 2!7/11 05-01C Prudhoe 029201360300 Sep -11 5 1 Need Choke Replacement 05-12B Prudhoe 029202440200 Mar -M 6 2 'VVH leak, evaluating sealtitejob or CTD 05-138 Prudhoe 029202500200 r-10 6 7 WVRP stuck post RWO" No success as of 1q 2012 removing WRP. Still working in 2013 05.169 Prudhoe 029202620200 Sep -1 0 6 2 Ann Comm Issues... Evaluating Well Work Options 05-17B Prudhoe D29202710200 Nov -02 6 5 Low existing value - collapsed tb •05-18A Prudhoe 029219600100 Feb -03 1 3 Casing Leak & High GOR. Slimhole. RST package in Hopper though High Cost wet 05.39 Prudhoe 029227150000 Au -10 6 2 Ann Comm Issues & Velocity Constraints 05.40 Prudhoe 0292270700DO Nov -02 1 6 5 Failed RWO - stuck CT dunn2 cleanout 06-15 Prudhoe 029204590000 Ju1.06 6 5 Surface casinq leak. InteoritX team sug2ests P&A 07-078 Prudhoe 029209010100 Jan -11 6 3 TxIA. Rig ST candidate. 2 DWP Patches over collar leaks 11 DGLVs high GOR" 07 -ISA Prudhoe 029208560100 Sep -1 1 6 7 RWO on schedule for May- 2013" SI for SC leak & IAxOA comm. LP access only. {D7-18 Prudhoe 029208790000 Jul -11 6 5 Not Operable PC leak Looks like doing reservoir P&A, High GOR. Need wellwork to iustifv re air 0721 Prudhoe 029209070000 Sep -1 0 6 7 RWO being written- Patchfaled. 07-34A029218120000 Prudhoe A w-05 6 7 RWO on schedule for January, 2013. IAxOA; Stuck IBP fish in tubing. Rig ST candidate but LP access only, 109-09 Prudhoe 029202320000 Jan -11 2 1 SI for high WC and H2S. Reservoir needs time to recover from over -injection. Injection rates reduced in Spring 2011 but this area of DS09 has been dump flooded for years There may not be a lot left for this well" On WBL for WSO. HEX Plug failed. Need 09-23A Prudhoe029210660100 Jul -OB 6 2 IAxOA after RWO cemented OA to surface, high OAP due to external gas, working on solutions On WBL for qel treatemnt Not on WBL as of 10/18/10 09-2BA Prudhoe 029212920100 Au -09 2 2 Shut In for high WC. Needs Zone 4 squeeze of 2009 adperfs. Was on hold due to LoSal pilot but actions can be progressed now" Would need flowline sleeves to com back online- PMPs have WO submitted. 109-30 Prudhoe 029214110000 pec -10 2 1 Si for WC. In bad injection conformance area. Likely to be used for LoSal Phase 1 An Ad erf is on WBL 09-31C Prudhoe 029213960300 Apr -11 5 5 In four injector patten. Unnecessary injection rales have watered out this pattern and .neighboring patterns, Injects in the same zones as 09-14i Will donate to Res Man inf needed" 09-35A Prudhoe 029213140100 Nov -10 2 1 4 S1 for high WC. Will POP when 09-15A MI comes around the bend. SI 09-31C Injector ril 2012 which watered out 09-35. 109-37 Prudhoe 029224510000 May -10 6 5 ,Attempted packer squeeze summer 2010. Pressure tests failed Needs evaluation on pother wellwork fixes If no wellwork fix there is no utilization In dual injector pattern with 139-17 Exhibit 10 2012 IPA Shut In Woll Rpnnrr Reason for We]I Future Utility Plans & sw name Field API Number SI Date Shu! -In° Posslblllties" Current Mechanical Condition/ Addillonal Comments Injector Injects out of zone for pattern conformance In dual injector pattern with 09-16i Prudhoe -which injects into Z4. No plans to restore injetion due to over injection in this area of 09-38 029219190000 r-11 7 5 DS09. 09-42A Prudhoe 029220590100 Dec -02 a 5 2009 RWO failed. Now Ibla SC Teale Sidetrack candldete. 09-47 Prudhoe 029220980000 Sep -1 1 2 3 High WC, low PI. WII7d for Coll ST (5 -spot Reconfiguration) Prudhoe IA" to gas- not manageable by bleeds. Economics don'l Justly RWO unless Res 09-48 029221280000 Oct -11 1 6 5 Man G9es as sldatrack candidate or adds lateral. 09-09 Prudhoe 029223170000 Se 11 2 3 Hob WC WID-ed for Sidetrack (SANTANA/ROOTS Prudhoe IIAxOA and F rank FL Progressing in-situ gas llftfRWO options and following PMP 11-01A 029206440100 May -1 1 6 7 iresolution. RWO in progress. 11-12 Prudhoe 029212120000 Dec -10 1 6 High GOR due to shut-in injector; waiting on injection to lower GORs 11-16 Prudhoe 029215810000 Sep -09 1 2 High GOR due to SI lNecionin role, can't flow, need Ib t lash out 11-25A Prudhoe 029204880200 Fab -02 9 5 PC Leak and IAxOA Commuilicakon. No current plans, Prudhoe PC leak; Waddng Seallite and RW0 trackage in tandem Next well on RWO schedule, 11-27 029216380000 r-11 6 7 (Finished b end Jan'l3. 11-29 Prudhoe 029224660000 Feb -06 1 6 7 TxIA that acts like a one-wa leak Prudhoe GSO failed twice (6/10 and 4/11). Working on CTD scab linerfor GSO Decided to do 11-30 029224840000 Oct -11 1 3 CST rather than patch with coil 11-33 Prudhoe 029224900.000 Mar -10 1 5 H IE due td shut-in In ➢Sar, and well is twinned with a more competitive weG Prudhoe 51 for velocity excursion. Well is twinned with a more competitive well and both cannot 11-34 029225160000 Sep -1 1 7 5 flow into the twinned line at current gas rates. Water injection fine Inoperable, waiting on repair. Slight TxIA comm, hot MIT -IA to Prudhoe confirm integrity post-flowline repair planned. We have SealTile job on WBL to fix well, 11-35 029224760000 May -06 1 6 1 estimated to happen 1013. Flowline is fixed Flowline 11-36 Prudhoe 029224770000 Sep -10 6 5 SC leak; Brinker treatment failed. Well does not justify RWO. Prudhoe High OA pressure post RWO that cemented GA, 5851 -Tito tried twice but faked Wailinq 12-03 029203770000 Sep -1 1 6 2 to be handled as a b] errO Prudhoe High OA pressure post RWO that cemented OA. Waiting to be handled as a bigger 12-07A 029204090100 Oct -09 6 2 reject Prudhoe ILTSI. Low oil rate. Stole 12-11's surface facilities for new grass roots well 12-37 CMIT- 12-11 029206010000 Feb -00 6 5 IIA passed on 6/11 Will consider testing with ASRC. 12-15 Prudhoe 029209180000 May -111 6 1 A/L PMP. Completed. Now needs TubinR patch to fix WI issue. 12-30 Prudhoe 029218910000 Dec -09 6 2 PO GLM leaking. RWO SOR a roved SC leak & leak Outside weIR Ouse; wall Nicely not operable perWT group even iI RWO Prudhoe completed given high risk in operating well! No plans at this time. Surface facilities 13-01 029203230000 Jul -06 6 5 donated to 13-37 f&as roots well Fla ed to Wells Groupfor P&A, TxlAxOA; prddudes rocks, Sa screen Installed, swiss chasse lub rip. Pians to further Prudhoe diagnose. Well to be Non -rig Reservoir Abandoned Dec 2012: Decided to proceed with 13-04 029203260000 Oct -03 6 7 RW0 not l0 be abandonedl Prudhoe 7xlA wl significant surface facility issues that would add -$1MM to package NWD 13-07 029206500000 Jul -91 6 2 screenin for ST. Prudhoe Tree Replacement followed by deep GL Design. 13-12A Drill -by, Ran LDL in Sept 2012, 13-OBA 029206670100 Oct -11 6 1 need to evaluate if patch is an option. Prudhoe IAxOA on GL: uneconomic RWO (high WC). No plans at this time. Looking into 13-10 029206780000 Jun -94 6 2 possible non -rig fix Prudhoe TxIA & possible packer or PC leak. NWD screening for ST. Idea to run LDL to evaluate if 13-11 029206040000 Dec -05 6 5 etch is an o tion. Prudhoe Waiting on MIS I Supply flowline repair to DS 13/14 MI line repaired to DS, well can't be on 13-17 0292071BOODD Ma -11 5 4 water due tobroken PWlline. 13-21A Prudhoe 029207890100 Dec -11 7 a IF rank on flowline; on schedule to be repaired 13-25 Prudhoe 029207610000 Oct -07 6 5 ANN COMM - NOT OP. TxIA Prudhoe Jax P2 sidetrack Into SAG Not pursued any further at this stage, but CST could be an 13-26 029207460000 Oct -11 1 6 5 option 13-28 Prudhoe 029209420000 May -94 6 5 PC took & bubbles in the guar RB 13-13A. 13-30C Prudhoe 029207680300 Oct -11 3 1 2 'Low PI. No Ras. Pressure. Needs Inj AupporL 13-33 Prudhoe 029207730000 Dec -94 6 5 TxlAxOA; Well to be Non -ria Reservoir Abandoned in 2012 or early 2013 . 13-36 Prudhoe 029226130000 Sep -10 6 7 ANN CUMM - NOT OP. TXIA and possible IAxOA Prudhoe TxIA and leaky 9513' scab. Uneconomlo RWO; not a Seallde canddate No current 14-03A 029203190100 Aug -09 6 5 plans for this well. Wells group wants to abandon well - Prudhoe IAxOA and flowline; uneconomic RWO. Flowline replacement not planned due to lack of 14-14 029206250000 Aua-06 6 5 reserves to 'ustify entire project Reserves ranked high FL repair complete 3011. POI waiting on IWL completion Prudhoe 1217/11: Needs a new choke (not ordered @ time of FL replacement); 1012 replacement anticipated (3 month lead time on parts). Flowline replaced, but well 14-27 1 029210460000 Nov -04 1 6 1 developped downhole ro x1A poor tubing, low rate for the last 6 months of life. Previously considered for UZI, Prudhoe (but project on hold due to FS3 projected water limitations. RWO package has been 14-31 029209890000 Jul -07 6 7 issued, On rg schedule for May 2013. Prudhoe TxIAWA; extended patch program with Weds Gaup for revision. RWO package walling 14-37 029218100000 Se -05 6 7 on resdubon of OA es source issue. 14-38 Prudhoe 029210620000 Nov -94 6 5 TxIA and low PI (SI 11/94). No flowline, 15-03 Prudhoe 029207220000 Jun -94 6 5 Cret leak. tsaki z ds, m or fish u1 tubi surface facilities given to another well Prudhoe Major leaks and a channel: n0 surface fapltTies; bottom hole location developed by 15• 15-10A 029205010100 Jan -91 6 5 49 Prudhoe Choke removed 8/1/10 (erosion) High GOR, Jul -10 Plug/perftested all gas Sidetrack 15-128 029206650200 Jul -10 1 2 candidate. 15-15C Prudhoe 029206910300 Ma •10 1 5 Hich GOR. Big ng sidetrack candidate Pulled leaking patch over parted tubing @ - 3000' MD & Liner Top Packer, calipered Prudhoe 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 15-19A 1 029218290100 Jul -11 6 1 5 Jul 15-24 Prudhoe 1 0292222300 Mar -95 6 5 Collapsed tubing, cret leak, no surface facilities 15-2BA Prudhoe 02922247010()011 Mar-04 6 5 MITOA fails, has cretaceous leak. Twinned with 15-22 15-33B Prudhoe 029224480200 May -1 1 1 3 End -of -life add efts failed. Sldetradc Planning delayed due to ma incl tubing 10/26/11 15-35 Prudhoe 0292248BOODO Sep -03 6 5 Cral leak dum flooded Ivisbak, TxIA and PO leak 15-40A Prudhoe Q29225110100 Jul -11 1 2 IHih GOR. Plu / erffailed in Sept -110. E -line RST/add erf program beingworked. Prudhoe PulAvishak comingling issue & already swept Ivishak zone makes wellwork unattractive. 15-41B I 029224920200 Feb -07 7 5 INo sidetrack tar et. 15-42B Prudhoe 029226240200 Mu -10 1 5 i h GOR. Sidetrack can011e Exhibit 10 2012 IPA Shut In Well Report Reason for Well Future Ulf Ity Plans & $w name Field AN Number SI Date Shut-InA Possibilitiesa Current Mechanical Condition I Additional Comments 15-03 Prudhoe 029225760000 Jul -11 6 2 'Wall developed SG leak at the wellhead on Dec 29 2000. Sealfits failed Sept -1 0. IMIT-OA Passed to 1000 psi w/diesel; MIT -OA Failed to N2 wit increase in N2, CO2, and Prudhoe ILEL's confirming SC leak Set TTP @ 10,130 for secure DHD set to establish / locate 15116 029226850000 Se -11 6 2 ISC leak depth- Possible Brinker candidate. IPC leak at 6130' MD. Will pert heal in movable oil Z4 to check injectivity If good, will 16-05A Prudhoe Prudhoe Dec -11 6 7 work over. If not good will give to reservoir management for sidetrack 16-OBB Prudhoe 029205840200 Oct -11 7 6 'vSWFlowlina. 'Wells Group working on non -rig fix involving expandable sleeve options to fix broken 16-09A Prudhoe 029205580100 Jul -07 6 2 5SSV- 16-24 Prudhoe 029215360000 Jul -D6 6 5 'TxIA communication and low productivity, 16-28 Prudhoe 029222760000 Oct -05 6 5 SI for high WC. SC leak. Will be non -rig reservoir abandoned 16-29A Prudhoe 029272720100 Nov -06 3 2 ILow roductivit /ht h watercut Reservoir needs further stud in this area. I for low PI. TxIA togas only- needs GL to produce In pattem with Injector which 16-31 Prudhoe 029222800000 A r-95 3 5 Injects out of zone. 17-048 Prudhoe 029204960200 Jun -12 2 2 HIGH WATER CUT 18-01A Prudhoe 029207520100 Oc1.11 I 1 1 Wellwork on WBL 18-028 Prudhoe 028207620200 Satio 6 3 Sidetrack package being prepared 18-11A Prudhoe 029211810100 Jul -10 6 5 IPC leak. High risk WO.NFU 18-19 Prudhoe 029215960000 Sep -03 6 7 AnnCDmm, RWO on schedule 18-20 Prudhoe 029218900000 Jan -07 6 5 IPC leak a 7900'& 0100' md. High risk WO 18-22A Prudhoe 029723030100 Oct -11 1 1 Wellwark on WBL. TEA Prudhoe 029218980100 Apr -11 1 5 'Well with slotted liner No possibilities for GSO 18-25A Prudhoe 0292'19480100 May -03 6 5 Crelaceous leak Nofutureutility FL was donated to well 18-15. 18-23 Prudhoe 029225840000 Jan -01 6 5 (Hole in tb and casin . CTU fish in well. Reserves too small for RWO 18-33A Prudhoe 1129225980100 Dec -05 6 5 TxlAxOA, Also has starting head leak Low Reserves (Hole in ibg and casing. Cement in lbg and IA. Multiple plugs in tbg. No way to recover 18-34 Prudhoe 02=6110000 Oct -00 6 5 this well. Remaining value very low anyway. Prudhoe iOperable. SI for high WC. Brightwater pumped in pattern in 2011. WSO/APF written. A -01A 029201080100 Dec -09 2 1 'Waiting on wells group approval to submit to WBL -1/12. On WLB for Prof Mod, ,4-13 Prudhoe 1 029206720001) Dec -10 6 5 .Anncomm - HOAP extemal as. Working P&Aro ram Low IOR, SC leak & TxIA communication. Well is on ADW P&A ist with BM approval. ,4-18A Prudhoe 029206300100 Jun -03 1 6 5 IFlowlines available for 2rassroots ST. A-24 Prudhoe 024207430000 Jul -12 6 2 ANN COMM • NOT OP A-26 Prudhoe 029207940000 Jul -11 3 1 C) erable. Law PI. Doin2 FRAC. A -32A Prudhoe 02921395010D Feb -10 6 7 ,Anncomm - TxIA Caliper showed tbg integrity issues. Working on RWO SOR. ,A-33 Prudhoe 029214100000 Feb -10 7 6 'Operable SI for GC3 H2S limits at 70ppm - 4/07/09. ,Anncomm - HOAP external gas Wefl is on the list [o POP UE and monitor for Prudhoe Irepressurization, but need new well's group breaking containment SOP first Waiting on A -34A 029213390100 Dec -09 6 2 'wells croLw :SC leak, TxIA comm. Plan to work reserves justification for RWO later in 2011 Well is A-40 Prudhoe 029223370000 Sep -09 6 5 on ADW P&A list. Operable. Well SI for low oil rate. Evaluating converting well to injection. Discussed in ,A -42A Prudhoe 029225420100 A -11 3 5 pattern review Sept -1 1. Need resman support to progress. 8-09 Prudhoe 02920316000D Sep -90 5 5 ewaterin . 1 'eats info faulL USed for 't dewatering- - No FL ; surface facilities given to B-35. Flag to ADW for P&A Need Simple IB-1 IB -11 Prudhoe 029203310000 Jan -91 2 5 secure. Secure. Txl com, low IOR. Well has been selected by Sag NWD team for use as donor well for IB -19A Prudhoe 029207030100 Oct -09 6 3 Sag Kona taret. ST will be drilled in 2013- B-24 Prudhoe 02 92 081 50000 Jan -93 2 5 ILTSI. Replaced by B-13. No FL. Do we need to flag this well for P&A? Well selected as donor wen for Sag Longboard targe[ ST will be dnfled late 2013/early B-260 Prudhoe 029209760200 Nov -09 6 3 :2014. MIT-TxIA failed. Injector used for GO MI plot Tested with ASR[ in 2006 for producer Prudhoe conversion - well was HGOR Well is available for ST to another location Injection IB -28 029215100000 Sep -09 6 5 !Facilities are intact (Operable. Released to RM for ST 7/11. High GOR cycle well - Does not heal. Twin with Prudhoe 'B-21. Shares a choke with B-21 and both wells can't flow at the same time due to I9 -30A 029215420100 Dec -08 1 5 velocity- Will -need to be delwinned if STU Suspected packer leak. Further dlagnosflcs in WBL (Putt LTTP, set TTP, MTT T & MIT - IC -19B Prudhoe 029207350200 Feb -11 6 2 JA :2008 CTD reservoir failure. On WBL for GSO & Addperfs JMS 4/12 and switched to C -23C Prudhoe 029207750300 Mar -09 1 1 Bine 9/12. WeII was tested twice in 2012 and showed no heeling Plan to P&A Cretaceous leak, flowline taken, evaluated CST, but add'I facility costs Prudhoe (makes it cost prohibitive. No current wellbore utilization; reserves captured by offset IC -38 029215710000 Nov -97 6 5 wells. D -19C Prudhoe 023207070300 Oct -11 5 3 Restricted flow Planned ST Pkr and PC leak @ 4950'. Candidate for squeeze but low IOR, no chance of executing ID -27A Prudhoe 029215430101) Apr -1 0 6 5 'this job. IE -14A Prudhoe 029207840100 Sep -07 6 5 TxIA Comm & surface asg leak E-25 Prudhoe 028217730000 Jan -13 1 3 ISI for HGOR. Awaiting a CST targe[ E -31A Prudhoe 02922411010D Dec -it 1 6 1 TxIA E -39A Prudhoe 029225870100 Se 05 6 5 IBP fish stuck in hole. 'Wells has annular communication MIT -T & CMIT-TxIA failed. Need [o run a LDL to IF -05A Prudhoe 029200950100 Jul -11 6 7 iidentify the source of the leak. LLR is 0 67 glom. F-096 Prudhoe 029204030200 Dec -11 1 2 SI - for HGOR, Wells no longer heals with cycles F-12 Prudhoe 029204250000 A 11 3 2 LOW PI Attempted POP 612011 without luck - well produced all gas. No cycle ability. On WBL IF -15A Prudhoe 029206510100 Jun -11 3 1 to remove CIBP to access Paris. F -16A Prudhoe 0292DB610100 Jan -07 6 5 No forward plans for this well. 'Well Not Operable. Potential Rig Sidetrack Opportunity in 2011 ResMan team working 17-22 Prudhoe 029219510001) Apr -08 6 7 on WID. F -23A Prudhoe 02921658010D Jul -08 6 5 Avail for ST <F-260 Prudhoe I 028219070200Apr-08 1 1 5 No obvious EOL wellwork remaini . F -28B Prudhoe 02921549020D A r-12 1 5 HIGH G0R IF -37 Prudhoe OM19740000 Dec -11 1 5 HIGH GOR Consider ST. G -03A Prudhoe 02920221010D Dec -04 6 5 Failed RWO in 2006. BHL replaced with G-31 B. G-07 Prudhoe 029203590000 Oct -11 6 $ ANN COMM - NOT OP G -11B Prudhoe 0292059.90200 Nov -11 6 2 ANN COMM - NOT OP. Currently diagnosing downhole problem This was a sidetrack package being worked but failed integrity lesfiing We are G -24A Prudhoe 029216710100 Nov -11 6 1 5 Ievaluatin whelhar to do a packer squeeze to restore [his well for sidetracking LTSI Cretaceous Disposal Well, No Flowkne, Repeated attempts to cleanout Haled, CT GC -2A Prudhoe 029201670000 Sep -95 1 6 5 fish Ro. hole, ao in'ectivit Exhibit 10 2012 IPA Shut In Well Report Reason for Well Future Utility Plans & sw name Field API Number SI Date Shut -In" Possibilities"' Current Mechanical Condition / Additional Comments GC -2C Prudhoe 029217740000 Sep -07 6 2 Monobore completion, OA valve oauge shows IAP, MITIA passed to 1700psi on 2/6/09 GC -30 Prudhoe 0292MMDDOO May -03 4 5 LTSI Cretaceous Disposal Well - requires CT FCO Replaced wish GNI-04 for Class 1 Injection. Available for Class 2 InlWlon and GNI-01 Prudhoe 029228450000 May -07 7 4 Observabon, Has no IlotMine NOT OPERABLE -Tubing coflasped at 2011'. Well was being flowed back afterfracjob- H-16B Prudhoe 029205920200 Sep -11 6 7 Camera confirms casing/tubing casing/tubingcollapse No flowline. NOT OPERABLE. Furmanite wrap from 912009 is weeping WIE planning to re -wrap H -23A Prudhoe 029217940100 Oct -11 1 6 1 with Funnanile. On WBL. Planning to set a plug to isolate reservoir. NOT OPERABLE- Pre -ng diagnostics on Prudhoe WBL Pkr Sqz program written, reserves look okay, but thin oil column and GOC may have moved further down; needs WH choke. May decide to repair packer and then H-28 029218060000 Apr -01 6 5 sidetrack. Lo Prudhoe NOT OPERABLE TxIA, PC leak. Repair with RWO and getZ4B well back with acid job H-34 029220030000 Nov -04 6 5 -or possible RWO and Sag ST. J-018 Prudhoe 029200200200 Aug -08 6 5 -Cellar is bubbling as wAvishack charactedstics- No utilization for well Prudhoe Wellhead leak, tree growing. Planning to perform RWO or wailing on wells to see if we J-03 029200250000 Nov -04 1 6 2 can wield to perform SC repair J -05C Prudhoe 029201200300 Sep -11 6 2 Furmanite clamp failed. Wells group is pJanninQ to weld it J-155 Prudhoe 029209010200 May -06 6 2 TxIA communication Looking into RWO options for well. E nd of life wellwork came back high GOR This well has no work left on it It will await a IK -06B Prudhoe 029210380200 May -1 0 1 3 OST. K -09C Prudhoe 029217360300 Feb -09 6 5 PC leak. Sealtite failed to repair. No current repair option K -19A Prudhoe 029225310100 Apr -09 6 5 Has a PC leak wit a LLR of 3 bpm. CurTenfly there are no future plans for this well L-01 Prudhoe 029230110000 Oct -11 3 2 ILdw PI- Not com etetive. L -02A Prudhoe 029230480100 May -07 7 6 Available for roducion inadequate gas Jift supply L-03 Prudhoe 029232690000 Nov -09 7 6 ,Avalable for production. inadequate gas lift supply. low Pll of rate L-50 Prudhoe 029232770000 Me •07 1 1 5 High GOR. No flowline now, no current utilization no tans L-61 Prudhoe 029233090000 Nov -10 3 2 Passible slim candidate Sao wet lacks injection support. Prudhoe (Evaluating RWO feaslbility & possible non -rig fix Can't flow to LPC due to gas L2 -08A 0.22217610100 Jut -99 6 5 limitations IL2-11 Prudhoe 02922BB50DOD Nov -DB 6 5 RWO pkg is pMpared but Co-owners won't sign due to poor economics. M -05A Prudhoe 029201940100 Dec -04 6 5 Gas lifted well TxIAxOA Communication, waiver cancelled. TTP stuck. Not operable. M-08 Prudhoe 029204990000 Dec -09 6 2 'Originally SI for high WC, SI now for possible SC leak and confirmed SS/GLM/pkr leaks M -13A Prudhoe 029205220100 Sep -07 1 6 2 'Twin w/ M-14. Flowline repaired but well has IA x OA communication M-188 Prudhoe 029208550200 Dec -11 7 6 Shut-in for flowline replacement- FL Replacement due early Dec. 2012 M -20A Prudhoe 029209120100 Dec -11 7 6 :Shut-in for flowline replacement FL Replacement due early Dec 2012 Originally SI due to low PI. Now a not operable well - TxIA LTSI, low rate, money pit M -27A Prudhoe 029219920100 Jul -97 6 5 Also TxIA Communication M -29A Prudhoe 025219040100 Dec -11 7 6 .Shut-in for flowline replacement- FL Replacement due early Dec -2012 M-30 Prudhoe 029222550ODD Dec -11 7 6 Shut-in for flowline re menL FL Replacement due early Dec.2D12 Prudhoe NOT OPERABLE: PC leak Well has flowine, but no P -pilot or nydra for SSV and N-03 029200870000 Jan -96 6 2 Chemical injection, Prudhoe NOT OPERABLE Work to P&A. Tod many integrity issues. Replaced with N -18A No N -O6 029200980000 Aug -05 6 5 flowline NOT OPERABLE: SH leak POP'd and got a few well tests for evaluation. Wells Group Prudhoe evaluating for weld repair- Ready to sidetrack Need reserve estimate for 54 Ac fault N -11C 1 (22921375(2200 May -11 6 2 black N -14B Prudhoe 029205940200 0ct-11 5 1 Sl for Solids production. On WBL for FCO- OWDW-Svv Prudhoe G29218170DOD Feb -10 7 5 Dis osial Well Not O erable Prudhoe SC leak. Available to Res Man for Sidetrack options. RWO option to be explored (sidetrack location ID'd, timing for WID?? Will use either P-15 or P-18. Well is secured P-15 029221200000 Feb -D9 6 2 with a pluo and A on P{ & Mannament list as Non R Reservoir Abandonment with BM SC leak. Available to Res Man for Sidetrack options- RWO option to be explored Prudhoe (sidetrack location ID'd, timing for WID?? Will use either P-15 or P-18 WeII is secured P-18 029220970000 Jul -07 6 2 with a plug Prudhoe Well is gas lift twinned with P-21. Well was originally shut in to evaluate gas lift optimization for P-21. P-20 has also had a recent caliper which shows significant build IP -20B (12 922 0 89 02 0 0 Aug -1 1 7 2 u df scale in the Lubin . After P-21 optimization evaluation is completed, O e Txl comm, probable bad packer, FTS -High risk Wellwork considering obs at 10500 Prudhoe that failed to be milled out- Flowline disconnected Well available to Res Man for RST P-22 029223960000 Dec -96 6 5 Well Secured with a Plu Injection lines given to P-28, looking to reposition (and RWO to repair integrity) for Prudhoe support of possible sidetrack of P -05A near toe of P-26 (4/15/11 update) or RWO if Y - P -23 029223930000 Jun -02 1 6 5 25A bottomhole location is replaced PWDW1-1 Prudhoe 02920226DOOD Jul -07 6 5 Si due to poor injectivity resulting from a SSSV fish down-hole- PWDW2-1 Prudhoe 0292012270000 Feb -03 6 5 LTSI Cretaceous Dis osal WellPC Leak at 2992' would re uire redrill Prudhoe Suspended with Ann Comm issues. No flowline or wellhouse- Replaced by R-39. Tobe R-01 029203530000 Nov -93 6 5 used for J -Pad UZI R-02 Prudhoe 029203540000 Au -11 6 1 Evalualinq another o lion to repair SSD leal<&potential another leak poing R -06A Prudhoe 029203880100 Jul -07 6 6 FL repaired. waiting on final tie-in ineed pad shut down). TxIA Prudhoe LT51, low rate (also has Ann Comm issues), Have approved CTST but needs RWO also R-]0 029206180000 Mar -01 3 5 .and can't afford- To be used for J -Pad UZI R -20A Prudhoe 028206410100 Jun -06 6 2 Surface Casing Leaks OA repressurizaion - external gas source- Evaluating for Sealtite treatment. POP for R-24 Prudhoe 029212320000 Oct -09 6 1 oval. WIE working issue. R-30 bottomhole reserves captured by R-41 grassroots well; however, R-30 is an R-30 Prudhoe 029222790000 Sep -05 6 2 excellent excavation and San Coi Sidetrack candidate when SC is repaired S-04 Prudhoe 0292095&1000 Dec -11 6 2 Tx7A and flowline repair needed. S-13 Prudhoe 029208100000 Mar -01 6 5 Avaiable for Ngh KO sidetrack ReseivoirAbandmonent program being worked- orkedS-15 S-15 Prudhoe 029211130000 Se -11 6 2 SC leek. RW0 m hl be end Ilw1 once S-16 and S•32A are back dnlne- S-16 Prudhoe 029211230000 Au -04 1 8 7 60 leak and IAxOA- RWO SOR approved b partners- 61 Bradenhead leak, fbg In poor condition, flowline needs to be replaced. Available to S-23Prudhoe 029220880000 Apr -04 6 5 IResMan. S-30 Prudhoe 029220:110000 Aug -03 6 1 5 17xIA Released for ST. -34 Prudhoe 029223050000 Jul -10 6 2 (Not o erable- IAxOA comm- -40A Prudhoe 029224940100 Aug -05 6 5 rSC Leak Eva] ST Salamatof. -01Prudhoe �T-07 0292'12410000 Jul -S9 5 5 (.TSI Injector, not an effective injector Prudhoe 0792D733W00 Jul -99 5 1 511 -TSI Injector. not an effective i gector Exhibit 10 2012 IPA Shut In Well Rrannrt 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 2. Under Evaluation 3. Sidetrack Planned 4. Reservoir Management 5. No Current Utilization 6. Surface Facilities 7. RWO Candidate 8. Waiting on Waiver easoil for well Future Utility Plans & sw name Field API Number SI Date shut -In" Possibilities" Current Mechanical Condition /Additional Comments Prudhoe TxIA, PC teak; Ffowknes in good shape - will be used to drill U-16 grassroots well. Well IU -02A 029211700100 Dec -02 6 5 available to Res Manma be used for UIW Pad bounds well Prudhoe Operable. High walerCul, Rawrinea given to U -15A Weft available to Res Manor Sag IU -08A 029211360100 Jan -02 2 5 Team For sidevsOL Prudhoe Operable. Low oll rate. Rock producer wl TTA. Welliwre available to Res Man/Sag.Team U-13 I 0292035500DO Jul -06 3 1 for sidetrack. Work on WBL to set a rock screen & POP Prudhoe No il, no flowkne, well suspected of hole collapse Wellbore is available to Res U -15B 029225650200 Jul -06 3 5 %a IMan/1 Team For sidetrack W -23A Prudhoe 029219930100 MOV -1 1 6 1 stuck coil while milling scale; Fishing is in progress X-01 Prudhoe 029203900000 Mar -11 6 2 ANN COMM - NOT OP X-02 Prudhoe 029203970000 Mer -11 6 7 SI - corroded tubing - working RWO acka e Prudhoe LDL run — found 2 leaks. IAxOA comm history is barrier to NRWO Side tracking to X-04 029204120000 May -03 6 3 Lon board target .X-10 Prudhoe 029204670000 Oct -11 6 3 ANN COMM - NOT OP. Planed for RWO-CST X-18 Prudhoe 029206750000 May -11 6 2 Identlryad IAxCA in wellhead. Possible downhole TxfA. X-23 Prudhoe 029211080000 Oct -11 6 2 Well SI for Startfrin head leak. Prudhoe SC leak Low1OR Can't justify RWO. Eval RST. POP'd and tested 1/2009 Still .X-34 029224170000 Jan -09 6 5 uncompetitive. TxIAxOA GL- Future offtake Y-03Ai Diagnostic confirm comm is not thru theWH Rapid Prudhoe -OA repressunzation. Plan is to ST away from a fault, wellbore available to Res Man/Sag Team for Sidetrack. Well is secured with a WRP - Simple secure on Risk management _ -D2A Y 029203950100 Oct -05 1 6 5 I Prudhoe Originally SI for low PI. Now Not Operable - TxIA, PC leak. Limited reserve. Flowline to (back of wellhouse. Conv/CRWO pkg submitted for approval 5/25/06. Should be done Y -08A 029205720100 Sep -93 0 5 isimultant w/ Y-07Ai RST/MI fac upgrade- Declined by Partner due to uneconomic. ST to TxIAxOA FTS. Poor lbg condition. Wellbore available to Res Man/Sag Team for Prudhoe lsidetrack (ST to east toward Y-34 candidate). Well is secured with sand over Y-12 029205170000 May -99 6 5 perforations. Y-13 Prudhoe 029206340000 Feb -06 6 3 Wet currently lisled as not operable -TxIA. Side-track planned for late 2012. HighWC - low oil rate & TxIA. PE notes indicate there is an obstruction in liner so Prudhoe cannot get into liner for WSO. Wellbore is available to Res Man/Sag Team for sidetrack, possibly to be used as Sag Proof of Concept Well WeII has not been 'Y -15A 029209400100 Jul -11 6 6 secured. SC Leak; $1 wet since the beginning Plan to plugback to Y -17A perfs For Y-031 cmake. Prudhoe 1 Wetllsdre. is available to Res Man/Sag Team for Sidetrack Originally SI for high WC but Y-176 029209200200 Jun -02 6 5 now has SC leak - wall is secured with PX. plua. Prudhoe Originally SI for High WC Now has TxIA. Well to be side-tracked late 2012. Well to be Y -19A 029218570100 Au -11 6 3 used for Slag Proof of Con _ well failed MIT -IA on 12r=011. Reservoir P8d1. Y-28 Prudhoe 029221690000 AU -11 2 5 1 LOW PI Prudhoe This area is swept. Mechanically operable well. Wellbore is available for Res Man/Sag Y-30 029221350000 Aug -1 1 2 5 'Team for Sidetrack. Not secured Y-31 Prudhoe 02922161000D Dec -07 1 2 5 SI for Ngh M_ No obvious ST 12Mets. Mai2onically operable well Y-32 Prudhoe 029221490000 Jan -09 1 2 5 Si for high WC. No obvious ST targets. 'Y-33 Prudhoe SI for 1-12S. Mechanically operable well. Wellbore Is available for Res MsrUSag Team 029221440000 Sep -12 7 2 for Sidetrack Well to be secured wllh a TTP 'Y Prudhoe SI for high WC. Mechanically Operable Well. No obvious ST targets and is available to -34A 029221780100 Dec -07 2 5 Res Man/Sag Team for sidetracks Not secured. Prudhoe TxIA, OAxCond. Collapsed tbg. Wellbore is available to Res Man/Sag Teaml for Sidetrack Well is on Risk management list for Rig Reservoir Abandonment with Base 'Y-38 029225530000 Dec -02 6 5 apiamyal, note to Caroline B to have Y-38 aowtlne pickled (twinned with Active well Y-18) Z -01B Prudhoe 02921BBOD200 Feb -11 3 2 LOW PI Z-05 Prudhoe 029220560000 Jul -10 2 4 High WC, low oil rate. POP after Z -09i on injection Z: -07D Prudhoe 029220460200 Nov -11 3 3 Low Pl. Sidetracking well. Z -08A Prudhoe 029217870100 Jul -10 2 4 High WC post acid stimulation, POP after Z -09i on injection Prudhoe Low Pl, Velcoity Constraints. Planned conversion to injection as twin with Z-67 in Z -09A 029219670100 Au -11 3 9 summer 2013. WTI work beginning now. Low Pl, no area injection - planning ST to reach Z-38 toe reserves. 10/2012 Sidetrack Prudhoe lin progress. 11/2012 Sidetrack completed. Waiting on WTI and downhole completion Z-10 029219860000 May -11 2 J 3 1 for POP. Prudhoe INot operable. TxIA. Well marginally competative at best Evaulating whether fix is .Z-15 029218490000 Dec -10 6 2 economic. Prudhoe OA repressudzalion due to Shallow gas, poor cement, waitbg on dedslon on annular .Z -19A 029222 51 01 00 Jul -08 6 6 vent system 7-35 Prudhoe I 02922BB400D0 I Aor-01 2 5 Hi hWC nocurrerllClaris 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 2. Under Evaluation 3. Sidetrack Planned 4. Reservoir Management 5. No Current Utilization 6. Surface Facilities 7. RWO Candidate 8. Waiting on Waiver Water'1 2012 • - - Surveillance by �.• .• .. .rf��~ �. "tib •.,•�ti f,1s Gas � �� ,�■~ � � iii, '• � ��:}��; �J�: •;�.•, _:;�^+,. �: r f f � v ; � ► ►♦ , ,�' water .�� = i ► I y • If Gas Previously but ;' a �� ► p rl •Ce ♦ l ►t no log within 2yrs rte: ".. � ... .. •'"� ' ;: �!. r^:rw—, [tt +R _ '^i)---� r _ .•� �H .... - , f �I a Produced water, no log z.:y1r.,;" \ •-..., •;•'`: f it '• - F T P51 Guard Wells } s - -=} .-ii : r - ••'T �r� r2^i.`-• .., .: 1 'Ac.. 2005 Extent of water • � • r tr.r��T'•rl�`4 �'��w]r ,r l= .� /• � 2006 Extend of water •� �', .' _-F f � � z y, :ti `_. : f .� ^ 2009 6derdofwater • m :fir„' ..� y • ,Y;:: .. m r r" ` �` ,�: ir• r .r .:; ... • 2071 Extentorwefer ij '� �v' .r r � •r F �- �" ,3•' 2077 Exterdofwater "IF: lkx� IIF. IF!llII11111'� \ `xkN-g !!!!!llllllllll �1� 1�lFl;l;l;1;1;1, film 4�1 IIII!l111111• ox I1111l111111 111111111111 I111!lII1111, Illlllllill11111111111r 11111111111.. 1,1,1.1.1.1.1.E-� • 1111111111111111111111111, 1111111111111111111111111 11111111111111111111111111 11111111111111111111111111 I11�111�1�l�1�1I'I'1'i' I111111111l11I11I111II.! 11111111111;1111111111' Ill�llllllll�llrlfllll� 111111111r1111111�11111 I!1!LI!LI!1!1!:}1!1 ...................... U) r_+ i co U) r-+ n O C� O 0 9 H I Exhibit 1-D Greater Prudhoe Bay 2012 Reservoir Pressure Map i NWFB �.•-- �'n 3��s pew ® [��i �'3 71W yl 1 N - y., �. 3 EWE �' �k' K'" � Sr�• G 0 T '� y�.p•d� $� e T z 11 4 3 K' •� ] x.-� r.. A .fie 31 `4 �i y� w.•ewissi . -T+� u TJ aid: ■A up�7 ""' j 373+7• _ • 0 C A C �xw t i Z-;RAIiWIH�n�1R y}��f�n��' Y fA P i g 3}7! 1� ate+ r r 3t7W�. r uia���r 51�1 1 =�e rs7r iSfYh 1 GD +1Y 2012 Reservior Pressure ° 2010 SBHP Well Test at 8800' SS Datum • 2011 SBHP Well Test 3,050 - 3,150 psi • 2012 SBHP Well Test 3,150 - 3,225 psi Prudhoe Bay 3,225 - 3,300 psi Unit Boundary 3,300 - 3,420 psi Depletion Polygons 3,420 - 3,550 psi 3,550 - 3,680 psi NOTE: Engineered control 3,680 - 3,790 psi points have been added to 3,790 - 3,890 psi the field permiter to provide 3,890 - 4,000 psi a more accurate contouring. 0 5,ODO 10,ODO 20,000 30,000 40,000 ' Y w 1T Y qfi " 1` t w PWz T ae 014" ",::.w Yirnl: C,t Isl 7SY7 � A] u IL?fA s ]36r 'lots 1549 Gas Cap i 1�7 >s i1fl0VY�A P'7-]-]4 3 ... 7L�i 3 a Y.a! F r111, f L`! -1,1w I A -, 00 !1 -' S1L Ol. Q7 7 .�•"Y F � ! ¢L 01 i I is:IIA 7 33,+.6 '_ 12•: q] 7:Ori r-�a � 1 r/�j' 3rd( 7. 1 as1 Neea�Ts�e —.. _.. 1 x1] i ' �7+}jlhl ,q� 1 0 16 XT �g b •++'Ik EPWZ - : 1123 12 1;!!'SA 17 'a 17-21 10-07 1 10 3T66 6Q�] 1T'!M '%•y�fat x�,]- 7Q 3131 01 ']�{ .. - •t A •1.� 3 IJ-SJ� y 116 fees ° u°' Irp.pfA , -- -I 137 } ,ralN Ih y'�f 36, ' ; 1 ' I I i T 650DOD 71
