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Home My WebLink About2014 Prudhoe Oil and Put River Oil Pools March 09, 2015 Ms. Cathy Foerster, Chair Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL and PUT RIVER OIL POOL - 2014 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, 2014. 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 Vivek Peraser at 564-5306, Vivek.Peraser@bp.com Sincerely, Katrina Garner Head of Base Management Alaska Reservoir Development, BPXA 564-4212 Attachments: Exhibits 1 through 12 Cc: H. Jamieson, ExxonMobil Alaska, Production Inc. K. Fishter, ExxonMobil Alaska, Production Inc. M. Agnew, ExxonMobil Alaska, Production Inc. E. Reinbold, CPAI J. Schultz, CPAI P. Ayer, Chevron USA D. Roby, AOGCC K. Smith, DNR S. Digert, BPXA J. Starck, BPXA J. Dean, BPXA E. Apolianto, BPXA R. Skillern, BPXA March 14, 2014 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 - 2013 Received by: ___________________________________________ ______________ Alaska Oil & Gas Conservation Commission Employee Date ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL AND PUT RIVER POOLS JANUARY THROUGH DECEMBER 2014 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 2 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 12 (includes previous section 4.6.2 used till 2007 report) 4.6.2 2015 Surveillance Plans 13 4.6.3 Plans for Change in Project Operation 13 4.7 Put River Pool 14 5.0 GAS MOVEMENT SURVEILLANCE 15 5.1 Gas Movement Summary 15 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 3 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 - 2014 12 Put River Lobe Map 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 4 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 2014. 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 2014 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. In response to the amendment of condition 5 of CO 547.004, an update on the Weatherford Gen- 2 meters in the Prudhoe Bay Unit will be provided in the Satellites surveillance report in September. 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 5 2.0 OVERVIEW Exhibit 1A identifies the five flood areas and gravity drainage areas in the Prudhoe Oil Pool as follows: FS-2, EPWZ, WPWZ, NWFB, EWE, and GD. The Waterflood Project encompasses all five flood areas. The Prudhoe Bay Miscible Gas Project (PBMGP) is currently active throughout the waterflood areas. The Eileen West End waterflood pilot concluded in March 1999, after successfully establishing EWE injection potential. EWE information since waterflood startup in September 2001 is included in this report. Exhibits 1-B and 1-C provide well, production, and injection statistics for the major project areas included in this report. As in last years’ report, wells do not share project boundaries, but belong to a single project area. The well counts therefore reflect the total number of wells actually contributing to production and injection. Similar to last year, only wells that actually produced or injected during the year are included. During the report period of January through December 2014, field production averaged 203.7 MBOD, 6930.8 MMSCFD (GOR 34,019 SCF/STB), and 899.6 MBWD (water-cut 81.5 %). Waterflood project injection during this period averaged 1453.4 MBWD with 160.72 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2014 was 12,228 MMSTB, while cumulative MI injection was 3,123 BCF. Cumulative production since waterflood startup was 2,932 MMSTB oil, 12,751 BCF gas, and 8,608 MMSTB water. As of December 31, 2014, cumulative production exceeded injection by 7,779 MMRB compared to 7,104 MMRB at the end of 2013. 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 2012 through 2014 at a datum of 8,800 ft, subsea for the Full Field Dominant Zone. Using the three year rolling technique improves the statistical validity of the pressure distribution since it roughly triples the number of data points employed versus only using the current year static pressures. As in the past, abnormal pressures, such as pressures taken in fault compartments and in the Sag Formation have been removed. As shown in Exhibit 1E, the historic pressure decline appears to have stabilized due to gas-cap water injection with 62% of repeat 2014 pressure surveys found equal to or greater than their 2012 or 2013 pressure measurements. For 2014, average pressure in the PBMGP project areas using three years of pressure static measurements was calculated to be 3,348.4 psia by areal weighting, as compared to 3,347.6 in 2013 (Exhibit 1F). The GD area pressure was stable decreasing six psi from 3,276 psia in 2013 to 3,270 in 2014. This subtle pressure decrease is within the expected statistical variation with a different annual pressure sampling data sets. Confirmed MI breakthrough has occurred in 119 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 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 6 average RMI rate over the number of producing days in a well exceeds 200 MCF/D. The previous year showed MI breakthrough in 85 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 2014 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 2014 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, as well as the pressure data acquired by SRT – Echometer, which were used for internal technical analysis and calibration purpose only. 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 2014 pressure map using 2012 through 2014 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 2015 calls for collection of 80 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 2014 is presented in Exhibit 9. 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 7 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 99 producing wells and 55 injection wells that contributed to production/injection during 2014 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 25.8 MBOD for 2014 compared to 21.7 MBOD in 2013. Cumulative production since waterflood start-up through the end of 2014 is 1,083 MMSTB of oil 5,692 BCF of gas, and 4,381 MMSTB of water. Injection rates averaged 473.3 MBWD and 49.03 MMSCFD in 2014. Since 12/31/11, the waterflood imbalance has increased from a cumulative under injection of 2,671 MMRB to 2,964 MMRB under injected. During the report period, production exceeded injection by 293 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 2014, is 6,435 MMSTB and 1,049 BCF respectively. The flood area's GOR decreased from an average of 23,851 SCF/STB in 2013 to an average of 23,300 SCF/STB in 2014. Gas influx continues along the FS-2/GD GDWFI area, and in the high permeability conglomerates in the Updip Victor area. Water-cut stayed the same, at 94%, from 2013 to 2014. A breakdown of the production and injection data is provided in Exhibit 3-B for the report period. See Exhibit 1-C for a comparison of the cumulative figures with last year’s AOGCC report. Exhibit 3-C presents the areal average waterflood pressure change over time. The pressure in the FS-2 area was 3402 psia in 2014. This is an increase of 11 psi over the 2013 pressure. Exhibit 3-D is a presentation of 2014 average returned MI (RMI) rates. Miscible gas return has been confirmed in 35 wells by gas compositional analysis (RMI>200 MSCFD). 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 8 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 2014, oil production averaged 17.3 MBOD, as compared to 17.8 MBOD in 2013, with an average 90% water cut and 22,179 SCF/STB Gas Oil Ratio. Injection averaged 166.6 MBWD and 27.39 MMSCFD of miscible injectant (MI). There are a total of 71 producers and 28 injectors in the flood area that contributed to production/injection during 2014. Of the 28 injectors, 4 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 640 MMSTB of oil, 3,329 BSCF of gas, and 1,714 MMSTB of water have been produced with 2213 MMSTB of water and 673 BSCF of miscible gas injected. Exhibit 4-B shows the monthly injected and produced volumes on a reservoir barrel basis during 2014 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 177 MMRB . Exhibit 4-C shows the trend of reservoir pressure change 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 3324 psia in 2014. This is a decrease of 10.6 psi as compared to 2013. Exhibit 4-D shows the 2014 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). 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 9 4.3 Western Peripheral Wedge Zone Water / MI Flood Project Exhibit 5-A is a map of the Western Peripheral Wedge Zone (WPWZ) water and miscible gas (MI) flood areas. During the report period oil production averaged 21 MBOD, as compared to 20.6 MBOD in 2013, with a gas/oil ratio of 13,616 SCF/STB and a watercut of 86%. Injection averaged 103.7 MBWD of water and 63.42 MMSCFD of miscible injectant. For the WPWZ project, 40 injectors (9 WAG injectors and 28 water injectors, 3 gas injectors), and 93 producers contributed to the production and injection during 2014. 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 2014 was 1,760 MMSTB while cumulative MI injection was 628 BSCF. Cumulative production since waterflood start-up is 530 MMSTB oil, 2,022 BSCF gas, and 1328 MMSTB water. As of December 31, 2014 cumulative production exceeded injection by 1353 MMRB. Exhibit 5-B provides the monthly injection and production data from 01/14 through 12/14. During the report period, production exceeded injection by 135 MMRB. The reservoir balance in Exhibit 5-B doesn’t identify support from the aquifer, thereby understating voidage replacement nor does it capture the production of gas-cap-gas which needs not be replaced. During 2006 a produced water tie- line was installed connecting two GC-1 slug catchers to GC-3 produced water tanks. This allowed up-dip Zone 4 waterflood expansion and should allow ideal voidage replacement in the eastern half of the WPWZ area. Exhibit 5-C shows that the pressure in the WPWZ was 3,314 psia in 2014. This is an increase of 0.5 psi over the pressure reported in 2013. Exhibit 5-D indicates wells with MI breakthrough and the 12-month averaged returned MI rates. Miscible gas breakthrough has been confirmed in 35 wells by gas compositional analysis. 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 10 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 7.6 MBOD, as compared to 9.6 MBOD in 2013, with a gas/oil ratio of 9,159 SCF/STB and a watercut of 87%. Injection averaged 42.1 MBWD and 5.0 MMSCFD of miscible injectant. For the NWFB project, 19 injectors (0 WAG injectors, 17 water injectors, and 2 gas injector), and 61 producers contributed to the production and injection during 2014. 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 2014 was 1,647 MMSTB while cumulative MI injection was 678 BCF as detailed in Exhibit 61-C. Cumulative production since waterflood start-up was 600 MMSTB oil, 1,382 BSCF gas, and 1019 MMSTB water. As of December 31, 2014 cumulative production exceeded injection by 559 MMRB. Exhibit 6-B provides the monthly injection and production data from 01/14 through 12/14. During the report period, production exceeded injection by 45 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 2014. 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 20 wells by gas compositional analysis. 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 11 4.5 Eileen West End Waterflood Project Exhibit 7-A is a map of the Eileen West End (EWE) waterflood area and miscible gas (MI) flood area. During the report period, oil production averaged 13.6 MBOD, as compared to 16.4 MBOD in 2013, with a gas/oil ratio of 2,857 SCF/STB and water cut of 69%. Injection averaged 43.3 MBWD and 14.2 MMSCFD of miscible gas injectant. For the EWE project, 16 injectors (5 WAG injectors, 9 water injectors and 2 gas injectors), and 60 producers contributed to the production and injection during 2014. The well counts reflect only the active wells for the year. Cumulative water injection from waterflood start-up in September 2001 through December 2014 was 176 MMSTB and cumulative MI injection was 96 BCF. Cumulative production since waterflood start-up was 79 MMSTB oil, 326 BCF gas, and 165 MMSTB water. As of December 31, 2014 cumulative production exceeded injection by 266 MMRB. Exhibit 7-B provides the monthly injection and production data from January 1, 2014 through December 31, 2014. During the report period, production exceeded injection by 24 MMRB. The EWE pressure was 3,652 psia in 2014 representing an average pressure decrease of 11 psi for this area from 2013. Exhibit 7-C indicates wells with MI breakthrough and the 12-month average returned MI rates. Miscible gas breakthrough has been confirmed in 10 wells by gas compositional analysis. 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 12 4.6 Gas Cap Water Injection Project Details of the volume of water injected into the Gas Cap during 2014 are shown below; units in thousands of barrels of seawater injected per month (MBWPM): PSI-01 PSI-05 PSI-06 PSI-07 PSI-08 PSI-09 PSI-10 Total 1/1/2014 2,294 2,150 2,177 2,178 2,198 2,235 2,206 15,438 2/1/2014 2,434 2,081 2,370 2,392 2,370 2,426 2,361 16,434 3/1/2014 1,378 824 974 1,032 882 867 901 6,858 4/1/2014 1,360 653 749 991 1,005 916 923 6,598 5/1/2014 1,272 972 874 1,210 1,168 1,253 1,178 7,927 6/1/2014 1,138 1,138 1,158 1,244 1,286 1,266 1,274 8,504 7/1/2014 2,671 2,415 2,600 2,605 2,637 2,597 2,519 18,044 8/1/2014 1,660 1,537 1,668 1,749 1,744 1,726 1,689 11,774 9/1/2014 1,228 985 1,041 1,167 1,143 1,100 1,103 7,767 10/1/2014 2,208 1,667 2,016 2,131 2,099 2,115 1,999 14,236 11/1/2014 2,975 2,874 2,953 2,977 2,960 2,968 2,792 20,499 12/1/2014 3,067 2,960 3,035 3,056 3,062 2,989 3,042 21,211 The 2014 volume of sea water injected in the PSI wells was 155.3 million barrels. The cumulative volume injected at the end of 2014 was 2.08 billion barrels of sea water since the project startup in 2002. The 2012 and 2013 reports had errors in cumulative volume injected. The cumulative volume injected at the end of 2012 was 1.76 billion barrels and the cumulative volume injected at the end of 2013 was 1.92 billion barrels. 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 red polygons indicate the interpreted current GCWI waterfront and the blue outline shows the 2013 interpretation for comparison. The information from the RST logging program was also used to develop the updated west-east and north-south cross sections (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: 04-10, 04-17, 04- 20, 05-28B, 11-08, 11-24A, 11-37, 15-07C, 18-08B, 18-15C, and L3-19. 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 in some areas and has noticeably increased in other areas (south and west). At this point, the changes in the waterfront have followed a relatively predictable pattern established in recent surveillance, where the largest extent of incremental waterfront coverage appeared in Zone 2C, as well as significant advancement to the south and west in Zone 1. The 2014 logs indicated the largest lateral extent of GCWI water front in Zone 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 13 2C, variable interpreted lateral extents and flood migration directions per zone most likely attributed to local geologic structure and shale continuity, and water column thickness increase in Zone 3 to the southeast. There is lateral movement of water seen to west near the gas injectors and southwest to southeast of the PSI wells. The RST log in the 15-07C well, located south/southeast of the NGI gas injectors, showed possible water for the first time in 2011 and continued to be interpreted as such in 2012 and 2013. However, recent surveillance in 15-07C in 2014 suggests it may be oil instead and a clear interpretation is difficult. Regardless, a possible water front in the west may be occluded from a more northerly migration due to the updip of the local geologic structure and potentially sealing faults. There has been no impact on the gas injection rates of the wells closest to GCWI wells. Understanding this area may be significantly improved by future observation wells closer to the gas injection wells. Lateral movement to the southwest is most apparent in Zones 1, 2A, and 2B. The fault orientation and potential fault transmissivity may be contributing to the increased rate of movement to the southwest. Water has continued to build to the south and southeast in DS-11 and DS-04, primarily in Zone 2C and Zone 3, as per the respective observation wells although the distinction between GCWI and local waterflood injection should be made in this area. The 2014 RST surveillance continues to support the interpretation of the 24N shale, which forms the base of Zone 2C, as clearly the most prominent unit controlling the lateral progression of the flood front. However, gas cap water has been produced from several wells in Zone 1 on DS-18 pad and in 11-28B, as indicated on the GCWI Zones 1A/1B map, which indicates that the water is potentially transmissible through the closest faults and draining down section where the 24N shale is not present. In general, the flood front continues to maintain a south-faced sloped aspect down the geologic structure indicating that gravity has a strong influence on the process. 4.6.2 2015 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 2015. 4.6.3 Plans for Change in Project Operation No changes to the Gas Cap Water Injection operation are planned for 2015. 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 14 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. 2014 Production and Injection For the year 2014, all of the production and injection in the Put River Pool occurred in the Southern Lobe. Production from the Put River Oil Pool in 2014 averaged 1051 BOPD for the days the reservoir was in production and 988 BOPD averaged across calendar days. The total production of the Put River Pool comes from two Put River producers, well 02-23A and 02-27A. 02-14A was planned to be worked over in 2014 and had potential perforations in the Put River but well value did not justify a workover and a non-rig fix was pursued to restore tubing integrity. The well returned to production in April 2014 but tubing integrity issues resurfaced in September 2014 and the well has been shut in since then. 02-14A is currently being re-evaluated to see if there is enough value for a stand-alone workover. If it does not have enough value, it will be worked over and then sidetracked. In both cases a sliding sleeve will be placed over potential Put River perforations to allow future access. Those perforations will be accessed if 02- 23A or 02-27A fails. Injection in the Southern Lobe of the Put River averaged 6,635 BWPD for the days the injector was online and 6,308 BWPD averaged across calendar days. Cumulative Put River water injection was 9.82 MMBW through 2014, of which 2.3 MMBW was injected in 2014. The 2014 cumulative production for the Put River Oil Pool was 360 MBO, 2,277 MBW and 213 MSCF gas. The full life cumulative production for the Put River Oil Pool through December 31, 2014 was 3.12 MMBO and 3.73 MMSCF gas. 2014 Pressures Put River Pressures taken during 2014 are listed in Exhibit 9. The Southern Lobe pressure obtained in 01-08A injector in December 2014 measured 3631 PSI at 8100’ SSTVD. No tracer breakthrough was observed in 2012, 2013, or 2014 but reservoir connection is evident through pressures. 2015 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. If one of these wells fails, 02-14A Put River perforations will be added. Static pressures will be taken periodically through the year to confirm volumetric calculations. Western Lobe - No 2015 production or surveillance planned. Central Lobe - No 2015 production or surveillance planned. 2014 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 15 5.0 GAS MOVEMENT SURVEILLANCE The report on gas movement surveillance activities and interpretations provides an overall summary of gas influx movement and summarizes the 2014 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 2014 through December 2014. A total of 98 gas-monitoring logs were run in the PBU of which 80 were cased-hole. Exhibit 1-B2014 PBU Well StatisticsWELL COUNT BY FIELD AREAWPWZNWFBEWEFS2EPWZGD2013 AOGCC ReportProducers93 63 68 100 71 434Injectors42 21 17 56 30 52 -WAG1113431 -Water Only31 19 12 51 26 19 -Gas01211322014Producers93 61 60 99 71 449Injectors40 19 16 55 28 50 -WAG905430 -Water Only28 179 51 24 20 -Gas3220130Production Well Status in 2014 -Newly Drilled000003 -Sidetracked or Redrilled3122125Gas Injection Well Status in 2014 -Newly Drilled000000 -Sidetracked or Redrilled100000WAG Injection Well Status in 2014 -Newly Drilled000000 -Sidetracked or Redrilled000000Water Injection Well Status in 2014 -Newly Drilled000000 -Sidetracked or Redrilled000002NOTES:(1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year(2) Project boundaries were simplified in 1998. Wells no longer share project boundaries, but belong to a single project area. (3) EOA GD and WOA GD have been combined. Exhibit 1-C2014 PBU Production/Injection StatisticsWaterflood TotalWPWZNWFBFS-2EPWZEWECumulative Production from WF Start-Up through 12/31/14Oil (MMSTB)530 600 1083 640 79 2932Gas (BCF)2022 1382 5692 3329 32612751Water (MMSTB)1328 1019 4381 1714 1658608Cumulative Injection from WF Start-Up through 12/31/14Water (MMSTB)1760 1647 6435 2213 173 12228MI (BCF)628678 1049 673963123Cumulative Balance from WF Start-Up through 12/31/13Cum Production (MMRB)3419 2577 9785 5140 46721388Cum Injection (MMRB)2201 2063 7113 2681 22614284Over/Under (MMRB)-1218 -514 -2671 -2459 -242-7104Cumulative Balance from WF Start-Up through 12/31/14Cum Production (MMRB)3564 2621 10126 5327 49422133Cum Injection (MMRB)2211 2062 7162 2691 22814354Over/Under (MMRB)-1353 -559 -2964 -2636 -266-7779MI Breakthrough in Producing Wells> 200 mcfd3520351910119AVERAGE RATE DATA 2014ProductionOil (MBD)21.07.6 25.8 17.3 13.685.3Gas (MMSCFD)286.2 69.8 601.2 384.5 38.71380.3Water (MBD)132.1 50.3 386.5 161.0 30.1759.9InjectionWater (MBD)103.7 42.1 473.5 166.6 43.3829.2Gas (MMSCFD)63.45.0 49.0 27.4 14.2159.0AVERAGE RESERVOIR PRESSURE (psia)GDWPWZNWFBFS-2EPWZEWEPBMGPPrevious report period: 20133276 3313 3329 3391 3335 36633348Current report period: 20143270 3314 3322 3402 3324 36523348Estimated Annual Change (psi/yr)-61-711-11-110Waterflood Project Area 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 3345 3308 3322 3265 3640 3338 Jul-12 3375 3338 3350 3302 3283 3632 3348 Jul-13 3391 3335 3313 3329 3276 3663 3348 Exhibit 1-G2014 Average Monthly CGF MI Rates and CompositionsEOA MI Rate *MMP MWMCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/14 96,144 3,294 32.07 20.77% 33.04% 20.58% 24.58% 0.80% 0.23% 0.00%02/14 96,513 3,307 33.12 21.23% 34.61% 21.19% 25.47% 0.87% 0.20% 0.00%03/14 96,670 3,310 31.83 19.84% 33.75% 20.81% 24.63% 0.80% 0.18% 0.00%04/14 106,119 3,227 32.32 21.04% 31.95% 20.95% 25.04% 0.82% 0.21% 0.00%05/14 109,490 3,153 32.41 20.17% 31.88% 21.06% 25.26% 1.14% 0.48% 0.00%06/14 84,261 3,124 32.05 17.78% 33.54% 20.77% 25.81% 1.39% 0.71% 0.00%07/14 30,000 3,346 31.93 20.51% 34.78% 18.72% 24.34% 1.18% 0.48% 0.00%08/14 56,677 3,228 32.41 20.87% 33.40% 19.05% 24.04% 1.46% 1.18% 0.00%09/14 79,464 3,097 32.75 20.25% 32.41% 19.85% 23.56% 1.73% 2.20% 0.00%10/14 78,783 3,144 32.56 20.19% 32.82% 19.86% 23.74% 2.25% 1.15% 0.00%11/14 107,013 3,225 32.16 19.55% 34.09% 19.71% 23.73% 1.94% 0.98% 0.00%12/14 77,198 3,210 31.32 19.76% 32.12% 19.31% 22.82% 1.94% 0.82% 0.00%Average 84,663 3,222 32.23 20.16% 33.19% 20.14% 24.41% 1.36% 0.74% 0.00%WOAMI Rate *MMP MWMCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/14 118,944 3,320 31.96 20.62% 33.45% 20.49% 24.42% 0.79% 0.22% 0.00%02/14 114,754 3,300 31.97 20.33% 33.49% 20.52% 24.46% 0.85% 0.36% 0.00%03/14 118,394 3,323 31.78 19.81% 33.96% 20.72% 24.53% 0.82% 0.17% 0.00%04/14 141,779 3,224 32.14 20.13% 32.45% 21.21% 25.17% 0.82% 0.21% 0.00%05/14 129,057 3,169 32.28 19.77% 32.33% 21.10% 25.16% 1.16% 0.47% 0.00%06/14 109,435 3,115 32.07 17.80% 33.19% 21.39% 25.45% 1.44% 0.74% 0.00%07/14 51,600 3,280 31.65 18.48% 34.11% 21.72% 24.35% 1.00% 0.35% 0.00%08/14 40,662 3,203 31.92 18.40% 33.63% 21.70% 23.98% 1.31% 0.99% 0.00%09/14 117,615 3,133 32.22 18.18% 34.19% 20.14% 23.47% 1.86% 2.16% 0.00%10/14 150,735 3,149 32.29 18.88% 33.76% 20.13% 23.61% 2.36% 1.26% 0.00%11/14 149,579 3,189 32.39 20.16% 33.24% 19.80% 23.83% 1.97% 0.99% 0.00%12/14 134,541 3,185 33.47 20.99% 33.90% 20.96% 24.38% 2.10% 0.90% 0.00%Average 114,595 3,216 32.18 19.46% 33.48% 20.83% 24.40% 1.38% 0.73% 0.00%Average Monthly Mole%Average Monthly Mole% Exhibit 2Fieldwide Reservoir BalanceJanuary - December 2014Produced Fluids (MMRB)JanuaryFebruaryMarchApril MayJuneOil 9.9 8.2 9.3 9.0 8.7 8.3Free Gas 216.0 189.0 209.4 198.6 179.9 179.3Water 34.5 28.8 32.5 30.7 32.5 32.0TOTAL 260.3 226.0 251.1 238.3 221.1 219.6Injected Fluids(MMRB)Water 48.8 45.9 39.1 37.6 40.1 40.4Gas 209.5 183.6 204.9 193.1 175.2 175.1TOTAL 258.3 229.5 244.0 230.7 215.3 215.5Net Injection Volumes = Injection - Production (MMRB)TOTAL-2.0 3.5 -7.2 -7.6 -5.8 -4.1Produced Fluids1/1/2014 -(MMRB)JulyAugust September October November December 12/31/2014Oil 5.6 5.2 7.4 8.8 8.7 9.0 98.2Free Gas 122.2 118.8 178.4 169.9 201.5 209.3 2,172.3Water 19.9 20.6 20.3 30.2 30.0 30.4 342.4TOTAL 147.7 144.7 206.1 209.0 240.2 248.7 2,612.8Injected Fluids(MMRB)Water 38.7 33.9 27.8 44.0 51.4 53.0 500.9Gas 118.2 115.4 175.9 188.8 195.5 204.3 2,139.5TOTAL 156.9 149.3 203.7 232.9 246.9 257.3 2,640.4Net Injection Volumes = Injection - Production (MMRB)TOTAL9.2 4.5 -2.4 23.9 6.7 8.6 27.5 Exhibit 3-BFS-2 Reservoir BalanceProduced Fluids Cumulative(MMRB)12/31/2013 January February March April May JuneFluid Properties Used Oil 1,409.2 1.188 1.092 1.218 1.184 1.206 1.155 Bo (rb/stb) 1.324Free Gas 3,984.2 16.219 15.742 17.452 17.246 17.552 16.019 Bg (rb/mscf) 0.862Water 4,391.3 14.621 13.250 14.459 13.436 14.321 14.602 *Bw (rb/stb) 1.040TOTAL 9,784.7 32.028 30.084 33.129 31.867 33.079 31.775 Bmi (rb/mscf) 0.700Rs (scf/stb) 620.8Injected Fluids(MMRB)Water 6,287.9 17.817 15.726 17.655 17.065 16.968 17.290Gas 681.7 1.200 0.826 1.157 1.230 1.068 1.038TOTAL 6,969.7 19.017 16.552 18.812 18.295 18.037 18.328Net Injection Volumes = Injection - Production (MMRB)TOTAL-2,526.2 -13.0 -13.5 -14.3 -13.6 -15.0 -13.4Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2014Oil 0.727 0.850 0.725 1.049 1.061 1.012 1,421.7Free Gas 11.083 11.953 13.626 13.843 16.193 15.339 4,166.4Water 8.479 10.784 6.150 11.779 12.593 12.239 4,538.0TOTAL 20.290 23.587 20.501 26.671 29.847 28.590 10,126.1Injected Fluids(MMRB)Water 10.106 13.448 7.256 14.103 16.153 16.140 6,467.6Gas 0.617 0.380 1.209 1.378 1.234 1.189 694.2TOTAL 10.723 13.828 8.465 15.481 17.387 17.328 7,161.9Net Injection Volumes = Injection - Production (MMRB)TOTAL-9.6 -9.8 -12.0 -11.2 -12.5 -11.3 -2,964.2 Exhibit 4-BEPWZ Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2013 January February March April May JuneOil 833.4 0.797 0.727 0.897 0.880 0.854 0.728 Bo (rb/stb) 1.321Free Gas 2,404.0 11.148 10.858 12.506 11.889 12.298 11.126 Bg (rb/mscf) 0.872Water 1,902.8 6.150 5.416 6.373 5.798 6.283 5.570 Bw (rb/stb) 1.040TOTAL 5,140.2 18.095 17.001 19.776 18.567 19.434 17.423 Bmi (rb/mscf) 0.700Rs (scf/stb) 614.0Injected Fluids(MMRB)Water 2,187.0 5.291 5.687 5.607 5.075 5.451 5.560Gas 433.9 0.757 1.157 1.107 0.563 0.761 0.772TOTAL 2,621.1 6.048 6.844 6.714 5.638 6.211 6.333Net Injection Volumes = Injection - Production (MMRB)TOTAL-2333.3 -12.0 -10.2 -13.1 -12.9 -13.2 -11.1Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2014Oil 0.393 0.550 0.530 0.672 0.622 0.708 841.8Free Gas 4.627 6.154 8.252 8.205 9.359 11.369 2,521.8Water 2.828 3.827 3.915 5.209 4.789 4.955 1,963.9TOTAL 7.848 10.531 12.697 14.087 14.771 17.032 5,327.5Injected Fluids(MMRB)Water 2.718 3.592 5.300 6.550 6.219 6.193 2,250.3Gas 0.158 0.171 0.397 0.467 0.288 0.399 440.9TOTAL 2.876 3.763 5.698 7.017 6.507 6.592 2,691.3Net Injection Volumes = Injection - Production (MMRB)TOTAL-5.0 -6.8 -7.0 -7.1 -8.3 -10.4 -2636.2Fluid Properties Used Exhibit 5-BWPWZ Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2013 JanuaryFebruaryMarchApril MayJuneOil 694.1 0.890 0.731 0.924 0.874 1.002 0.827 Bo (rb/stb) 1.322Free Gas 1,393.0 7.957 7.006 8.602 7.536 7.220 6.378 Bg (rb/mscf) 0.869Water 1,331.5 5.017 3.542 4.231 4.039 4.716 3.527 Bw (rb/stb) 1.040TOTAL 3,418.6 13.863 11.279 13.756 12.449 12.938 10.732 Bmi (rb/mscf) 0.700Rs (scf/stb) 616.2Injected Fluids(MMRB)Water 1,752.4 3.560 3.012 3.259 3.518 3.820 2.667Gas 403.2 1.416 1.419 1.323 1.327 1.521 1.070TOTAL 2,155.7 4.977 4.431 4.581 4.845 5.341 3.736Net Injection Volumes = Injection - Production (MMRB)TOTAL-1109.2 -8.9 -6.8 -9.2 -7.6 -7.6 -7.0Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2014Oil 0.655 0.437 0.875 1.012 0.985 0.930 704.3Free Gas 4.590 3.437 7.467 7.734 8.727 8.822 1,478.4Water 3.191 2.711 4.519 4.865 4.684 5.114 1,381.7TOTAL 8.436 6.586 12.861 13.611 14.396 14.867 3,564.4Injected Fluids(MMRB)Water 3.109 2.777 2.997 3.473 3.383 3.783 1,791.8Gas 0.689 0.865 1.912 1.776 1.620 1.267 419.4TOTAL 3.798 3.642 4.909 5.248 5.003 5.050 2,211.2Net Injection Volumes = Injection - Production (MMRB)TOTAL-4.6 -2.9 -8.0 -8.4 -9.4 -9.8 -1353.1Fluid Properties Used Exhibit 6-BNWFB Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2013 JanuaryFebruaryMarchApril MayJuneOil 751.1 0.446 0.255 0.313 0.336 0.303 0.443 Bo (rb/stb) 1.318Free Gas 831.7 2.862 1.049 1.647 1.858 1.102 2.711 Bg (rb/mscf) 0.882Water 994.0 2.093 1.283 1.568 1.752 1.578 2.335 Bw (rb/stb) 1.040TOTAL 2,576.9 5.401 2.587 3.527 3.946 2.982 5.489 Bmi (rb/mscf) 0.700Rs (scf/stb) 607.3Injected Fluids(MMRB)Water 1,594.5 2.085 0.823 1.197 1.625 1.695 1.880Gas 425.1 0.095 0.000 0.042 0.141 0.210 0.293TOTAL 2,044.8 2.180 0.823 1.239 1.766 1.905 2.173Net Injection Volumes = Injection - Production (MMRB)TOTAL-479.2 -3.2 -1.8 -2.3 -2.2 -1.1 -3.3Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2014Oil 0.219 0.018 0.234 0.452 0.370 0.279 754.8Free Gas 1.313 0.069 1.298 2.465 3.571 1.634 853.3Water 1.159 0.056 1.130 2.572 1.862 1.695 1,013.1TOTAL 2.691 0.142 2.662 5.488 5.803 3.608 2,621.2Injected Fluids(MMRB)Water 1.126 0.169 0.855 1.597 1.341 1.596 1,608.8Gas 0.037 0.000 0.088 0.160 0.124 0.086 426.3TOTAL 1.163 0.169 0.943 1.757 1.465 1.682 2,062.0Net Injection Volumes = Injection - Production (MMRB)TOTAL-1.5 0.0 -1.7 -3.7 -4.3 -1.9 -559.2Fluid Properties Exhibit 7-BEWE Reservoir BalanceProduced FluidsCumulative(MMRB)12/31/2013 JanuaryFebruaryMarchApril MayJuneOil 98.2 0.772 0.561 0.640 0.626 0.685 0.639 Bo (rb/stb) 1.344Free Gas 209.9 0.965 0.721 0.954 0.793 0.727 0.792 Bg (rb/mscf) 0.800Water 159.3 1.125 0.670 0.998 1.124 1.209 1.222 Bw (rb/stb) 1.040TOTAL 467.4 2.863 1.952 2.592 2.543 2.621 2.653 Bmi (rb/mscf) 0.700Rs (scf/stb) 667.8Injected Fluids(MMRB)Water 137.1 1.550 1.591 1.852 1.438 1.724 2.040Gas 58.4 0.289 0.256 0.491 0.299 0.199 0.279TOTAL 207.8 1.839 1.847 2.343 1.737 1.923 2.319Net Injection Volumes = Injection - Production (MMRB)TOTAL-227.7 -1.0 -0.1 -0.2 -0.8 -0.7 -0.3Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2014Oil 0.325 0.000 0.458 0.643 0.630 0.668 104.9Free Gas 0.470 0.000 0.696 0.663 0.758 0.957 218.4Water 0.640 0.000 1.019 1.286 0.996 1.119 170.7TOTAL 1.435 0.000 2.174 2.592 2.385 2.744 493.9Injected Fluids(MMRB)Water 1.110 0.232 1.199 1.595 1.202 0.921 151.8Gas 0.064 0.000 0.154 0.538 0.525 0.534 62.0TOTAL 1.174 0.232 1.353 2.133 1.726 1.454 227.9Net Injection Volumes = Injection - Production (MMRB)TOTAL-0.3 0.2 -0.8 -0.5 -0.7 -1.3 -266.0Fluid Properties Used Exhibit 8 2014 Wells Surveyed for Gas Movement # Well Log Date OH / CH GOC (MD) GOC (TVDSS) # Well Log Date OH / CH GOC (MD) GOC (TVDSS) 1 01‐15B 15‐Oct‐14 CH 9,160 8,845 1 02‐01C 6‐Mar‐14 CH 9327.4 8848 2 01‐19C 15‐Feb‐14 CH 10,628 8,945 2 02‐08B 7‐May‐14 CH 9988 8891 3 02-07B 8-Jul-14 CH 11,300 8,962 3 02‐11A 16‐Apr‐14 CH 12406.3 8993.2 4 02-09D 7-Jun-14 CH 10,389 8,846 4 03‐29 13‐Jan‐14 CH Not present over logged interval 5 02‐18C 23‐Apr‐14 CH 5 04‐10 8‐Jul‐14 CH 8,767.8 8,531.5 6 02‐32C 6‐Nov‐14 CH 10,385 8,810 6 04‐17 12‐Sep‐14 CH 9,480.1 8,508.2 7 03‐33C 6‐May‐14 CH 7 05‐19 7‐Apr‐14 CH 9819.5 8832 8 06-01A 26-May-14 CH 9,909 8,983 8 05‐28B 2‐May‐14 CH 12,361.3 8,712.3 9 06-03B 7-May-14 CH 9 06‐16A 28‐Nov‐14 CH 9,684.7 8,820.7 10 09-47A 2-Apr-14 CH Not present over logged interval 10 06‐19A 4‐Jun‐14 CH 9,104 8,833 11 11-39 28-Oct-14 OH 15,639 8,580 11 06‐21B 5‐Jun‐14 CH 9,418 8,796 12 11-39PB1 27-Oct-14 OH 12,587 8,643 12 07‐08B 3‐Feb‐14 CH 9,828 8,919 13 14-22B 29-Sep-14 OH Not present over logged interval 13 07‐14C 9‐Jul‐14 CH 11,553 8,945 14 15-28B 25-Nov-14 CH 11,051 8,745 14 07‐20B 6‐Feb‐14 CH 10,455.4 8,849.5 15 15-45C 6-Jan-14 CH 11,982 8,700 15 07‐24 18‐Oct‐14 CH 11,001.5 8,823.7 16 18-04D 29-May-14 CH 12,612 8,736 16 09‐28A 7‐Jul‐14 CH Not present over logged interval 17 A-45 22-Feb-14 CH 9,347 8,675 17 09‐35A 22‐Aug‐14 CH 9,594.8 8,607.7 18 B-19B 3-Apr-14 OH Not present over logged interval 18 11‐16 4‐May‐14 CH 11,738 8,563.5 19 B-26C 7-May-14 OH Not present over logged interval 19 11-17A 9-May-14 CH 10,255 8,629.5 20 C-16C 21-Jul-14 CH 10,311 8,945 20 11‐24A 17‐Sep‐14 CH 9,144.9 8,573.1 21 C-19C 3-May-14 OH 12,230 8,909 21 11‐37 29‐Oct‐14 CH 8,737.3 8,573 22 C-29C 9-Jun-14 OH 12,625 8,954 22 14‐03A 19‐Aug‐14 CH 11,434 8,911 23 D‐14B 13‐Sep‐14 CH 9743 8902 23 14-19 28-Oct-14 CH 9,868.4 8,758.4 24 D‐30C 26‐Aug‐14 CH 10,047 8,942 24 14-32 26-Apr-14 CH 10,340 8,752.6 25 E-05C 21-Nov-14 CH 12,260 9,020 25 14‐43 28‐Nov‐14 CH 9263.6 8758.4 26 E-34A 9-Nov-14 CH 9,983 9,003 26 15-02B 6-Jan-14 CH 10,780 8,895 27 E‐36B 11‐Jul‐14 CH 9,757 8,975 27 15‐07C 25‐Aug‐14 CH 12,180 8,635.7 28 F-28C 8-Dec-14 CH 9,265 8,976 28 18‐08B 12‐Jul‐14 CH 10,094.3 8,634.9 29 F-41A 21-Dec-14 CH 12,382 8,897 29 18‐15C 2‐Nov‐14 CH 9,206 8,582.8 30 G-01B 4-Oct-14 CH 9,856 8,893 30 18-30A 17-May-14 CH 13,387 8,749 31 G-15C 18-Oct-14 CH 10,232 8,923 31 B‐09 20‐Oct‐14 CH 9,790 8,697 32 G-18B 14-Aug-14 OH 10,707 8,910 32 B-14A 27-Jul-14 CH 11,866 8,842 33 H-09A 4-Aug-14 OH Not present over logged interval 33 B‐20A 25-May-14 CH Not present over logged interval 34 H-19C 3-Jun-14 OH Not present over logged interval 34 B‐23A 27-Jul-14 CH 10,216 8,818 35 H-28A 13-Sep-14 CH 11,957 8,918 35 B-29A 23-Aug-14 CH 9,820 8,779 36 H‐35A 26-Jul-14 CH 8,990 8,843 36 C-17B 3-Jun-14 CH 11,030.5 8,846 37 K‐21 17-Jul-14 OH 11,337 8,890 37 C‐32D 10‐Oct‐14 CH 10,333.5 8,928 38 R‐17B 10-Apr-14 OH Not present over logged interval 38 D-10 6-Dec-14 CH 10,873.5 8,829.5 39 S‐09A 26-Dec-14 OH Not present over logged interval 39 E‐08A 24‐May‐14 CH 10,170.5 8,964 40 S‐13A 25-Oct-14 OH Not present over logged interval 40 F-03A 22-Jun-14 CH 10,885 8,747 41 X-04A 4-Mar-14 OH 11,794 8,763 41 G-24A 31-Jul-14 CH 42 Y-01C 25-Sep-14 CH 12,490 8,790 42 H-07A 6-Jun-14 CH 10,704 8,829.5 43 Y-14C 29-Dec-14 OH Not present over logged interval 43 H-18 17-Mar-14 CH 9,421.5 8,829 44 Y-39 21-Aug-14 OH Not present over logged interval 44 H‐21 2‐Jul‐14 CH 9,450 8,694 45 Y-39PB1 20-Jul-14 OH Not present over logged interval 45 J‐02B 1‐Oct‐14 CH 10,272 8,939 46 J‐19 9‐Apr‐14 CH 9,930.5 8,861 47 J-20C 12-Jun-14 CH 11,207 8,939.5 48 N-07A 18-Nov-14 CH 10,484.5 8,834 49 R-12A 30-Nov-14 CH 10,777 8,714 50 R-14B 12-Sep-14 CH 13,783 8,711 51 W-40 29-May-14 CH Not present over logged interval 52 X-15A 11-Apr-14 CH 10,438 8,753 53 X-16A 13-Feb-14 CH 10,508 8,764.5 OH ‐ Open Hole Log CH ‐ Cased Hole Log 2014 Drilling 2014 Surveillance Log inconclusive Poor quality data Log inconclusive Poor quality data Exhibit 92014 PrudhoeRESERVIOR PRESSURE REPORT1. Operator:2. Address:BP Exploration (Alaska) Inc.P.O. Box 196612, 900 E. Benson Blvd., Anchorage, AK 99519-66123. Unit or Lease Name:6. Oil Gravity:Prudhoe Bay Unit0.9 SG/27° API8. Well Name and Number:9. API Number 50XXXXXXXXXXXX NO DASHES10. Type See Instructions11. AOGCC Pool Code12. Zone 13. Perforated Intervals Top - Bottom TVDSS14. Final Test Date15. Shut-In Time, Hours16. Press. Surv. Type (see instructions for codes)17. B.H. Temp.18. Depth Tool TVDSS19. Final Observed Pressure at Tool Depth20. Datum TVDSS (input)21. Pressure Gradient, psi/ft.22. Pressure at Datum (cal)01-15A 500292028701 O6401509001-9005, 9015-9018, 9015-9024, 9018-9024, 9030-9033, 9054-90562/22/14 13,863.SBHP194.2 8,800.49 3,253.58,8004.E-01 3,253.301-15A 500292028701 O6401509001-9005, 9015-9018, 9015-9024, 9018-9024, 9030-9033, 9054-90563/26/14 14,631.SBHP192.7 8,811.62 3,278.28,8004.E-01 3,273.802-32B 500292220902 O6401508905-8922, 8922-89155/2/14 1,088.SBHP190.2 8,800.04 3,287.38,8008.E-02 3,287.303-07A 500292022001 GI6401509046-9047, 9047-9047, 9048-9048, 9048-9049, 9049-9048, 9049-9049, 9049-9050, 9051-9052, 9052-9049, 9052-9052, 90529053, 9053-9054, 9054-905410/23/14 ########SBHP172.8 8,599.68 3,258.68,8003.E-01 3,329.1903-16A 500292041501 WI6401508731-8738, 8745-8752, 8776-8786, 8786-8793, 8810-8828, 8848-8866, 8866-8882, 8983-8980, 8987-8986, 9018-9019, 90199016, 9033-9028, 9035-9040, 9040-9044, 9048-905110/15/14 203.SBHP140.8 8,770.51 3,683.48,8005.E-01 3,696.5503-24A 500292101501 O6401508853-8873, 8883-88904/24/14 2,805.SBHP134.7 6,500.27 2,996.38,8009.E-02 3,226.03-31 500292112900 O6401508626-8649, 8720-8739, 8753-8775, 8753-8816, 8775-8789, 8775-8816, 8789-8811, 8789-8816, 8811-8816, 8842-8849, 88598866, 8872-8879, 8889-8892, 8892-8897, 9018-9022, 9027-904010/3/14 721.47SBHP189.8 8,600.16 3,290.38,8003.E-01 3,356.2303-31 500292112900 O6401508626-8649, 8720-8739, 8753-8775, 8753-8816, 8775-8789, 8775-8816, 8789-8811, 8789-8816, 8811-8816, 8842-8849, 88598866, 8872-8879, 8889-8892, 8892-8897, 9018-9022, 9027-904010/3/14 721.SBHP189.4 8,650.17 3,306.88,8003.E-01 3,356.203-36A 500292234001 WI6401509043-9043, 9043-9044, 9046-9046, 9046-9047, 9047-9045, 9047-90473/11/14 852.5SBHP172.6 8,900.13 3,355.58,8004.E-01 3,318.703-36A 500292234001 WI6401509043-9043, 9043-9044, 9046-9046, 9046-9047, 9047-9045, 9047-90473/11/14 852.5SBHP177.7 8,800.22 3,318.88,8004.E-01 3,318.703-36A 500292234001 WI6401509043-9043, 9043-9044, 9046-9046, 9046-9047, 9047-9045, 9047-90473/11/14 852.5SBHP176.5 8,700.25 3,283.48,8004.E-01 3,318.703-36A 500292234001 WI6401509043-9043, 9043-9044, 9046-9046, 9046-9047, 9047-9045, 9047-90473/11/14 850.5SBHP171.7 8,600.15 3,249.58,8004.E-01 3,318.704-05A 500292010701 O6401508634-8637, 8648-8652, 8690-8693, 8771-8799, 8799-8808, 8799-8817, 8808-8817, 8817-8827, 8827-883212/22/14 696.SBHP170.03 8,599.63 3,297.028,8003.E-01 3,358.104-35A 500292214701 O6401508615-8621, 8628-8636, 8655-8660, 8662-8661, 8666-8692, 8686-867811/25/14 33,989.SBHP175.8 8,599.96 3,262.28,8004.E-01 3,339.704-38 500292221000 O6401508574-8588, 8605-8617, 8617-8630, 8687-8694, 8707-8709, 8726-8736, 8849-8859, 8849-8863, 8859-8863, 8866-8873, 8877-888710/7/14 5,002.SBHP172.7 8,650.49 3,301.38,8004.E-01 3,355.9405-16C 500292026204 O6401508808-8813, 8813-8819, 8823-88312/25/14 334.SBHP176. 8,416.54 3,050.8,8000.313,196.105-16C 500292026204 O6401508808-8813, 8813-8819, 8823-88312/25/14 333.SBHP178. 8,637.36 3,118.8,8003.E-01 3,169.105-16C 500292026204 O6401508808-8813, 8813-8819, 8823-88312/25/14 334.SBHP176. 8,493.19 3,074.8,8000.313,196.105-16C 500292026204 O6401508808-8813, 8813-8819, 8823-88312/25/14 333.SBHP178. 8,559.17 3,094.8,8000.313,169.106-01500292017200 O6401508908-8949, 8908-8958, 8949-8958, 8973-8995, 9004-9014, 9004-9030, 9014-9015, 9014-9030, 9015-9024, 9024-9027, 90249030, 9027-9030, 9030-9032, 9032-90502/11/14 136.SBHP195.4 8,799.73 3,271.68,8001.E-01 3,271.606-02B 500292028202 O6401509012-90217/19/14 205.SBHP199. 8,600.11 3,272.8,8007.E-02 3,286.06-03A 500292018601 O6401508979-8982, 9018-9019, 9030-9032, 9032-90401/30/14 11,743.SBHP195.9 8,799.79 3,236.98,8003.E-01 3,237.06-12B 500292045602 O6401508775-8776, 8776-87738/16/14 868.SBHP211. 8,699.41 2,998.8,8000.44 3,042.307-03A 500292029101 O6401508885-8891, 8891-8894, 8906-8907, 8947-8952, 8998-9000, 8999-899810/9/14 633.SBHP205.5 8,800.01 3,271.58,8000.33 3,271.507-08B 500292029602 O6401509022-9024, 9026-90268/31/14 2,690.SBHP194.8 8,799.91 3,212.48,8000.32 3,212.407-33B 500292180902 O6401508893-8905, 8911-8922, 8929-8940, 8951-8953, 8957-8951, 8967-8967, 8968-8973, 8969-8968, 8976-8969, 8976-8979, 8979-89782/16/14 1,113.46SBHP188. 8,800.03 3,280.8,8000.08 3,280.09-02 500292019800 O6401508788-8801, 8807-8811, 8807-8823, 8807-8852, 8811-8823, 8823-8827, 8823-8852, 8827-8828, 8827-8852, 8828-8836, 88368852, 8867-8880, 8867-8906, 8880-8891, 8880-8906, 8891-8899, 8899-8906, 8919-8920, 8920-8926, 8920-8939, 8926-8939, 8951-8959, 8963-8974, 8982-8990, 9016-9023, 9034-90416/2/14 3,798.SBHP189.1 8,799.98 3,327.78,8000.29 3,327.709-03 500292020900 O6401508690-8699, 8699-8714, 8714-8742, 8742-8747, 8757-8759, 8768-8770, 8785-8786, 8786-8796, 8796-8798, 8812-8820, 88128850, 8820-8840, 8820-8850, 8840-8841, 8840-8850, 8841-8850, 8851-8854, 8854-8873, 8898-8944, 8969-8980, 8987-8992, 9000-90047/31/14 9,390.SBHP181.7 8,490.28 3,203.48,8000.44 3,338.409-15A 500292025601 GI6401508737-8736, 8737-8737, 8745-8744, 8745-8745, 8746-8745, 8747-8746, 8748-8747, 8756-8756, 8757-8756, 8758-8757, 87588758, 8768-8767, 8769-8768, 8770-8769, 8771-8770, 8787-8786, 8787-8787, 8788-878710/15/14 2,087.SBHP170.1 8,799.94 3,370.18,8000.4 3,370.109-47A 500292209801 O6401508979-8976, 8997-8995, 9000-8999, 9008-9012, 9011-9014, 9013-90105/7/14SBHP164.7 8,152.6 3,218.68,8000.44 3,503.4609-47A 500292209801 O6401508979-8976, 8997-8995, 9000-8999, 9008-9012, 9011-9014, 9013-90105/12/14 46.SBHP169.8 8,152.6 2,952.8,8000.4 3,210.9611-31A 500292250901 O6401508657-8660, 8754-8759, 8768-8772, 8800-8792, 8815-8806, 8815-8811, 8815-8819, 8816-8818, 8825-8828/26/14 634.SBHP176. 8,721.4 3,318.8,8000.473,355.411-37500292271600 O6401508679-8686, 8689-8690, 8690-8695, 8720-8724, 8745-8750, 8753-8755, 8763-8768, 8784-8795, 8865-8867, 8889-8858, 8889-88898/25/14 9979SBHP179.7 8,700. 3,332.58,8000.34 3,366.712-11 500292060100 O6401508874-8895, 8972-9000, 9010-90287/15/14 103,420.SBHP206.8 8,800.31 3,285.98,8000.44 3,285.812-21 500292110100 WI6401508719-8735, 8810-8812, 8810-8813, 8810-8826, 8810-8848, 8812-8813, 8813-8821, 8821-8826, 8826-8830, 8830-8838, 88388848, 8848-8856, 8848-8857, 8856-8857, 8857-8864, 8864-8871, 8864-8879, 8871-8879, 8879-8884, 8887-8893, 8898-8913, 8898-8930, 8913-8930, 8940-8948, 8940-8959, 8948-8959, 8969-8998, 9044-9058, 9058-907211/28/14 12,071.SBHP77.1 8,800.36 3,291.58,8000.45 3,291.312-22 500292110700 O6401508782-8791, 8791-8796, 8818-8835, 8877-8889, 8877-8930, 8889-8930, 8943-8964, 8978-901311/23/14 3,590.SBHP198.7 8,800.15 3,367.898,8000.43 3,367.812-28A 500292108601 O6401508690-8711, 8906-8916, 8922-8926, 8922-8933, 8922-8949, 8926-8933, 8933-8938, 8933-8949, 8938-8948, 8938-8949, 89488949, 8995-90078/12/14 1,284.SBHP190.36 8,590.38 3,225.8,8000.29 3,285.3212-37 500292339800 O6401508726-8744, 8815-8828, 8830-8842, 8853-8863, 8897-8902, 8913-8920, 8924-8927, 8971-8980, 8988-89951/13/14 1,277.52SBHP200.5 8,800.15 3,285.38,8000.43 3,285.213-08A 500292066701 O6401509000-9009, 9002-9000, 9007-9005, 9023-9032, 9024-9017, 9031-9035, 9036-9041, 9039-9036, 9042-9038, 9043-9048/19/14 8,074.SBHP204.9 8,799.95 3,352.98,8000.33 3,352.913-12A O6401508/10/14 744.PBU206. 8,664.27 2,454.8,8000.44 2,514.13-17 500292071800 GI6401508767-8770, 8767-8810, 8770-8778, 8778-8786, 8786-8794, 8794-8802, 8802-8809, 8809-8810, 8817-8825, 8829-8831, 88298853, 8831-8839, 8839-8842, 8842-8850, 8850-8853, 8855-8858, 8858-8871, 8858-8874, 8871-8874, 8875-8883, 8886-8900, 8886-8941, 8900-8904, 8904-8911, 8911-8922, 8922-8935, 8935-8941, 9018-90489/9/14 29,257.SBHP180. 8,699.7 3,244.18,8000.1 3,253.9913-30C 500292076803 O6401508893-8902, 8897-8899, 8901-8893, 8901-890112/17/14 27,456.SBHP212.51 8,800.38 2,267.18,8000.25 2,267.14-03A 500292031901 O6401508859-8862, 9007-9009, 9013-9015, 9019-9021, 9023-9024, 9025-9026, 9025-9028, 9026-9028, 9041-90468/30/14 44,424.11SBHP210.3 8,799.74 3,267.78,8000.39 3,267.814-08A 500292033001 O6401508963-8969, 8963-8970, 8970-8965, 8972-8979, 8979-8994, 8982-8966, 8996-9002, 9001-90065/18/14 144.SBHP224. 8,797.52 3,317.8,8000.43 3,318.14-22A 500292074701 O6401508877-8885, 8890-8899, 8949-8953, 8953-8963, 8953-8970, 8963-8970, 8983-8987, 8999-9003, 9040-90486/14/14 1,300.98SBHP224. 8,800.28 3,328.8,8000.33 3,328.14-23A 500292075701 O6401508666-86858/18/14 922.6SBHP207.7 8,600.08 2,925.78,8000.08 2,942.14-31 500292098900 O6401508775-8777, 8783-8803, 8839-8844, 8844-8847, 8851-8861, 8873-8880, 8893-8899, 8904-8907, 8904-8914, 8907-8913, 89078914, 8913-8914, 8914-8919, 8914-8929, 8914-8949, 8919-8929, 8929-8934, 8929-8949, 8934-8949, 8973-89752/13/14 56,754.SBHP213.1 8,800.42 3,263.18,8000.42 3,262.914-32 500292099900 O6401508799-8801, 8803-8830, 8833-8847, 8847-8851, 8847-8856, 8851-8856, 8921-8930, 8939-8944, 8939-8957, 8944-8957, 89578966, 8966-8971, 8966-8975, 8971-8975, 8983-8992, 8992-90124/1/14 2,599.SBHP206.8 8,799.57 3,266.68,8000.1 3,266.615-28A 500292224701 O6401508775-8777, 8779-8775, 8783-87797/1/14 168.SBHP184.3 8,700.94 3,331.8,8000.34 3,365.16-05A 500292057401 WI6401509000-9021, 9005-9005, 9005-9006, 9006-9007, 9007-9007, 9016-9017, 9020-9018, 9024-9023, 9025-9026, 9025-9029, 90269028, 9028-9029, 9029-9046, 9032-9030, 9046-9046, 9046-9050, 9050-9050, 9057-9073, 9070-9051, 9073-90711/21/14 18,668.1SBHP171. 8,799.74 3,496.78,8000.423,497.4. Field and Pool:5. Datum Reference:7. Gas Gravity:Prudhoe Bay Field, Prudhoe Oil Pool8800 TVDss0.9 Exhibit 92014 PrudhoeRESERVIOR PRESSURE REPORT16-07500292143000 O6401508801-8819, 8829-8832, 8842-8848, 8873-8880, 8891-8917, 8891-8953, 8917-8935, 8935-8953, 8962-8974, 8962-9014, 89748991, 8991-9014, 9020-9029, 9020-9038, 9029-9038, 9049-90736/4/14 8683SBHP187.9 8,800.48 3,858.58,8000.403,858.316-14B 500292057002 G6401508993-8992, 9007-9007, 9008-9007, 9008-9008, 9024-9021, 9025-9024, 9039-9039, 9040-90395/9/14 335.SBHP174.5 8,800.04 3,303.38,8000.383,303.316-15500292147400 O6401508845-8856, 8860-8874, 8877-8889, 8891-8902, 8910-8947, 8979-8991, 8991-8995, 8991-8996, 8991-9007, 8995-8996, 89969003, 8996-9007, 9003-9007, 9007-901912/4/14 14,218.SBHP171. 8,822.05 3,522.8,8000.323,514.916-15500292147400 O6401508845-8856, 8860-8874, 8877-8889, 8891-8902, 8910-8947, 8979-8991, 8991-8995, 8991-8996, 8991-9007, 8995-8996, 89969003, 8996-9007, 9003-9007, 9007-90195/28/14 9,667.SBHP173.3 8,822.05 3,554.98,8000.413,554.916-17500292144100 O6401508797-8885, 8891-8909, 8926-8933, 8945-8946, 8945-8951, 8946-8950, 8950-89517/27/14 166.SBHP189.68 8,599.77 3,486.698,8000.443,573.916-27A 500292226001 O6401508875-8892, 8900-8899, 8902-8908, 8909-8906, 8921-8915, 8968-8977, 8971-8959, 8979-8996, 9013-9022, 9028-9036/3/14 1,170.SBHP197. 8,800.43 3,922.58,8000.303,922.417-02500292048600 O6401508818-8827, 8920-8929, 8936-8941, 8951-8959, 8965-8990, 9002-9019, 9033-90519/10/14 116.SBHP204.01 8,799.94 3,295.18,8000.433,295.117-04B 500292049802 O6401508885-90098/9/14 18,528.SBHP201.8 8,793.29 3,549.98,8000.163,550.17-06500292053000 WI6401508792-8817, 8900-8918, 8927-8954, 8973-8991, 9006-90432/9/14 1,909.SBHP143.4 8,799.69 3,472.38,8000.443,472.417-08500292060200 WI6401508835-8857, 8938-8965, 8984-9011, 9024-9037, 9024-9058, 9037-9058, 9157-9176, 9236-9256, 9259-9285/2/14 1,103.SBHP145.1 8,799.93 3,925.8,8000.083,287.317-09A 500292061701 O6401508954-8966, 9018-9030, 9040-9042, 9055-9053, 9057-9062, 9064-9057, 9065-9070, 9080-90659/10/14 311.SBHP199.41 8,799.86 3,554.548,8000.433,554.617-12A 500292126001 O6401508762-8777, 8764-8761, 8770-87692/8/14 687.SBHP174.3 8,749.75 1,870.78,8000.071,874.318-20500292189000 O6401508814-8821, 8826-8833, 8826-8837, 8833-8837, 8848-8856, 8861-8869, 8872-88862/9/14 56,359.SBHP177.9 8,780.07 3,294.78,8000.433,303.218-33A 500292259801 O6401508689-8698, 8695-86951/4/14 68,033.57SBHP174. 8,550.02 3,306.8,8000.433,415.4A-26500292079400 O6401508731-8752, 8819-8852, 8819-8860, 8852-8860, 8865-8920, 8928-89499/30/14 1,821.SBHP225.9 8,699.79 3,261.8,8000.443,304.55A-38 500292234700 O6401508854-8871, 8947-90057/16/14 283.SBHP224.7 8,790.19 3,229.68,8000.413,234.9B-07500292028500 O6401508894-8899, 8907-8927, 8907-8931, 8907-8935, 8927-8931, 8931-8933, 8931-8935, 8933-8935, 8942-8959, 8959-8972, 89598975, 8972-8975, 8991-8997, 9000-9003, 9003-9010, 9010-9040, 9040-9041, 9040-9046, 9041-90464/18/14 402.SBHP202.7 8,777.11 3,255.38,8000.083,257.1B-13B500292034102 WI6401508837-8855, 8938-89543/2/14 280.SBHP146.2 8,799.11 3,331.8,8000.55 3,331.5B-33A 500292233901 O6401508724-8742, 8826-8845, 8826-8849, 8845-8849, 8849-8864, 8849-8869, 8864-88698/27/14 1,050.SBHP222.4 8,649.49 3,189.68,8000.433,253.6C-29A 500292147201 O6401508832-8835, 8843-8852, 8926-8929, 8995-8988, 9006-9011, 9008-90012/14/14 857.SBHP197.4 8,739.86 3,262.8,8000.073,266.5E-05B500292019702 O6401509047-9048, 9063-9065, 9064-9065, 9065-9065, 9066-9061, 9068-9064, 9075-90704/24/14 815.SBHP192.8 8,800.16 3,297.38,8000.273,297.E-25A500292177301 O6401508974-8966, 8988-8990, 8993-8984, 8997-8989, 9002-9001, 9004-9004, 9008-9004, 9012-9011, 9013-90154/9/14 5,924.SBHP191.5 8,799.82 3,196.18,8000.083,194.9E-34500292243700 O6401508731-8727, 8731-8754, 8754-87274/12/14 3,735.SBHP187.2 8,599.92 3,217.8,8000.483,313.5E-36A500292256301 O6401509052-9055, 9055-9058, 9062-9059, 9062-9062, 9066-90673/23/14 4,452.SBHP196.3 8,799.73 3,257.98,8000.35 3,258.F-34B 500292198002 O6401508987-9019, 9019-90304/24/14 6,639.SBHP197.1 8,801.11 3,220.38,8000.083,220.2F-36500292263100 O6401508846-8935, 8975-90336/19/14 14,096.SBHP196.9 8,709.59 2,997.68,8000.343,032.3F-41500292220300 O6401508695-8702, 8919-8931, 8946-8952, 8952-8961, 8952-8966, 8961-8966, 9020-90268/29/14 4,358.SBHP200.2 8,650.97 2,730.98,8000.292,774.2F-41500292220300 O6401508695-8702, 8919-8931, 8946-8952, 8952-8961, 8952-8966, 8961-8966, 9020-902611/25/14 6,472.SBHP198.1 8,800.18 3,214.98,8000.083,214.9G-01A 500292021401 O6401508979-8987, 8982-8964, 8987-8994, 8994-9000, 9007-8991, 9014-9017, 9018-90165/2/14 27.SBHP185.4 8,797.52 3,199.8,8000.043,199.G-15B 500292064702 O6401509020-9022, 9022-9021, 9024-9022, 9025-9025, 9026-9018, 9037-90267/4/14 346.SBHP196.9 8,788.54 3,188.38,8000.323,189.G-16A 500292064301 O6401509018-9028, 9028-9037, 9036-904812/8/14 597.SBHP198.5 8,800.44 3,249.28,8000.073,249.2GNI-03 500292282000 WI6401506597-6613, 6852-68697/30/14 264.SBHP77.3 6,539.81 3,085.38,8000.444,082.9GNI-04 500292336700 WI6401506504-65227/6/14 204.SBHP80.6 6,449.56 3,051.8,8000.444,081.9H-09500292048200 WI6401508738-8758, 8847-8864, 8847-8878, 8864-8878, 8878-8882, 8887-8908, 8908-8914, 8917-8948, 8961-8973, 8981-8997, 9004-90243/9/14 540.SBHP145.3 8,791.02 3,256.18,8000.443,260.H-26500292148700 O6401508928-8938, 8938-8946, 8938-8956, 8946-8950, 8946-8956, 8950-8956, 8966-8968, 8966-8970, 8966-8981, 8968-8970, 89708975, 8970-8978, 8970-8981, 8975-8978, 8978-8981, 8981-8987, 8981-8988, 8981-8990, 8987-8988, 8988-8990, 8990-8995, 8990-8998, 8995-8998, 8998-9001, 8998-9008, 9001-9005, 9005-9007, 9005-9008, 9007-9008, 9008-9014, 9008-9018, 9014-9016, 9014-9018, 9016-9018, 9018-9022, 9018-9024, 9022-9023, 9022-9024, 9023-9024, 9024-9026, 9024-9034, 9026-9027, 9026-9034, 9027-9034, 9034-9037, 9034-9044, 9037-9038, 9037-9044, 9038-9044, 9044-905610/17/14 2,879.SBHP217.4 8,800.3 3,281.58,8000.583,281.3J-28500292172100 O6401508951-8958, 8979-9008, 9008-9025, 9025-90329/9/14 1,298.SBHP207.7 8,799.95 3,232.98,8000.433,232.9K-06C 500292103803 O6401509004-9016, 9016-9017, 9016-9031, 9017-9031, 9033-908112/4/14 3,515.SBHP185.6 8,729.23 3,356.38,8000.113,364.1K-10C 500292176204 O6401508722-8727, 8727-8719, 8727-8727, 8727-8728, 8728-8728, 8728-8730, 8729-8728, 8745-8734, 8753-875010/16/14 637.SBHP174. 8,499.92 3,322.38,8000.083,347.58K-12B 500292175902 O6401508825-8815, 8907-8827, 8940-8948, 8948-89562/8/14 1,655.SBHP187.5 8,799.85 3,294.98,8000.063,294.9L-03500292326900 O6401508912-8963, 8949-8964, 8956-89509/11/14 42,384.SBHP0.01 1,460.8,8000.33 3,797.N-12 O6401509/16/14 1,447.SBHP220.9 8,799.6 3,250.38,8000.423,250.5P-28500292342500 O6401508959-8971, 8989-8993, 8989-8997, 8999-9008, 9013-9015, 9014-9002, 9015-9018, 9019-90158/5/14 446.SBHP230.5 8,799.66 3,318.38,8000.373,318.4R-23A 500292101301 O6401508841-8805, 8900-88419/10/14 1,310.SBHP206.8 8,799.91 2,050.98,8000.432,050.9R-31A 500292227701 O6401508720-8696, 8743-87209/11/14 1,326.SBHP207.2 8,697.88 2,332.88,8000.332,366.9S-02A500292069801 O6401508723-8726, 8745-8745, 8746-8745, 8746-8746, 8746-8747, 8747-8747, 8749-8749, 8753-8753, 8754-8754, 8755-8824/21/14 74.SBHP226. 8,656.43 3,155.28,8000.413,214.2S-16500292112300 O6401508802-8805, 8805-8833, 8805-8837, 8833-8837, 8936-8940, 8940-8951, 8940-8955, 8951-8955, 8960-8963, 8969-8991/25/14 82,895.SBHP218.9 8,799.32 3,341.28,8000.433,341.5S-26500292204700 O6401506704-6727, 8743-8753, 8757-8845, 8877-8922, 8976-897810/3/14 1,854.SBHP164.4 6,793.18 3,208.58,8000.353,900.88S-29A 500292208201 WI6401508855-8860, 8989-90309/20/14 9,086.SBHP210.8 8,800.08 3,409.68,8000.413,410.1S-31A500292210901 WI6401506660-6729, 6775-6790, 8763-8785, 8784-88137/11/14 5.SBHP205.2 8,599.75 3,626.18,8000.43 3,713.1U-06B 500292111702 O6401508868-8886, 8975-8979, 8980-8991, 8980-9023, 8981-8977, 8986-8964, 8992-9004, 9009-9013, 9013-8992, 9014-9024, 90158983, 9020-9014, 9025-9027, 9028-9026, 9028-9029, 9029-90299/12/14 1,356.SBHP228.09 8,800.26 3,332.728,8000.433,328.99V-02 500292320900 O6401508949-8948, 8949-8966, 8950-8948, 8950-8949, 8953-8950, 8954-8953, 8954-8954, 8955-8953, 8955-8954, 8955-8955, 89588961, 8961-8958, 8962-8969, 8965-8958, 8967-8966, 8969-8970, 8971-8968, 8971-8969, 8972-8972, 8973-8971, 8973-8973, 8974-8973, 8974-8976, 8975-8974, 8975-8975, 8976-8980, 8976-8986, 8977-8974, 8979-8969, 8979-8977, 8980-8981, 8981-8979, 8981-8980, 8993-89828/4/14 424.SBHP233.56 8,800.05 3,541.278,8000.363,541.3V-04500292332200 O6401508815-8852, 8858-8871, 8875-8878, 8885-8818, 8897-8891, 8909-8931, 8912-8901, 8925-89241/4/14 473.SBHP232.32 8,699.89 3,805.588,8000.453,850.4V-05500292339100 WI6401508895-8948, 8960-8983, 8962-8949, 8964-8962, 8965-8992, 8970-8966, 8980-8971, 8983-8987, 8986-8983, 8995-8981/6/14 513.5SRT-57.8 130.8,8000.44 4,027.4W-01A 500292186601 O6401508894-8922, 8922-89361/6/14 1,196.5SBHP209. 8,164.53 2,976.8,8000.42 3,242.9W-01A 500292186601 O6401508894-8922, 8922-893610/15/14 7,968.SBHP206.3 8,164.53 3,120.8,8000.4 3,374.19W-04 500292190700 O6401508904-8915, 8925-8936, 8941-8947, 8951-8957, 8957-8963, 8963-8964, 8970-8972, 8970-8974, 8972-8974, 8974-8988, 89748990, 8988-8990, 8990-8996, 9001-9010, 9010-9036, 9044-9052, 9061-906910/8/14 1,296.SBHP215. 8,327.72 3,072.8,8000.4 3,260.91W-22 500292186900 O6401508864-8873, 8877-8885, 8894-8899, 8902-8908, 8902-8927, 8908-8925, 8925-8927, 8930-8932, 8930-8940, 8932-8940, 89478952, 8952-8956, 8952-8981, 8956-8981, 8992-8994, 8992-9012, 8994-9012, 9012-9012, 9028-9038, 9028-9061, 9038-90619/4/14 1,296.SBHP213. 8,336.26 3,445.8,8000.39 3,626.W-26A 500292196401 O6401508825-8846, 8849-8865, 8880-8878, 8881-8878, 8881-8880, 8882-8881, 8884-8900, 8886-8881, 8886-8882, 8887-8878, 88878886, 8890-8887, 8890-8890, 8905-8916, 8924-8935, 8973-8986, 8987-8981, 8991-89911/25/14 4,126.SBHP232.7 8,799.91 3,575.8,8000.383,575.W-38A 500292180701 O6401508875-8933, 8915-8978, 8936-89175/18/14 236SBHP233.7 8,749.89 3,433.68,8000.413,453.9W-51500292348800 O6401508946-8941, 8952-8984, 8965-9006, 8978-8950, 8998-9029, 9012-898510/2/14 1,296.SBHP214. 8,365.05 3,373.8,8000.33 3,516.53W-56 500292342300 O6401508902-8981, 8910-8932, 8928-8900, 8933-8930, 8937-8944, 8944-8934, 8952-8949, 8956-8970, 8958-8955, 8970-8930, 89718981, 8976-8964, 8977-8974, 8984-89789/4/14 1,296.SBHP219. 8,528.49 3,141.8,8000.39 3,247.X-30A 500292255001 O6401509009-9010, 9013-9014, 9024-9027, 9028-9027, 9038-9038, 9039-90547/4/14 341.SBHP224. 8,799.71 3,377.8,8000.163,377.Y-03A500292041101 WI6401508926-8929, 8936-8939, 8956-8959, 8977-8990, 8990-89923/5/14 14,484.SBHP194. 8,799.97 3,284.8,8000.433,284. Exhibit 92014 PrudhoeRESERVIOR PRESSURE REPORTY-10B500292058702 G6401508875-8881, 8883-8880, 8891-8886, 8894-8892, 8898-8893, 8901-88988/19/14 782.SBHP218. 8,799.95 3,652.8,8000.413,652.02Y-14B 500292183202 O6401508878-8895, 8979-8986, 8987-8985, 8987-8997, 8997-9000, 9000-90383/26/14 37.SBHP202. 7,900.43 2,488.8,8000.062,541.9Y-32500292214900 O6401508861-8877, 8898-8910, 8954-8956, 8954-8975, 8956-8957, 8956-8975, 8957-8963, 8963-8972, 8972-8975, 8975-8977, 89758982, 8977-8982, 8982-8987, 8982-9011, 8987-8996, 8987-9011, 8996-9002, 9002-9011, 9016-9031, 9016-9040, 9031-9036, 9036-9040, 9051-9068, 9073-90782/9/14 150.SBHP227.9 8,800.16 3,293.48,8000.43 3,293.3Z-01B 500292183002 O6401508943-8951, 8951-8954, 8959-8969, 8959-8973, 8969-8973, 8973-8979, 8985-8987, 8993-8995, 8995-89989/4/14 89,556.SBHP209. 8,299.74 3,492.8,8000.42 3,731.5Z-03A 500292278701 O6401508868-8896, 8899-8917, 8923-8929, 8932-8949, 8955-8968, 8975-8979, 8986-89918/26/14 963.SBHP230.3 8,750.01 3,221.38,8000.023,237.Z-04A500292199001 O6401508881-8911, 8882-8895, 8888-8880, 8899-8902, 8905-8894, 8906-8910, 8919-8909, 8922-8935, 8928-8949, 8940-8950, 89568969, 8997-90009/10/14 1,704.SBHP225. 8,838.87 2,711.8,8000.332,724.Z-04A500292199001 O6401508881-8911, 8882-8895, 8888-8880, 8899-8902, 8905-8894, 8906-8910, 8919-8909, 8922-8935, 8928-8949, 8940-8950, 89568969, 8997-90008/26/14 954.SBHP227.1 8,800.15 2,859.18,8000.332,859.1Z-06A500292179801 O6401508879-8903, 8883-8974, 8893-8875, 8919-8901, 8954-89383/10/14 888.FL8,500.86 1,800.8,8000.33 2,749.Z-06A 500292179801 O6401508879-8903, 8883-8974, 8893-8875, 8919-8901, 8954-89388/28/14 4,973.SBHP226. 8,800.2 2,737.88,8000.332,737.7Z-13A500292206901 O6401508941-8940, 8941-8947, 8942-8942, 8943-8943, 8945-8943, 8947-8946, 8949-8948, 8952-8951, 8954-8958, 8957-8954, 89588957, 8960-8990, 8961-8959, 8962-8961, 8967-8962, 8969-8967, 8997-9003, 9034-9043, 9053-90599/4/14 1,176.SBHP206. 7,675.04 3,232.8,8000.4 3,682.Z-14B 500292184402 O6401508870-8875, 8891-8903, 8912-8925, 8937-89429/28/14 15,045.SBHP234.6 8,750.12 3,667.78,8000.163,675.87Z-24 500292191700 O6401508858-8865, 8865-8869, 8865-8872, 8869-8872, 8890-8921, 8934-8952, 8934-8967, 8952-8967, 8989-9017, 9024-9025, 90249046, 9025-90466/18/14 4,296.SBHP218. 8,066.59 3,472.8,8000.4 3,765.Z-32C 500292192403 O6401508867-8873, 8871-88659/4/14 2,640.SBHP211. 8,228.02 3,472.8,8000.4 3,701.Z-34 500292346900 O6401508886-8908, 8914-8906, 8919-8971, 8924-8917, 8951-8978, 8974-8954, 8982-9001, 9002-8980, 9011-9004, 9011-9020, 9022-90238/26/14 944.SBHP229.4 8,749.9 3,216.68,8000.313,232.3Z-38500292287300 O6401508914-8927, 8931-8952, 8933-8945, 8935-8939, 8943-8967, 8950-8958, 8960-8929, 8963-8967, 8968-8936, 8968-8943, 89688974, 8973-8970, 8974-8978, 8976-8978, 8978-8986, 8988-8992, 8992-8979, 8995-8975, 8995-8994, 8996-89989/4/14 1,896.SBHP213. 8,197.7 3,504.8,8000.4 3,745.Z-40 500292346200 O6401508858-8921, 8903-8931, 8928-8956, 8933-8915, 8952-8970, 8961-8982, 8971-8961, 8985-8975, 8996-90499/4/14 1,176.SBHP214. 8,309.88 3,217.8,8000.33 3,379.Z-40 500292346200 O6401508858-8921, 8903-8931, 8928-8956, 8933-8915, 8952-8970, 8961-8982, 8971-8961, 8985-8975, 8996-90492/27/14 288.SBHP222. 8,309.8 3,241.8,8000.33 3,403.Z-50 500292346300 O6401508879-8915, 8907-8924, 8920-8908, 8933-8965, 8937-8970, 8971-8926, 8985-9007, 9000-89798/27/14 972.SBHP232.4 8,800.03 3,628.18,8000.423,628.1Z-65500292345100 O6401508898-8896, 8902-8901, 8905-8904, 8915-8908, 8923-8920, 8932-8926, 8969-8986, 8971-8965, 8976-8961, 8988-8996, 89928980, 8997-89943/22/14 2,376.SBHP210. 8,243.09 3,456.8,8000.41 3,684.Z-65 500292345100 O6401508898-8896, 8902-8901, 8905-8904, 8915-8908, 8923-8920, 8932-8926, 8969-8986, 8971-8965, 8976-8961, 8988-8996, 89928980, 8997-89949/4/14 1,176.SBHP211. 8,243.09 3,448.8,8000.41 3,676.Z-66 500292348200 O6401508777-8880, 8880-8880, 8896-8929, 8931-8937, 8936-8936, 8937-8931, 8938-8937, 8939-89749/4/14 1,176.SBHP210. 8,198.52 3,384.8,8000.41 3,631.Z-69 500292347100 O6401508871-8880, 8891-89004/25/14 915.SBHP232.2 8,770.04 3,684.58,8000.44 3,698.Z-71 500292348400 O6401508953-8968, 8965-8955, 8975-8997, 8976-9010, 8986-8973, 9018-9040, 9020-9038, 9025-8991, 9054-9039/4/14 1,176.SBHP217. 8,410.31 3,373.8,8000.44 3,544.23. All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission.The following well pressure measurements were excluded for the average pressure map computation: 01-08A, 03-16A, 06-12B, 09-47A, 11-31A, 13-30C, 14-23A, 17-12A, F-36, F-41, G-01A, R-23A, R-31A, S-26, S-31A, W-01A, Y-10B, Y-14B, Z-03A, Z-04A, Z-04A, Z-06AI hereby certify that the foregoing is true and correct to the best of my knowledge.SignatureTitle Sr Reservoir EngineerPrinted Date 9-Mar-2015NameVivek PeraserSignatureTitle Sr Reservoir EngineerPrinted Date 9-Mar-2015NameVivek Peraser Exhibit 10 2014 IPA Shut In Well Report sw_name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 01-09A PBU 500292016401 3/19/2007 7 5 SI, prod casing needs repair. 01-16 PBU 500292028800 11/11/2011 6 7 Currently working on a RWO package 01-24A PBU 500292086001 12/13/2013 6 2 SI, Tubing needs repair 02-02A PBU 500292007401 6/1/2006 6 5 Well suspended. 02-03B PBU 500292007702 12/26/2013 6 1 LDS needs repair. 02-05A PBU 500292008101 1/1/2009 6 3 Well in plan for RWO/CTD beginning of 2014. 02-10B PBU 500292016302 2/21/2014 3 2 Perfs need repair Look into acid job. 02-17B PBU 500292045302 8/30/2011 7 6 SI, waiting for Flowline VSM repair, high GOR well, 02-30B PBU 500292220202 9/1/2006 6 5 Well Suspended 02-39A PBU 500292272101 12/2/2007 5 2 Well is operable. SI for HGOR 03-12 PBU 500292039200 7/10/2010 6 7 PC needs repair RWO to be completed in March 2015 03-26 PBU 500292102700 7/9/2009 3 2 SI for high watercut and low oil rate. Evaulating GL optimization. Well needs removal of downhole obtacles preventing water shut off. 03-27 PBU 500292110900 6/29/2013 2 2 High WC well. Working a package for FCO and POP the well to get MIST benefits from new well 09-31D 03-34B PBU 500292113202 4/10/2010 6 5 F Furmanite wrapping not functioning. Evaluate welding to prevent SH leak 04-04A PBU 500292009601 1/1/1995 6 5 CTD BHA stuck in a window. Well classified as suspended. 04-07 PBU 500292018900 1/1/1997 2 6 SI for high WC 04-12 PBU 500292029700 9/20/1994 6 5 Cemented tubing. Well classified as suspended. 04-14 PBU 500292031000 12/20/2011 7 6 Flowline needs to be repaired. Package Approved. Repair 2/15-3/29 04-17 PBU 500292153200 8/9/2012 7 6 Flowline/Surface. Tripled with 04-19/45 04-26 PBU 500292152000 5/31/2011 3 5 High WC, low oil/IOR. Well is now P&A-ed. 04-28 PBU 500292148800 7/29/2010 4 1 Wellwork on WBL 04-32A PBU 500292132601 4/11/2011 2 6 Currently SI for high WC. Expect 09-39 WAG response.. 04-34A PBU 500292216001 11/19/1997 2 5 High WC, low IOR. 04-35A PBU 500292214701 1/8/2011 2 2 High WC, low IOR. 04-36 PBU 500292216200 11/14/2001 2 2 High WC, low IOR. May try acid stim. 04-39 PBU 500292218100 4/11/1998 2 2 High WC, low IOR. Need pattern review. 04-40 PBU 500292222400 5/23/2010 7 2 SI for velocity excursion. High GOR Evaluating WSO options. 04-41 PBU 500292223701 4/24/2013 2 2 Evaluating adding perfs and WSO 04-42 PBU 500292222900 8/18/2012 6 4 SC needs repair. Evaluating a fix. 04-43 PBU 500292244300 12/20/2011 7 6 FL repair package approved. Repair 2/15-3/29 05-03C PBU 500292014703 1/11/2012 7 6 SI, waiting for flowline repair. 05-06A PBU 500292017301 10/15/2010 6 3 Released to NWD 05-12B PBU 500292024402 1/19/2005 6 2 Originall SI for High GOR. Now Mechanical. Evaluating for wellwork/RWO or sidetrack 05-15B PBU 500292025502 10/13/2014 6 6 SI, waiting for flowline VSM repair. 05-17B PBU 500292027102 11/1/2002 6 5 collapsed tbg 05-18A PBU 500292196001 2/3/2003 6 5 Casing needs repair. 05-25C PBU 500292198803 9/19/2012 1 2 High GOR. 05-27B PBU 500292197902 12/17/2013 7 1 Well work is currently planned 05-28 PBU 500292220800 #N/A 1 2 Future being evaluated 05-32A PBU 500292219001 11/1/2013 7 2 Choke Obstruction. Will resolve during next shutdown if possible. 05-33B PBU 500292216802 7/10/2013 7 2 Possible solids production. 05-39 PBU 500292271500 7/3/2010 7 1 Waiting for RWO 05-40 PBU 500292270700 11/1/2002 6 5 Failed RWO - stuck CT during cleanout 06-06B PBU 500292020102 1/4/2013 7 6 sand in header, need new header fab'd. 06-15 PBU 500292045900 7/15/2006 6 5 Surface casing needs repair, Released to NWD for excavation repair + sidetrack 07-07B PBU 500292090101 3/1/2010 6 3 TxIA. 2 DWP Patches over damaged collar , 11 DGLVs, high GOR. Scheduled for RST in 2015 07-10A PBU 500292033501 7/10/2010 6 5 Did Reservoir P&A. Not Operable. PC damage. High GOR 07-34A PBU 500292181201 4/6/2005 6 3 RWO failure Feb, 2013. IAxOA; Stuck IBP fish in tubing. Rig ST scheduled for 2015. 09-03 PBU 500292020900 7/5/2013 6 2 Well not operable. IAxOA. 09-07 PBU 500292022300 2/9/2014 2 2 High water cut well with bad lip from liner collapse downhole. Wellwork options limited due to liner damage. 09-18 PBU 500292025900 6/14/2012 5 1 SI for Organoseal Job to squeeze off zone 3. Cement squeeze with Fiber was partially successful. New Job submitted in JMS 09-24 PBU 500292142800 5/15/2012 2 3 High Water cut. WID-ed for Coil ST (BELVEDERE) 09-27 PBU 500292129100 10/23/2013 6 2 Not Operable. SC needs repair. 09-29 PBU 500292142200 10/2/2012 2 5 High WC. 09-36C PBU 500292142903 1/25/2013 6 5 Well Not operable. TxIA. 09-37 PBU 500292245100 7/7/2009 6 5 Attempted packer squeeze summer 2010. Pressure tests failed. Needs evaluation on other wellwork fixes. In dual injector pattern with 09-17. 09-38 PBU 500292191900 4/10/2011 8 3 Injector injects out of zone for pattern conformance. Candidate for Z4 MIST trials 09-42A PBU 500292205901 12/12/2002 6 5 2008 RWO failed. Now possible SC damage needing repair. 09-44A PBU 500292208701 2/18/2010 7 5 Well took a big kick while drilling sidetrack and had problems with the hole. Sidetrack was abandoned and radioactive source left downhole 09-48 PBU 500292212800 11/30/2004 6 7 IAxOA to gas- not manageable by bleeds. Evaluating use as sidetrack candidate or lateral. RWO package in motion 09-49 PBU 500292231700 9/21/2011 2 3 High WC. WID-ed for Sidetrack (SANTANA/ROOTS) 09-51 PBU 500292232000 11/28/2012 7 6 Candidate to go on PWI but Frank on PWI line. 11-06A PBU 500292067401 3/16/2013 2 5 Well was high GOR and WC. Well currently blinded and Released (Surface kit to be used by the new well 11-39 to be drilled in Fall) 11-15 PBU 500292122100 P&A 2/14/91. 11-25A PBU 500292048802 2/11/2002 6 5 PC needs repair and IAxOA Communication. No current plans. Released to NWD 11-26 PBU 500292162800 3/22/2013 5 5 Well is currently shut in for drill by on DS-18. Decided to keep it SI to manage the reservoir differently and bring more rich gas in the pattern 11-29 PBU 500292246600 12/31/2012 6 5 Has Ann comm 11-02 is another injector in the same pattern 11-34 PBU 500292251600 3/1/2011 7 6 SI for velocity excursion. And F rank on S riser. Well is twinned with a more competitive well and both cannot flow into the twinned line at current gas rates. Have S-riser change out completed and now waiting to POP the well 11-35 PBU 500292247600 12/31/2012 6 5 This is the UDVG well. Released for sidetrack, no current plans for well. 11-36 PBU 500292247700 8/31/2010 6 5 SC needs repair; Brinker treatment failed. On excavation list. 11-37 PBU 500292271600 12/19/2012 2 1 Well used to be high oil/high gas, now only water from water injection. The well is blinded and since FS2 is water limited, will not be unblinded at this time. Plan to get RPM and look for addperf uphole. The water may have pushed the oil----Based on the RPM, WSO and uphole add-perf is on the WBL Exhibit 10 2014 IPA Shut In Well Report sw_name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 12-01 PBU 500292036300 2/13/2013 6 7 Failed a MIT-IA on 3/23/2013 and a CMIT-TxIA on 3/18/2013 during CTD candidate screening. LDL show PC leak and a potential packer leak. RWO package signed Oct'13. 12-03 PBU 500292037700 1/29/2009 6 2 High OA pressure post RWO that cemented OA, Seal-Tite tried twice but failed. Waiting to be handled as a bigger project. 12-07A PBU 500292040901 5/29/2009 6 2 High OA pressure post RWO that cemented OA. Waiting to be handled as a bigger project. 12-11 PBU 500292060100 2/1/2000 6 5 LTSI. Low oil rate. 12-11's surface facilities used for new grass roots well 12-37. CMIT- IA passed on 6/11. Will consider testing with ASRC. 12-21 PBU 500292110100 7/12/2013 7 2 Waiting on Flowline repair 12-25 PBU 500292104200 3/5/2013 5 4 SI for Res Mgmt 13-01 PBU 500292032300 7/21/2006 6 5 SC and surface facilities need repair; well likely not operable No plans at this time. Surface facilities donated to 13-37 grass roots well. Flagged to Wells Group for P&A. 13-04 PBU 500292032600 10/3/2003 6 7 TxIAxOA; produces rocks, sand screen installed, swiss cheese tubing. Plans to further diagnose. Well to be Non-rig Reservoir Abandoned. Dec 2012: Decided to proceed with RWO, not to be abandoned! RWO package complete & submitted. 13-05 PBU 500292062600 11/1/1997 6 5 TxIAxOA; replaced by 13-06Ai MI injector. FL decommissioned 8/09. No plans at this time. P&A with Cement Plug in 2004. Well was reservoir abandoned in 2012. 13-07 PBU 500292065000 7/1/1991 6 5 TxIA, \ surface facility repairs required. NWD screening for ST. 13-10 PBU 500292067800 6/1/1994 6 5 IAxOA on GL: uneconomic RWO (high WC). No plans at this time. Released. 13-11 PBU 500292060400 12/5/2005 6 5 TxIA & possible hole in packer or PC. NWD screening for ST. Idea to run LDL to evaluate if patch is an option. Working on Evaluating the leak. 13-12 PBU 500292053800 12/25/2007 6 3 Well was shut in on 12/2007 for TxIA communication. Well was sidetracked to 13-12A in early 2012. 13-17 PBU 500292071800 5/9/2011 7 1 Well originally SI due to broken PWI line. Flowline has been repaired, but the well developed a PC leak. There is currently a program in the works to fix the PC. 13-25 PBU 500292076100 10/21/2007 6 5 TxIA 13-26 PBU 500292074600 10/11/2011 6 5 Jax P2 sidetrack into SAG. Not pursued any further at this stage, but CST could be an option 13-28 PBU 500292094200 5/1/1994 6 5 PC needs repair & bubbles in the cellar. Replaced by 13-13A. 13-30B PBU 500292076802 7/17/2008 7 3 B lateral was abandoned due to low resistivity/water. Sidetracked to Sag contingency target (13-30C) 13-30C PBU 500292076803 10/29/2011 3 5 Low PI. No Res. Pressure. Needs inj support. 13-33 PBU 500292077300 12/1/1994 6 5 TxIAxOA; Well to be Non-rig Reservoir Abandoned in 2012 (or early 2013). 13-36 PBU 500292261300 9/23/2010 6 7 TXIA and possible IAxOA 14-03A PBU 500292031901 8/5/2009 6 2 TxIA and leaky 9-5/8" scab. Present to WIC to POP well under evaluation to see if it’s a competitive well and look at options for fixing the well (Non-rig vs. RWO). April 2014: Evaluating Possible RWO and coil. 14-11A PBU 500292052901 7/3/2013 2 3 Well makes almost 100% water. Looking into sidetracking well. 14-14 PBU 500292062500 8/10/2006 7 5 IAxOA and flowline; Not a RWO candidate 14-17 PBU 500292056200 1/4/2003 7 3 Sidetracked to 14-17A to target a location better suited to support new production in the area from nearby wells. 14-24 PBU 500292097000 12/6/2012 4 1 Sand back over Ivishak, Sag frac Complete in 2015. 14-26 PBU 500292063200 9/12/2012 6 7 Well failed MIT-IA Nov'12 and LDL found 5 leaks. Already has patch, needs a RWO. Planned for execution in 2015. 14-27 PBU 500292104600 11/17/2004 6 7 Flowline replaced, but well developed PC leak. IA cement squeeze or RWO candidate. 14-28A PBU 500292070801 12/24/2012 2 1 Makes ~100% water. High probability that the perfs are connected to a fault. Plan forward is to squeeze off existing perfs. 14-32 PBU 500292099900 12/13/2013 6 7 RWO Candidate. Planned for execution in 2015. 14-38 PBU 500292186200 11/1/1994 6 5 14-39 PBU 500292188800 6/1/1994 6 5 IAxOAxForm. P&A completed in 11/10 with 5000' of cement in IA & TBG. 14-44 PBU 500292257300 9/25/2002 2 3 Well was sidetracked to 14-44A because the parent well (14-44) oil production quickly declined due to the slotted liner having connectivity with the WOC. 15-03 PBU 500292072200 6/1/1994 6 5 Had Cret leak, leaking sqz perfs, major fish in tubing; surface facilities given to another well 15-08C PBU 500292118003 1/29/2013 6 1 Starting Head. welding completed in 2015 and BOL. 15-10A PBU 500292050101 1/1/1991 6 5 Had major down hole leaks and a channel; no surface facilities; bottom hole location developed by 15-49 15-12B PBU 500292066502 7/10/2010 1 5 Choke removed 8/1/10 (erosion). High GOR. Jul-10 Plug/perf tested all gas. Sidetrack candidate. 15-19A PBU 500292182901 7/9/2009 6 1 Pulled leaking patch over parted tubing @ ~ 3000' MD. Barely failed CMIT-TXIA in 1/09. Plans to repeat CMIT TxIA and if passing, set patch over parted tubing. 15-24 PBU 500292222300 3/1/1995 6 5 Collapsed tubing, had cret leak, no surface facilities 15-30B PBU 500292228202 9/12/2012 3 5 Reset liner top packer in 4/13. Tried putting the well on production with coil N2 lift with no success. Stacked CIBP’s. 15-32B PBU 500292246202 12/21/2013 1 5 High GOR 15-33B PBU 500292244802 6/11/2011 1 3 Sidetrack planned to 2015 15-35 PBU 500292248800 9/3/2003 6 5 Had Cret leak, dumpflooded Ivishak, TxIA and PC communication 15-36B PBU 500292248002 7/8/2013 1 5 High GOR 15-38A PBU 500292249601 11/10/2013 1 5 High GOR. PoP in 2015 and turns out to be a cycle well 15-40A PBU 500292251101 9/10/2010 1 2 High GOR. Plug/perf failed in Sept-10. 15-41 PBU 500292249201 2/5/2007 7 5 Put/Ivishak comingling issue & already swept Ivishak zone makes, not a candidate for wellwork. No sidetrack target. DUPLICATE 15-41B PBU 500292249202 5/9/2006 3 5 Low PI well 15-42B PBU 500292262402 3/1/2010 1 5 High GOR. 15-43 PBU 500292267600 12/8/2009 6 1 Well has a hole in SC at the wellhead on Dec 24, 2008. Sealtite failed Sept-10. Plans to weld leak 15-44 PBU 500292268300 3/6/2013 1 1 High GOR. Evaluating patching gassy area 15-46 PBU 500292266500 9/30/2011 6 1 Not operable. Hole in SC, evaluating weld 15-47 PBU 500292261700 10/1/2002 6 5 Reservoir P&A'd in 2011. Tbg very damaged, IA cemented. Well secured w/ sand plug chunks of tbg falling down on plug. BH location replaced by 15-14A in 2005. 16-06B PBU 500292058402 9/3/2011 7 6 VSM/Flowline. Facility Contrained 16-07 PBU 500292143000 11/27/2012 2 6 SI due to 16D CL pressure limits 16-08A PBU 500292054901 7/6/2013 1 6 VSM repairs underway, and wellwork planned to get well online shortly after VSM repairs completed. 16-09A PBU 500292055801 10/15/2007 6 1 Wells group has pushed toolstring down hole. Going to wait till it gets closer to time for VSM to be repaired then do last wellwork package (SL punch holes). Facility Constrained Exhibit 10 2014 IPA Shut In Well Report sw_name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments 16-15 PBU 500292147400 4/20/2013 7 6 SI due to 16D CL pressure limits. Facility Constrained. Low PI. Sidetrack option being pursued for the 2016 East of Sag drilling season. 16-18 PBU 500292146100 12/12/2012 2 6 SI due to 16D CL pressure limits. Facility Constrained 16-24 PBU 500292153600 7/6/2006 6 5 TxIA communication and low productivity. 16-28 PBU 500292227600 10/5/2005 6 5 SI for high WC. Hole in SC. Will be non-rig reservoir abandoned. Wells group is also working on possible surface casing repair to reinstate integrity to this well. 16-31 PBU 500292228000 4/1/1995 3 5 SI for low PI. TxIA to gas only- needs GL to produce. In pattern with injector which injects out of zone. 17-04B PBU 500292049802 6/29/2012 7 3 Well being sidetracked to new location in 2Q 2015. 17-20 PBU 500292230000 8/2/2012 2 5 High WC 18-07B PBU 500292080302 Well is sidetr 7 3 New Well Delivery working on sidetrack. estimate well will be drilled within the year 18-09B PBU 500292156602 9/24/2013 7 3 Cut and pull attempt by New Well Delivery unsuccessful for sidetrack attempt. Evaluating plan forward. 18-13C PBU 500292175603 4/13/2012 1 1 F Rank choke being fixed during FS1 TAR this summer and will then be POP’d 18-14C PBU 500292161403 10/10/2012 1 2 Fishing candidate 18-19 PBU 500292159600 9/1/2003 6 7 AnnComm, RWO written and being approved. 18-20 PBU 500292189000 1/29/2015 7 2 RWO completed and POP’d. Came in at high WC. Wellwork on WBL 18-23A PBU 500292189801 7/1/2010 1 5 Well with slotted liner. No possibilities for GSO 18-25A PBU 500292194801 5/2/2003 6 5 Cretaceous leak was found. No future utility. FL was donated to well 18-15. 18-28 PBU 500292256400 8/30/2003 7 5 18-33A PBU 500292259801 12/1/2005 7 3 Wellwork executed to POP well. Evaluating current use of wellbore for production and if poor production then will side track. 18-34 PBU 500292261100 10/1/2000 6 5 Hole in tbg and casing. Cement in tbg and IA. Multiple plugs in tbg. No way to recover this well. 7-18 PBU 500292087900 1/11/2011 6 5 Hole in Surface Casing , Not Operable. No further plans. Well house, flowline and slot will be used for new grass roots well 07-38 scheduled for 2015 7-28 PBU 500292174400 8/1/1990 6 5 8900' of coil stuck in hole. Suspended. No surface facilities or slot. A-01A PBU 500292010801 3/26/2013 3 5 Removed from IPC. Released for sidetrack. A-06 PBU 500292011800 8/24/2012 7 7 Operable. SI for velocity. 2013 Caliper found possible holes in tbg. A-13 PBU 500292067200 10/18/2010 6 5 Removed from IPC. Reservoir abandoned. A-18A PBU 500292063001 6/13/2003 6 5 Removed from IPC. Low IOR, SC hole @ 5'. Possible Welding candidate A-21 PBU 500292071000 6/10/2004 8 5 On ADW list for P&A. A-17 Sidetrack replaced A-21. A-44 using A-21 Facilities. A-33 PBU 500292141000 2/25/2010 2 5 SI for high WC. Released for sidetrack. A-34A PBU 500292133901 3/28/2009 7 2 HOAP - cemented annulus. Well failed the shell test in October, 2013. Well may be candidate for CannSeal/Well lock OA down squeeze. Flagged 6/2014 for inclusion in candidate list. Going to deal with the wells that passed the shell test first so this is a ways out. A-40 PBU 500292233700 9/5/2009 6 1 Hole in SC and failing MIT-IA. Needs SC excavation or RWO. A-41 PBU 500292253000 11/1/2000 3 5 Removed from IPC. Suspended. Reservoir Abandoned. A-42A PBU 500292254201 9/9/2011 3 5 Removed from IPC. Possible conversion or sidetrack. B-02A PBU 500292006601 7/30/2004 6 5 T&A 9/23/06. Failed RWO. Well replaced by B-37. B-02A is suspended per AOGCC sundry. On ADW list for P&A. Well is not included in the IPC. May need to be removed from the LTSI list since it is suspended. B-04A PBU 500292007201 4/17/2013 7 6 Needs FL to be sleeved. B-11 PBU 500292033100 1/1/1991 2 5 T&A. LTSI - No FL ; surface facilities given to B-35. Flag to ADW for P&A. Need Simple secure. B-24 PBU 500292081500 1/1/1993 2 5 LTSI. Replaced by B-13. No FL. Evaluating for P&A B-28 PBU 500292151000 7 5 Not operable Injector no current use. C-02A PBU 500292012301 10/31/2014 6 6 SSV failure C-06B PBU 500292012702 12/20/2013 6 1 Identified hole in TxI. APE developing repair solution. C-38 PBU 500292157100 11/1/1997 6 5 Plan to P&A. Had Cretaceous leak, flowline taken, not a candidate for CST. No current wellbore utilization; resources captured by offset wells. D-18A PBU 500292069401 11/6/2012 6 3 LDL confirmed hole in tbg..Candidate for RST in 2015. Being ST right now. D-24 PBU 500292150600 7/13/2012 6 3 Failed MIT-T. RWO + CST plans for 2015 D-27A PBU 500292154301 4/20/2010 6 5 Tbg holes, Pkr and PC compromised @ 4950'. Decision to move fwd w the RWO. Will be CST after flush production is over. Unable to pull the LTP – now fish (spear) stuck downhole & cannot complete RWO. Will take the flowline for this well & use for new Rotary well D-35. This should be drilled in 2015. This well to be removed from IPC. E-07A PBU 500292045101 12/1/2013 6 5 SC hole at 11'7". Was DPBGL source well for E-102. E-14A PBU 500292078401 9/5/2007 6 5 TxIA Comm & surface csg hole E-18B PBU 500292065402 11/8/2004 6 5 Suspended 2008. Sidetrack 2nd attempt failed. Need Rotary Rig for sidetrack. E-25A PBU 500292177301 8/1/2013 1 5 New well in 2013…came on poorly and WW didn't help. E-31A PBU 500292241101 11/23/2011 6 7 Evaluating for RWO and integrity wellwork E-34A PBU 500292243701 10/22/2014 7 1 None, well work completed in 2015 POPed and online E-39A PBU 500292258701 9/4/2005 6 5 IBP fish stuck in hole. F-07 PBU 500292011900 7/1/1991 6 5 Abandoned during RWO. Flowline removed. No forward plans. F-16A PBU 500292066101 1/29/2007 6 7 LDL on backlog. RWO candidate F-19A PBU 500292062901 11/10/2010 1 5 Sag well w/Slotted liner - no means to SO uniform gas entry F-28C PBU 500292164903 11/29/2014 7 3 Sidetrack planned and completed in 2014. POP 2015 F-34B PBU 500292198002 7/23/2013 1 6 Wellwork planned & Needs choke repair F-35 PBU 500292184300 6/16/2013 7 6 Discussing to swap header lines to gain access LP F-37 PBU 500292197400 6/22/2008 1 5 Considering for Sidetrack. F-41A PBU 500292220301 12/11/2014 7 3 Sidetrack planned and completed in 2014. POP 2015 G-03A PBU 500292022101 12/3/2004 6 5 BHL replaced with G-31B. A RWO failed when scale was found in the 7" tubing due to a cretaceous leak. The only opportunity available for this well is a RST. G-09B PBU 500292058202 7/2/2012 6 1 There are 2 BHA stuck in the well. A SL SOR to fish the top BHA is on the wobble. Evaluating opportunity to shoot perfs in a lens (use G-21 as an archetype). G-13A PBU 500292060001 5/7/2007 6 5 SL found collapsed tubing @ ~47' SLM. G-27A PBU 500292164601 3/29/2013 6 1 WellLock is planned to be used to fix the hole in PC. G-30DXX PBU 500292161304 #N/A 7 5 Developed integrity problem during drilling G-32A PBU 500292163601 8/29/2013 1 5 Not a candidate for well work. Plans to release the well to NWD on 7/15/14. H-04B PBU 500292010402 1/6/2012 6 5 TxIA & SC hole(s). Released for ST. Released flowline too H-40 is a new rotary well that will use H-04B’s flowline. Possibly drilled in late 2015 or early 2016… ideally when ground is frozen. H-10A PBU 500292048701 11/24/1997 6 5 SUSPENDED - lost drill pipe and neutron source when drilling sidetrack. Cemented up to 2293’MD H-11 PBU 500292048500 2/9/2012 6 1 SC hole - working on plan to weld in 2015. Exhibit 10 2014 IPA Shut In Well Report sw_name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments H-12 PBU 500292048400 5/17/1991 6 5 SUSPENDED. NOT OPERABLE.Tubing collasped at 2011'. Well was being flowed back after frac job. Camera confirms casing/tubing collapse. No flowline. H-14B PBU 500292058003 2/17/2015 1 1 Was waiting for PBGL to POP & then perfs didn’t flow. Wellwork brought it online in 01/15 & well was high GOR. 2/24/15 – setting CIBP for a GSO H-16B PBU 500292059202 5/10/2011 6 2 Well has a SC hole – looking at an OA downsqueeze. If this doesn’t work, will redo economics for a RWO H-31 PBU 500292244400 8/28/2013 7 6 Two VSM supports need to be raised – will complete before spring – then need evaluation to determine if line is plastically deformed. H-34 PBU 500292280300 11/4/2004 6 5 NOT OPERABLE TxIA, PC hole. May be potential for a RWO/ST - but no current plans J-01B PBU 500292002002 8/8/2008 6 2 The current plan is to use WellLock to squeeze to stop the IAxOA COMM. The problem with this well is the bubbling in the cellar and re-pressurization of the OA during production. J-03 PBU 500292002500 11/3/2004 6 1 A RWO SOR has been approved and it will be placed on the RWO schedule for 4Q 2014. J-05C PBU 500292012003 9/13/2011 6 1 Awaiting SH Weld J-26 PBU 500292173400 7/29/2011 6 5 Reservoir Abandoned K-09C PBU 500292173603 2/11/2009 6 2 Sealtite failed. Looking at cement squeeze or thermaset, then OrganoSeal. K-10D PBU 500292176205 12/23/2014 7 3 Sidetrack planned and completed in 2014. POP 2015 K-12B PBU 500292175902 12/1/2013 1 5 Operable well SI for HGOR. Great candidate for coil ST. Released for ST. K-13 PBU 500292175700 10/1/1997 6 5 Suspended 2010. Secured well with 500' of cement above production packer and TT plug. K-19A PBU 500292253101 4/22/2009 7 5 PC hole(s) L-01 PBU 500292301100 10/15/2011 3 3 Low PI. Not competetive. Well released. Sidetrack complete 2015. L-02A PBU 500292304801 5/7/2007 3 5 last ditch wellwork evaluated and not competative in current surface constraints. Well released. Possible ST being evaluated. L-03 PBU 500292326900 11/10/2009 7 6 High TGOR, previously unsupported. Plan to static and POP- when U-pad jumper opens and well is more competative. L2-08A PBU 500292176101 7/1/1999 6 5 Evaluating RWO feasibility & possible non-rig fix . Can't flow to LPC due to gas limitations. L2-11 PBU 500292288500 11/1/2008 6 5 RWO pkg is prepared but Partners won't sign due to poor economics. L2-18A PBU 500292176601 9/1/2001 6 5 Tbg and casing damaged. Evaluating repair options and TT CTD options. Plans to P&A L-50 PBU 500292327700 5/7/2007 1 5 No flowline M-01 PBU 500292004200 8/1/1987 7 5 Suspended, replaced with M-28i. No flowline and no MI line. M-05A PBU 500292019401 12/11/2004 6 5 2014 RWO unsuccesful. Collapsed 9-5/8" and thermocase. Released well. M-13A PBU 500292052201 6 5 Production csg leak. Released well. M-14 PBU 500292051200 7/14/2013 6 5 Low value injector. 7" corroded tbg. Released for ST. M-16 PBU 500292061300 7/13/2012 6 1 Not Operable. Hole(s) in SC. On excavation list for this year. M-18B PBU 500292085502 7 6 SI for flowline repairs. Repair scheduled for 2015. M-20A PBU 500292091201 7 6 SI for flowline repairs. Repair scheduled for 2015. M-23 PBU 500292093700 3/17/2013 7 6 Needs GL spool replaced. M-27A PBU 500292199201 7/24/1997 6 5 Being screened for ST. The fish and fill in the well may make ST and kickoff difficult. M-29A PBU 500292190401 7 6 SI for flowline repairs. Repair complete March 2015. M-30 PBU 500292225500 12/31/2011 7 6 SI for flowline repairs. Repair complete March 2015. N-02 PBU 500292008300 7/1/1988 6 5 SUSPENDED. N-24 replaced this well. SC and PC holes. No flowline. N-03 PBU 500292008700 1/1/1996 6 5 NOT OPERABLE: PC hole(s). Well has flowline, but no P-pilot or hydra for SSV and chemical. injection. - Released for ST N-06 PBU 500292009800 8/5/2005 6 5 NOT OPERABLE. Work to P&A. Many down hole fluid barrier issues. Replaced with N- 18A. No flowline. N-07A PBU 500292013701 10/6/2013 3 4 N-30 used this well's flowline in late 2014 & came online 2/21/15. N-07A will be converted to an injector in Q3 2015 as part of N-pad UZI. N-16 PBU 500292088600 8/5/2013 7 1 Well was SI for proactive tree change. Now it is waiting for N2 Lift to help kick off (or else long enough CNG hose)… In schedule for early March 2015 NGI-05 PBU 500292019600 12/26/2013 6 2 Will remain LTSI until more gas injectors are shut in creating the need for more to be fixed. P-18 PBU 500292209700 7/9/2007 6 5 Shallow surface casing hole(s), possible fix with SC excavation but no current use for well, needs a target to pursue SC work. Well is secure with a plug. P-22 PBU 500292239600 12/10/1996 6 5 TxIA comm, probable bad packer, FTS.High risk Wellwork considering obs at 10500 that failed to be milled out. Flowline disconnected. Well available to Res Man for RST. Well Secured with a Plug P-23 PBU 500292239300 11/4/2000 6 5 Holes in tubing and leaking packer, Surface Lines will be given to P-30 pre-produced injector once WTI takes place ~2Q 2015. Will need to fish releasable spear from top patch to secure well. PWDW1-1 PBU 500292022600 7/6/2007 6 5 SI due to poor injectivity resulting from a SSSV fish down-hole. PWDW2-1 PBU 500292022700 2/1/2003 6 5 LTSI Cretaceous Disposal Well, PC hole at 2992', would require redrill R-01 PBU 500292035300 11/1/1993 6 5 Suspended with Ann Comm issues. No flowline or wellhouse. Replaced by R-39. To be used for J-Pad UZI R-02 PBU 500292035400 6/11/2011 6 3 Packer squeeze then ST, in 2015. R-06A PBU 500292038801 6/6/2006 6 6 RWO package sent 5/2013. TxIA, collapsed tbg. RWO 2015. R-08 PBU 500292054800 8/13/2012 6 3 ST 2014. R-10 PBU 500292061800 3/1/2001 6 3 Well is released for ST. Multiple holes in tbg. R-20A PBU 500292064101 6/6/2006 6 5 Surface Casing holes. On RST list. R-22 PBU 500292100500 10/22/2012 6 3 Being screened for a ST. Has TxIA that could be addressed with a patch. R-22A PBU 500292100501 7 6 Did packer squeeze on R22 and sidetrack in Jan 2015, now R22Ai. Waiting for surface tie in now. R-24 PBU 500292123200 10/2/2009 6 1 OA cemented to surface. Builds up too fast to manage w bleeds. Top job candidate. R-30 PBU 500292227900 9/3/2005 6 1 Surface csg excavation under way. Likely ST well after repair. S-04 PBU 500292095900 12/2/2011 6 1 TxIA and flowline repair needed. S-07A PBU 500292082901 2/20/2012 6 5 SH hole(s). Waiting on wells group to progress SH weld. S-13 PBU 500292081000 3/1/2001 6 5 Available for high KO sidetrack. Reservoir Abandmonent program being worked. S-15 PBU 500292111300 9/10/2010 6 2 SC hole(s). RWO might be an option once S-16 and S-32A are back online. S-16 PBU 500292112300 8/4/2004 6 7 SC leak and IAxOA. RWO SOR approved by partners. S-17C PBU 500292114803 11/20/2013 2 1 Water shut off is on the WBL S-19 PBU 500292161100 10/25/2013 1 5 SI For HGOR. Shut the ivishak off and perfed the SAG all Gas S-27B PBU 500292205702 5/2/2013 3 5 Operable. SI for low rate, high wc, otherwise an operable well. BOL and retested w/ portable in 07-07 which confirmed last rate. Plan forward to POP, PPROF, pending WSO. WSO complete but no oil Exhibit 10 2014 IPA Shut In Well Report sw_name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments S-30 PBU 500292205100 8/20/2003 6 5 TxIA. Released for ST. S-32A PBU 500292209901 4/6/2013 7 2 Well has bent flowline and GL line S-34 PBU 500292230500 7/12/2010 6 1 Not operable. IAxOA comm. S-400A PBU 500292328901 11/6/2008 7 5 No longer has a surface drive module. GC2 no longer has water supply issues. S-401 PBU 500292331300 11/6/2008 7 5 No longer has a surface drive module. GC2 no longer has water supply issues. S-40A PBU 500292249401 8/28/2006 6 5 SC hole(s). Eval ST Salamatof. S-44 PBU 500292273500 4/20/2012 2 5 Well is SI for high WC/water handling. Fish in well prevent downhole diagnostics. Release for ST. T-01 PBU 500292124100 7/1/1999 8 5 LTSI Injector, not an effective injector, main line to pad corroded/too expensive to repair T-07 PBU 500292073300 7/1/1999 8 5 LTSI Injector, not an effective injector, main line to pad corroded/too expensive to repair U-02A PBU 500292117001 12/8/2002 6 5 TxIA, PC hole(s); No flowlines. Released to NWD for ST evaluation. Well is not secured. Removed from IPC 6/11/13 U-07 PBU 500292112700 10/15/2011 2 5 Operable. High watercut, no flowline. Released to NWD for ST evaluation. Well is not secured. Removed from IPC U-08A PBU 500292113601 1/1/2002 2 5 Operable. High watercut, no flowline. Released to NWD for ST evaluation. Well is not secured. Removed from IPC 6/11/13 U-09A PBU 500292114401 2/21/2013 7 5 Operable. Rock producer. Well is released to NWD for ST. Removed from IPC 9/18/13 - Not a candidate for FCO (low % success). U-12 PBU 500292140900 7 3 Well has been sidetracked to U-12A and U12AL1 in 2004 and 2011. U-13 PBU 500292035500 7/1/2006 7 5 Operable. Low oil rate. Rock producer w/ fill. Released to NWD for ST eval. Well is not secured. Removed from IPC 10/10/13 - Uneconomic U-15B PBU 500292256502 7/14/2006 2 5 Operable. High watercut, no flowline. Released to NWD for ST evaluation. Well is not secured. Removed from IPC 6/11/13 V-01 PBU 500292321000 11/11/2012 7 6 High TGOR. Not competative in the EWE LDF. W-01A PBU 500292186601 11/17/2013 7 6 SI on high TGOR. POP when space in the EWE LDF. W-09A PBU 500292194701 8/4/2004 6 5 No access to liner to due damaged liner top, never perforated. Wet when drilled. W-10A PBU 500292189301 10/11/2013 7 6 SI on high TGOR. POP when space in the EWE LDF. W-15A PBU 500292204201 1/29/2013 6 5 Cretacious hole(s) detected, Not a candidate to fixor for RWO. Released to NWD team W-25A PBU 500292187401 12/26/2012 3 1 Well loaded up. Needs wellwork- hydrtaed off and now Non-operable. When U-pad W-26A PBU 500292196401 9/15/2013 6 7 Capital RWO/CST submitted to WIOS April. Sidetrack 12/2014. POP 2015. W-27A PBU 500292189401 10/11/2013 7 6 SI for high TGOR W-42 PBU 500292181600 4/9/2013 6 1 GCWI SI due to lapse on state MIT witness. Under Eval for MIT due to derated tubing, based on caliper. Chance of collapsing the tubing. Well Integrity group evaluating path forward; cannot MITIA due to tubing condition (70% tubing loss due to erosion); wellwork on WBL. X-01 PBU 500292039000 3/18/2011 6 8 SI for sustained pressure in OA. Candidate for WI waiver. X-14A PBU 500292047401 12/4/2012 7 5 No current use X-18 PBU 500292067500 4/7/2011 6 5 Identified IAxOA in wellhead. Possible downhole TxIA. X-34 PBU 500292241700 12/31/2008 6 5 SC hole(s) detected. Low IOR. Not a candidate for RWO. Eval RST. POP'd and tested 1/2009. Y-02A PBU 500292039501 10/5/2005 6 5 TxIAxOA GL. Future offtake Y-03Ai.Diagnostic confirm comm is not thru theWH. Rapid OA repressurization. Well is secured with a WRP and cement for reservoir abandonment. Y-08A PBU 500292057201 9/1/1993 6 5 Originally SI for low PI. Now Not Operable - TxIA, PC hole(s) detected. Limited reserve. Y-32 sidetracked into Y-08A area to access reserves. Reservoir abandonment completed, cement to 8,469’ SLM plans for P&A. Y-12 PBU 500292051700 5/1/1999 6 5 TxIAxOA. FTS. Poor tbg condition. Wellbore available to Res Man/Sag Team for sidetrack (ST to east toward Y-34 candidate). Well is secured with a plug and sand over perforations. Y-15A PBU 500292094001 9/21/2010 2 5 High WC - low oil rate and packer leak. PE notes indicate there is an obstruction in liner so 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. Well is secured with a plug, cement behind tubing is acting as our new packer. Y-17B PBU 500292092002 6/16/2002 6 5 SC hole(s) detected; SI wet since the beginning. Plan to plugback to Y-17A perfs for Y- 03i offtake. Wellbore is available to Res Man/Sag Team for Sidetrack. Originally SI for high WC but now has SC hole(s) - well is secured with PX plug. Y-22A PBU 500292155801 1/1/1990 6 5 LTSI…suspended & BHL re-drilled as Y-25 no surface facilities. Removed from IPC - subsurface abandoned Y-24 PBU 500292160800 6/13/2013 6 1 Well failed MIT-IA 6/2013. Patch set in October 2014 passed MIT-IA but well did not have injectivity when we were prepping for AOGCC MIT-IA, Current plans to remove patch and mill out/FCO restriction and establish injectivity. Well work planned for 1Q 2015. Y-25A PBU 500292188301 12/8/2009 6 5 Left liner full of cement during CST. There are no active plans for this wellbore - Removed from IPC - subsurface abandoned Y-26A PBU 500292219101 8/6/2013 3 5 No current plans for the well, low PI. Operable. Not secured. Y-28 PBU 500292216900 6/1/2010 2 5 Low rate high WC well. Operable Well and is available to Res Man/Sag team for sidetrack. Not secured Y-30 PBU 500292213500 1/12/2009 2 5 This area is swept. Mechanically operable well. Wellbore is available for Res Man/Sag Team for Sidetrack. Not secured Y-31 PBU 500292216100 12/4/2007 2 5 SI for high WC. No obvious ST targets. Mechanically operable well. Wellbore is available for Res Man/Sag Team for Sidetrack. Not secured Y-34A PBU 500292217801 12/4/2007 2 5 SI for high WC. Mechanically Operable Well. No obvious ST targets and is available to Res Man/Sag Team for sidetracks. Not secured. Cannot POP well due to saggy FL. Y-37A PBU 500292240301 4/22/2002 6 5 Suspended Well. Coil cemented in hole. RST/Conversion candidate as part of Y-24i Pat reallignment. Removed from IPC - subsurface abandoned. Wellbore is available to Res Man/Sag Team for sidetrack. Y-38 PBU 500292255300 12/13/2002 6 5 TxIA. OAxCond. Collapsed tbg. Wellbore is available to Res Man/Sag Teaml for Sidetrack. Removed from IPC - Uneconomic. P&A complete 4Q 2014. Y-39 PBU 500292351400 2/19/2015 7 2 Drilled August 2014, WTI was prolonged. POP’ed in January 2015, well has OA repressurization, currently performing diagnostics - well is SI. Z-01B PBU 500292183002 2/9/2011 3 5 Low PI LTSI well. Has live downhole gauge which is monitored real time to watch pressure trends in the HSFB during all the infill drilling. Pressure changes are used to adjust injection targets more frequently. Z-05A PBU 500292205601 11/17/2013 2 5 Gas on water when sidetracked. Not competative on TGOR sorts. Some wellwork addperfs with estimated high gor- not competative action in the EWE LDF. Exhibit 10 2014 IPA Shut In Well Report sw_name Field API Number SI Date Reason for Well Shut-InA Future Utility Plans & PossibilitiesB Current Mechanical Condition / Additional Comments Z-08A PBU 500292178701 7/10/2010 7 5 During ST last year rig got milling BHA stuck in the window and could not retrieve the milling BHA. Sidetrack cancelled. Parent P&A. Z-09A PBU 500292196701 8/12/2011 2 5 conversion cancelled due to failure of new drills in the block. No utilization Z-14B PBU 500292184402 1/9/2013 6 1 Larger than expected rocks downhole. Wellwork planned to pump sand consolidation and set screen. On WBL. Z-15 PBU 500292184900 12/17/2010 6 3 Not operable. TxIA. Capital RWO/sidetrack planned for 2015. Z-19A PBU 500292225101 #N/A 6 2 Well has micro-OA repressurization which did not have any wellwork fix until 2015. Z-20 PBU 500292185900 2/9/2013 7 6 High TGOR- not competative in the EWE LDF for total gas, including gas lift usage. If U-pad jumper open, this well at 16k would be marginal. Z-22B PBU 500292203702 12/8/2012 3 5 Well not competitive in the EWE LDF. Low PI well. Z-23B PBU 500292195002 2/10/2013 7 6 Well SI due to low marginals in the EWE LDF. POP when space allows. Z-26A PBU 500292194501 9/23/2012 6 1 Well SI originally for scale downhole. Would not flow. Wellwork not progressed due to high GOR and low marginals. Wellwork submitted to WBL late 2014 after U-pad jumper opened. Z-30A PBU 500292201301 2/9/2013 7 6 High TGOR- not competative in the EWE LDF for total gas, including gas lift usage; high TGOR; Z-31 PBU 500292187100 11/26/2011 7 6 VSM's need repair. until VSM is fixed - put well on injection; looking to fix all VSMs Z-35 PBU 500292288400 4/1/2001 2 5 High WC, no current plans for well; no flowline Z-39A PBU 500292299501 2/10/2013 7 6 High TGOR- not competitive in the EWE LDF for total gas, including gas lift usage; high TGOR; Z-67 PBU 500292344100 12/25/2012 2 9 SI for high WC. Planned conversion to injection approved and construction began. Z-68 PBU 500292349300 9/13/2013 6 5 Well drilled but not perfed. Structural and fluid uncertainties. Likely to be ST. Released. Not tied in on surface- has no flowline Z-70 PBU 500292350000 1/1/2014 6 5 Well wet when drilled. P&A subsurface. Not tied in. SI Code Future Utility Code 1‐ High GOR 1‐ Wellwork Planned 2 ‐ High WC 2‐ Under Evaluation 3 ‐ Low PI 3‐ Sidetrack Planned 4 ‐ Wellwork 4‐ Res Mgmt 5‐ Res Mgmt 5‐ No Current Utilization 6‐ Mech 6‐ Surface Facilities 7‐ Other 7‐ RWO Candidate 8‐ Out of Zone Inject 8‐ Waiting on Waiver 9‐ Conversion Exhibit 11-1 Exhibit 11-2GCWI Water Bank Cross-section Interpretation 2014 Exhibit 12Put River Sandstone Distribution 1-08A