The URL can be used to link to this page

Home My WebLink About2015 Prudhoe Oil and Put River Oil Pools ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL AND PUT RIVER OIL POOL JANUARY THROUGH DECEMBER 2015 2015 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 2016 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 2015 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 - 2015 12 Put River Lobe Map 2015 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 4 1.0 INTRODUCTION As required by Conservation Orders 341F (Approved October 15, 2015) 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 2015. 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 2015 calendar year (Exhibit 10) 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. Relating to condition 5 of CO 547.004 (as amended by CO 547.006), there are currently no Weatherford Gen-2 meters being used in the Prudhoe Bay and Put River Oil Pools. 2015 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 2015, field production averaged 196.4 MBOD, 6879.5 MMSCFD (GOR 38,244 SCF/STB), and 731.4 MBWD (water-cut 80.3 %). Overall Waterflood injection during this period averaged 1468.2 MBWD with 103.49 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2015 was 12,499 MMSTB, while cumulative MI injection was 3,159 BCF. Cumulative production in these same areas (not including Gravity Drainage) since waterflood startup was 2964 MMSTB oil, 13,267 BCF gas, and 8,837 MMSTB water. As of December 31, 2015, cumulative production exceeded injection by 8,176 MMRB compared to 7,779 MMRB at the end of 2014. 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 2013 through 2015 at a datum of 8,800 ft, subsea for the Full Field Dominant Zone. Using the three year rolling technique improves the statistical validity of the pressure distribution since it roughly triples the number of data points employed versus only using the current year static pressures. As in the past, abnormal pressures, such as pressures taken in fault compartments and in the Sag Formation have been removed. As shown in Exhibit 1E, the historic pressure decline appears to have stabilized due to gas-cap water injection with 69% of repeat 2015 pressure surveys found equal to or greater than their 2013 or 2014 pressure measurements. For 2015, average pressure in the PBMGP project areas using three years of pressure static measurements was calculated to be 3,350 psia by areal weighting, as compared to 3348.4 psia in 2014 (Exhibit 1F). The GD area pressure was stable increasing five psi from 3,270 psia in 2014 to 3,275 psia in 2015. This subtle pressure increase is within the expected statistical variation with a different annual pressure sampling data sets. Confirmed MI breakthrough has occurred in 116 wells during the reporting period. RMI production is an indicator of EOR pattern performance and the presence of RMI is determined by gas sample analyses that show a separator gas composition richer in intermediate range hydrocarbon components. MI breakthrough in a well is considered to have occurred when the average RMI rate over the number of producing days in a well exceeds 200 MCF/D. The 2015 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 6 previous year showed MI breakthrough in 119 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 2015 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 2015 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 were 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 2015 pressure map using 2013 through 2015 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 2016 calls for collection of 60 pressure surveys fieldwide. The number of surveys proposed is less than last year. Per administrative approval 341C.01, dated June 22, 1999, a summary of pressure surveys run during 2015 is presented in Exhibit 9. 2015 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 101 producing wells and 59 injection wells that contributed to production/injection during 2015 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 24.9 MBOD for 2015 compared to 25.8 MBOD in 2014. Cumulative production since waterflood start-up through the end of 2015 is 1,092 MMSTB of oil 5,939 BCF of gas, and 4,484 MMSTB of water. Injection rates averaged 400.1 MBWD and 19.19 MMSCFD in 2015. Since 12/31/11, the waterflood imbalance has increased from a cumulative under injection of 2,964 MMRB to 3132 MMRB under injected. During the report period, production exceeded injection by 168 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 2015, is 6,581 MMSTB and 1,056 BCF respectively. The flood area's GOR increased from an average of 23,300 SCF/STB in 2014 to an average of 27,138 SCF/STB in 2015. Gas influx continues along the FS-2/GD GDWFI area, and in the high permeability conglomerates in the Updip Victor area. Water-cut decreased from 93% to 92% from 2014 to 2015. 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 3,398 psia in 2015. This is a decrease of 4 psi over the 2014 pressure. Exhibit 3-D is a presentation of 2015 average returned MI (RMI) rates. Miscible gas return has been confirmed in 18 wells by gas compositional analysis (RMI>200 MSCFD). 2015 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 2015, oil production averaged 16.4 MBOD, as compared to 17.3 MBOD in 2014, with an average 89% water cut and 19,787 SCF/STB Gas Oil Ratio. Injection averaged 139.8 MBWD and 14.59 MMSCFD of miscible injectant (MI). There are a total of 75 producers and 27 injectors in the flood area that contributed to production/injection during 2015. Of the 27 injectors, 2 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 646 MMSTB of oil, 3,448 BSCF of gas, and 1,762 MMSTB of water have been produced with 2,264 MMSTB of water and 678 BSCF of miscible gas injected. Exhibit 4-B shows the monthly injected and produced volumes on a reservoir barrel basis during 2015 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 100 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 3,330 psia in 2015. This is a increase of 6 psi as compared to 2014. 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 15 wells (RMI >200 MSCFD). 2015 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 (no change from 2014), with a gas/oil ratio of 12,883 SCF/STB and a watercut of 86%. Injection averaged 112.6 MBWD of water and 26.42 MMSCFD of miscible injectant. For the WPWZ project, 43 injectors (8 WAG injectors and 33 water injectors, 2 gas injectors), and 101 producers contributed to the production and injection during 2015. 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 2015 was 1,802 MMSTB while cumulative MI injection was 638 BSCF. Cumulative production since waterflood start-up is 538 MMSTB oil, 2,121 BSCF gas, and 1,376 MMSTB water. As of December 31, 2015 cumulative production exceeded injection by 1,444 MMRB. Exhibit 5-B provides the monthly injection and production data from 01/15 through 12/15. During the report period, production exceeded injection by 91 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 3,313 psia in 2015. This is a decrease of 1 psi over the pressure reported in 2014. Exhibit 5-D indicates wells with MI breakthrough and the 12-month averaged returned MI rates. Miscible gas breakthrough has been confirmed in 41 wells by gas compositional analysis. 2015 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 8.8 MBOD, as compared to 7.6 MBOD in 2014, with a gas/oil ratio of 9,922 SCF/STB and a watercut of 84%. Injection averaged 50.6 MBWD and 13.7 MMSCFD of miscible injectant. For the NWFB project, 26 injectors (3 WAG injectors, 21 water injectors, and 2 gas injector), and 63 producers contributed to the production and injection during 2015. 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 2015 was 1,665 MMSTB while cumulative MI injection was 683 BCF as detailed in Exhibit 61-C. Cumulative production since waterflood start-up was 603 MMSTB oil, 1,414 BSCF gas, and 1,036 MMSTB water. As of December 31, 2015 cumulative production exceeded injection by 585 MMRB. Exhibit 6-B provides the monthly injection and production data from 01/15 through 12/15. During the report period, production exceeded injection by 25 MMRB. However, this does not include support obtained from aquifer influx or gas cap expansion. The areally weighted pressure in the NWFB area was 3,335 psia in 2015. This is an increase of 13 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 25 wells by gas compositional analysis. 2015 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 14.4 MBOD, as compared to 13.6 MBOD in 2014, with a gas/oil ratio of 3,953 SCF/STB and water cut of 75%. Injection averaged 38.7 MBWD and 24.9 MMSCFD of miscible gas injectant. For the EWE project, 18 injectors (9 WAG injectors, 9 water injectors and 0 gas injectors), and 64 producers contributed to the production and injection during 2015. The well counts reflect only the active wells for the year. Cumulative water injection from waterflood start-up in September 2001 through December 2015 was 190 MMSTB and cumulative MI injection was 105 BCF. Cumulative production since waterflood start-up was 84 MMSTB oil, 345 BCF gas, and 180 MMSTB water. As of December 31, 2015 cumulative production exceeded injection by 279 MMRB. Exhibit 7-B provides the monthly injection and production data from January 1, 2015 through December 31, 2015. During the report period, production exceeded injection by 13 MMRB. The EWE pressure was 3,645 psia in 2015 representing an average pressure decrease of 7 psi for this area from 2014. Exhibit 7-C indicates wells with MI breakthrough and the 12-month average returned MI rates. Miscible gas breakthrough has been confirmed in 17 wells by gas compositional analysis. 2015 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 2015 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 1/1/2015 3,196 3,136 3,194 3,213 3,200 3,226 3,070 22,234 2/1/2015 2,749 2,709 2,767 2,789 2,757 1,430 2,701 17,903 3/1/2015 2,419 3,240 3,255 3,275 3,257 - 3,225 18,671 4/1/2015 2,422 3,044 3,007 2,979 2,967 - 2,818 17,237 5/1/2015 2,565 2,545 2,609 2,574 2,581 559 2,257 15,689 6/1/2015 1,890 1,910 1,936 1,841 1,783 1,405 1,331 12,097 7/1/2015 2,747 2,851 2,807 2,775 2,791 2,745 2,728 19,445 8/1/2015 2,359 2,307 2,298 2,123 2,327 1,269 2,245 14,927 9/1/2015 1,558 1,501 1,559 1,559 1,553 - 1,431 9,161 10/1/2015 2,009 2,036 2,318 2,304 2,131 1,460 2,024 14,283 11/1/2015 2,749 2,679 2,761 2,784 2,767 2,796 2,636 19,171 12/1/2015 2,711 2,680 2,718 2,763 2,676 2,730 2,727 19,005 The 2015 volume of sea water injected in the PSI wells was 199.8 million barrels. The cumulative volume injected at the end of 2015 was 2.28 billion barrels of sea water since the project startup in 2002. 4.6.1 Observation Well RPM Surveys and Zonal Conformance The RPM (Reservoir Performance Monitor) 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 RPM 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 orange polygon indicates the interpreted current GCWI waterfront and the red outline shows the 2014 interpretation for comparison. The information from the RPM 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 RPM surveillance logs included the following wells: 02-28A, 02-36A, 04-02A, 04-47, 05-02A, 05-23B, 11-04A, 11-31A, 15-36B, 18-20, L1-01, L1-09, L2-13A, and L3-11. 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 east). 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 in Zone 1B. The 2015 logs indicated the largest lateral extent of GCWI 2015 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 13 water front in Zone 2C (similar to 2014 surveillance), 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 in the waterflood area. Surveillance wells for 2015 saturation monitoring were chosen for sufficient coverage in the GCWI area to better define the polygon boundaries as opposed to more repeat logs where water has been seen in the past. This year, several wells (02-28A, 02-36A, 05-02A, 15-36B, L1-09) saw only gas in section. There was no new evidence that water has migrated further west than the 2014 extent. GCW has flooded further south and southeast as evidenced by anomalous water production as far south in 05-01C though somewhat constrained laterally by the mid-field graben structures. A nearby water sample to 05-02A in 05-13B indicated water in section was waterflood water and not GCW, thus GCW may have flooded into the mid-field graben through DS-18. GCW has continued to flood through the waterflood pads DS-11 and DS-4 although differentiating between the two on RPM fluid logs alone is difficult. The largest extent of GCW seen in the Ivishak reservoir remains in Z2C owing to significant lateral continuity of the 24N shale. Several wells, notably the new well 18-35, have seen GCW from Z3 down to bottom of Z1B. It remains unclear if GCW has flooded Z1A in any significant area. As the GCW floodfront propagates to the south, targets in the mid-field graben appear to be at risk of watering out. Scrutiny on the exact leading boundary of the GCWI floodfront in this area is of high importance. Anomalous production continues to aid the investigation of GCWI extent and will provide the basis for selecting wells for more focused surveillance logging in 2016. 4.6.2 2016 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 RPM’s This program will continue as it has in the past by running RPM’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 2016. 4.6.3 Plans for Change in Project Operation No changes to the Gas Cap Water Injection operation are planned for 2016. 2015 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. 2015 Production and Injection For the year 2015, all of the production and injection in the Put River Pool occurred in the Southern Lobe. However, production and injection has been offline since May 2015 due to lack of water injection capabilities. DS-12’s seawater line had integrity issues and has been shut in. DS-01 receives water from DS-12 and does not have access to other sources of water. Since the Put River reservoir is very small, in order to avoid the risk of dropping below bubble point, Put River producers have been SI since May 2015 until injection resumes. Historical data shows that producing just 100 days without injection support could drop reservoir pressure by 500 psi. Production from the Put River Oil Pool in 2015 averaged 710 BOPD for the days the reservoir was in production and 270 BOPD averaged across calendar days. The total production of the Put River Pool comes from two Put River producers, wells 02-23A and 02-27A. 02-14A was originally planned to be rig worked over to mitigate integrity issues and had sliding sleeves inserted for easy access to the Put River. However the addition of the sleeves made the prospect uneconomical and a decision was made to exclude it and perforate the Put River in the future if need be. Those perforations could potentially be accessed if 02-23A or 02-27A fails and cannot justify a rig workover. Injection in the Southern Lobe of the Put River averaged 7,568 BWPD for the days the injector was online and 2,861 BWPD averaged across calendar days. Cumulative Put River water injection is 10.65 MMBW, of which 1.04 MMBW was injected in 2015. The 2015 cumulative production for the Put River Oil Pool was 99 MBO, 861 MBW and 145 MSCF gas. The full life cumulative production for the Put River Oil Pool through December 31, 2015 was 3.21 MMBO and 3.88 MMSCF gas. 2015 Pressures Put River pressures taken during 2015 are listed in Exhibit 9. The Southern Lobe pressure obtained in 02-23A producer in June 2015 measured 3,763 PSI at 8100’ SSTVD. The pressure in 02-27A producer taken in that same month was 3,254 PSI at 8100’ SSTVD. No tracer breakthrough was observed in 2012, 2013, 2014, or 2015 but reservoir connection is evident through pressures. 2016 Surveillance Plan Southern Lobe –Production will continue from wells 02-23A and 02-27A at around 800 BOPD when water injection capabilities are re-established. Voidage replacement ratios will be closely monitored to ensure a VRR of 1.0. Static pressures will be taken periodically through the year to monitor pressure. A pressure was obtained for 02-23A in early 2016. 2015 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS Page 15 Western Lobe - No 2016 production or surveillance planned. Central Lobe - No 2016 production or surveillance planned. 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 2015 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 2015 through December 2015. A total of 85 gas-monitoring logs were run in the PBU of which 55 were cased-hole. Exhibit 1-BWELL COUNT BY FIELD AREAWPWZNWFBEWEFS2EPWZGD2014 AOGCC ReportProducers93 63 68 100 71 434Injectors42 21 17 56 30 52 -WAG1113431 -Water Only31 19 12 51 26 19 -Gas01211322015Producers101 63 64 101 75 469Injectors43 26 18 59 27 52 -WAG839101 -Water Only33 219 56 25 20 -Gas2202231Production Well Status in 2015 -Newly Drilled521006 -Sidetracked or Redrilled3360018Gas Injection Well Status in 2015 -Newly Drilled000000 -Sidetracked or Redrilled000000WAG Injection Well Status in 2015 -Newly Drilled000000 -Sidetracked or Redrilled000000Water Injection Well Status in 2015 -Newly Drilled000000 -Sidetracked or Redrilled300000NOTES:(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-CWaterflood TotalWPWZNWFBFS-2EPWZEWECumulative Production from WF Start-Up through 12/31/15Oil (MMSTB)538603 1092 646842964Gas (BCF)2121 1414 5939 3448 34513267Water (MMSTB)1376 1036 4484 1762 1808837Cumulative Injection from WF Start-Up through 12/31/15Water (MMSTB)1802 1665 6581 2264 18712499MI (BCF)638683 1056 678 1053159Cumulative 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 -266-7779Cumulative Balance from WF Start-Up through 12/31/15Cum Production (MMRB)3705 2669 10451 5485 52822838Cum Injection (MMRB)2261 2085 7319 2748 24914661Over/Under (MMRB)-1444 -585 -3132 -2737 -279-8176MI Breakthrough in Producing Wells> 200 mcfd3520351910119AVERAGE RATE DATA 2015ProductionOil (MBD)21.08.8 24.9 16.4 14.485.5Gas (MMSCFD)270.7 87.5 676.4 325.1 52.21411.9Water (MBD)131.1 46.0 280.4 131.6 39.1628.2InjectionWater (MBD)112.6 50.6 400.1 139.8 38.7741.9Gas (MMSCFD)26.4 13.7 19.2 14.6 24.998.7AVERAGE RESERVOIR PRESSURE (psia)GDWPWZNWFBFS-2EPWZEWEPBMGPPrevious report period: 20143270 3314 3322 3402 3324 36523348Current report period: 20153275 3313 3335 3398 3330 36453350Estimated Annual Change (psi/yr)5-113-46-72Waterflood Project Area Exhibit 1-F Units=psia 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-GEOA MI Rate MMP MWMCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/15 67,763 3,150 32.44 19.79% 33.13% 19.55% 24.70% 1.96% 0.87% 0.00%02/15 71,258 3,356 33.00 20.93% 36.46% 19.55% 24.32% 1.69% 0.62% 0.00%03/15 66,413 3,229 32.15 19.71% 33.75% 20.12% 23.81% 1.75% 0.86% 0.00%04/15 50,936 3,342 32.06 20.83% 34.61% 19.44% 22.13% 2.01% 0.98% 0.00%05/15 14,951 3,288 32.18 20.61% 33.99% 20.01% 22.21% 2.03% 1.15% 0.00%06/15 17,408 3,209 32.43 20.39% 33.86% 19.00% 23.07% 2.03% 1.65% 0.00%07/15 26,641 3,107 32.68 20.14% 32.66% 19.43% 24.25% 2.18% 1.34% 0.00%08/15 28,866 3,192 32.28 19.53% 33.88% 19.77% 23.40% 2.12% 1.30% 0.00%09/15 19,941 3,348 31.80 19.65% 35.50% 19.21% 22.93% 1.70% 1.00% 0.00%10/15 17,575 3,242 32.10 19.62% 34.24% 19.46% 24.10% 1.68% 0.91% 0.00%11/15 18,251 3,339 31.72 19.23% 35.58% 19.22% 23.67% 1.59% 0.71% 0.00%12/15 8,908 3,415 30.43 18.40% 35.30% 18.66% 22.34% 1.48% 0.61% 0.00%Average 33,852 3,267 32.10 19.89% 34.39% 19.45% 23.41% 1.85% 1.00% 0.00%WOAMI Rate MMP MWMCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/15 124,586 3,147 32.45 19.81% 33.08% 19.56% 24.72% 1.95% 0.87% 0.00%02/15 102,030 3,318 31.96 20.20% 34.37% 19.90% 23.29% 1.64% 0.60% 0.00%03/15 132,164 3,313 32.02 20.31% 34.37% 19.79% 22.96% 1.73% 0.83% 0.00%04/15 128,162 3,332 32.03 20.48% 34.77% 19.42% 22.28% 2.04% 1.01% 0.00%05/15 115,493 3,265 32.25 20.58% 33.92% 19.61% 22.74% 2.01% 1.14% 0.00%06/15 87,278 3,143 32.60 20.20% 33.24% 19.01% 23.93% 1.99% 1.63% 0.00%07/15 95,669 3,090 32.59 19.55% 32.45% 20.39% 24.21% 2.10% 1.31% 0.00%08/15 67,664 3,180 32.24 19.14% 34.01% 19.80% 23.60% 2.12% 1.34% 0.00%09/15 101,816 3,369 31.63 19.18% 35.96% 19.27% 23.08% 1.50% 0.99% 0.00%10/15 106,225 3,351 31.61 18.71% 36.32% 18.88% 23.45% 1.66% 0.98% 0.00%11/15 116,408 3,401 31.42 18.64% 36.75% 18.93% 23.46% 1.54% 0.68% 0.00%12/15 99,265 3,328 32.78 19.91% 36.39% 20.21% 24.44% 1.62% 0.67% 0.00%Average 106,410 3,269 32.14 19.72% 34.63% 19.57% 23.52% 1.83% 1.01% 0.00%Average Monthly Mole%Average Monthly Mole% Exhibit 2Produced Fluids (MMRB)JanuaryFebruaryMarchApril MayJuneOil8.6 7.5 8.8 8.5 8.0 7.0Free Gas199.8 173.9 209.0 197.4 182.4 152.8Water0.0 26.5 30.5 30.0 28.3 23.0TOTAL208.4 207.9 248.3 235.9 218.8 182.8Injected Fluids(MMRB)Water53.9 46.2 49.9 47.0 42.3 34.5Gas194.9 169.9 204.4 193.2 177.7 148.8TOTAL248.8 216.2 254.3 240.2 220.1 183.3Net Injection Volumes = Injection - Production (MMRB)TOTAL40.3 8.3 6.0 4.3 1.3 0.6Produced Fluids1/1/2015 -(MMRB)JulyAugust September October November December 12/31/2015Oil6.7 5.8 7.4 8.7 8.8 9.0 94.7Free Gas145.0 135.5 179.7 170.9 202.8 213.6 2,162.9Water23.9 17.4 20.2 28.0 28.5 30.3 286.8TOTAL175.7 158.6 207.3 207.6 240.1 253.0 2,544.4Injected Fluids(MMRB)Water45.4 34.3 29.0 38.1 43.7 45.8 510.1Gas141.0 131.3 176.4 189.8 197.7 208.4 2,133.7TOTAL186.3 165.6 205.4 227.9 241.5 254.2 2,643.8Net Injection Volumes = Injection - Production (MMRB)TOTAL10.7 7.0 -1.9 20.2 1.4 1.2 99.4 Exhibit 3-A Exhibit 3-BProduced Fluids Cumulative(MMRB)12/31/2014 January February March April May JuneFluid Properties Used Oil1,421.7 0.974 0.888 0.999 1.059 1.077 0.943 Bo (rb/stb) 1.324Free Gas4,166.4 15.382 13.915 15.828 18.123 19.468 16.578 Bg (rb/mscf) 0.862Water4,538.0 0.000 10.232 11.332 11.290 10.657 8.791 *Bw (rb/stb) 1.040TOTAL10,126.1 16.356 25.036 28.160 30.472 31.202 26.313 Bmi (rb/mscf) 0.700Rs (scf/stb) 620.8Injected Fluids(MMRB)Water6,467.6 15.140 13.956 15.871 15.277 13.856 11.111Gas694.2 1.094 1.120 1.092 0.792 0.267 0.088TOTAL7,161.9 16.234 15.076 16.963 16.068 14.122 11.200Net Injection Volumes = Injection - Production (MMRB)TOTAL-2,526.2 -0.1 -10.0 -11.2 -14.4 -17.1 -15.1Produced FluidsCumulative(MMRB)July August September October November December 12/31/2015Oil1.082 0.989 0.861 1.064 1.012 1.095 1,433.7Free Gas19.867 20.943 15.443 15.522 16.438 18.396 4,372.3Water9.988 7.419 7.511 9.894 9.155 10.170 4,644.4TOTAL30.937 29.351 23.815 26.480 26.605 29.662 10,450.5Injected Fluids(MMRB)Water12.281 9.235 9.495 11.804 11.386 12.457 6,619.5Gas0.188 0.263 0.000 0.000 0.000 0.000 699.1TOTAL12.469 9.497 9.495 11.804 11.386 12.457 7,318.7Net Injection Volumes = Injection - Production (MMRB)TOTAL-18.5 -19.9 -14.3 -14.7 -15.2 -17.2 -3,131.8 Exhibit 3-D Exhibit 4A Exhibit 4-BProduced FluidsCumulative(MMRB)12/31/2014 January February March April May JuneOil841.8 0.746 0.626 0.779 0.782 0.758 0.525 Bo (rb/stb) 1.321Free Gas2,521.8 10.911 9.077 10.899 9.714 9.128 7.135 Bg (rb/mscf) 0.872Water1,963.9 0.000 4.719 5.621 5.753 5.496 3.743 Bw (rb/stb) 1.040TOTAL5,327.5 11.657 14.421 17.299 16.249 15.381 11.403 Bmi (rb/mscf) 0.700Rs (scf/stb) 614.0Injected Fluids(MMRB)Water2,250.3 6.178 5.308 5.065 5.140 4.794 4.075Gas440.9 0.372 0.276 0.349 0.278 0.052 0.277TOTAL2,691.3 6.550 5.584 5.415 5.417 4.845 4.352Net Injection Volumes = Injection - Production (MMRB)TOTAL-2333.3 -5.1 -8.8 -11.9 -10.8 -10.5 -7.1Produced FluidsCumulative(MMRB)July August September October November December 12/31/2015Oil0.345 0.493 0.524 0.685 0.782 0.877 849.7Free Gas4.711 4.763 6.186 6.588 9.254 10.935 2,621.1Water2.759 2.647 3.219 4.675 5.401 5.937 2,013.9TOTAL7.815 7.903 9.929 11.947 15.436 17.749 5,484.7Injected Fluids(MMRB)Water4.028 2.481 3.753 3.880 3.939 4.433 2,303.4Gas0.390 0.358 0.419 0.381 0.383 0.193 444.7TOTAL4.418 2.839 4.171 4.261 4.323 4.626 2,748.1Net Injection Volumes = Injection - Production (MMRB)TOTAL-3.4 -5.1 -5.8 -7.7 -11.1 -13.1 -2736.5Fluid Properties Used Exhibit 4-D Exhibit 5-A Exhibit 5-BProduced FluidsCumulative(MMRB)12/31/2014 January February March April May JuneOil704.3 1.004 0.852 0.886 0.986 0.909 0.784 Bo (rb/stb) 1.322Free Gas1,478.4 8.584 6.898 7.365 7.358 7.301 6.619 Bg (rb/mscf) 0.869Water1,381.7 0.000 4.295 4.922 4.995 4.639 4.066 Bw (rb/stb) 1.040TOTAL3,564.4 9.588 12.045 13.173 13.338 12.849 11.468 Bmi (rb/mscf) 0.700Rs (scf/stb) 616.2Injected Fluids(MMRB)Water1,791.8 3.758 3.207 4.091 4.058 3.358 3.153Gas419.4 0.966 0.621 0.882 0.674 0.390 0.236TOTAL2,211.2 4.724 3.829 4.973 4.732 3.748 3.389Net Injection Volumes = Injection - Production (MMRB)TOTAL-1109.2 -4.9 -8.2 -8.2 -8.6 -9.1 -8.1Produced FluidsCumulative(MMRB)July August September October November December 12/31/2015Oil0.828 0.535 0.611 0.881 0.922 0.941 714.4Free Gas6.387 4.057 5.824 6.050 6.884 7.492 1,559.3Water4.844 2.777 3.896 4.802 5.021 5.517 1,431.4TOTAL12.059 7.369 10.331 11.733 12.828 13.950 3,705.1Injected Fluids(MMRB)Water4.340 2.475 2.901 3.634 3.770 4.002 1,834.5Gas0.367 0.322 0.375 0.494 0.939 0.485 426.2TOTAL4.707 2.797 3.276 4.128 4.710 4.487 2,260.7Net Injection Volumes = Injection - Production (MMRB)TOTAL-7.4 -4.6 -7.1 -7.6 -8.1 -9.5 -1444.4Fluid Properties Used Exhibit 5-D Exhibit 6-A Exhibit 6-BProduced FluidsCumulative(MMRB)12/31/2014JanuaryFebruaryMarch April MayJuneOil754.8 0.279 0.264 0.333 0.270 0.263 0.257 Bo (rb/stb) 1.318Free Gas853.3 1.985 1.843 2.325 2.123 1.697 1.414 Bg (rb/mscf) 0.882Water1,013.1 0.000 1.682 1.998 1.245 1.415 1.443 Bw (rb/stb) 1.040TOTAL2,621.2 2.264 3.788 4.656 3.637 3.375 3.114 Bmi (rb/mscf) 0.700Rs (scf/stb) 607.3Injected Fluids(MMRB)Water1,608.8 1.852 1.688 1.795 1.523 1.254 1.050Gas426.3 0.112 0.090 0.148 0.343 0.600 0.422TOTAL2,062.0 1.964 1.777 1.943 1.866 1.853 1.472Net Injection Volumes = Injection - Production (MMRB)TOTAL-479.2 -0.3 -2.0 -2.7 -1.8 -1.5 -1.6Produced FluidsCumulative(MMRB)JulyAugustSeptemberOctoberNovemberDecember12/31/2015Oil0.360 0.289 0.352 0.589 0.546 0.441 759.0Free Gas1.936 1.944 2.159 2.526 3.500 2.961 879.7Water1.404 0.954 1.042 2.335 2.224 1.703 1,030.6TOTAL3.700 3.186 3.553 5.451 6.269 5.106 2,669.3Injected Fluids(MMRB)Water1.381 2.302 1.308 1.581 1.715 1.767 1,626.8Gas0.265 0.089 0.218 0.464 0.460 0.278 429.8TOTAL1.646 2.391 1.526 2.044 2.174 2.045 2,084.7Net Injection Volumes = Injection - Production (MMRB)TOTAL-2.1 -0.8 -2.0 -3.4 -4.1 -3.1 -584.6Fluid Properties Exhibit 6-D Exhibit 7-A Exhibit 7-BProduced FluidsCumulative(MMRB)12/31/2014 January February March April May JuneOil104.9 0.681 0.592 0.643 0.640 0.562 0.486 Bo (rb/stb) 1.344Free Gas218.4 1.136 1.030 1.069 1.113 0.980 0.826 Bg (rb/mscf) 0.800Water170.7 0.000 1.115 1.254 1.323 1.317 1.264 Bw (rb/stb) 1.040TOTAL493.9 1.817 2.738 2.966 3.076 2.859 2.576 Bmi (rb/mscf) 0.700Rs (scf/stb) 667.8Injected Fluids(MMRB)Water151.8 1.446 1.324 1.439 1.184 1.218 1.258Gas62.0 0.531 0.265 0.585 0.636 0.675 0.404TOTAL227.9 1.977 1.589 2.024 1.820 1.893 1.662Net Injection Volumes = Injection - Production (MMRB)TOTAL-227.7 0.2 -1.1 -0.9 -1.3 -1.0 -0.9Produced FluidsCumulative(MMRB)July August September October November December 12/31/2015Oil0.569 0.451 0.519 0.652 0.606 0.640 111.9Free Gas0.955 0.858 0.859 1.146 1.158 1.035 230.5Water1.510 1.039 1.025 1.695 1.592 1.710 185.5TOTAL3.034 2.348 2.403 3.494 3.355 3.385 528.0Injected Fluids(MMRB)Water1.396 0.928 0.916 0.948 1.296 1.356 165.3Gas0.738 0.499 0.700 0.472 0.325 0.527 68.3TOTAL2.134 1.427 1.616 1.420 1.622 1.882 249.0Net Injection Volumes = Injection - Production (MMRB)TOTAL-0.9 -0.9 -0.8 -2.1 -1.7 -1.5 -279.0Fluid Properties Used Exhibit 7-C Exhbit 8 # Well Log Date OH / CH GOC (MD) GOC (TVDSS) # Well Log Date OH / CH GOC (MD) GOC (TVDSS) 102‐41 10‐Oct‐15 OH 12,659 8,944 1 01‐16 12‐Sep‐15 CH Not present over logged interval 203‐01A 14‐Feb‐15 CH Not present over logged interval 2 01‐29 1‐Sep‐15 CH Not present over logged interval 303‐31A 28‐Jan‐15 OH Not present over logged interval 3 02‐28A 3‐Sep‐15 CH Not present over logged interval 407‐07C 1‐Jun‐15 OH 13,888 8,965 4 02‐36A 20‐Aug‐15 CH Not present over logged interval 507‐33C 29‐Apr‐15 CH 10,994 8,849 5 04‐02A 15‐Jun‐15 CH 9,145 8,541 607‐34B 5‐Jul‐15 OH 9,939 8,932 6 04‐03 25‐Nov‐15 CH 10,231 8,636 707‐38 2‐Sep‐15 OH 12,382 8,956 7 04‐47 8‐Sep‐15 CH 11,585 8,538 811‐30A 31‐Jan‐15 CH 13,952 8,694 8 05‐02A 1‐Sep‐15 CH Not present over logged interval 911‐32A 15‐Dec‐15 CH Not present over logged interval 9 05‐23B 5‐Dec‐15 CH 10,082.7 8,692.7 10 11‐40 6‐Nov‐15 OH 12,657 8,646 10 07‐07C 19‐Jun‐15 CH 13,888 8,965 11 15‐07D 6‐Nov‐15 CH 12,895 8,615 11 07‐25A 10‐Feb‐15 CH 9,884.8 8,942.4 12 15‐49C 17‐Oct‐15 CH 11,608 8,756 12 07‐35A 5‐Oct‐15 CH 9,380 8,912 13 18‐07C 1‐Oct‐15 CH 12,630 8,663 13 09‐06 26‐Jun‐15 CH Not present over logged interval 14 18‐35 7‐Dec‐15 OH 9,364 8,346 14 11‐04A 6‐Jul‐15 CH 8,895.6 8,574.5 15 D‐18B 9‐Mar‐15 CH 10,781 8,839 15 11‐22A 25‐Jan‐15 CH 10,303.8 8,628.6 16 D‐24A 7‐Apr‐15 CH 10,847 8,918 16 11‐31A 28‐Oct‐15 CH 9,178 8,479 17 D‐35 9‐Dec‐15 OH 9,418 8,928 17 12‐29 23‐Nov‐15 CH 10,369 8,796 18 E‐15E 14‐May‐15 CH 10,865 8,873 18 13‐13A 29‐Aug‐15 CH Not present over logged interval 19 F‐15B 19‐Jul‐15 CH 9,524 8,954 19 14‐18B 29‐Apr‐15 CH 10,921.6 8,758.4 20 F‐23B 8‐May‐15 CH 10,767 8,958 20 15‐36B 3‐Sep‐15 CH Not present over logged interval 21 G‐02C 6‐Jun‐15 CH Not present over logged interval 21 18‐20 8‐Apr‐15 CH 12,150 8,715 22 G‐07A 12‐Sep‐15 CH 11,274.6 8,888.8 22 C‐08B 12‐Jan‐15 CH 11,241 8,869 23 G‐10D 4‐Dec‐15 CH 9,864 8,910.4 23 C‐12C 6‐Jan‐15 CH 12,020 8,958 24 G‐16B 24‐Mar‐15 CH 10,070 8,940 24 D‐10 16‐Sep‐15 CH 10,892.7 8,844.7 25 H‐26A 13‐Jan‐15 CH 9,737 8,817 25 D‐24A 4‐Nov‐15 CH 10,847.7 8,918 26 H‐40 26‐Aug‐15 OH 9,867 8,903 26 D‐35 31‐Dec‐15 CH 9,417 8,927.5 27 J‐10B 17‐Aug‐15 CH 9,608 8,945 27 E‐12 12‐Jun‐15 CH 9,095.7 8,940.5 28 K‐06D 25‐Apr‐15 CH 12,575 9,012 28 E‐27A 5‐Jun‐15 CH 9,600 8,866 29 K‐10D 8‐Jan‐15 CH 13,137 8,648 29 F‐42A 17‐Dec‐15 CH 10,925.6 8,848.6 30 Z‐15A 27‐Jul‐15 OH Not present over logged interval 30 H‐08 19‐Mar‐15 CH 9,363 8,885 31 H‐19C 25‐Mar‐15 CH Not present over logged interval 32 H‐27A 11‐Jul‐15 CH 11,218 8,916.4 33 H‐30 25‐Apr‐15 CH 11,350.2 8,920.4 34 J‐03 1‐Jul‐15 CH 9,947.8 8,845.8 35 J‐06 2‐Jul‐15 CH 11,255 8,845 36 J‐13A 10‐Jun‐15 CH 11,149 8,861 37 L‐01A 5‐Oct‐15 CH Not present over logged interval 38 L2‐13A 19‐Oct‐15 CH 10,249.5 8,552.4 39 N‐06 25‐Sep‐15 CH Log inconclusive 40 N‐17 8‐Jun‐15 CH 8,963.6 8,711 41 N‐17 30‐Jul‐15 CH 8,963.6 8,711 42 N‐21A 12‐Nov‐15 CH 11,076.7 8,839 43 N‐28 15‐Sep‐15 CH 10,089.7 8,751 44 N‐29 15‐Sep‐15 CH 10,035 8,774.6 45 N‐30 11‐Dec‐15 CH 9,650 8,806.5 46 R‐08AL1 12‐Jul‐15 CH Not present over logged interval 47 R‐17B 21‐Mar‐15 CH Not present over logged interval 48 R‐41 4‐Dec‐15 CH Not present over logged interval 49 S‐28B 24‐Jan‐15 CH 10,049 8,806 50 S‐129 26‐Mar‐15 CH Not present over logged interval 51 W‐06A 21‐Apr‐15 CH Not present over logged interval 52 W‐36 4‐Apr‐15 CH 9,501 8,878 53 W‐37A 4‐Apr‐15 CH 10,069 8,860 54 W‐51 23‐Jun‐15 CH Log inconclusive 2015 Drilling 2015 Surveillance OH ‐ Open Hole Log CH ‐ Cased Hole Log Exhibit 91. 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)01-05B 500292007602 O6401508598-87118/13/15 307.SBHP187. 8,599.69 2,548.218,8000.09 2,566.603-21500292099000 O6401508673-8692, 8774-8798, 8798-8804, 8804-8827, 8827-8831, 8831-8841, 8841-8845, 8845-8863, 8863-8865, 8865-8884, 8908-8909, 8908-8930, 8908-8955, 8909-8915, 8915-8930, 8930-8955, 8965-89748/22/15 362.SBHP190.76 8,775.14 3,363.98,8000.43 3,374.603-36A 500292234001 GI6401509043-9043, 9043-9044, 9044-9044, 9046-9046, 9046-9047, 9047-9045, 9047-90476/24/15 1,235.SBHP178.93 8,799.66 3,355.978,8000.42 3,356.1104-02A 500292008801 O6401508665-8681, 8691-8695, 8701-8705, 8711-8721, 8760-8768, 8800-8816, 8832-88517/20/15 2,093.SBHP176.4 8,800.22 3,329.958,8000.36 3,341.304-02A 500292008801 O6401508665-8681, 8691-8695, 8701-8705, 8711-8721, 8760-8768, 8800-8816, 8832-88518/26/15 2,982.SBHP171.22 8,700.3 3,341.48,8000.31 3,360.804-16A 500292097701 O6401508688-8706, 8718-8730, 8744-8749, 8808-8824, 8825-8827, 8826-8828, 8829-8839, 8843-8854, 8850-8857, 8853-8853, 8857-8854, 8858-885110/25/15 776.SBHP174.85 8,500.36 3,075.058,8000.33 3,173.104-18500292152100 O6401508653-8663, 8706-8719, 8725-87464/22/15 10,752.SBHP179.8 8,651.4 3,276.28,8000.41 3,343.904-20500292099600 WI6401508612-8627, 8627-8643, 8651-8652, 8654-8655, 8657-8658, 8660-8661, 8663-8664, 8666-8667, 8671-8671, 8676-8677, 8683-8684, 8685-8686, 8690-8690, 8691-8692, 8695-8715, 8717-873910/5/15 181.SBHP144.11 8,597.57 3,679.18,8000.44 3,767.04-20500292099600 WI6401508612-8627, 8627-8643, 8651-8652, 8654-8655, 8657-8658, 8660-8661, 8663-8664, 8666-8667, 8671-8671, 8676-8677, 8683-8684, 8685-8686, 8690-8690, 8691-8692, 8695-8715, 8717-873910/5/15 181.2SBHP8,797.17 3,767.8,8000.44 3,766.0404-22A 500292145401 O6401508677-8734, 8714-8698, 8716-8714, 8725-8718, 8736-87294/1/15 216.SBHP169.68 8,600.18 3,275.78,8000.43 3,362.04-36500292216200 O6401508743-8752, 8752-8761, 8780-87958/25/15 39,694.SBHP180. 8,700.16 3,147.488,8000.41 3,188.804-48500292249800 O6401508690-8694, 8694-8700, 8780-8785, 8791-8795, 8801-8804, 8814-8820, 8827-8833, 8871-8890, 8897-8916, 8925-89445/16/15 30,073.SBHP176.14 8,599.57 3,272.058,8000.44 3,359.809-01500292018800 O6401508764-8782, 8799-8808, 8799-8826, 8808-8821, 8808-8826, 8821-8826, 8875-8888, 8901-8903, 8903-8907, 8903-8911, 8903-8930, 8907-8911, 8911-8930, 8930-8935, 8944-8961, 8944-8979, 8961-8979, 8990-9004, 9013-90276/22/15 7,866.SBHP189.04 8,798.08 3,404.98,8000.31 3,405.509-02500292019800 O6401508785-8798, 8805-8809, 8805-8821, 8805-8849, 8809-8821, 8821-8825, 8821-8849, 8825-8825, 8825-8833, 8825-8849, 8833-8849, 8864-8871, 8864-8874, 8864-8877, 8864-8903, 8871-8874, 8874-8877, 8877-8888, 8877-8903, 8888-8896, 8896-8903, 8916-8918, 8918-8924, 8918-8936, 8924-8936, 8948-8956, 8961-8972, 8980-8987, 9014-9020, 9031-90396/3/15 6,447.SBHP186.45 8,797.44 3,374.768,8000.23 3,374.809-11500292023600 WI6401508853-8854, 8853-8858, 8854-8856, 8856-8858, 8866-8869, 8869-8871, 8869-8885, 8871-8885, 8906-8909, 8922-8925, 8922-8927, 8925-8927, 8931-8934, 8934-8936, 8934-8948, 8936-8948, 8960-8965, 8965-8966, 8965-8982, 8966-8982, 8989-8998, 9014-9015, 9015-9021, 9021-9022, 9024-9026, 9041-9044, 9051-90568/24/15 5,767.SBHP180.68 8,799.83 3,312.758,8000.11 3,312.809-28A 500292129201 O6401508580-8584, 8587-8595, 8598-8606, 8610-8620, 8623-8637, 8644-8654, 8680-8681, 8680-8693, 8681-8688, 8681-8693, 8688-8693, 8693-8707, 8707-8707, 8726-8728, 8728-8732, 8872-8885, 8916-8924, 8989-90606/20/15 345.SBHP165.35 8,600.22 3,322.958,8000.43 3,408.809-29500292142200 O6401508622-8651, 8651-8653, 8661-8675, 8675-8688, 8693-8697, 8719-8727, 8727-8732, 8732-8738, 8747-8749, 8747-8751, 8749-8751, 8757-8761, 8761-8772, 8772-8780, 8964-8988, 8995-8999, 9003-9008, 9011-9016, 9020-9025, 9020-9035, 9025-9028, 9028-903510/2/15 19,649.SBHP179.12 8,649.88 3,300.8,8000.44 3,365.809-37500292245100 WI6401508839-8845, 8874-8880, 8889-8902, 8927-8940, 8989-90277/13/15 45,085.SBHP170. 8,600.12 3,412.528,8000.41 3,412.609-49500292231700 O6401508766-8771, 8774-8777, 8777-8793, 8777-8798, 8793-8798, 8798-8807, 8868-8880, 8901-8910, 8960-8967, 8975-8978, 9045-90566/6/15 32,500.63SBHP183.47 8,799.89 3,332.868,8000.40 3,333.09-51500292232000 GI6401508847-8862, 8926-8941, 8957-8972, 9019-9023, 9045-90527/13/15 22,480.SBHP179.78 8,599.93 3,306.898,8000.43 3,355.811-10500292139400 WI6401508710-8725, 8710-8739, 8725-87393/19/15 7,639.SBHP86.22 8,661.61 3,278.218,8000.43 3,337.811-12500292121200 O6401508680-8684, 8820-8839, 8861-8875, 8896-8903, 8935-8953, 8963-8968, 8963-8969, 8968-8969, 8979-904111/20/15 1,585.SBHP184.1 8,693.73 3,294.668,8000.39 3,333.311-22A 500292203501 O6401508682-8686, 8700-8704, 8811-8814, 8829-8833, 8856-8860, 8947-8962, 8986-8979, 8986-8986, 8987-89862/21/15 5,197.SBHP158.44 8,798.77 3,317.138,8000.36 3,317.111-32500292251200 O6401508600-8605, 8621-8626, 8645-8646, 8645-8650, 8646-8650, 8650-8659, 8664-8670, 8685-8688, 8688-8693, 8693-8694, 8737-8744, 8744-8755, 8744-8762, 8755-87623/25/15 3,995.SBHP166.7 8,626.24 3,245.8,8000.45 3,322.4611-39500292351800 O6401508690-8679, 8709-8698, 8725-8711, 8731-8736, 8758-87572/23/15 192.PBU8,009.988,8003,499.12-05A 500292039101 O6401508739-8752, 8753-8754, 8754-87538/4/15 1,270.SBHP188.4 8,600. 2,460.68,8000.44 2,547.812-06A 500292040101 O6401508753-8764, 8764-8774, 8851-8867, 8867-8869, 8867-8885, 8869-8885, 8887-8913, 8925-89671/30/15 661.SBHP195.2 8,800.14 3,304.18,8000.44 3,304.12-12A 500292061001 O6401508698-8700, 8734-87008/3/15 1,257.SBHP185.9 8,600.2 2,287.98,8000.44 2,374.912-14A 500292065901 O6401508981-8993, 8989-8989, 8990-8991, 8994-8991, 9021-9006, 9023-9025, 9026-9026, 9029-9028, 9035-9038, 9037-90365/20/15 206.SBHP207.46 8,800.29 3,273.888,8000.42 3,273.812-15500292091800 O6401508920-8935, 9010-9038, 9010-9052, 9038-9052, 9063-9067, 9094-91085/7/15 4,855.92SBHP212.13 8,800.03 3,281.048,8000.43 3,281.0312-36500292260600 O6401508887-90455/8/15 4591SBHP216.84 8,799.93 3,284.098,8000.43 3,284.114-05A 500292032701 O6401508711-8724, 8729-8741, 8802-8812, 8816-8822, 8827-8836, 8839-8840, 8839-8848, 8840-8848, 8848-8849, 8852-8853, 8852-8861, 8853-8855, 8855-8861, 8861-8873, 8861-8874, 8861-8875, 8873-8874, 8874-8875, 8882-8891, 8896-89017/21/15 406.SBHP219.7 8,793.74 3,268.98,8000.19 3,269.814-11A 500292052901 O6401508828-8830, 8830-8841, 8877-8993, 9009-89124/14/15 15,622.SBHP222.83 8,803.17 3,297.828,8000.34 3,297.714-12500292063100 O6401508652-8671, 8813-8842, 8847-8856, 8869-8898, 8903-8909, 8909-892410/5/15 2,039.SBHP219.6 8,800.08 3,302.528,8000.43 3,302.514-26500292063200 O6401508791-8792, 8792-8799, 8792-8806, 8799-8800, 8800-8806, 8822-8841, 8884-8896, 8896-8906, 8910-8914, 8916-8923, 8923-8946, 8923-8961, 8946-8961, 8964-896912/10/15 28,427.68SBHP216.32 8,799.83 3,329.188,8000.43 3,329.314-29500292068000 O6401508692-8701, 8701-8703, 8703-8707, 8726-8745, 8869-8903, 8906-8912, 8917-8936, 8941-8968, 9041-904312/20/15 10,392.88SBHP200.21 8,276.07 3,210.078,8000.10 3,262.714-38500292186200 O6401508845-8857, 8875-8892, 8936-8939, 8944-8950, 8952-8963, 8966-8989, 9000-9003, 9004-9016, 9025-9031, 9032-903811/1/15 178,702.SBHP223.5 8,886.74 3,419.618,8000.46 3,381.9814-40A 500292187501 O6401509028-90277/24/15 839.SBHP220. 8,799.96 3,324.18,8000.42 3,324.115-45C 500292267103 O6401508755-8755, 8756-8756, 8756-8757, 8757-8758, 8759-8758, 8759-8759, 8783-8788, 8789-8798, 8801-880710/27/15 1,034.SBHP180.4 8,600.04 3,282.38,8000.31 3,343.516-03500292055400 WI6401508962-8972, 8975-8979, 8979-8994, 9016-9030, 9049-9056, 9056-9071, 9086-9108, 9122-91378/24/15 1,177.SBHP163.91 8,799.94 3,739.568,8000.44 3,739.616-10A 500292050601 WI6401509016-9016, 9017-9017, 9019-9018, 9022-9022, 9023-9079, 9026-90258/24/15 1,187.SBHP165.47 8,800.19 3,608.468,8000.44 3,608.416-11500292051600 WI6401508922-8939, 8944-8954, 8964-8994, 9010-9040, 9081-9081, 9081-9082, 9082-9083, 9083-9084, 9084-9085, 9085-9086, 9086-9087, 9087-9088, 9088-9089, 9089-9090, 9090-9091, 9091-9092, 9092-90938/23/15 1,151.SBHP149.86 8,800.22 3,809.848,8000.44 3,809.716-17500292144100 O6401508798-8835, 8798-8886, 8835-8886, 8892-8910, 8927-8934, 8946-8947, 8946-8952, 8947-8951, 8951-89528/18/15 4,346.SBHP193.74 8,763.76 3,796.788,8000.29 3,807.2917-11500292125900 O6401508760-8770, 8760-8779, 8770-8772, 8772-8779, 8786-8791, 8791-8795, 8795-8809, 8832-8843, 8860-8893, 8902-8944, 8953-8969, 8953-8988, 8969-8988, 9006-9012, 9014-9020, 9045-90578/24/15 1,499.SBHP194.76 8,799.89 3,365.558,8000.41 3,365.618-12C 500292161503 O6401508543-8544, 8612-8610, 8614-8613, 8623-8622, 8625-8624, 8628-8627, 8651-8658, 8655-86338/7/15 1,018.SBHP148.38 8,350. 3,290.048,8000.34 3,443.AGI-03 500292231800 GI6401508187-8202, 8277-8293, 8364-8379, 8407-8414, 8432-8439, 8470-84852/20/15 417.SBHP117.59 8,399.79 3,418.078,8000.10 3,459.1C-08B500292012902 O6401508999-8952, 9000-8999, 9000-9000, 9013-9017, 9015-9020, 9019-9006, 9020-9019, 9023-90156/21/15 1,643.SBHP196.9 8,759.07 2,382.88,8000.05 2,384.87C-11A500292038201 O6401509016-9016, 9017-9018, 9018-9019, 9020-9015, 9021-902110/22/15 903.SBHP197.84 8,799.86 3,221.268,8000.33 3,221.5C-21500292075300 O6401508874-8876, 8876-8881, 8892-8973, 8892-8977, 8973-8977, 8985-8986, 8986-8995, 8986-8997, 8986-9006, 8986-9016, 8995-8997, 8997-9006, 9006-9014, 9006-9016, 9014-9016, 9016-9021, 9021-9026, 9026-90329/30/15 1078SBHP196.86 8,800.27 3,262.258,8000.24 3,262.2D-08A500292037201 O6401508965-8974, 8976-8980, 8990-9002, 9015-90328/17/15 411.SBHP212.66 8,800.14 3,239.798,8000.41 3,241.6E-15D500292066804 O6401508966-8975, 8979-8986, 8987-8992, 9000-9003, 9003-8998, 9004-9006, 9006-9010, 9012-9013, 9017-90202/24/15 97.SBHP187.92 8,799.72 3,247.358,8000.08 3,247.4E-20B500292057602 O6401509004-904710/16/15 2,720.SBHP190.48 8,800.2 3,327.778,8000.12 3,327.7F-17A500292065201 O6401509045-9046, 9047-9052, 9048-9048, 9049-9048, 9050-9049, 9050-9050, 9053-90512/18/15 1,441.SBHP198.4 8,799.77 3,151.78,8000.08 3,152.22F-19A500292062901 O6401508656-86876/8/15 2,690.SBHP194.91 8,618.25 2,719.8,8000.26 2,767.1F-23A500292165801 O6401509033-90552/13/15 1,010.SBHP189.9 8,479.86 3,157.68,8000.09 3,185.4F-35500292184300 O6401508774-8788, 8881-8889, 8967-8968, 8968-8972, 8972-8984, 8984-8991, 8991-9003, 8991-9018, 9003-9018, 9027-9043, 9164-9168, 9171-9172, 9242-92442/14/15 14,594.SBHP181.3 8,699.5 2,702.78,8000.22 2,723.2F-45B500292214202 O6401509057-9057, 9057-9058, 9058-9057, 9059-9058, 9059-9059, 9060-90595/25/15 4,999.SBHP194.85 8,800.19 3,215.168,8000.34 3,215.1G-07500292035900 O6401508861-8881, 8889-8923, 8934-8941, 8948-8954, 8948-8958, 8954-8958, 8958-8972, 8972-8976, 8976-8980, 8980-8985, 8985-8986, 8985-8987, 8986-8987, 8987-8992, 8992-8996, 8996-9000, 9000-9001, 9004-9014, 9017-90356/17/15 4,290.SBHP194.7 8,815.19 2,677.68,8000.08 2,676.384. Field and Pool:5. Datum Reference:7. Gas Gravity:Prudhoe Bay Field, Prudhoe Oil Pool8800 TVDss0.9 Exhibit 9G-08A500292058101 O6401508989-8992, 8993-8993, 8996-8995, 9007-9017, 9023-9019, 9028-9027, 9031-9036, 9034-90308/30/15 996.7SBHP198.41 8,878.05 3,244.218,8000.08 3,221.03G-10C 500292055303 O6401509030-9031, 9035-90346/24/15 1,287.SBHP197.3 8,799.82 3,230.28,8000.34 3,230.3GC-1D 500292177200 Disposal6401505348-5399, 5404-5416, 5495-5514, 5554-5575, 5582-5596, 5638-5665, 5702-5735, 5840-58609/18/15 9,837.SBHP79.16 3,999.57 1,917.338,8000.46 4,114.5GNI-02A 500292285101 WI6401506536-65498/26/15 222.SBHP73.3 6,475.33 3,102.748,8000.44 4,123.2GNI-03 500292282000 WI6401506597-6613, 6852-68697/20/15 157.SBHP75.1 6,539.81 3,110.98,8000.45 4,119.9GNI-04 500292336700 WI6401506504-65228/3/15 160.SBHP83.2 6,449.56 3,066.058,8000.44 4,103.3H-37A500292277201 O6401508842-8847, 8842-8848, 8847-8848, 8942-8958, 8958-8979, 8964-8957, 8987-8994, 9004-9017, 9108-91546/30/15 759.SBHP229.35 8,799.8 3,328.638,8000.36 3,328.7J-13A500292049701 O6401509012-9020, 9029-90378/27/15 659.SBHP196.97 8,799.96 3,219.448,8000.33 3,220.5J-18A500292098601 O6401509027-9017, 9030-9031, 9031-9036, 9032-9027, 9033-9034, 9035-9035, 9035-9036, 9038-9039, 9042-90435/21/15 3,477.SBHP200.44 8,799.69 3,175.698,8000.34 3,175.7K-10D500292176205 O6401508701-8703, 8711-8723, 8723-87088/18/15 1,505.SBHP178.08 8,599.88 3,306.948,8000.32 3,371.2L2-03A 500292146501 O6401508711-8697, 8727-8717, 8731-8727, 8735-87409/28/15 3,422.SBHP177.42 8,644.73 3,327.368,8000.29 3,372.4L-51500292330900 O6401508736-8832, 8830-8873, 8875-89359/21/15 1,084.SBHP226.72 8,600.02 2,611.928,8000.30 2,672.7M-06A 500292036701 O6401508580-8597, 8690-8705, 8705-8723, 8723-8734, 8740-8796, 8979-8985, 8990-90027/24/15 594.SBHP214.7 8,575. 3,059.68,8000.43 3,156.M-08500292049900 O6401508669-8674, 8674-8706, 8706-8708, 8713-8722, 8722-8744, 8722-8745, 8744-8745, 8745-8746, 8752-8758, 8758-8803, 8758-8834, 8803-8834, 8871-8878, 8884-8908, 8918-89278/4/15 1,613.SBHP214.3 8,599.69 3,164.8,8000.42 3,248.8M-23500292093700 O6401508643-8718, 8726-8729, 8730-8755, 8730-8757, 8730-8781, 8755-8757, 8757-8781, 8789-8800, 8801-8834, 8801-8842, 8801-8867, 8834-8842, 8842-8850, 8850-8867, 8959-89769/22/15 2,782.SBHP222. 8,602.5 3,176.8,8000.42 3,260.1N-06500292009800 O6401508846-8868, 8882-8901, 8882-8907, 8901-8907, 8920-8930, 8920-8946, 8930-8946, 8961-8979, 9002-9011, 9011-902811/19/15 89,733.2SBHP210.5 8,600.07 3,156.168,8000.42 3,240.1NGI-13A 500292034701 GI6401508107-85139/6/15 897.SBHP137.65 8,437.8 3,365.648,8000.20 3,436.3P-30500292352200 O6401508999-9013, 9044-902212/5/15 5,079.SBHP31.89 1,630.75 1,898.098,8000.09 2,549.14PSI-09 500292309500 WI6401508269-8293, 8293-8335, 8360-8379, 8391-8404, 8436-8464, 8474-8484, 8494-85425/1/15 1,791.SBHP64.8 8,400.28 3,569.28,8000.45 3,749.4R-02500292035400 WI6401508650-8685, 8778-8787, 8796-8836, 8836-8840, 8848-8868, 8848-8870, 8848-8889, 8868-8870, 8870-8876, 8870-8889, 8876-8889, 8912-8919, 8912-8934, 8919-8923, 8919-8924, 8919-8934, 8923-8924, 8924-8934, 8942-8944, 8942-8945, 8942-8971, 8944-8945, 8945-8954, 8954-8955, 8954-8971, 8955-8971, 8984-9015, 8984-9022, 9015-902212/3/15 16,020.15SBHP173.93 8,612.01 2,610.98,8000.31 2,669.51R-10500292061800 O6401508861-8899, 8989-9005, 8989-9031, 9005-9007, 9005-9031, 9007-90315/16/15 88,166.SBHP207.48 8,803.12 2,897.578,8000.32 2,896.58R-26B500292154701 O6401508854-8879, 8855-88463/21/15 2,580.SBHP206.11 8,799.85 2,220.548,8000.37 2,220.6R-35500292242400 O6401508865-8901, 8983-90197/8/15 357.2SBHP210.1 8,848.34 2,528.98,8000.34 2,512.5R-39A500292252601 O6401508732-8817, 8732-8818, 8817-8900, 8818-88174/24/15 9,333.SBHP210.69 8,599.89 3,156.8,8000.41 3,237.3S-13A500292081001 O6401508423-8427, 8496-8500, 8810-8810, 8810-8811, 8810-8815, 8810-8817, 8810-8818, 8810-8832, 8810-8863, 8811-8817, 8817-8817, 8817-8818, 8818-8832, 8832-8833, 8833-8863, 8861-8815, 8863-88616/7/15N/ASBHP214.28 8,775. 3,034.748,8000.40 3,044.7T-07500292073300 WI6401508841-8850, 8850-8860, 8850-8884, 8860-8879, 8879-8884, 8965-8984, 8965-8997, 8984-8997, 9007-9012, 9007-9060, 9012-90604/11/15 138,271.SBHP166.76 8,799.67 3,254.078,8000.47 3,253.1U-14500292238600 O6401508748-8755, 8748-8776, 8755-8776, 8867-8885, 8867-8914, 8885-8901, 8901-8914, 8923-8978, 8985-899510/15/15 748.SBHP230.29 8,799.82 3,233.38,8000.40 3,233.4V-03500292312400 O6401508892-8982, 8921-8921, 8922-8922, 8925-8921, 8927-8925, 8939-8927, 8943-8939, 8943-8945, 8947-8956, 8953-8921, 8953-8943, 8956-8963, 8965-8962, 8968-8970, 8968-8976, 8970-8971, 8971-8976, 8984-8986, 8984-9006, 8985-8986, 8986-8987, 8987-9006, 8988-8988, 8989-8995, 9008-89685/31/15 560.SBHP236.33 8,799.55 3,359.158,8000.39 3,359.3W-10A 500292189301 O6401508894-8896, 8894-8900, 8896-8894, 8898-8906, 8899-8901, 8903-8898, 8903-8907, 8911-8917, 8912-8914, 8914-8911, 8918-8932, 8920-8923, 8925-8922, 8926-89274/11/15 13,132.SBHP228.7 8,700.12 3,535.398,8000.14 3,549.6W-18A 500292188001 O6401508922-8923, 8923-8924, 8924-8926, 8927-8924, 8946-8944, 8948-8946, 8950-8948, 8950-8955, 8955-8957, 8957-8968, 8968-8979, 8979-8981, 8997-90059/10/15 546.SBHP229.4 8,799.43 3,454.98,8000.45 3,455.W-25A 500292187401 O6401508880-8888, 8890-8890, 8899-8906, 8909-8933, 8935-8939, 8941-8950, 8955-8957, 8963-8969, 8975-89819/22/15 4,562.SBHP230. 8,749.77 3,562.8,8000.38 3,581.3W-26A 500292196401 O6401508825-8842, 8825-8846, 8842-8846, 8846-8849, 8849-8865, 8865-8867, 8880-8878, 8881-8878, 8881-8880, 8882-8881, 8884-8890, 8884-8900, 8886-8881, 8886-8882, 8887-8878, 8887-8886, 8890-8887, 8890-8890, 8890-8900, 8900-8905, 8905-8913, 8905-8916, 8913-8916, 8924-8935, 8973-8986, 8987-8981, 8991-89919/4/15 398.SBHP234.4 8,799.91 3,465.38,8000.36 3,465.3W-39A 500292178401 O6401508952-8932, 8962-8928, 8968-8966, 8969-8969, 8969-8976, 8971-8975, 8974-8973, 8977-8979, 8979-8978, 8980-8981, 8982-8984, 8990-89881/2/15 2,691.SBHP226.7 8,800.16 3,561.8,8000.34 3,560.95W-42500292181600 WI6401508763-88235/4/15 18,111.SBHP205.65 8,550.14 3,425.828,8000.43 3,533.7W-51500292348800 O6401508946-8941, 8952-8984, 8965-9006, 8978-8950, 8998-9029, 9012-89855/18/15 273.SBHP234.02 8,799.75 3,356.068,8000.40 3,356.2W-59500292349800 O6401508849-8940, 8878-8826, 8900-8905, 8903-8884, 8946-8899, 8953-89545/17/15 244.SBHP232.93 8,799.64 3,197.378,8000.32 3,197.5WGI-09 500292332700 GI6401508183-85795/19/15 234.SBHP162.58 8,492.21 3,380.678,8000.08 3,406.5Y-06A500292043101 WI6401508969-8969, 8972-89804/16/15PFO8,293.73 3,085.8,8000.44 3,307.77Y-13A500292063401 O6401508850-8853, 8864-8869, 8865-8859, 8875-8883, 8876-8876, 8877-8876, 8877-8877, 8880-88809/1/15 576.SBHP210. 8,521.86 2,270.8,8000.39 2,377.Y-24500292160800 WI6401508889-8900, 8984-8992, 8984-9015, 8984-9046, 8992-9015, 9015-9038, 9015-9046, 9038-9046, 9046-90635/3/15 16,353.SBHP205. 8,710.92 3,285.8,8000.42 3,326.3Y-24500292160800 WI6401508889-8900, 8984-8992, 8984-9015, 8984-9046, 8992-9015, 9015-9038, 9015-9046, 9038-9046, 9046-90635/2/15 16,329.SBHP205. 8,710.92 3,289.8,8000.42 3,322.39Y-34A500292217801 O6401509008-9005, 9008-9006, 9013-9011, 9013-9015, 9023-9021, 9034-90435/30/15 65,619.SBHP226.8 8,799.96 3,333.78,8000.31 3,333.7Y-35A500292218601 O6401508951-8982, 8953-8961, 8966-8986, 8977-89489/26/15 159.SBHP224. 8,800.25 3,315.8,8000.27 3,314.9Y-39500292351400 O6401509032-9061, 9053-9032, 9054-9060, 9059-90483/9/15 456SBHP8,502.93 3,160.8,8000.43 3,288.Z-06A500292179801 O6401508879-8903, 8883-8974, 8893-8875, 8919-8901, 8954-89385/28/15 483.63SBHP229.77 8,799.43 2,851.8,8000.42 2,850.8Z-07B500292204602 O6401508910-8910, 8915-8910, 8916-8918, 8917-8919, 8918-89163/16/15 4,130.SBHP230.65 8,800.02 3,732.888,8000.30 3,732.9Z-34500292346900 O6401508886-8908, 8914-8906, 8919-8971, 8924-8917, 8951-8978, 8974-8954, 8982-9001, 9002-8980, 9011-9004, 9011-9020, 9022-90235/27/15 464.SBHP233.4 8,799.97 3,223.38,8000.34 3,223.3Put River02-23A 500292079501 O6401828239-8264, 9033-9033, 9035-9025, 9036-9034, 9037-90346/2/15 342.SBHP183.8 8,099.53 3,763.58,1000.43 3,763.502-27A 500292199401 O6401828202-8210, 8202-8221, 8210-8221, 8962-8969, 8969-8972, 8981-8986, 8990-9003, 8994-8977, 9002-89976/8/15 669.SBHP179.3 8,099.29 3,254.38,1000.42 3,254.323. 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: R-26B, 12-12A, C-08A, R-35, 12-05A, 01-05B, L-51, G-07, F-35, F-19A, 09-29, Z-06A, R-10, S-13A, Z-34, PSI-09, W-59, V-03, M-06AI hereby certify that the foregoing is true and correct to the best of my knowledge.SignatureTitle Sr Reservoir EngineerPrinted Date10-Mar-2016NameVivek PeraserSignatureTitle Sr Reservoir EngineerPrinted Date10-Mar-2016NameVivek Peraser PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-20281-01-00 01-14A 7 10/28/2014 Y Well Fit for service 6 SI for sand production 50-029-20885-01-00 01-26A 6 11/20/2013 N Not operable 6 Needs Divert and Choke 50-029-20074-01-00 02-02A 6 6/1/2006 N TxIA comm 5 Well suspended. . No flowline or surface slot in the manifold building. 50-029-20077-02-00 02-03B 6 12/6/2013 Y Well Fit for service 1 LDS have been repaired and the well recently passed an MIT-IA. 50-029-20081-01-00 02-05A 6 1/1/2009 N TxIA comm 6 Waiting VSM fix before repairing TxIA. 50-029-20163-02-00 02-10B 6 2/21/2014 N TxIA comm 3 TxIA comm through the wellhead; Waiting on rig for repair. 50-029-20446-01-00 02-14A 6 8/25/2014 N TxIA comm 3 Waiting on rig for repair 50-029-20453-02-00 02-17B 7 8/30/2011 N Well Fit for service; needs VSM repair 6 SI, waiting for Flowline VSM repair. 50-029-20721-00-00 02-20 6 5/27/2011 Y RWO just completed 6 RWO just completed to fix TxIA. Waiting for WTI to be complete 50-029-22721-01-00 02-39A 1 12/2/2007 Y Well Fit for service 5 LTP stuck downhole. 50-029-21027-00-00 03-26 6 7/9/2009 N Well Fit for service; flowline needs repair 6 PMP on the flowline in the manifold building. The well is currently SI for the PMP so the flowline needs to be fixed before being put back online. Operations is progressing the flowline fix 50-029-21118-00-00 03-29 2 7/1/2014 Y Well Fit for service 5 SI for high water cut. 50-029-21132-02-00 03-34B 6 4/10/2010 N Well Fit for service; waiting on AL line to be reconnected 1 waiting on the AL line to be reconnected. 50-029-22184-00-00 03-35 6 4/5/2014 N Well Fit for service; needs AL line repair 6 Waiting on AL line fix. 50-029-20189-00-00 04-07 6 1/1/1997 N TxIA comm, PC leak 5 50-029-21326-01-00 04-32A 7 4/11/2011 Y Well Fit for service 6 Waiting for POP 50-029-22160-01-00 04-34A 2 11/19/1997 Y Well Fit for service; needs flowline repair 5 TTP set. 50-029-22147-01-00 04-35A 2 1/8/2011 Y Well Fit for service; needs flowline repair 5 TTP set. 50-029-22162-00-00 04-36 3 11/14/2001 Y Well Fit for service 5 Low PI. Twin with high rate, HP 4-46. 50-029-22181-00-00 04-39 2 4/11/1998 Y Well Fit for service ; no flowline 5 High WC, low IOR. Flowline removed. 50-029-22224-00-00 04-40 7 5/23/2010 Y Well Fit for service 6 Waiting on POP 50-029-20147-03-00 05-03C 7 1/11/2012 N Not operable 5 Shut in 50-029-20173-01-00 05-06A 6 10/15/2010 N Not operable 3 Waiting on coil sidetrack 50-029-20248-01-00 05-08A 1 8/1/2014 Y Well Fit for service 2 HGOR – no room in DS5 common lines. 50-029-20244-02-00 05-12B 6 1/19/2005 N Not operable 2 Evaluating for wellwork/RWO or sidetrack 50-029-20255-02-00 05-15B 6 10/13/2014 N Well Fit for service; needs VSM repair 6 SI, waiting for flowline VSM repair 50-029-20271-02-00 05-17B 6 11/1/2002 N Not operable 5 Collapsed tbg 50-029-21960-01-00 05-18A 6 2/3/2003 N Not operable 5 Casing needs repair. 50-029-21988-03-00 05-25C 1 9/19/2012 Y Well Fit for service 2 High GOR – no room in DS5 common lines. 50-029-22168-02-00 05-33B 7 7/10/2013 Y Well Fit for service 2 Possible solids production – considering POP’ing this year to evaluate 50-029-22182-01-00 05-36A 1 2/3/2014 Y Well Fit for service 2 HGOR 50-029-22707-00-00 05-40 6 11/1/2002 N Not operable 5 Failed RWO - stuck CT during cleanout PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-20291-01-00 07-03A 6 1/24/2014 Y see comments 3 CST planned 50-029-20296-02-00 07-08B 1 see comments Y Online see comments GSO/ Add perf completed 12/2015 and well online now 50-029-20879-00-00 07-18 6 1/08/11 N Not operable; no surface facilities 5 Casing leak. No surface facilities given to another well 50-029-20198-00-00 09-02 2 12/25/2013 Y see comments 3 No mechanical issues. High WC. Sidetrack drilled. Rig released 2/6/2016 50-029-20236-00-00 09-11 6 see comments Y Online. see comments Well converted to injector during the year. 50-029-20240-00-00 09-13 2 8/20/2014 Y Well Fit for service 5 Bull IBP from WSO, shut-off oil. No issues. Can be POP’d. High WC, not comp 50-029-21036-00-00 09-21 6 6/10/2014 N Well Fit for service; needs AL line repair 6 PMP on AL line. Repair flowline to POP well. 50-029-21422-00-00 09-29 2 10/2/2012 N Well Fit for service; needs AL line repair 6 Repair AL line to POP. Recent wellwork WSO to reduce WC. 50-029-22059-01-00 09-42A 6 12/12/2002 N SC damage 5 2008 RWO failed. Now possible SC damage needing repair. 50-029-22128-00-00 09-48 6 11/30/2004 N IAxOA leak 1 IAxOA to gas- not manageable by bleeds. Wellwork option to fix IAxOA leak 50-029-22317-00-00 09-49 2 9/21/2011 Y Well Fit for service 3 High WC. 50-029-20674-01-00 11-06A 2 3/16/2013 N Well Fit for service; no surface kit 5 The wellbore is fit for service but the well is not operational. 11-06's surface kit (flowline, AL line, pressure gauges, instrumentation, and manifold building slot) were used for a 11-39 grassroots well. There is no current utilization. 50-029-22035-01-00 11-22A 6 3/4/2013 N Well Fit for service; needs surface kit reconnect 7 The well was SI for IAxOA communication. A RWO package was signed and approved on 3/19/15. The RWO was completed on 10/30/15. It was waiting on surface kit reconnect (flowline, AL line, pressure gauges, and instrumentation). 50-029-21610-01-00 11-23A 1 12/23/2013 Y Well Fit for service 3 Intially, the well was SI for high GOR. The well needs to be coil sidetracked and de-twinned from 11-23. 50-029-20488-02-00 11-25A 6 2/11/2002 N Not operable 5 The producer is Not Operable due to having IAxOA communication and a probable Cretaceous leak in the production casing. The producer has no current utility. 50-029-22516-00-00 11-34 7 3/1/2011 Y Well Fit for service 6 The well is SI for velocity limitations in the flowline. It is twinned with 11-05 which is a full-time LP producer. 11- 34 is an HP producer so they cannot flow together. 11-05 is a more valuable well so 11-34 has to be SI. The Pad Engineer is pursuing a potential de-twin opportunity. 50-029-22477-00-00 11-36 6 8/31/2010 N Not operable 5 The well was SI for a surface casing leak. There was no value in the well so the surface kit for 11-36 was used for a 11-40 grassroots well. 50-029-22723-01-00 11-38A 5 7/5/2015 Y Well Fit for service 4 The well was SI for reservoir management. 50-029-20363-00-00 12-01 6 2/13/2013 N Not operable 7 Failed a MIT-IA on 3/23/2013 and a CMIT-TxIA on 3/18/2013 during CTD candidate screening. LDL shows PC leak and a potential packer leak. 50-029-20601-00-00 12-11 6 2/1/2000 N Not operable 5 LTSI. Low oil rate. 12-11's surface facilities used for new grass roots well 12-37. CMIT-IA passed on 6/11. 50-029-20918-00-00 12-15 7 October 2014 Y Well Fit for service; AL line repair in progress 6 0 50-029-20323-00-00 13-01 6 7/21/2006 N Surface casing leaks 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. 50-029-20326-00-00 13-04 6 10/3/2003 N TxIAxOA comm 7 TxIAxOA; produces rocks, sand screen installed, poor tubing. 50-029-20650-00-00 13-07 6 7/1/1991 N TxIA comm 5 TxIA, \ surface facility repairs required. Screening for ST. 50-029-20678-00-00 13-10 6 6/1/1994 N IAxOA comm 5 IAxOA on GL: High WC. No plans at this time. PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-20604-00-00 13-11 6 12/5/2005 N Tubing & packer leaks 5 TxIA & possible hole in packer or PC. NWD screening for ST. LDL found several leaks in the well. 50-029-20746-00-00 13-26 6 10/11/2011 N TxIA comm 5 50-029-20942-00-00 13-28 6 5/1/1994 N TxIAxPC comm 5 PC needs repair & bubbles in the cellar. Replaced by 13-13A. 50-029-20773-00-00 13-33 6 12/1/1994 N TxIAxOA comm 5 TxIAxOA; Well secured with IBP. Evaluating non-rig fix. 50-029-20319-01-00 14-03A 6 8/5/2009 N TxIAxOA; no flowline 5 TxIA and leaky 9-5/8" scab. No flowline. 50-029-20708-01-00 14-28A 2 12/24/2012 Y Well Fit for service 3 Makes ~100% water. High probability that the perfs are connected to a fault. 50-029-20680-00-00 14-29 4 2/2/2016 Y Well Fit for service 1 Was SI for a long time waiting on flowline repair. Flowline repair complete in 1/2016. 50-029-21862-00-00 14-38 6 11/1/1994 N TxIA comm; no flowline 3 Has TxIA with no flowline. 50-029-20722-00-00 15-03 6 6/1/1994 N Not operable; no surface kit 5 Had Cret leak, leaking sqz perfs, major fish in tubing; surface facilities given to another well 50-029-20501-01-00 15-10A 6 1/1/1991 N Not operable 5 Had major down hole leaks and a channel; no surface facilities; bottom hole location developed by 15-49 50-029-20691-03-00 15-15C 6 5/28/10 N Not operable 5 PC leak & HGOR. No GSO opportunity. 50-029-22448-02-00 15-33B 1 6/11/2011 Y Well Fit for service 5 High GOR, no more well work opportunities left. 50-029-22488-00-00 15-35 6 9/3/2003 N Not operable 5 Had Cret leak, dumpflooded Ivishak, TxIA and PC communication 50-029-22492-02-00 15-41B 3 5/9/2006 Y Well Fit for service 5 Low PI well, bottomhole location has been replaced. 50-029-22624-02-00 15-42B 1 3/1/2010 Y Well Fit for service 5 High GOR. No well work opportunities. 50-029-22676-00-00 15-43 6 12/8/2009 N Well Fit for service; needs surface reconnection 1 Surface casing leak repaired with WellLock in 2015. Waiting for Operations to reconnect the well. Requires a pad shut down 50-029-22665-00-00 15-46 6 9/30/2011 Y Well Fit for service; needs surface reconnection 1 Reclassified as operable after passing and MIT-IA with diesel. Waiting for Operations to reconnect the well. Requires a pad shut down 50-029-20561-01-00 16-04A 6 7/20/2014 Y Well Fit for service; VSMs need repair 6 Repair VSMs to make operable 50-029-20584-02-00 16-06B 7 9/3/2011 Y Well Fit for service; VSMs need repair 6 VSM/Flowline. Facility Constrained 50-029-21430-00-00 16-07 2 11/27/2012 Y Well Fit for service 5 No Mechanical issues. High WC, uncompetitive. . 50-029-20549-01-00 16-08A 6 7/6/2013 Y VSMs Need repaired before well can flow. 6 VSM repairs underway, and wellwork planned to get well online shortly after VSM repairs completed. 50-029-20558-01-00 16-09A 6 10/15/2007 Y Well Fit for service; needs VSMs repaired. 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 50-029-21474-00-00 16-15 7 4/20/2013 Y Well Fit for service 3 Evaluating sidetrack. 50-029-21461-00-00 16-18 2 12/12/2012 Y Well Fit for service 5 SI due to 16D CL pressure limits. Facility Constrained. Plug Securing well. 50-029-21475-00-00 16-19 6 12/13/2014 Y Well Fit for service; needs AL line repair 6 Fix PMP to POP 50-029-21493-00-00 16-20 6 12/1/2014 Y Well Fit for service; needs AL line repair 6 Fix PMP to POP 50-029-21536-00-00 16-24 3 7/6/2006 Y TxIA comm 5 TxIA communication and low productivity. 50-029-22276-00-00 16-28 6 10/5/2005 N SC leak 5 SI for high WC. Hole in SC. Wells group is also working on possible surface casing repair to reinstate integrity to this well. 50-029-22280-00-00 16-31 3 4/1/1995 Y TxIA to gas 5 SI for low PI. TxIA to gas only- needs GL to produce. 50-029-22300-00-00 17-20 3 8/2/2012 Y Well Fit for service; needs VSM repair 5 Needs VSM work. 50-029-20797-02-00 18-06B 1 7/30/2014 Y Well Fit for service 5 Will bring on line when the DS Is not constrained PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-21614-03-00 18-14C see comments 10/10/2012 Y On line see comments Brought on line in 2016 50-029-21596-00-00 18-19 6 9/1/2003 N Ann comm 7 AnnComm, needs RWO 50-029-21898-01-00 18-23A 1 7/1/2010 Y Well Fit for service 5 No current use 50-029-21948-01-00 18-25A 6 5/2/2003 N Ann comm; no flowline 5 Cretaceous leak was found. No future utility. FL was donated to well 18-15. 50-029-22564-00-00 18-28 7 8/30/2003 N Ann comm; no flowline 5 No Flowline and subsurface location has been replaced 50-029-22611-00-00 18-34 6 10/1/2000 N Ann comm 5 Hole in tbg and casing. Cement in tbg and IA. Multiple plugs in tbg. 50-029-22374-00-00 2- 66/SD- 12 see comments see comments N see comments see comments Casing ran and shot perfs in the reservoir (1993) to test well as a potential seasonal replacement for the STP, and following testing we subsequently squeezed those perfs 6 months later (6/19/94). The well has no tubing, No flowlines or wellhouse. 50-029-20108-01-00 A-01A 3 3/26/2013 Y Well Fit for service 5 No current utilization. 50-029-20672-00-00 A-13 6 10/18/2010 N Not operable 5 Reservoir abandoned. 50-029-20630-01-00 A-18A 6 6/13/2003 N Ann comm 5 SC hole @ 5'. 50-029-20841-00-00 A-29 see comments see comments N Not operable see comments Well is being ST 50-029-21339-01-00 A-34A 7 3/28/2009 N Not operable 2 HOAP - cemented annulus. Well failed the shell test in October, 2013. 50-029-22542-01-00 A-42A 3 9/9/2011 Y Well Fit for service 5 No current utilization. 50-029-20331-00-00 B-11 2 1/1/1991 Y Well Fit for service; no surface kit 5 LTSI. No FL. Surface facilities- given to B-35. 50-029-20815-00-00 B-24 2 1/1/1993 Y Well Fit for service 5 LTSI. Bottomhole location taken by B-13. Surface equip given to B-33A. 50-029-20127-02-00 C-06B 6 12/20/2013 N Ann comm 7 Identified hole in tubing and production casing. Well will require a RWO + CTD/RDST to justify a fix. 50-029-20439-02-00 C-17B see comments 10/31/2014 Y On line see comments SI for SSV failure. New actuator installed 2/2/2016. 50-029-21571-00-00 C-38 6 11/1/1997 N Not operable 5 Had Cretaceous leak, flowline taken, not a candidate for CST. No current wellbore utilization; resources captured by offset wells. 50-029-21522-01-00 D-25A 7 9/29/2014 Y Well Fit for service 1 SI for potential solids production during POP. The well has been placed on a slow bean up procedure and currently working a procedure to flow back through portable test separator to evaluate for solids. 50-029-21543-01-00 D-27A 6 4/20/2010 N Not operable 5 Tbg holes, Pkr and PC compromised @ 4950'. 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. . 50-029-20451-01-00 E-07A 6 12/1/2013 N Surface casing leak 1,3 Needs surf casing leak fix. Well is being screened for sidetrack. 50-029-20784-01-00 E-14A 6 9/5/2007 N Surface casing leak 1, 7 Needs surf casing leak fix Well will be evaluated for a RWO/ST. 50-029-20577-02-00 E-21B 1 11/16/2014 N SSV requires new actuator 1 This well was shut in for SSV supplemental test failure and a fix was not aggressively pursued due to the high GOR of the well. The well is due for an SSV actuator replacement and an adperf program is being pursued to make the well competitive. 50-029-22411-01-00 E-31A 6 11/23/2011 N TxIA comm 7 Potential RWO 50-029-22587-01-00 E-39A 6 9/4/2005 N Not operable 5 Production casing leak, IBP fish stuck in hole 50-029-21843-00-00 F-35 see comments 6/16/2013 Y On line see comments Well is online and producing!! POP’d 01/29/2016 50-029-22215-00-00 F-40 1 12/18/2014 Y Well Fit for service 4 Low utilization, potential shutoffs being evaluated 50-029-20221-01-00 G-03A 6 12/3/2004 N PC Leak 5 BHL replaced with G-31B. A RWO failed when scale was found in the 7" tubing due to a cretaceous leak. 50-029-20582-02-00 G-09B 6 7/2/2012 Y BHA stuck downhole 1 There are 2 BHA stuck in the well. A SL SOR to fish the top BHA is on the wobble. Evaluating sidetrack potential. PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-20100-02-00 H-02B 2 9/15/14 Y No safety kit 6 Cannot flow as the safety kit was stolen for the twin H-28. 50-029-20104-02-00 H-04B 6 1/6/2012 N Not operable; No flowline 5 TxIA & SC hole(s). Released flowline to H-40 which is a new rotary well that is using H-04B’s flowline. 50-029-20485-00-00 H-11 6 2/9/2012 N Potential SC leak; needs VSM repair 1 SC leak suspected-waiting on warm MIT-OA to assess the problem. Currently waiting on VSM’s(FL/GL) to be fixed to be able to flow the well. 50-029-21478-00-00 H-25 1 4/14/14 Y Well Fit for service 3 High GOR. Looking at possible sidetrack. 50-029-22803-00-00 H-34 6 11/4/2004 N Not Operable 5 NOT OPERABLE TxIA, PC hole. May be potential for a RWO/ST. 50-029-20020-02-00 J-01B 6 8/8/2008 N Well Fit for service; no flowline 6 With new SC leak requirements, this well does not qualify as having a SC leak; no fluid returns to surface were observed. Investigating reconnecting flowline. 50-029-21734-00-00 J-26 6 7/29/2011 N Not operable 5 Packer leak, production casing leak, surface casing leak, starting head leak 50-029-21045-05-00 K-07E 1 12/04/2014 Y Well Fit for service 3 Investigating potential sidetrack 50-029-21340-00-00 L1-10 1 12/7/2007 Y Well Fit for service 5 Well was successfully patched, but tested with very high GOR. 50-029-21381-00-00 L1-14 1 3/10/1996 Y Well Fit for service 5 High GOR. Choke has been removed. 50-029-23255-00-00 L-124 3 10/4/2013 Y Well Fit for service 5 Well is SI for low PI. Low productivity of this well is due to the lack of injection support from L-123i. Poor rock quality in this area. 50-029-21792-00-00 L1-28 1 12/17/1992 Y Well Fit for service 2 Low Rate High GOR. Under evaluation for stimulation work. 50-029-22010-00-00 L1-30 6 8/8/2009 N Not operable 5 Hole in PC – not a candidate for RWO 50-029-23191-00-00 L-200 7 6/30/2012 N Well Fit for service; plugged with sand 5 Solids produciton - Sand. Well SI, plugged. Mangled junction prevents clean out. 50-029-23416-00-00 L-203 7 10/1/2012 N Well Fit for service; plugged with sand 1 Plugged with sand. Unable to sustain production despite FCOs due to violent slugging behavior. Likely caused by water breakthrough or MBE. Suspect MBE to be from L-216. 50-029-23388-00-00 L-205 7 8/21/2012 N Well Fit for service; plugged with sand 2 Plugged with sand. Unable to sustain production despite FCOs due to violent slugging behavior. Planning FCO with sand consolidation. Challenges getting isolation equipment down wellbore. 50-029-21761-01-00 L2-08A 6 7/1/1999 N Not operable 5 Evaluating RWO feasibility & possible non-rig fix. Can't flow to LPC due to gas limitations. 50-029-23187-00-00 L-210 see comments see comments Y Well Fit for service see comments Currently planning changing water flood regulating valves that are installed down hole 50-029-22885-00-00 L2-11 4 11/1/2008 Y Well Fit for service 1 RWO has been completed. Well passed MIT-IA on 12/3/15. Well awaiting final tie-in work before POP. 50-029-21376-00-00 L2-20 6 6/29/1995 N Not operable; no flowline 1 TxIA integirty restored in 2015. Flowline re-connect justification being worked. 50-029-21525-00-00 L2-25 6 1/26/2009 N Well Fit for service; no flowline 5 Annular communication - blinded at wing with no flowline. 50-029-21359-00-00 L2-26 6 11/7/1996 N Not operable; no flowline 5 Tbg x IA dual completion with both tubing strings compromised. Not a candidate for well work - blinded at the wing. No flowline. 50-029-21298-00-00 L2-28 3 11/10/2009 N Well Fit for service; no flowline 5 Well passed MIT-IA in July-07. No flowline. Test through portable separator attempted in 2015 but well would not flow. 50-029-21505-00-00 L2-29 6 10/30/2009 N Not operable 5 T x IA and low PI. ASRC extended test showed modest results. Not a candidate for RWO. 50-029-21272-00-00 L2-30 6 12/13/1992 N Not operable; no flowline 5 TxIA dual string completion. Low Rate High GOR - suspended - blinded at wing. No flowline. 50-029-21778-00-00 L2-32 3 12/1/2012 Y Well Fit for service 1 Well tends to Hydrate off and won’t stay on line long. Add-perfs, new GL design and acid stimulation executed. Awaiting POP. 50-029-21534-00-00 L2-33 6 10/3/2009 N Not Operable; no flowline 5 High GOR with TxIA communication. Blinded at wing. No flowline. 50-029-21019-00-00 L3-08 6 7/1/1994 Y Well Fit for service 1 Well passed MIT-T and MIT-IA in 1Q 2015. CT cleanout and tubing isolation plug recovery successful. Currently awaiting gas-lift re-connect to POP. 50-029-21651-00-00 L3-12 1 11/29/2011 Y Well Fit for service 1 SI for High GOR. PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-21476-00-00 L3-15 2 11/28/2011 Y Well Fit for service 1 Low PI cycle well in communication with L3-23. 50-029-21670-00-00 L3-24 2 12/31/2007 Y Well Fit for service 1 High WC. Investigating acid stimulate. 50-029-21831-00-00 L4-03 6 5/10/2014 Y Well Fit for service; Pad PL OOS 6 3-phase pad pipeline is out of service. 50-029-21983-00-00 L4-10 6 6/2/2014 Y Well Fit for service; Pad PL OOS 6 3-phase pad pipeline is out of service. 50-029-21846-00-00 L4-11 6 12/3/1993 N Not operable; Pad PL OOS 6 3-phase pad pipeline is out of service. Well also has TxIAxPC communication. 50-029-22216-00-00 L4-12 6 10/15/2005 N Not operable; Pad PL OOS 6 3-phase pad pipeline is out of service. Well also has PC leak. 50-029-21973-00-00 L4-14 6 1/6/2014 Y Well Fit for service; Pad PL OOS 6 3-phase pad pipeline is out of service. 50-029-20952-00-00 L4-15 6 6/2/2014 Y Well Fit for service; Pad PL OOS 6 3-phase pad pipeline is out of service. 50-029-21845-00-00 L4-18 6 12/30/2011 N Not operable; Pad PL OOS 6 3-phase pad pipeline is out of service. Well also has TxIA communication 50-029-21860-00-00 L4-30 6 3/24/2014 Y Well Fit for service; Pad PL OOS 6 3-phase pad pipeline is out of service. 50-029-21966-00-00 L4-31 6 1/6/2014 Y Well Fit for service; Pad PL OOS 6 3-phase pad pipeline is out of service. Well also is high WC. 50-029-22205-00-00 L4-32 6 3/3/2003 N Not operable; Pad PL OOS 6 3-phase pad pipeline is out of service. Well also has TxIA communication (tubing cut). 50-029-22189-00-00 L4-36 6 5/12/2014 Y Well Fit for service; Pad PL OOS 6 3-phase pad pipeline is out of service. Well is also low PI. 50-029-23277-00-00 L-50 1 5/7/2007 N Well Fit for service; No flowline 5 No flowline 50-029-21908-00-00 L5-01 6 1/2/2003 N Not operable 2 Hole(s) in T x IA and PC leak. 50-029-21742-00-00 L5-05 1 12/31/2013 Y Well Fit for Service 2 High GOR. Stimulation potential being worked. 50-029-22086-00-00 L5-09 6 9/11/2007 N Well Fit for Service 5 Well is technically operable but will not flow due to 13,000' of e-line fish stuck (hydrated) in well. 50-029-21059-00-00 L5-13 see comments see comments Y On line see comments Well has been on line for almost all of 2015. 50-029-21868-00-00 L5-15 see comments see comments Y On line see comments Well has been on line for almost all of 2015. 50-029-21732-00-00 L5-21 1 1/8/2008 Y Well Fit for Service 1 Well integrity restored in 2015. Plan to POP well in near future. 50-029-22039-00-00 L5-23 6 7/25/2014 Y Well Fit for Service 6 Header problems on odd-side of L5 pad have prevented well POP. 50-029-21886-00-00 L5-25 6 3/23/2010 N Not operable 2 High GOR, TxIA comm from multiple holes. Tubing patch stuck in well. Evaluating options for further wellwork. 50-029-22079-00-00 L5-26 1 3/3/2011 Y Well Fit for service 2 Was high GOR, but GCWI might be reversing this in area. Needs some surface hydraulic panel repair work to POP. 50-029-22091-00-00 L5-31 1 8/4/2012 Y Well Fit for service 2 High GOR. Might have slim chance for GSO. 50-029-21943-00-00 L5-33 1 8/7/2010 Y Well Fit for service 2 High GOR well that tends to hydrate off. Evaluating well intervention options. 50-029-21783-00-00 LGI-04 7 11/28/1996 N Well Fit for service; no flowline 5 Significant facilities modifications required to flow producers from LGI to L1. No well flowline or operable pad flowline. 50-029-21560-00-00 LGI-12 7 3/1/1995 N Well Fit for service; no flowline 5 Module modification required to POP. No well flowline or operable pad flowline. 50-029-20105-00-00 M-04 6 12/2/2014 N Ann com 5 PC leak. 50-029-20373-00-00 M-07 7 2/12/2014 Y Well Fit for service; needs 6 Flowline repairs require work over pit. PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments flowline repair 50-029-21992-01-00 M-27A 6 7/24/1997 Y Well Fit for service 5 Fish in liner and low PI. 50-029-20087-00-00 N-03 6 1/1/1996 N Not operable; no flowline 5 NOT OPERABLE: PC hole(s). No flowline. 50-029-20098-00-00 N-06 6 8/5/2005 N ot operable; no flowline 5 NOT OPERABLE. Being used for UZI surveillance. Many down hole fluid barrier issues. Replaced with N-18A. No flowline. 50-029-20137-01-00 N-07A 3 10/6/2013 N Converted to an injector 4 N-30 used this well's flowline in late 2014 & came online 2/21/15. N-07A is converted to an injector in Q3 2015 as part of N-pad UZI. Troubleshooting injectivity problem 50-029-22410-01-00 NK-07A 6 9/2/2010 Y Well Fit for service 6 TxIA repaired with QCLL, waiting on new A/L line choke to POP 50-029-22507-01-00 NK-19A 3 3/4/2012 Y Well Fit for service 5 Low PI, IUD unsuccessful 50-029-22760-00-00 NK-25 see comments see comments Y On line see comments This well has been online 50-029-22852-01-00 NK-62A 2 12/8/2008 N TxIA comm 5 Swept 50-029-22704-00-00 P1-09 1 1/20/2014 Y Well Fit for service 6 SI for high GOR. Will be produced when 36" line returns to service 50-029-22284-00-00 P1-11 2 11/17/2012 Y Well Fit for service 6 Possible metering issue indicating higher wc than actual 50-029-22134-00-00 P1-12 see comments see comments Y Well Fit for service see comments P1-12 is currently on injection and was during 2015 also 50-029-22372-00-00 P1-13 1 1/27/2016 Y Well Fit for service 2 PC leak repaired 2015, currently SI for high GOR. Under review for logging to determine potential profile mods. 50-029-22953-01-00 P1-18A 6 4/9/2011 N Not operable 1 Surface casing hole(s); under review for RWO/ surface casing repair 50-029-22288-00-00 P1-20 2 8/22/2012 Y Well Fit for service 5 50-029-22690-00-00 P1-23 3 6/28/2012 Y Well Fit for service 6 Well Slugging 50-029-22097-00-00 P-18 6 7/9/2007 N Not operable 5 Shallow surface casing hole(s), possible fix with SC excavation but no current use for well.Well is secure with a plug. 50-029-22761-00-00 P2-01 2 11/13/2012 Y Well Fit for service 6 SI for High WC, need GC-1 line to bring online 50-029-22388-00-00 P2-06 6 11/2/1999 N Not operable 5 PC hole(s)/'Tbg cut. 50-029-22469-00-00 P2-07 2 9/30/2011 Y Well Fit for service 1 High WC, plus LPC PM2 to GC1 C/L SD, unblinding in progress for POP and wc sampling 50-029-22896-01-00 P2-08A 2 10/1/2012 Y Well Fit for service 6 SI for WC 50-029-22923-01-00 P2-11A 7 11/13/2011 Y Well Fit for service 6 LPC PM to GC-1 C/L SD 50-029-22888-00-00 P2-14 2 11/12/2011 Y Well Fit for service 6 LPC PM2 to GCI C/L SD 50-029-22765-01-00 P2-19A 2 11/12/2011 Y Well Fit for service 6 LPC PM2 to GCI C/L SD 50-029-22396-00-00 P-22 6 12/10/1996 N Not operable; flowline disconnected 5 TxIA comm, probable bad packer, FTS.High risk Wellwork considering obs at 10500 that failed to be milled out. Flowline disconnected. Well Secured with a Plug 50-029-22467-00-00 P2-21 2 8/18/2012 Y Well Fit for service 5 2-1-12 analysis by RLW, WSO low probability of success 50-029-22850-01-00 P2-22A 3 1/26/2012 Y Well Fit for service 6 Low PI 50-029-22785-00-00 P2-27 1 7/22/2012 Y Well Fit for service 6 Possible metering issue indicating higher wc than actual 50-029-22593-00-00 P2-32 6 10/24/2009 N Not operable 5 Surface casing hole(s)/ P2-32 replaced with P2-39 redrill 2012, no slot guts 50-029-22812-02-00 P2-33B 2 11/19/2013 Y Well Fit for service 6 SI for WC 50-029-23454-00-00 P2-39 2 7/19/2012 Y Well Fit for service 2 High Water Cut 50-029-22309-00-00 P2-48 2 9/30/2011 Y Well Fit for service 6 High WC (GC1 Water handling issues) plus LPC PM2 to GCI C/L SD 50-029-20353-00-00 R-01 6 11/1/1993 N Ann com;nNo flowline or AL line 5 Suspended with Ann Comm issues. No flowline or wellhouse. PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-20686-00-00 R-16 6 10/26/2015 N Not operable 3 Damaged liner, unable to clean out rocks. Well is being sidetracked currently (2/17/16). 50-029-21547-01-00 R-26B 7 12/4/2014 Y Well Fit for service 4 SI initially because of suspected ann comm, that has been addressed. Recently has been SI for drill by/simops. Will be put on production when R44i is complete at end of March. 50-029-22273-00-00 R-28 see comments see comments Y On line see comments Wellwork is complete. Operable after OA down squeeze. Its online. 50-029-22279-00-00 R-30 6 9/3/2005 Y Well Fit for service 1 Surface csg repair has been completed. Some well tie in work remains. 50-029-22277-01-00 R-31A 3 12/3/2014 Y Liner appears to be obstructed. 1 Wellwork planned. 50-029-20869-01-00 S-05A see comments see comments Y Online see comments Online 50-029-20829-01-00 S-07A 6 2/20/2012 N Not operable 5 SH hole(s). Waiting on SH weld. 50-029-23188-00-00 S-118 6 9/17/14 N Not operable 7 Collapsed tubing and TxIA communication. RWO not economic. 50-029-21611-00-00 S-19 1 10/25/2013 Y Well Fit for service 5 Operable SI For HGOR. Shut the Ivishak off and perfed the SAG; all Gas 50-029-22846-00-00 S-200 6 10/31/2001 N Well Fit for service 5 Collapsed liner. Possible ST in future 50-029-22987-00-00 S-201 6 10/12/2012 N Well Fit for service 1 Jet pump failed - procedure on WBL to replace 50-029-22989-00-00 S-216 8 7/6/2006 N Well Fit for service 5 Plan is to use surface hole + slot for future producer. Replaced DH location with new well S-217. 50-029-22088-00-00 S-23 6 12/4/2014 N Not operable 5 SH leak, IAxOA, flowline blinded, pinhole leak on S riser 50-029-22057-02-00 S-27B 3 5/2/2013 Y Well Fit for service 5, 2 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. Evaluating add perfs 50-029-22082-01-00 S-29A 5 see comments Y See comments 5 Operable, no offtake from pattern, no need for injection support in the area currently 50-029-22051-00-00 S-30 6 8/20/2003 N TxIA comm 5 TxIA. Missing sections of gas lift and production lines 50-029-22099-01-00 S-32A 7 4/6/2013 N See comments 2 Well has bent flowline and GL line 50-029-22494-01-00 S-40A 6 8/28/2006 Y RWO completed, should be POPd by end of month 5 1 SC hole(s). Eval ST Salamatof. 50-029-22645-01-00 S-41A 6 see comments Y Online under eval for IA pressurization 2 0 50-029-21170-01-00 U-02A 6 12/8/2002 N Well Fit for service; no flowlines 5 TxIA, PC hole(s); No flowlines. Well is not secured. 50-029-21127-00-00 U-07 2 10/15/2011 Y Well Fit for service; no flowlines 5 Operable. High watercut, no flowline. Well is not secured. 50-029-21136-01-00 U-08A 2 1/1/2002 Y Well Fit for service; no flowlines 5 Operable. High watercut, no flowline. Well is not secured. 50-029-20355-00-00 U-13 7 7/1/2006 N Well Fit for service; rock producer 5 Operable. Low oil rate. Rock producer w/ fill. Well is not secured. 50-029-22565-02-00 U-15B 2 7/14/2006 N Well Fit for service; no flowlines 5 Operable. High watercut, no flowline. Well is not secured. 50-029-23210-00-00 V-01 7 11/11/2012 Y Well Fit for service; no flowlines 3 High TGOR. Not competitive in the EWE LDF. 50-029-23391-00-00 V-05 see comments 05/10/2011 Y Online Injector see comments Well converted to injection. Is online as an injector. 50-029-23008-00-00 V-100 see comments see comments Y Online injector see comments Currently injecting PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-23074-00-00 V-101 6 1/8/2013 N Not operable 1 Surface casing hole(s) detected @ 45''-81''. Excavatable. Needs conductor cement top-out. Evaluating Brinker Platelet short term solution. 50-029-23156-00-00 V-117 2 7/18/2014 Y Well Fit for service 2 High Water Cut 50-029-23201-00-00 V-119 6 1/15/2010 N Not operable 5 Surface Casing hole(s) detected @ 15' 2'' from surface. Excavatable. 50-029-22023-01-00 W-12A 2 01/22/2014 Y Well Fit for service 3 Well SI for high WC. Planned for possible sidetrack. 50-029-22042-01-00 W-15A 6 1/29/2013 N Not operable 3 Cretaceous hole(s) detected, Not a candidate to fix or for RWO. Planned as possible sidetrack. 50-029-21867-01-00 W-34A 6 07/01/2014 N Not operable 1 Well SI for TxIA communication. Wellwork planned. 50-029-22322-00-00 WB-03 7 7/27/2005 Y Well Fit for service; FL need to be pigged 2 While the well is operable from an integrity perspective, WB flowlines off pad await ILI pigging priority. Significant temporary facilities required to pig lines. Sand control treatment has not been effective thus far. 50-029-22117-00-00 WB-04 7 9/15/2009 Y Well Fit for service; FL need to be pigged 6 WB flowlines off pad await ILI pigging priority. Significant temporary facilities required to pig lines. 50-029-22817-02-00 WB-05B 7 8/6/2009 Y Well Fit for service; FL need to be pigged 6 While the well is operable from an integrity perspective, WB flowlines off pad await ILI pigging priority. Significant temporary facilities required to pig lines. 50-029-20474-01-00 X-14A 7 12/4/2012 Y Well Fit for service 5 Low PI. 50-029-20675-00-00 X-18 6 4/7/2011 N IAxOA wellhead comm 1 A fix is being explored. 50-029-21112-00-00 X-27 4 8/19/2014 Y Not operable 2 Collapsed PC. May set downhole screen and produce. 50-029-20572-01-00 Y-08A 6 9/1/1993 N Not operable 5 Originally SI for low PI. Now Not Operable - TxIA, PC hole(s) detected. 50-029-20517-00-00 Y-12 6 5/1/1999 N Not operable 5 TxIAxOA. FTS. Poor tbg condition. Well is secured with a plug and sand over perforations. 50-029-20940-01-00 Y-15A 2 9/21/2010 N Not operable 5 High WC - low oil rate and packer leak. Obstruction in liner so cannot get into liner for WSO. Well is secured with a plug, cement behind tubing is acting as our new packer, well needs a passing MIT-IA to confirm. 50-029-20920-02-00 Y-17B 6 6/16/2002 N Not operable 5 SC hole(s) detected; SI wet since the beginning. Plan to plugback to Y-17A perfs for Y-03i offtake. Originally SI for high WC but now has SC hole(s) - well is secured with PX plug. 50-029-22191-01-00 Y-26A 3 8/6/2013 Y Well Fit for service 5 No current plans for the well, low PI. Operable. Not secured. 50-029-22169-00-00 Y-28 2 6/1/2010 Y Well Fit for service 5 Low rate high WC well. Operable Well. Not secured 50-029-22135-00-00 Y-30 2 1/12/2009 Y Well Fit for service 5 This area is swept. Mechanically operable well. Not secured 50-029-22161-00-00 Y-31 2 12/4/2007 N Not operable 5 Originally SI for high WC. No obvious ST targets. Secured, passed a CMIT-TxIA but failed MIT-T 50-029-22178-01-00 Y-34A 2 12/4/2007 Y Well Fit for service 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. 50-029-21830-02-00 Z-01B 3 2/9/2011 Y Well Fit for service 5 Low PI LTSI well. No sidetrack opportunities in the vicinity. 50-029-22056-01-00 Z-05A 2 11/17/2013 Y Well Fit for service 5 Gas on water when sidetracked. Not competitive on TGOR sorts. Some wellwork addperfs with estimated high gor- not competitive action in the EWE LDF. 50-029-22046-02-00 Z-07B 3 09/25/2014 Y Well Fit for service 5 Well SI due to low marginals in the EWE LDF. Low PI well. 50-029-22978-00-00 Z-101 3 4/1/2002 N Well Fit for service; no flowlines 5 No flowlines. Siderite area--tight rock. Evaluated this well for an injectorconversion, and it was cancelled. 50-029-23353-00-00 Z-102 see comments see comments Y Online injector see comments Currently injecting 50-029-23235-00-00 Z-103 see comments see comments Y Online injector see comments Currenlty injecting 50-029-23292-00-00 Z-108 3 1/31/2013 Y Well Fit for service 5 TGOR= 74-84 mscf/stbo..Even with U pad jumper open, this well is uncompetitive on a TGOR basis. Low PI. Well's total gas rate is too much for the small amount of oil it makes. 50-029-22001-01-00 Z-17A 7 02/03/2014 Y Well Fit for service 6 Well SI due to low marginals in the EWE LDF. POP when space allows. PRODUCTION Exhibit 10 State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-22037-02-00 Z-22B 3 12/8/2012 Y Well Fit for service 5 Well not competitive in the EWE LDF. Low PI well. 50-029-21950-02-00 Z-23B 7 2/10/2013 Y Well Fit for service 3 Well SI for low marginals in the EWE LDF. No wellwork opportunity. 50-029-22013-01-00 Z-30A 7 2/9/2013 N Not operable- 6 High TGOR- not competitive in the EWE LDF for total gas, including gas lift usage; well SI and broke MOASP. Classified as non-operable, no space to get back online to troubleshoot. 50-029-21924-03-00 Z-32C 7 05/17/2014 Y Well Fit for service 2 Well SI due to low marginals in the EWE LDF. POP when space allows. 50-029-22884-00-00 Z-35 2 4/1/2001 Y Well Fit for service; no flowlines 5 High WC, no current plans for well; no flowline 50-029-22995-01-00 Z-39A 2 2/10/2013 Y Well Fit for service 6 High TGOR- not competitive in the EWE LDF for total gas, including gas lift usage; high TGOR; 50-029-23474-00-00 Z-61 7 06/29/2014 Y Well Fit for service 1 Well SI due to low marginals in the EWE LDF. Wellwork in progress. 50-029-23441-00-00 Z-67 see comments see comments Y Online injector see comments SI for high WC. Planned conversion to injection approved and construction began. Well is online as injector. INJECTION State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-20042-00-00 M-01 7 8/1/1987 N No flowline 5 Suspended, replaced with M-28i. No flowline and no MI line. Setting TTP. 50-029-20103-00-00 H-03 7 7/15/2013 N No surface kit 6 It is a Cretaceous injector. Last used for pit dewatering into Cretaceous on 7/15/13. Does not have surface kit. 50-029-20164-01-00 01-09A 7 3/19/2007 N Needs prod casing repair 5 SI, prod casing needs repair. 50-029-20167-00-00 GC-2A 7 2/21/2006 N No flowline. 5 No flowline, has had injectivity issues historically. Non operable because it doesn’t have a flowline and MIT due date lapsed. Last MIT-IA, 1987, passed. MIT-T, 1990, passed. 50-029-20226-00-00 PWDW1 -1 6 7/6/2007 N Not operable 5 SI due to poor injectivity resulting from a SSSV fish down-hole. 50-029-20227-00-00 PWDW2 -1 6 2/1/2003 N Not operable 5 LTSI Cretaceous Disposal Well, PC hole at 2992’, would require redrill. 50-029-20259-00-00 09-18 5 6/14/2012 N MIT-IA 3 SI for Organoseal Job to squeeze off Zone 3. Cement squeeze with Fiber was partially successful. No mechanical barriers; needs to pass MIT-IA. 50-029-20309-00-00 GC-3D 7 6/28/2014 N MIT-IA 5 Could not be placed on injection for AOGCC MITIA 50-029-20316-00-00 B-09 7 8/19/2014 N TxIA comm 5 Has been replaced by B-32A. Was used for pit de-watering in the past, but its IA pressures up now when doing this. Tubing most likely in bad shape. 50-029-20354-00-00 R-02 6 6/11/2011 N Ann com. 2 Ann com at sliding sleeve. Reviewing repair options. 50-029-20512-00-00 M-14 6 7/14/2013 N Not operable 5 7” corroded tbg. Last MIT-IA, 2009, passed. Last MIT-T, 2015, passed. Well is secured. 50-029-20522-01-00 M-13A 6 10/26/2015 N Not operable 5 Production csg leak. Well is secured. 50-029-20574-00-00 16-05 6 7/6/2015 N Well fit for service; needs VSMs repaired 6 Needs VSMs repaired 50-029-20625-00-00 14-14 6 8/10/2006 N Not operable 5 IAxOA and no flowline; Leaks from a tubing patch & IA to formation. 50-029-20641-01-00 R-20A 6 6/6/2006 N Surface casing leak 5 Surface casing leak. Well is secured. 50-029-20642-01-00 13-06A 4 1/30/2016 N Needs tree change out 1 Had IA & OA cemented to restore integrity. Needs a tree change out. INJECTION State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-20671-00-00 13-09 6 12/25/2014 N Flowline decommissioned 5 Well is fine. Flowline decommissioned. 50-029-20710-00-00 A-21 8 6/10/2004 N See Comments 5 A-17 Sidetrack replaced A-21. A-44 using A-21 Facilities. 50-029-20733-00-00 T-07 6 7/1/1999 N Ann com; no flowline 5 Ann com and no flowline. Well is secured. 50-029-20761-00-00 13-25 6 10/21/2007 N TxIA comm 5 TxIA 50-029-20860-01-00 01-24A 6 12/13/2013 N Not operable 2 Tubing needs repair 50-029-20959-00-00 S-04 6 12/2/2011 N TxIA comm 1 , 3 TxIA and flowline repair needed. 50-029-21005-00-00 R-22 6 10/22/2012 N Needs tie in and MIT-IA 6 Has been sidetracked to R22A. Waiting for well tie in/ simops then MIT-IA and put on injection. 50-029-21018-00-00 14-35 7 10/5/2014 N Well Fit for Service; needs flowline reconnect & new wellhouse 6 VSM issues fixed. Waiting on flowline reconnect and new wellhouse. 50-029-21042-00-00 12-25 7 3/6/2013 N Well Fit for service; needs flowline repair 6 Well OK, FL will be repaired 50-029-21046-00-00 14-27 6 11/17/2004 N See comments 1 Flowline replaced, but well developed PC leak. IA cement squeeze was performed 12/2015 50-029-21101-00-00 12-21 7 7/14/2013 N Well Fit for service; needs flowline repair 6 Needs Flowline repair 50-029-21113-00-00 S-15 6 9/10/2010 N Not operable 2, 5 SC hole(s). 50-029-21142-03-00 03-33C 3 11/17/2014 Y Well Fit for service 6 . The well is SI due to surface facility issues with the main MI line to DS-03 The well passed an AOGCC MIT-IA to 3,000 psi on 11/28/12. The last passing MIT-IA to 3,500 psi was on 1/6/14. 50-029-21241-00-00 T-01 6 7/1/1999 N Ann com; no flowline 5 Ann com and no flowline. Main line to pad corroded. Well is secured. 50-029-21394-00-00 11-10 5 5/4/2014 Y Well Fit for service 3 Well recently sidetracked. The last passing MIT-IA was the AOGCC MIT-IA to 2,472 psi on 2/23/16. The well will be brought online to support the producers in the injection pattern. INJECTION State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-21423-00-00 U-10 6 1/4/2014 N Well fit for service; needs flowline repair 5 Flowline is SI for corrosion. 50-029-21488-00-00 04-28 6 7/29/2010 N TxIA comm 5 Needs RWO and flowline replacement. 50-029-21510-00-00 B-28 6 1/1/2000 N TxIA comm 5 Tub holes and possible packer leak; no current use, 50-029-21628-00-00 11-26 5 3/22/2013 N Well Fit for service 4 The injector had integrity and it was SI for reservoir management to allow the gas to enter the DS-11 producers for increased oil production. The well passed an AOGCC MIT-IA to 2,500 psi on 1/28/12. The last passing MIT-IA to 2,500 psi was on 2/17/16. Another AOGCC MIT-IA will be obtained pending post Borax logging results for the liner (to check the liner for behind liner channeling). If the liner has no channels then the well will be brought online and AOGCC tested. 50-029-21772-00-00 GC-1D 6 8/5/2014 Y Under Eval 2 The 9-5/8” casing developed a leak in August 2014. A RWO was completed in November 2015 to repair the leak and passed a MIT-IA to 2500 psi. The well is ready to POI under eval to facilitate AOGCC witnessed MIT-IA. 50-029-21774-00-00 GC-2C 7 10/4/2007 N Well Fit for service; needs flowline repair 6 SI because of flowline issues. Last MIT-IA, 2009, passed. 50-029-21776-00-00 W-40 7 10/18/2014 Y Well Fit for service 2 Well SI due to low marginals in the EWE LDF. POP when space allows. 50-029-21871-00-00 Z-31 7 11/26/2011 N Well Fit for service; needs VSMs repaired 6 VSM's need repair. 50-029-21903-00-00 12-31 7 3/2/2014 N Well Fit for service; needs flowline replaced 6 FL needs to be replaced 50-029-21909-00-00 12-33 7 6/30/2014 N Well Fit for service; needs flowline replaced 6 FL needs to be replaced 50-029-21919-00-00 09-38 8 4/10/2011 N Well Fit for service; no flowline 3 No PWI line or flowline. Injector injects out of zone for pattern conformance. Candidate for Z4 MIST trials 50-029-22044-01-00 S-24A see comments see comments Y Online see comments Online 50-029-22229-00-00 04-42 6 8/18/2012 N Surface Casing leak 5 SC leak 50-029-22251-01-00 Z-19A 6 9/1/2015 N Not -operable 1 Well has micro-OA repressurization 50-029-22305-00-00 S-34 see comments see comments Y Online see comments . Online currently, RWO in Nov. 2015 50-029-22338-00-00 P1-14 6 2/1/2013 N Well Fit for service 2 PC leak repaired, Ops working leak check, blind rolling, signoff. 50-029-22348-00-00 AGI-08 6 3/4/2014 N Ann comm 7 Needs RWO 50-029-22393-00-00 P-23 6 11/4/2000 N Not Operable 5 Holes in tubing and leaking packer. 50-029-22443-00-00 04-43 6 12/20/2011 N TxIA comm 2 TxIA comm; run LDL 50-029-22447-00-00 NK-16 5 6/8/2008 N TxIA comm 5 TxIA comm INJECTION State API Sw Name Reason for Shut-in Date Well was Shut- in Operati onal (Y/N) Current Mechanical Condition Analysis of Future Utility of Well Comments 50-029-22451-00-00 09-37 6 7/7/2009 N Broken pit valve 6 Got passing MIT-IA in Summer 2015. Waiting on repair,but has broken pit valve. 50-029-22466-00-00 11-29 6 12/31/2012 N Well Fit for service needs surface kit installed 6 The injector completed a rig workover on 11/23/15 to fix TxIA communication. It passed a MIT-IA to 2,500 psi with the rig on the well on 11/21/15. The well has integrity. It is scheduled to have the surface kit installed prior to bringing it online. After the injector is online, an AOGCC test will be obtained. 50-029-22476-00-00 11-35 6 12/31/2012 N Not operable 5 The injector not placed online in time for its required AOGCC test. There is no current utilization. 50-029-22613-00-00 13-36 6 9/23/2010 N Not operable 1 TXIA and possible IAxOA 50-029-22745-00-00 NK-15 6 2/12/2013 N TxIA comm 2 Tubing leak confirmed with LDL, attempting to patch. 50-029-22845-00-00 GNI-01 6,7 5/6/07 N Not operable; no flowline 6 Erosion tubing damage; No Flowline 50-029-22929-00-00 WB-06 6 9/3/2003 N Not operable 5 OA squeeze failed 50-029-23172-00-00 W-215 6 9/28/2014 N Not operable 7 Needs RWO 50-029-23197-00-00 L-211 5 7/24/2012 Y Well Fit for service 4 SI for reservoir management. No offtake in area (L-200). 50-029-23206-00-00 L-216 5 7/28/2012 N Not operable 4 SI for reservoir management. (Cycles with other offset injectors to V-205 as needed). 50-029-23252-00-00 L-212 5 7/24/2012 Y Well Fit for service 4 SI for reservoir management. No offtake in area (L-200). 50-029-23272-00-00 L-218 5 7/24/2012 Y Well Fit for service 4 SI for reservoir management. No offtake in area (L-200). 50-029-23289-01-00 S-400A 7 11/6/2008 N Well Fit for service; needs surface drive module 5 No longer has a surface drive module. 50-029-23290-00-00 L-123 3 10/8/2013 Y Well Fit for service 5 No current utilization 50-029-23350-00-00 V-218 5 11/18/2014 Y Well Fit for service 4 SI for reservoir management. 50-029-23385-00-00 L-221 5 10/10/2010 Y Well Fit for service 4 SI for reservoir management. No offtake in area (L-200). 50-029-23387-00-00 L-220 5 10/10/2010 Y Well Fit for service 4 Offsets L-205. Will return to service after L-205 is online. 50-029-23417-00-00 V-227 4 6/21/2011 N Not operable 1 Fish 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 INJECTION 8- Out of Zone Injection 8- Waiting on Waiver 9- Conversion Exhibit 11-1 Exhibit 11-2 Note: Current producers at Ds-02 are 02-23A and 02-27A Exhibit 12 Put River Sandstone Distribution 1-08A