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2016 Prudhoe Oil and Put River Oil Pools
2 BP Exploration (Alaska) Inc. P. 0. Box 196612 900 East Benson Boulevard Anchorage, AK 99519-6612 March 15, 2017 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7t' Avenue, Suite 100 Anchorage, AK 99501 Re: ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL and PUT RIVER OIL POOL - 2016 Dear Chair Foerster, BP Exploration (Alaska) Inc. (BPXA), as the operator of the Prudhoe Bay Unit, submits the enclosed consolidated Surveillance Report for the Prudhoe Bay Waterflood Project, Miscible Gas Project, Gas Cap Water Injection Project, Field Gravity Drainage Area and Put River Oil Pool. This report is submitted in accordance with the requirements of Conservation Orders 341F and 559, and covers the time period of January 1 through December 31, 2016. BPXA may alter the content of the analyses contained in this report as it obtains new surveillance information. Please direct any questions you may have to the undersigned or to Bill Bredar at 564-5348, william.bredar@bp.com. Sincerely, L�� Diane Richmond Performance and Data Management Team Lead Alaska Reservoir Development, BPXA 564-4136 101 Attachments: Exhibits 1 through 12 Cc: H. Jamieson, ExxonMobil Alaska, Production Inc. G. Smith, ExxonMobil Alaska, Production Inc. E. Reinbold, CPAI D. White, Chevron USA D. Roby, AOGCC R. Kruse, DNR ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL AND PUT RIVER OIL POOL JANUARY THROUGH DECEMBER 2016 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS CONTENTS !1 r/1T1/ L1 P'1A 11r 1.0 INTRODUCTION 4 2.0 OVERVIEW 5 3.0 PRESSURE UPDATE 6 3.1 Pressure Monitoring 6 3.2 Pressure Plan 7 4.0 PROJECT SUMMARIES 8 4.1 Flow Station Two Water / MI Flood Project 8 4.2 Eastern Peripheral Wedge Zone Water / MI Project 9 4.3 Western Peripheral Wedge Zone Water / MI Project 10 4.4 Northwest Fault Block Water / MI Project 11 4.5 Eileen West End Waterflood Project 12 4.6 Gas Cap Water Injection Project 13 4.6.1 Observation Well RST Surveys and Zonal Conformance 13 (includes previous section 4.6.2 used till 2007 report) 4.6.2 2016 Surveillance Plans 14 4.6.3 Plans for Change in Project Operation 14 4.7 Put River Pool 15 5.0 GAS MOVEMENT SURVEILLANCE 16 5.1 Gas Movement Summary 16 Page 2 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 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 Not used. A Sl Well List to be provided by March 31, 2017 per 20 AAC 25.115 11-1 GCWI Flood Front and Well Locator Map 11-2 GCWI Water Bank Cross-section Interpretation - 2016 Page 3 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 1.0 INTRODUCTION As required by Conservation Order (CO) 341F and CO 559, 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 2016. 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 A report of completed development or service wells that have been shut-in for 365 days or longer as of January 1, 2017, will be separately filed with the Commission by March 31, 2017, in accordance with 20 AAC 25.115. Separate sections are provided for the five major flood areas: Flow Station 2 (FS -2), Eastern Peripheral Wedge Zone (EPWZ), Western Peripheral Wedge Zone (WPWZ), North West Fault Block (NWFB), and Eileen West End (EWE) along with information on the GCWI in the Gravity Drainage region and the Put River Pool. Water and miscible gas floods are described in each section. A separate section has been provided with detailed information on gas -oil contact surveillance. As agreed in 2004 with the Commission, the discussion of Gas Production Mechanisms was not included in the report. Page 4 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 2.0 OVERVIEW Exhibit lA 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 year's 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 2016, field production averaged 197.9 MBOD, 7042.9 MMSCFD (GOR 35,586 SCF/STB), and 852.3 MBWD (water -cut 81.15 %). Overall Waterflood injection during this period averaged 1175 MBWD with 135.38 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2016 was 12,742 MMSTB, while cumulative MI injection was 3,206 BCF. Cumulative production in these same areas (not including Gravity Drainage) since waterflood startup was 2,994 MMSTB oil, 13,735 BCF gas, and 9,118 MMSTB water. As of December 31, 2016, cumulative production exceeded injection by 9,073 MMRB compared to 8,246 MMRB at the end of 2015. 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 2014 through 2016 at a datum of 8,800 ft, subsea for the Full Field Dominant Zone. Using the three year rolling technique improves the statistical validity of the pressure distribution since it roughly triples the number of data points employed versus only using the current year static pressures. As in the past, abnormal pressures, such as pressures taken in fault compartments and in the Sag Formation have been removed. As shown in Exhibit IE, the historic pressure decline appears to have stabilized due to gas -cap water injection with 60% of repeat 2016 pressure surveys found equal to or greater than their 2014 or 2015 pressure measurements. For 2016, average pressure in the PBMGP project areas using three years of pressure static measurements was calculated to be 3,343 psia by areal weighting, as compared to 3350 psia in 2015 (Exhibit 1F). The GD area pressure was stable increasing two psi from 3,275 psia in 2015 to 3,277 psia in 2016. This subtle pressure increase is within the expected statistical variation with a different annual pressure sampling data sets. Confirmed MI breakthrough has occurred in 100 wells during the reporting period. RMI production is an indicator of EOR pattern performance and the presence of RMI is determined by gas sample analyses that show a separator gas composition richer in intermediate range hydrocarbon components. MI breakthrough in a well is considered to have occurred when the Page 5 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS average RMI rate over the number of producing days in a well exceeds 200 MCF/D. The previous year- showed MI breakthrough in 116 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 2016 average monthly CGF MI rates and compositions for the field. Relating to condition 5 of CO 547.004 (as amended by CO 547.006), during the reporting period there were two Gen 2 (VSRD) meters utilized in the Prudhoe Oil Pool, at L Pad and V Pad. Production from L and V Pads comes from the Prudhoe Pool (Ivishak Formation), Borealis Pool (Kuparuk), and Orion Pool (Schrader Bluff), and presents a wide range in fluid types and composition involving a challenge for metering. The Gen 2 (VSRD) meters at both pads, when calibrated by independent means such as the ASRC test separator, have had close matches with total fluids, and formation gas, but have struggled to match water cut. The Gen 2 meters at L and V Pads are known as VSRD meter kits, and are composed of four components: a Venturi meter, Sonar flow meter, Red-eye water cut meter, and gamma Densitometer. When one of the four components of the Gen 2 VSRD meter kits is non- operational, the others are also down. Maintenance of the Gen 2 VSRD is challenged because it requires specialized skills that are only available from the vendor. L pad has both a pad test separator and a Gen 2 VSRD metering kit. The pad test separator is thought to be more accurate for the one active Ivishak well on the pad so allocations were typically done using the pad test separator well tests. At V pad the pad test separator was taken out of service in 2012. The Gen 2 VSRD metering kit is used to test and allocate the three active Ivishak producers. A calibration test was done in 2016 with a portable test separator. There was a wider error band than expected for the Ivishak wells. To mitigate the allocation uncertainty in the short term, well head temperatures were compared to other Ivishak wells on pads with more metering certainty. A study is currently under way to determine if the Gen 2 VSRD meter can be better calibrated for Ivishak wells or if the pad test separator should be reinstated. 3.0 PRESSURE UPDATE 3.1 Pressure Monitoring Exhibit 9 provides pressure, buildup, and falloff data collected in 2016 at a datum of 8,800 ft, subsea used for the Full Field Dominant Zone. Beginning this year, per CO 341F, as modified by the Commission on July 20, 2016, use of calculated BHP's from surface data in injectors are permitted. All of these new data are listed in Exhibit 9 as "FL". Inclusion of the reasonable surface calculated data, based on consistency of the results, reveals an elevated pressure area in the Gas Cap associated with the GCWI project. For this report, as in the past, pressures taken in fault compartments, the Sag River Formation, and in Zone 1 of the G -Pad LPA (Low Pressure Area), which don't appear to be in good communication with the rest of the reservoir, have been excluded from Exhibit 1-D. Also excluded were wells shut-in less than a week that had not stabilized as compared to offsetting statics. Other wells completed in Zone 1 and Zone 413, which Page 6 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 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 2016 pressure map using 2014 through 2016 data points. 3.2 Pressure Plan Per CO 341F Rule 6b, the following pressure surveillance plan information is provided, 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 plan for 2017 calls for collection of 60 pressure surveys fieldwide. The number of planned surveys is the same as last year. A summary of pressure surveys run during 2016 is presented in Exhibit 9. Page 7 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 4.0 PROJECT SUMMARIES 4.1 Flow Station Two Water / MI Flood Project The Flow Station Two area (FS -2), which comprises the eastern third of the Eastern Operating Area, is shown in Exhibit 3-A. The locations of production and injection wells are shown with the EOR injection patterns identified. There were 105 producing wells and 58 injection wells that contributed to production/injection during 2016 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 23.5 MBOD for 2016 compared to 24.9 MBOD in 2015. Cumulative production since waterflood start-up through the end of 2016 is 1,101 MMSTB of oil 6,142 BCF of gas, and 4,601 MMSTB of water. Injection rates averaged 329.5 MBWD and 38.5 MMSCFD in 2016. Since 12/31/15, the waterflood imbalance has increased from a cumulative under injection of 3145 MMRB to 3303 MMRB under injected. During the report period, production exceeded injection by 157 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 2016, is 6,702 MMSTB and 1,070 BCF respectively. The flood area's GOR decreased from an average of 27,138 SCF/STB in 2015 to an average of 17,640 SCF/STB in 2016. 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 92% to 90% from 2015 to 2016. A breakdown of the production and injection data is provided in Exhibit 3-13 for the report period. See Exhibit 1-C for a comparison of the cumulative figures with last year's AOGCC report. Exhibit 3-C presents the areal average waterflood pressure change over time. The pressure in the FS -2 area was 3,409 psia in 2016. This is an increase of 11 psi over the 2015 pressure. Exhibit 3-D is a presentation of 2016 average returned MI (RMI) rates. Miscible gas return has been confirmed in 20 wells by gas compositional analysis (RMI>200 MSCFD). Page 8 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 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 2016, oil production averaged 17.9 MBOD, as compared to 16.4 MBOD in 2015, with an average 91% water cut and 17,640 SCF/STB Gas Oil Ratio. Injection averaged 125 MBWD and 16.8 MMSCFD of miscible injectant (MI). There are a total of 77 producers and 20 injectors in the flood area that contributed to production/injection during 2016. Of the 20 injectors, 5 injected miscible gas at some point throughout the year, while the remaining wells injected water only. Production and injection values have been calculated using polygon boundaries the same as last year's report. Two waterflood start-up dates have been used, 12/30/82 for the DS 13 flood and 8/20/84 for the down -dip sections, rather than the start-up dates of each injection pattern. A cumulative total of 653 MMSTB of oil, 3,563 BSCF of gas, and 1,829 MMSTB of water have been produced with 2,310 MMSTB of water and 685 BSCF of miscible gas injected. Exhibit 4-13 shows the monthly injected and produced volumes on a reservoir barrel basis during 2016 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 118 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 3,332 psia in 2016. This is an increase of 2 psi as compared to 2015. Exhibit 4-D shows the 2016 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). Page 9 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 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 18.9 MBOD compared with 21 MBOD in 2015, with a gas/oil ratio of 14,959.7 SCF/STB and a watercut of 89%. Injection averaged 124 MBWD of water and 36.38 MMSCFD of miscible injectant. For the WPWZ project, 41 injectors (10 WAG injectors and 30 water injectors, 1 gas injectors), and 99 producers contributed to the production and injection during 2016. 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 2016 was 1,846 MMSTB while cumulative MI injection was 651 BSCF. Cumulative production since waterflood start-up is 545 MMSTB oil, 2,224 BSCF gas, and 1,435 MMSTB water. As of December 31, 2016 cumulative production exceeded injection by 1,546 MMRB. Exhibit 5-13 provides the monthly injection and production data from 01115 through 12/15. During the report period, production exceeded injection by 96 MMRB. The reservoir balance in Exhibit 5-13 doesn't identify support from the aquifer, thereby understating voidage replacement nor does it capture the production of gas -cap -gas which needs not be replaced. During 2006 a produced water tie - line was installed connecting two GC -1 slug catchers to GC -3 produced water tanks. This allowed up -dip Zone 4 waterflood expansion and should allow ideal voidage replacement in the eastern half of the WPWZ area. Exhibit 5-C shows that the pressure in the WPWZ was 3,303 psia in 2016. This is a decrease of 10 psi over the pressure reported in 2015. Exhibit 5-D indicates wells with MI breakthrough and the 12 -month averaged returned MI rates. Miscible gas breakthrough has been confirmed in 30 wells by gas compositional analysis. Page 10 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 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 9.8 MBOD, as compared to 8.8 MBOD in 2015, with a gas/oil ratio of 8626.2 SCF/STB and a watercut of 85%. Injection averaged 50.4 MBWD and 17.4 MMSCFD of miscible injectant. For the NWFB project, 31 injectors (2 WAG injectors, 24 water injectors, and 5 gas injector), and 62 producers contributed to the production and injection during 2016. 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 2016 was 1,684 MMSTB while cumulative MI injection was 689 BCF as detailed in Exhibit 61-C. Cumulative production since waterflood start-up was 607 MMSTB oil, 1,445 BSCF gas, and 1,057 MMSTB water. As of December 31, 2016 cumulative production exceeded injection by 640 MMRB. Exhibit 6-13 provides the monthly injection and production data from 01/16 through 12/16. During the report period, production exceeded injection by 27 MMRB. However, this does not include support obtained from aquifer influx or gas cap expansion. The areally weighted pressure in the NWFB area was 3,332 psia in 2016. This is a decrease of 3 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 18 wells by gas compositional analysis. Page 11 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 4.5 Eileen West End Waterflood Project Exhibit 7-A is a map of the Eileen West End (EWE) waterflood area and miscible gas (MI) flood area. During the report period, oil production averaged 13.8 MBOD, as compared to 14.4 MBOD in 2015, with a gas/oil ratio of 3,151 SCF/STB and water cut of 75%. Injection averaged 35.2 MBWD and 16.6 MMSCFD of miscible gas injectant. For the EWE project, 18 injectors (4 WAG injectors, 13 water injectors and I gas injectors), and 70 producers contributed to the production and injection during 2016. The well counts reflect only the active wells for the year. Cumulative water injection from waterflood start-up in September 2001 through December 2016 was 200 MMSTB and cumulative MI injection was III BCF. Cumulative production since waterflood start-up was 89 MMSTB oil, 361 BCF gas, and 196 MMSTB water. As of December 31, 2016 cumulative production exceeded injection by 309 MMRB. Exhibit 7-13 provides the monthly injection and production data from January 1, 2016 through December 31, 2016. During the report period, production exceeded injection by 15 MMRB. The EWE pressure was 3,650 psia in 2015 representing an average pressure increase of 5 psi for this area from 2015. Exhibit 7-C indicates wells with MI breakthrough and the 12 -month average returned MI rates. Miscible gas breakthrough has been confirmed in 12 wells by gas compositional analysis. Page 12 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 4.6 Gas Cap Water Injection Project Details of the volume of water injected into the Gas Cap during 2016 are shown below; units in thrnisands of harrels of seawater iniected ner month (MBWPMI: The 2016 volume of sea water injected in the PSI wells was 117.3 million barrels. The cumulative volume injected at the end of 2016 was 2.4 billion barrels of sea water since the project startup in 2002. 4.6.1 Observation Casedhole Saturation Logs and Zonal Conformance Pulsed neutron logs (RPM, RMT, etc) run in offset producers continue to be the primary method of monitoring water movement from the Gas Cap Water Injection project. Many of these wells have had several repeat logs since injection began. By comparing the latest neutron logs with the baseline and previous logs, the presence of injected water can be readily observed. This procedure has provided a very clear picture of water in the Ivishak Formation and allows the monitoring of vertical and lateral movement of the waterfront. Exhibit 11-1 is the locator map for the GCWI area and shows the PSI injectors along with the observation wells. The red polygon indicates the interpreted current GCWI waterfront, which has very minimal change since 2015. Surveillance well 02-36A, south of the mid -field graben had no water logged in 2016. Surveillance well 15-30B, in the western extent of the front, also had no water logged in 2016. Surveillance well 05-02A, however, did have water logged in 2016, resulting in a slight extent of the polygon in the south. The information from the neutron logs was also used to develop the updated northwest -southeast and north -south cross sections (Exhibit 11-2) showing the interpretation of the surveillance data for the current time period. Page 13 PSI -01 PSI -05 PSI -06 PSI -07 PSI -08 PSI -09 PSI -10 Total 1/1/2016 2,719 2,607 2,613 2,657 2,587 2,569 2,361 18,114 2/1/2016 2,498 2,421 2,329 2,276 2,371 2,240 2,139 16,273 3/1/2016 2,076 1,996 1,982 1,994 2,030 2,047 1,984 14,109 4/1/2016 115 504 89 0 108 447 434 1,697 5/1/2016 0 0 1 0 0 0 0 0 0 6/1/2016 0 0 1 0 0 0 0 0 0 7/1/2016 0 0 0 0 0 0 0 0 8/1/2016 1,909 1,922 2,045 2,114 1,917 1,979 1,989 13,875 9/1/2016 2,212 2,021 2,152 2,174 2,114 2,126 2,077 14,875 10/1/201 6 1,375 1,282 1,228 1,292 1,369 1,308 1,292 9,146 11/1/201 6 1,493 1,461 1,803 1 1,777 1 1,604 1,526 1,540 11,203 12/1/201 6 2,725 2,691 2,810 2,807 1,663 1 2,740 2,601 18,038 The 2016 volume of sea water injected in the PSI wells was 117.3 million barrels. The cumulative volume injected at the end of 2016 was 2.4 billion barrels of sea water since the project startup in 2002. 4.6.1 Observation Casedhole Saturation Logs and Zonal Conformance Pulsed neutron logs (RPM, RMT, etc) run in offset producers continue to be the primary method of monitoring water movement from the Gas Cap Water Injection project. Many of these wells have had several repeat logs since injection began. By comparing the latest neutron logs with the baseline and previous logs, the presence of injected water can be readily observed. This procedure has provided a very clear picture of water in the Ivishak Formation and allows the monitoring of vertical and lateral movement of the waterfront. Exhibit 11-1 is the locator map for the GCWI area and shows the PSI injectors along with the observation wells. The red polygon indicates the interpreted current GCWI waterfront, which has very minimal change since 2015. Surveillance well 02-36A, south of the mid -field graben had no water logged in 2016. Surveillance well 15-30B, in the western extent of the front, also had no water logged in 2016. Surveillance well 05-02A, however, did have water logged in 2016, resulting in a slight extent of the polygon in the south. The information from the neutron logs was also used to develop the updated northwest -southeast and north -south cross sections (Exhibit 11-2) showing the interpretation of the surveillance data for the current time period. Page 13 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS The most recent round of neutron log surveillance included the following wells: 02-36A, 05- 02A, 05-2313, 11-26, 15-3013, L2 -03A, L2-11, L2-24 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 most areas. 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 2016 logs indicated very little direct evidence of increased lateral extent; rather, the zones 4, 3 and 2 had increased vertical extent of water. Surveillance wells for 2016 saturation monitoring were chosen for sufficient coverage to monitor GCW extent, as well as better refine understanding of the water movement into the producing zones IA and 113. This year, two wells (02-36A, 15-30B) saw only gas in section. With the exception of 05-02A, there was no new evidence that water has migrated further than the 2015 extent. GCW has continued to produce through the waterflood pads DS -11 and DS -4, although differentiating between the two sources of water on cased hole saturation 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 18-35 which was completed in late 2015, have seen GCW from Z3 down to bottom of Z113. It remains unclear if GCW has flooded ZIA in any significant area. Understanding the water pathway to Zone 1, which is the oil bearing interval in this far upstructure area of the field, is a focus for future logging and analysis. Also, as producing wells experience water breakthrough, production evidence is increasingly important to incorporate with log analysis. Future surveillance will continue to include repeat neutron logs for monitoring the maximum lateral extent of the flood front, monitoring water movement within each zone, and specifically in the producing Zone 1. 4.6.2 2017 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 Casedhole Saturation Logs This program will continue as it has in the past by running casedhole saturation logs every year with the final timing and locations determined based on the results to date. Gravity Survey A gravity survey is not planned for 2017. 4.6.3 Plans for Change in Project Operation No changes to the Gas Cap Water Injection operation are planned for 2017. Page 14 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 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. 2016 Production and Injection For the year 2016, all of the production and injection in the Put River Pool occurred in the Southern Lobe. However, most 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 regular access to other sources of water. Water injection was restarted on June 23, 2016, when pit water became available for injection. Production was restarted in well 02-27A on June 27, 2016, and in well 02-23A on July 5, 2016. Injection and production were intermittent over the period late -July -August 2016. On August 26, 2016, well 02-23A was shut-in. Water injection stopped on September 3, 2016 as the pit water source became unavailable. Well 2-27A was returned to production on September 22, 2016, and production continued until the well was shut-in on December 7, 2016. During this approximate 2.5 month period there was no water injection into the pool. The commission was notified of this period on February 23rd, 2017. Production from the Put River Oil Pool in 2016 averaged 725 BOPD for the days the reservoir was on 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 will be considered for perforation in the Put River in the future. Those perforations could potentially be accessed if 02-23A or 02-27A fails and are economics do not justify a rig workover. Injection in the Southern Lobe of the Put River averaged 7530 BWPD for the days the injector was online and 1220 BWPD averaged across calendar days. Cumulative Put River water injection is 11.3 MMBW, of which 444 MBW was injected in 2016. The 2016 cumulative production for the Put River Oil Pool was 99 MBO, 447 MBW and approximately 57 MMSCF formation gas. The full life cumulative production for the Put River Oil Pool through December 31, 2016 was 4.01 MMBO, 7.03 MMBW, and approximately 2.3 BSCF formation gas. 2016 Pressures Put River pressures taken during 2016 are listed in Exhibit 9. The Southern Lobe pressure obtained in 02-23Aproducer in January 2016 measured 3,529 PSI at 8100' SSTVD. No tracer breakthrough was observed in 2012, 2013, 2014, or 2015 but reservoir connection is evident through pressures. Page 15 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 2017 Surveillance Plan Southern Lobe — Production will restart/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 targeting a cumulative VRR of 1.0. Static pressures will be taken periodically through the year to monitor pressure. A pressure was obtained for 02-27A in early 2017. Western Lobe - No 2017 production or surveillance planned. Central Lobe - No 2017 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 2016 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 2016 through December 2016. A total of 67 gas -monitoring logs were run in the PBU of which 55 were cased -hole. On July 20, 2016 the Commission modified the neutron log requirements in CO 341F Rule 7 (341F.002 Page 16 2016 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS (Corrected)) to provide that either cased or open hole neutron logs are useable to fulfill the minimum requirements of 40 neutron log surveys to be run annually. Page 17 Exhibit 1-A Prudhoe Bay Unit Field Schematic Exhibit 1-13 NOTES: (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. WELL COUNT BY FIELD AREA WPWZ NWFB FS2 EPWZ EWE GD 2015 AOGCC Report Producers 101 63 101 75 64 469 Injectors 43 26 59 27 18 52 -WAG 8 3 1 0 9 1 -Water Only 33 21 56 25 9 20 -Gas 2 2 2 2 0 31 2016 Producers 99 62 105 77 70 446 Injectors 41 31 58 20 18 53 -WAG 10 2 5 4 4 -Water Only 30 24 50 16 13 21 -Gas 1 5 3 1 32 Production Well Status in 2016 -Newly Drilled 0 0 0 0 0 1 Sidetracked or Redrilled 1 4 7 3 1 14 Gas Injection Well Status in 2016 -Newly Drilled 0 1 0 0 0 0 -Sidetracked or Redrilled 0 0 0 0 0 0 WAG Injection Well Status in 2016 -Newly Drilled 0 0 0 0 0 0 -Sidetrcaked or Redrilled 0 0 1 0 0 0 Water Injection Well Status -Newly Drilled 0 0 0 0 0 0 -Sidetracked or Redrilled 0 0 0 0 0 0 NOTES: (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. Cumulative Production from WF Start -Up thru 2016 Oil (MMSTB) Gas (BCF) Water (MMSTB) Cumulative Injection from WF Start -Up thru 2016 Water (MMSTB) MI (BCF) Cumulative Balance from WF Start -Up thru 2015 Cum Production (MMRB) Cum Injection (MMRB) Over/Under (MMRB) Cumulative Balance from WF Start -Up thru 2016 Cum Production (MMRB) Cum Injection (MMRB) Over/Under (MMRB) MI Breakthrough in Producing Wells > 200 mcfd AVERAGE RATE DATA 2016 Production Oil (MBD) Gas(MMSCFD) Water (MBD) Injection Water (MBD) Gas (MMSCFD) AVERAGE RESERVOIR PRESSURE (psia) Previous report period: Current report period: Estimated Annual Change (psi/yr) Exhibit 1-C Waterflood Project Area WPWZ NWFB FS2 EPWZ EWE TOTAL 545 607 1101 653 89 2994 2224 1445 6142 3563 361 13735 1435 1057 4601 1829 196 9118 1846 1684 6702 2310 200 12742 651 689 1070 685 111 3206 3711 2671 10464 5491 529 22866 2261 2058 7319 2748 235 14620 -1450 -613 -3145 -2743 -295 -8246 3863 2722 10756 5661 562 24264 2317 2081 7454 2800 253 15190 -1546 -640 -3303 -2861 -309 -9073 30 18 20 15 12 95 18.9 9.8 23.5 17.9 13.8 83.8 282.9 84.3 554.3 314.9 435 1280.0 149.2 54.4 291.6 169.9 41 2 7064 124.0 50.4 329.5 125.0 35.2 664.1 36.4 17.4 38.5 16.8 16.6 1257 GD WP WZ NWFB FS -2 EPWZ EWE PBMGP 3275 3313 3335 3398 3330 3645 3350 3277 3303 3332 3409 3332 3650 3343 2 -10 -3 11 2 5 -7 0 S 2 0 S 0 k 5s,on(1r, M Mrq wtw,�,,s 4•�i L03 7&5!0 3797 7 + 2 3787 7.•v r8re I 374337'JS r:1n�)0n NWFB3342 8-033 3349 -1- S -02A 349-1- 5 02A 3-2 A 3214 EWE 10 Z12C 2-l3A 37U1 ■ w -0 26A x09Zj41�B 3465 36818785 'C'43F1 3676• W-25A40 gW�e2 37781 3581�-3V2B Z5e 3455 W_56 �{p W51 • IG6$ ° 32A7W.0�W. 78E•65 3356 ■ 1 °3616 Z-71 N''�2 3261 3142 75 ■ W� A 36613334 3544 3454 W -10A f ° 3550 1 2016 Reservior Pressure 0 2014 SBHP at 8800' SS Datum • 2015 SBHP F 3,050 - 3,150 psi 0 2016 SBHP 3,150 - 3,225 psi 2016 Calculated 3,225 - 3,300 psi from Surface Data 3,300 - 3,420 psi _..� Prudhoe Bay _ 3,420 - 3,550 psi L__-; Unit Boundary 3,550 - 3,680 psi 3,680 - 3,790 psi Depletion Polygons 3,790 - 3,890 psi NOTE: Engineered control 3,890 - 4,000 psi points have been added to the field permiter to provide _ a more accurate contouring. 0 5,000 10,000 20,000 30,000 40,000 Feet 650000 680000 kip Exhibit 1-D ���0- Greater Prudhoe Bay 2016 01 Reservoir Pressure Map 710000 ,0000 680000 710000 R 08F 3Y:3 r,•,y, 32.69 - I- m 52iG ir•ii . 3370 77,5 ., 11 $309 C.4K•� 0 34$9 Gas Cap li• 9n °_ _ az5aa�Ss?g4 x-�ze m 7 8 oA � d8 E.35A 5207 K•" L'72A6 373 123.1 FIB 3211 � 97477�?2 •: ' VOGI.09 8 Qg ns1 88 P$1.10 h1 3 He vit 5219 F47p FISC 0 3328 3327 3V°07 14Gf■ 3A K •0C O 6 p� L.. 37 3706 360 C 32253348 343b K -10D ■ 3018 FA3 ,. 149 37 ,-• 11-V5 315? 337115-0168 3800 ,0013"2 E40 Son 15-28A3365 3408 tl7A 3816 Hat 8A3.1541 a'70 vf±L7F{I3' G•160 V_ 3392 G.2prp6 18.3A 18-,20 8351 it 3t78 tl O�G3{�.n84 31DR 3200 18-007C 1g. 5903'115 43 '•3B 7 U.l4 281 G -!$B {).3:• •'•8 3221 G•1OC 3344 0 G D 18-04D L2 SR 3-187 1]• �r �` AO40 S ■3502 333311.19 90) U 303 362 7g0.G-1$A 33026 9372 A148-mr 33A7� . �60 U-10 d. _9 SA 1°2 14 ]344 Li $ p 33.652 Ff-MH•1)G ,I-1tlY.yp03?86 3256. 0-OfiA ■ ] 43 17.29 3$22 C-89A�-30A 05�,0C 11 3340 22 0436: 3316 3329 32$9 983767 ! 840i 0'1•: !3 0202A 31 p& tltli M1 04. 5A 3 80 v.05A •• A.28 ° 3200 a28r SR670.27C 3903 1t�8 64•-V002A (VA ■■■""""' i. Y-31 -2A4 ,�7f� S7LhJA bO 07.0 p7 l3C 3205 3212 3756 OTC O {�. 5043361 ,1473 3362 Wpw2 A ■ i 3878 Wo 3964 337$x° Y -304A 8.138 o p7.22A 0 09.01A 02.131: 09.05A 3373 _ 0 3334 7-,yg o. 62•o2a $219 -'■� "1� �•2T309•T4 09.37 P•16L1 0 Y -35A �5•ial 3854 14.03A 06. 28 Mkt 7337 322!1 01•D,8 30ti3 31u9 ■ ■ 14.31 9 5277 0 0@ -it ° 380.0 3278 333 3088 �']3 �6 " 04 3 A•38 f 1 1 33 x•93 3248 a321 E- 3326 ° 3279 Cyq 01.16A? 03.31 ■ 5338•,1 1,1•12- I 13.57 0 •pg pSA 3358 337 0.61 P.7-1 3770. R 3303 ■ 3367 3'i$3 1.6•20 32.74 ��qq 14-11A 33fi8 4 M,01 08.1ftypg.13 12• -74 3204 app 0 0 ' 03.21 v 34083387 3348 Y-39 ■ 12-2dj"■ •36 • IA y3Y 18-118 FVL� X63278 03. ^ . _ _ .. - _ . _ _ . - _ ° 3288 5298 3329 C..6F,929f 3 1 14.0118 E � W � 7236 � Q7A 1�A o , 389G 1 3353 i7 3363 . 3�! 3510 ' 3313 14-22A 14-0:A 12 -OB 1 3515 3}•• .:. f0O 0 F2-22 • d 10.0} T6yI4 k93 � ,30A • 3.8 33x414,oeA 1�1+ 72 �4 i' ■ 33sr17.Q6 • . i0.. s•� I 33$6 17.42 3656 i��� , ..-._._-..-._«»........---I 337r ! 30 3318.428. $ 86 � • 32878854. 4&93749 E ' �1 1 304 1709A 3497 ' 13 /2.36 3 r -R49 556 i 16 -WA 35 afi4e j L._------.-..-------_.------------ . -. .. ---•- ,0000 680000 710000 Exhibit 1-E Areal Average Pressure L1—Dec-77 Jul -78 Dec -78 Jul -79 Dec -79 Jul -80 Dec -80... 3900 . 3800 3700 3600 P 3500 S A 3400 - 3300 I 3200 3100 3000 Dec -82 Jan -87 Jan -91 Jan -95 Jan -99 Jan -03 Jan -07 Jan -11. Jan -15 Jan -19 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-G EOA MI Rate MCFD MMP PSI MW Mol Wt CO2 C1 Average Monthly Mole% C2 C3 IC4 NC4 C5+ 01/16 19,996 3,331 31.71 19.11% 35.39% 19.63% 23.61% 1.49% 0.77% 0.00% 02/16 20,000 3,326 32.95 20.15% 36.40% 20.39% 23.99% 1.59% 1.04% 0.00% 03/16 16,774 3,361 31.68 19.45% 35.36% 19.83% 23.19% 1.40% 0.76% 0.00% 04/16 20,000 3,362 31.71 19.66% 35.21% 19.68% 23.54% 1.25% 0.66% 0.00% 05/16 63,871 3,309 31.90 19.66% 34.94% 19.28% 23.75% 1.36% 1.00% 0.00% 06/16 100,538 3,287 31.94 19.49% 34.80% 19.51% 23.65% 1.52% 1.04% 0.00% 07/16 78,813 3,268 32.00 19.33% 34.85% 19.61% 23.03% 1.60% 1.58% 0.00% 08/16 54,615 3,343 31.68 19.05% 35.66% 19.50% 23.38% 1.35% 1.05% 0.00% 09/16 33,441 3,400 31.57 19.38% 35.99% 19.60% 22.66% 1.43% 0.95% 0.00% 10/16 65,288 3,386 31.51 18.82% 36.51% 18.93% 23.39% 1.47% 0.88% 0.00% 11/16 72,692 3,393 31.49 18.84% 36.61% 18.75% 23.54% 1.43% 0.82% 0.00% 12/16 76,452 3,317 31.81 19.21% 35.58% 18.92% 23.70% 1.66% 0.94% 0.00% Averaae 52.083 3,340 31.82 19.34% 35.60% 19.46% 23.45% 1.46% 0.96% 0.00% WOA MI Rate MCFD MMP PSI MW Mol Wt CO2 C1 Average Monthly Mole% C2 C3 IC4 NC4 C5+ 01/16 113,927 3,369 31.91 20.69% 34.92% 19.07% 23.12% 1.45% 0.75% 0.00% 02/16 145,175 3,320 31.76 19.11% 35.41% 19.50% 23.43% 1.53% 1.02% 0.00% 03/16 143,297 3,310 31.77 19.06% 35.26% 19.36% 24.18% 1.38% 0.75% 0.00% 04/16 108,486 3,282 31.85 19.12% 34.95% 19.11% 24.94% 1.22% 0.65% 0.00% 05/16 106,997 3,256 31.94 19.07% 34.87% 18.98% 24.87% 1.28% 0.92% 0.00% 06/16 51,432 3,221 32.06 19.02% 34.65% 18.97% 24.72% 1.52% 1.11% 0.00% 07/16 51,032 3,216 32.07 18.87% 34.82% 19.05% 24.13% 1.57% 1.56% 0.00% 08/16 76,740 3,268 31.84 18.65% 35.38% 18.99% 24.48% 1.42% 1.09% 0.00% 09/16 138,747 3,323 31.72 19.00% 35.43% 19.57% 23.64% 1.43% 0.93% 0.00% 10/16 119,537 3,333 31.73 19.11% 35.62% 19.25% 23.59% 1.52% 0.90% 0.00% 11/16 133,433 3,340 31.69 19.06% 35.80% 19.01% 23.83% 1.45% 0.85% 0.00% 12/16 99,242 3,328 32.79 19.82% 36.79% 19.61% 24.42% 1.66% 0.93% 0.000/c Average 107,019 3,297 31.93 1 19.22% 35.33% 19.20% 24.12% 1.45% 0.96% 0.00% Exhibit 2 Fieldwide Produr.+no Fluids fj%MRB7 January February March April May June Oil 8.9 8.2 8.7 7.2 8.0 7.1 Free Gas 208.3 188.8 204.5 164.3 184.9 158.1 Water 29.6 28.4 28.7 26.0 26.9 24.0 TOTAL 246.7 225.4 241.9 197.5 219.8 189.2 Injected Fluids (MMRB) Water 45.2 42.0 40.8 22.7 20.9 18.8 Gas 203.3 183.2 198.9 159.9 181.9 154.8 TOTAL 248.5 225.2 239.6 182.6 202.8 173.5 Net Injection Volumes = Injection - Production (MMRB) TOTAL 1.8 -0.2 -2.2 -14.9 -171 -15.7 Producing Fluids (MMRB) July Auaust September October November December Totals Oil 7.6 7.6 72 8.0 8.3 8.6 95.3 Free Gas 169.4 179.6 176.7 186.8 2040 210.9 2236.1 Water 26.0 22.7 21.6 28.4 30.2 31.8 324.4 TOTAL 202.9 209.9 205.4 223.2 242.5 251.3 2655.8 Injected Fluids (MMRB) Water 21.2 34.8 36.2 34.4 38.3 472 402.5 Gas 165.9 176.5 173.4 183.8 201.3 208.0 2190.8 TOTAL 187.1 211.4 209.6 218.2 239.6 255.1 25933 Net Injection Volumes = Injection - Production (MMRB) TOTAL -15.8 1.5 4.1 -5.0 -2.9 3.8 -62.6 Exhibit 3-A X211 I o4 -31A FSS LEGM „ - Gas Ih]/Cgr 04-210 Gas InjestorShut-m 04-m Gfiacihle Injector 11-27 _ _ - _ vscihle IhjactorShw • " 213 IaA 01-35 G4-27 ■ 00 Pm*Aer Fkwng Oil -26 1t_ 1T 04-17 .Y i p7 ProdwEr Shrsm 'r yi-11-06 $p A MIN, s,j Wr 11-3 11 5 ii ,�- 9 Waxr "rlecwrslns-s 05 TT -24A N-4 04-29ALI � a Ares gu5w 5�as st�48A 04-13 2 04-1 OTIIA t t13-45 _ Phq?.' T7-04►" 't4-31 _ t 11�.7A tt-1 11-18 M,,, 0x94,*A vi—n Y Q9 -3A Ark- 71 7 t' D4-1 _ 24 - 11- A 09-=iry 11- G445 O9 -VA t LL' L Q0.+ 7 A4� 111-12 GD -W 0¢29 ■ yt t — 98-08 X04 09-SDa tI30i_ 0�2e 46 09- 03-10j*310 _ r 03-I8A D3 i 03 • 09-5# 723'+ A 03-17 09-25 03—K-5 I" T 19 16-12. 7 C. 03-30 1 # d+� 3,7 fl 03-W 03-04 16-178 i... 77A a 1 1b 491• T- 'ia-037k- &-T= + g f4--06 1 D3 44�#1 1 -f 0.5_13 1 7 N _ 77-2-C 1 1 Liter 8 I&ZIA 16-05E I S 17-M 10-16 1611 16-03 1 QA -16 _ iI TC it 1�7,--1 SAbp T 643BA 17 T -0I ! 1 0 1 tT ! Miles t8 1UA Exhibit 3-13 Net Injection Volumes (Injection - Production (MMRB) TOTAL -3,145.1 -15.9 -12.2 -114 -115 -14.8 -10.8 Produced Fluids (MMRB) FS2 Reservoir Balance FS2-Exhibit August September October November December Cumulative FS2 0.838 0.631 0.791 1.104 1.224 1,445.1 Free Gas 10.717 Produced Fluids (MMRB) 12/31/2015 January February March April May June Fluid Properties Used 7.112 Oil 1,433.8 1.040 0.939 0 993 0.835 1.017 0 885 Bo (rb/stb) 1.324 Free Gas 4,374.5 17.550 13.838 14 415 11.389 14.941 11 735 Bg (rb/mscf 0.862 Water 4,655.5 9 794 9.067 9.623 8.662 9.700 8 578 "Bw (rb/stb) 1.040 TOTAL 10,463.7 28.384 23.844 25.031 20.886 25.658 21.199 Bmi (rb/mscf) 0.700 Rs (scf/stb) 620.8 Injected Fluids (MMRB) Water 6,619.5 12.446 11 646 13 604 9 340 9.872 8.642 Gas 699.1 1.004 1 784 TOTAL 7,318.6 12.446 11 646 13.604 9.340 10.876 10 427 Net Injection Volumes (Injection - Production (MMRB) TOTAL -3,145.1 -15.9 -12.2 -114 -115 -14.8 -10.8 Produced Fluids (MMRB) July August September October November December Cumulative Oil 0.838 0.631 0.791 1.079 1.104 1.224 1,445.1 Free Gas 10.717 9 674 12.762 17.739 17.310 18 281 4,544.8 Water 7.813 5.334 7.112 11.102 11.366 12.860 4,766.5 TOTAL 19.369 15.638 20.665 29.920 29.780 32.365 10,756.4 Injected Fluids (MMRB) Water Gas TOTAL Net Injection Volumes (Injection - Production (MMRB) TOTAL 8.102 5.993 7.594 11.968 12.349 13.869 6,7449 1.551 1.172 0.418 1.154 1.107 1.669 7090 9.654 7.165 8.011 13.122 13.455 15 538 7,453.9 -9.7 -8.5 -12.7 -16.8 -16.3 -16.8 -3,302.6 Exhibit 3-C FS -2 Areal Average Reservoir Pressure 3900 3800 3700 A U) Q 3600 U) U) c 3500 co 3400 U) w CD a 3300- 0 Z m Nl 3200 3100 - - - — - - - - — - 3000 - Jan -87 Jan -91 Jan -95 Jan -99 Jan -03 Jan -07 Jan -11 Jan -15 Jan -19 Exhibit 3-D �rJ2 c�ren L3 z r+ 04-33A Gas Injector ii -t9 CAH Gas Injector Shut-in 04 .:' 24 04-2-1L 1s Miscible Injector 11-10A — Miscible Injector Shut -i � t3 • - 04- - eCPN�" •• 04-35 • Oil Producer Flowing • II IA, 1t 11�tii tea. '1 r rL� • Oil Producer Shut-in 11 ' C0 sc 36 1 11 11-26 2,04 tsA .e A- Mater Injector 11_35 04-10 � _ �'8 � Water Injector Shut-in � 4111- e14 oe Od- 2'A 11 F -- Abandoned . 7 04-13 Ot.13 i 04 -IIA F: Pfugged-Sack 1136A 1 1 c -_— - Ambiguous Status 114nA 17- OC 61A w RMI Z-06 11-29 01-15_ 4 < 200 mscfld 11{C�+r � 1147A 20-0 - 2000 msrfid _ • s�_06-1 44`7A r�C••43 0 10 21 11 E$04.37 > 2000 R15cfrd 09 7A - D�f64 x 09 rr 8 979-17"= _ 09-16 03 1 ' 26 2QU 7? 6 MA 0348A 01 x 03=- 13331A 18 09- 179-25 3 03.23 0317�r = L• 16-19 - ? ' 16-13 01 t 03 1 03 16- F4 62''1 9 :t 63-37 A3 -6A 16- OX05 A: � '•6- - -16111 �-0Td � 1 •t 6-27 GG-tA ! mm 17-1 14OLl 30? 03.11 17 0 1L 0313 76 N 1 i 16-0 17-M 16- 16-16 16-17 16-03 7-! 17-1141G12A 17-1 - i _ .-15A bp 17 16728A i . 77-01A 16-23AM 1 1 + 6 ,� Files Exhibit 4A EPWZ EGEW }� %eS IrFpmr h Gas lrgomr Shut4n h6sable 7nAcwr ,^ WelkAe Infeetor S?i%4J • Od Pro. q =�apm¢ • (X PmcC - 2r Sh" - syal2- L,]&cbx v wm, - l2*ctx S71UC I -B"ek 0 Zot* 14.201ArWguous 1 14-1 • 4-19 14-4.3 14-75 W24A = -13 04-..4 01-17C 7 7 S 14- 13-17 .� O1 a1 OT -W ;-36 r • t4- art 1337 13- '` � p6 -18A .0 1-i1TA -1D 61'11 as ,R 7- •I-29 t� -1244 79 fY1 3�r �7 ■ ` [3�12B 06 1 11 13-1 12-1 f11 1 7 124)SALt-j� 12-322 m - 5 13_46 1 13-01 12.2 �7A 12 7= 3 3+} 3 A-: �4 43-25 1831 7 _6 � 1, 13ti �-1S � 14-1Tfi B 12 2-03 12A • ' A 03 14 1 a 73-05 ? 12 j S ■ ``tom" 12-25 a D7� 2-25 1 13-M 10 17432 _211 14-44A _ 1 1 72-10A_1 2-14AL* 12-34 1 1 2`. 1 32� N bo i 3 4 1 Miles I e Exhibit 4-13 EPWZ-Exhibit EPWZ Produced Fluids (MMRB) 12/31/2015 January February March April May June Oil 8497 0 795 0.757 0.788 Free Gas 2,6220 9.841 8 117 8.357 Water 2,0194 5.365 5.321 5.911 TOTAL 5,491.1 160 14.2 15.1 Injected Fluids (MMRB) 9.618 9.454 Bmi (rb/mscf) 0.700 Water 2,303.4 4.140 3.893 4 029 Gas 4449 0.434 0 402 0.434 TOTAL 2,7482 46 4.3 4.5 Net Injection Volumes (Injection - 3.9 35 Production (MMRB) -11.5 -103 Water 4 100 TOTAL -2,742.9 -11.4 -9.9 -10.6 0 641 0.797 0 721 Fluid Properties Used October 6 635 9 002 7.397 Bo (rb/stb) 1.321 4.443 5.611 5.713 Bg (rb/mscf) 0.872 11.7 15.4 13.8 BW (rb/stb) 1.040 8.636 9.618 9.454 Bmi (rb/mscf) 0.700 5.752 4 945 3.763 Rs (scf/stb) 614.0 3 877 3 539 3 223 13.4 12.0 0.341 0 368 0.327 16.4 5,6614 4.2 3.9 35 -7.5 -11.5 -103 Water 4 100 Produced Fluids (MMRB) July August September October November December Cumulative Oil 0.693 0 600 0.494 0.753 0.797 0.797 8583 Free Gas 6.945 6 426 6.595 8.636 9.618 9.454 2,7191 Water 5.752 4 945 3.763 5.740 5.993 6.123 2,084.0 TOTAL 13.4 12.0 10.9 15.1- 16.4 16.4 5,6614 Injected Fluids (MMRB) Water 4 100 3.998 3.915 4 242 4.408 4.204 2,350.9 Gas 0.158 0.268 0 262 0.390 0 921 449.2 TOTAL 4.3 40 42 4.5 4.8 5.1 2,8001 Net Injection Volumes (injection - Production (MMRB) TOTAL -91 -8.0 -6.7 -10.6 -11.6 -112 -2,861 3 3900 3800 3700 A a 3600 y 0 3500 w 3400 Nl d a 3300 0 Z m 12 3200 3100 Exhibit 4-C EPWZ Areal Average Reservoir Pressure 3000 Jan -87 Jan -91 Jan -95 Jan -99 Jan -03 Jan -07 Jan -11 Jan -15 Jan -19 Exhibit 4-D E P WZ LEGEND Gas Injector m Gas Injector Shut-in Miscible Injector Miscible Injector Shut -i • Qil Producer Flowing OR Producer Shut-in Water Injector - Water Injector Shut-in a Ambiguous Statt7s 14-10, f RM! x- • < 200 mscUd is 1 16 200 - 2000 fnsef/da ix-_ 24 t4-35 14 -13 :� ty7-T fD14 sc i > 2000 mifd =4 7 Pii11t]tt { • -`' f 4-12 13-27 �P 91 (t73tY 1 A 5318143' T 1r — 7 ..14- 1 46-1&Or1- 0113 Of D7 -1t 14B DS -13A • L 131 F Cr 1 OCr126 13812 13� 12-19 1237 1 12 12-32 t$ 14-47 13- 7 -i tai • T 1 ''22.1 -18 1� 1T 1321A 12-1�93 -26 -1'A ,1 11 `IA , 15.11PZ 's 1' - l2 12 . �� -]3d1 13- 9 • �i31671 U! F�Fi78i0i5C I� X12-257 -07k 13A _ 12-7 7-1 r 13 t�33 t231-ir ; tOT4Xx•� 1335 13-M �' t2-14af� 1 4A 12; 1234 N i 13- 3s bp 1 I) 1 Miles Exhibit 5-A WPWZLEGEND T 13�L' S • 11--0 x Gas lk� for WsN�e=rSh�Pe Wsable LEscibie Ags-..or Sh - U-07 • 01 Pla.&cw .lma • Oil PrpGxp_r Sh=r t,� = UhlerjeCR7r • fF'•! 53yLrr'njeCbr Smr, .n S3-QBA T�_Y 31 Rba�eonea •r`rF310 A 6.61A Mugged-3�. A123 6 . DMA Ambiquw S=: T9C 7eC P- -4 Y-0 L1_t A-44 ?A P111A • Y -23B Y -06A 1F X17 a • ;�,_ �A %w A-13 �. • •P-09 y A-03• eti�5. •.A -12A. A-350 " iS ~-26 } Y- -• A Ate' &15 PLICA PI_ TLS 95 P ?3 Y-30 A33 • A -ORA T2s r - P -T1 Pte. Y�fhL1 4 835 A-7 tL • B-2?— PA, P_ ; P -M v --w= f • 'A to A-2 AX IP --:7* 25L1._P�14 14C Y -. " Y -IUB AAO 19 31 B -S 5-19$ 8.24 -)� 19 R1 �# A �18A 1 7B3s M8F.i Y -G68 Y X -G6 25 Y31a Y S 8 F, -18A _^i8 -L42 p- Y A-21 .- 140A• -15A 1 Y-� Y ~ MSLT 9 i 7C-73 12 X-01 Y-GQ%LI-M • _ SA X-26 :-21A • MT! N X-1 I A - -X _QA X--23 x-loIA 7 X, 1 X_1 495 r x, x a bp 1 Al 1 k • x Miles Exhibit 5-13 Injected Fluids (MMRB) Water 1,834.6 3.804 WPWZ-Exhibit 3.846 3.288 3.063 2.682 Gas 426.2 wPWZ 0.652 0.806 0.544 0 258 TOTAL 2,260.7 4.381 4.337 Produced Fluids (MMRB) 12/31/2015 January February March April Mav June Fluid Properties Used Oil 714.4 0.910 0.835 0.877 0.762 0.656 0.570 Bo (rb/stb) 1.322 Free Gas 1,560.2 8.149 7 319 8.144 7.012 5.418 5.632 Bg (rb/mscf) 0.869 Water 1,436.6 5.477 5.330 5.346 5,232 3.673 3.077 Bw (rb/stb) 1.040 TOTAL 3,711.1 14.536 13 484 14.367 13.005 9 747 9.278 Bmi (rb/mscf) 0.700 8 051 1,646.4 Water 4 574 4.710 4 493 4.691 5.040 Rs (scf/stb) 616.2 Injected Fluids (MMRB) Water 1,834.6 3.804 3 685 3.846 3.288 3.063 2.682 Gas 426.2 0.577 0.652 0.806 0.544 0.713 0 258 TOTAL 2,260.7 4.381 4.337 4 652 3 833 3.776 2.941 Net Injection Volumes (Injection - Production (MMRB) TOTAL -1,450.4 -102 -9.1 -97 -9.2 -6.0 -63 Produced Fluids (MMRB) July August September October November December Cumulative Oil 0.724 0.759 0.705 0.756 0.790 0 805 723.5 Free Gas 6 587 6 877 7 256 7.616 8.187 8 051 1,646.4 Water 4 574 4.710 4 493 4.691 5.040 5 166 1,493.4 TOTAL 11 884 12.346 12 454 13.063 14.017 14 022 3,863.3 Injected Fluids (MMRB) Water 4.021 4.705 4 629 3.989 4 574 4.902 1,881 7 Gas 0.863 0.995 1.233 1 100 0.770 0.810 4355 TOTAL 4.884 5.699 5 862 5.089 5.343 5 712 2,317.2 Net Injection Volumes (Injection - Production (MMRB) TOTAL -7.0 -6.6 -6.6 -8.0 -87 -83 -1,546.1 3900 3800 3700 m N Q 0 3600 r c 3500 Go 00 aU 3400 N N d IL 3300 0 Z CD N N IX 3200 3100 Exhibit 5-C WPWZ Average Reservoir Pressure 3000 Jan -87 Jan -91 Jan -95 Jan -99 Jan -03 Jan -07 Jan -11 Jan -15 Jan -19 Exhibit 5-D wPwz bp L=_GEH{7 RMI Gas Injector < 200 mscfdd Gas Injector Shut-in L3 -Q6 LW7 ■ 200 2000 Miscible Injector l.i463P x � 11-11 H-24 - rnscifd H 11 Miscible Injector Shut -i ° 1i11A a 2000 rnsctrd • Oil Producer f=lowing EQ41112 w1 4L H-31 23 - 0a Producer Shut-in H-] = 52 D")tA 043aA Water Injector B1 �Y--1 Y D-03 18 " H C ~ x Water Injector Shut-in Y4T7A A a ,+ ;pLJ0M2.A 1AP83 �. �.y Ate'., 1 25 '- Abandoned Y4MA YA 7 A-�M • �Y Y$ 8-17 8-03„ Pfugged-Back x ` _ - AA 3 �q B-1 _ Ambiguous Staws j• ti's. L = Y-22 1,k. _Pry A "++.-35 p_}pg1• PD6$ R� aY.tBV Y-7 A03� • - -. 4 • P P -3E,,- P- L1 ► yy Y-1fL4t. _ evMA 15 B-t13PB1 LL 30 1 .y n P-05 M PS{� KT: 10'- Y -M Y &� A 10 p�3 -1 Y l?2 �2i ? Rt 31 P-23 Yti i11 t '� Y 1 '-`r A l A �y; &'`8 • 73 ;.8-_ D7-26 1ti3 11 31' ,12A r' P�2 a - `�- 34 �`�* ¢ F��rA A -iiia, 'a' �t3�1 9-t 5-12 5-.22A M 1d .1TA . Yy_13AP6t , ,^ P 0 P-12 Y- �.='E+5,�- '� Y T3�. T9 A -UB Y-11 - Y-108 X133 a '77 & !}7 P -T 8Lt ,;.P-14 N r v X-03 X s R-0SA c• a 18h 431A_ • +�7it A t t' : -76 3 + 8 Ti470C�� t7 � Y-27 Y�1A -_Y-1 L�t7 A-'15 • Y� • B y& x-218 1f -37A ,. .B ,s P^ �' HL -0 x P-1 Y.11c^ A-16 Y', C - ! x 15 • Y-20 ,29 A -17A Y+4 PLA , A_VA x_19 x - .P -1 L1 .�L38L7 A-21 Y-� 'f t - Y -09A X k 13A X -n P51 X—mko i4.'-:J�PEiw X-01 X-1 • ` Y-09ALT-01 X 1 X Z8 1 4S. X-31 • x 18 21P -06 13-37 x , • J�eT�X-11A. )F -01 • 1" 23 X_10 IPA -I 1 0 ' Wiles Exhibit 6-A NW'FB �i` i..tGEND Gas Injector Gas Injector Shut-in -n Miscible Injector Miscible Injector Shut -i a Oil Producer Flawing Oil Producer Shut-in �tfl3 r 31A R i9A Water Injector �dI ILI Water Injector Shut-in S24 . - $.Qqh _ a s 32 ' =p„� Abandoned F 1A R-16-,As7 t 3rr t_i S -110a 31 • -1 . - a -Back S-44. •. y ti r "- R-08 .r S2 as �s 7 R-18 o -tr R- F- 7A ; .., T�ii Ambiguous Slatus = �;��•: r r ,` –�ii2 R31A R-094 > 1'r R r A rPFCT3i?t3 C3 NWFB WF a S1D x ■ R-21 „� S-1 C R-25' =_ T � =` 9 {� Rte'=` Rid R.34 ■ F_ 1 i F� i s' R 14 F-41 - - + r- c R Fi-i 5i T• -ilA" t �� R'�i 27 X13. }ylA M•12 �=3 S 2iE r S [ii S7 M-21At OM -1 - x R- Ft -0d ` SMkLi a $1 a -... 2 fr sMA 51 S mv, M-23M28A 26 _ c R-14 UZJ2,} '= I B&©4A M Cr^3F N-1; T N -zi ■ i� ll��,PB +� 2 --3fi At-17Br` L i2 _7_U_04 CJ N- tSti �.� rats "-� ra ��ry GCM N-tIBPH ■ FF ` H-26 I Vy., p A I i i ® i v Miles Exhibit 6-13 NWFB Produced Fluids (MMRB) 12/31/2015 January February March April May June Fluid Properties Used 0.466 Oil 7590 0.467 0.419 0.357 0 400 0.492 0 406 Bo (rb/stb) 1.318 Free Gas 879.8 3 019 2.851 2.113 2.453 2028 2 167 Bg (rb/mscf) 0.882 Water 1,032.3 2.160 2.403 1,271 1.896 1.939 1 502 Bw (rb/stb) 1.040 TOTAL 2,671.1 5 646 5.673 3.742 4.749 4 459 4 074 Bmi (rb/mscf) 0.700 Rs (scf/stb) 607.3 Injected Fluids (MMRB) Water 1,628.0 2 223 2 131 1.510 1.217 1 453 1 470 Gas 429.8 0.358 0.260 0.372 0196 0.075 TOTAL 2,057.8 2 581 2.392 1.882 1.413 1.528 1.470 Net Injection Volumes (Injection - Production (MMRB) TOTAL -613.3 -3.1 -3.3 -1.9 -3.3 -2.9 -26 Produced Fluids (MMRB) July August September October November December Cumulative Oil 0.466 0.450 0 318 0.269 0.322 0.350 763.8 Free Gas 1.807 1.989 1.798 1.018 2.116 1.941 905.0 Water 2.046 2.013 1080 1147 1.492 1.745 1,053.0 TOTAL 4.319 4.452 3.196 2.434 3.930 4.036 2,721.8 Injected Fluids (MMRB) Water Gas TOTAL Net Injection Volumes (Injection - Production (MMRB) TOTAL 1.503 1.623 1.264 1.391 1 716 1.685 1,647.2 0.088 0.649 0.516 1.127 0.817 4342 1.503 1.711 1.913 1 907 2 842 2.502 2,081.5 -2.8 -2.7 -1.3 -05 -1 1 -1.5 -6403 Exhibit 6-C NWFB Areal Average Reservoir Pressure 3900 3800 3700 A U) a p 3600 y N c 3500 3 3400 N N m a 3300 0 2 d N d 3200 3100 3000 - Jan -87 Jan -91 Jan -95 Jan -99 Jan -03 Jan -07 Jan -11 Jan -15 Jan -19 Exhibit 6-D NWf-B LEGEND -;= Gas Injector Gas Injector Shut in Miscible Injector Miscible Injector Shula a Oil Producer Flowing 09 Producer Shut-in t� 1A t Far19R tLt ? Water Injector - s S-31 ,7r `s -ti Water Injector5hut-in • s16 t 5.32 - 5-43 = .- Abandoned 1 F-37AL1 R-TfiA t0 Plugged -Back $11as RUB lit ; 7A • _ - -r 07 544S22S cS? = L R -1i t6 �7 L , r. - . • �_'.'_. •_ti $� W16 E{.agq R -is R new ° Ambiguous Status RMI �1TC SAd y- t23 ~ `%"da G6 < 200 mscfld = _ • R�&B� F�1 _ F3 1 R F F-41 200 - 2000 mscfld r SZ■;-' ~ 3A # R -R -t 1 S a 2000 mscfdd ,. iS s -t. S -1,28M -t int i Nt i R-13 C3 I+ WFB WF;� 5-0i i 2 .� 8 Y 3t �'1A w M-2 Fk1fl �-�-�•N-0S � Nig tom. �t S-1 N W M , 3 61�28A h1''3� 75 S t -25 N t F N nom, - ; 9 "IA dx-02 U APB 12 N-1 Y Um ? Nwt M1-17AL _* x _ U-04 N -i r - fs 7tSr �. 4-26 i A by Miles Exhibit 7-A EWE LEGEND _,09 Gas lnpecypr - Gas In+ecmr sh w. -D4 L-213 {,f : Wsdble "P=r ' _ °j ti V 3 4'Waer roctor3 vmu r'Ell - Ab� ' Ptvgy-edtiac� _ - AmBiquou% Saws "3 G 117 1A�� ■ ^ • _a 'A ?�Ai1 # -178 :24 #i • Iseu Z-148 # • W-214 r 1 L-QSA 'AL2¢ M zs. 12w, '� "1AL1 '7A 4��a z •wA ❑ ' 9 YY�10 r MMT Z67 Z DB 7A ` -P-30 _llA W-2 A--^ LL16 P-25 # X3181 • Y -,m L a` 6A Aw � tiY - j bp 1 d 7 l�aa 0 MW Files Exhibit 7-B EWE July August September October November December Cumulative Oil 0,468 Produced Fluids (MMRB) 12/31/2015 January February March April May June Fluid Properties Used 0.655 oil 111.9 0 613 0 553 0.558 0.529 0.543 0.424 Bo (rb/stb) 1.344 Free Gas 230.8 1 109 0 838 0.852 0.870 0 761 0.698 Bg (rb/mscf 0.800 Water 186.7 1 594 1 354 1.357 1.344 1.206 0.937 Bw (rb/stb) 1.040 TOTAL 529.5 3 317 2 745 2.766 2.744 2.510 2,059 Bmi (rb/mscf) 0.700 Rs (scf/stb) 667.8 Injected Fluids (MMRB) Water 1665 1 492 1 435 1.080 1.194 1.116 1 033 Gas 68.4 0 646 0.576 0.652 0.462 0.529 0.315 TOTAL 234.9 2138 2.011 1.732 1.655 1645 1349 Net Injection Volumes (Injection - Production (MMRB) TOTAL -294.6 -12 -07 -10 -1.1 -09 -07 Produced Fluids (MMRB) July August September October November December Cumulative Oil 0,468 0.607 0,500 0.600 0.691 0.706 118.7 Free Gas 0.560 0.790 0.655 0.777 1.077 1 058 2409 Water 1.115 1.297 0.971 1 118 1.745 1 661 2024 TOTAL 2.143 2.694 2.127 2.495 3.513 3.425 5620 Injected Fluids (MMRB) Water Gas TOTAL Net Injection Volumes (Injection - Production (MMRB) 1 036 0.806 0 669 1 042 1.205 1 301 179.9 0.180 0 295 0 286 0 181 0.130 72.6 1.036 0.986 0.963 1328 1386 1.432 252.5 TOTAL -1 1 -1.7 -12 -1 2 -21 -20 -309.5 Exhibit 7-C ELEGM Gas Injector Gas Injector Shut in = Miscible injector Miscible Injector Shun • 01 Producer Rowing ` L 2�� f as -. Oil Producer Shut-in • Water Injector Mater Injector Shut-in RMI X13 V m- C 200 mscf1d 290 -2000 mscfrd > 2000 msctdd t.3s a '+19 —vv IM -1 Z�. _ r w -1:L u yw w -f _ � l � iF�-iSk v 1 ' Y f z� 11 �zvs wazA 400 _ • ' NO dY-0A •Lcfb Z-34 VZ -34• - Z -46A 7x78 'P!_t i bp W-1 • 1 0 I Z Miles Exhibit B 2016 Wells Surveyed for Gas Movement OH - Open Hole Log CH - Cased Hole Log Not present over logged interval all fluid Not present over logged interval all gas 2016 Surveillance 2016 Orllling # # Well Log Date OH / CH GOC (MD) GOC (TVDSS) 1 02-148 13 -Dec -16 CH 9,800 -8,914 2 06-04B 16 -Sep -16 CH 9,400 -8820 3 06-04B 16 -Sep -16 CH 10,854 -8777 4 07-15B 16 -Nov -16 CH Not present over logged interval 5 07-198 8 -Dec -16 CH 11,679 1 -8.904 6 09-27A 21 -Mar -16 OH Not present over logged interval 7 11-12A 26 -Sep -16 CH 12,190 -8,610 8 1 14-28B 21-5e -16 OH 10,246 -8,775 9 15-33C 20 -Sep -16 CH 10,835 -8,727 10 15-45D 10 -Dec -16 CH 9,833 -8,687 11 A -29A 2S -Apr -16 OH 11,428 -8,655 12 B -27C 30 -Jan -16 CH 13,093 -8,812 13 C -21A 4 -Apr -16 CH 9,166 -8,903 14 C -31C 22 -Dec -16 CH 12,001 -8,950 15 D -20A 29 -Jul -16 OH 10,158 -8,849 16 D -20A 8 -Aug -16 CH 10,164 -8,852 17 E -20C 28 -Jan -16 CH 10,207 -8,919 18 F -45C 5 -Jan -16 CH 9,517 -8,957 19 F -45C 5 -Jan -16 CH 11,305 -8,949 20 H -25A 29 -Oct -16 OH 12,660 -8,713 21 H -27B 17 -Jul -16 CH 12,137 -8974 22 K -07F 27 -Jun -16 CH 9,799 -8,741 23 K -19B 9 -Jan -16 OH 1 11,292 -8,589 24 K -19B 9 -Jan -16 OH 14,883 -8,569 25 K-19BPB1 1 -Jan -16 OH 11,302 -8,592 26 N-31 13 -Feb -16 OH 9,830 -8,793 27 N-31 13 -Feb -16 CH 9,832 -8,793 28 11-10A 8 -Jan -16 OH Not present over logged interval 29 R_ 16A 23 -Feb -16 OHiNot present over logged interval 30 R-44 20 -Mar -16 OH Not present over logged interval OH - Open Hole Log CH - Cased Hole Log Not present over logged interval all fluid Not present over logged interval all gas 2016 Surveillance # Well Log Date OH / CH GOC (MD) GOC (TVDSS) 1 01-06A 30 -Aug -16 CH 11.405 -8,740 2 02-25A 19 -Feb -16 CH 10,042 -8,971 3 02-36A 8 -Sep -16 CH Not present over logged interval 4 03-25A 19 -Feb -16 CH 11,700 -8,668 5 04-21 19 -Dec -16 CH 12,638 1 -8.380 6 04-43 24 -Sep -16 CH Not present over logged interval 7 OS -02A 20 -Apr -16 CH Not present over logged interval 8 05-23B 12 -Dec -16 CH 10,085 -8,693 9 06-20A 12 -May -16 CH 9,797 -8,839 10 07-28B 21 -Mar -16 CH 11,787 -8,906 11 07-38 2 -Se -16 I CH 10,026 -8,925 12 1 11-26 17 -Feb -16 CH 10,676 -8,668 13 15-12B 26 -Dec -16 CH 9,618 -8,783 14 15-30B 9-5ep-16 CH 11,381 -8,675 15 15-44 1 -Mar -16 CH 10,127 -8,735 16 B-06 16 -Sep -16 CH 9,013 -8,850 17 B-18 10 -Oct -16 CH 9,101 -8,867 18 D -08A 22 -Dec -16 CH 9,903 -8862 19 D -17B 24 -Dec -16 CH 10,013 -8,841 20 F -05A 4 -Oct -16 CH 11,023 -8709 21 F -19B 30 -Sep -16 CH 10,272 -8,720 22 F-22 13 -Nov -16 CH 9,682 -8,941 23 J-29 2 -Oct -16 CH 10,605 -8,787.2 24 K -02D 19 -Nov -16 CH 10,924 -8,864 25 K -12C 13 -Jan -16 CH 10,817 8,901 26 1-2-03A I 17 -Mar -16 CH 1 10,755 -8.659 27 12-11 10 -Sep -16 CH 8,878 8,379 28 12-24 14 -Sep -16 CH 9,320 8,330 29 1-3-11 11 -Sep -16 CH 9,941 8,303 30 N -01A 25 -Feb -16 CH 9,293 -8,724 31 N -18A I 21 -Jun -16 CH 9,983 -8,669 5 32 N -20A 11 -Jul -16 CH 9,775.6 -8,748.5 33 N-27 3 -Apr -16 CH 9,091 -8,633 34 N-27 28 -Jun -16 CH 9,091 -8,633 35 R-42 21 -Jan -16 CH Not present over logged interval 36 W -27A 28 -Nov -16 CH 117094 -8,689 37 W-45 2 -Dec -16 I CH Not present over logged interval Exhibit 9 1- Operet4r: gp 6x Ln. 2. Adtlress: P.O. Boa 196612 900 E Benson BHtl_ Anchors . AK 985199612 - Unit or Lease Name.F pia LU9< .m P4N. Prp6.tl4 Fift piII OO Rad S. Datum Reference: 8900 TVD -09 S. 04 Grerny: S=- Api ] Gas G -q: 09 o. Vle-ii Name and Number 9 -API Number NO DASHES 10 -Type See Btsstlaem 11. A❑GGC 12. PnnI COdt Gone to lop-Bo6om1VOSS 14. F.0 T.. 16. Date 6kui- 16. Press 1n Tlmit, Su -Type HoOrs Io44 b- e4dee 17 B.H. Temp. 18. Oeplh TooI TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVOSS (input) 21. 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SBHP 172 8.500.04 3 7737 8'WO 1.09 330 i 06.618 501782017201 O 64/150 411I3D60M-40315Q]0.9031-ml 9t1Y16 573. 3SHP 18627 6788.73 3251.32 :ADO 031 ].251,4 06-04.9 500MD17Po1 0 040150 aBrr-aee6.ee51�ae1sa91sa9t4 Y1YS6 7044, SBHP 206.49 5601.13 330729 dAm 0.09 ]307.3 07-22A 50 029=92 5Q2 0 849150 90x35014 YL18 415.55 sww 23@:66 6.800.041 3.271.76 801313 OAS 7]75.6 07-0.30 500292150903'037A.35-9030 O 640150 a535-@941,6944;849,68 49 .e501-0981.eg62.8g63,68e5.8563.696+8905.6@654986.d@7639B9,8pyfrBGpO0LR003, 9116/18 644, SBHP 1BB 880017 325626 BB00 , 0.30 3.256.2 07.30 5011282757610 6 B+OIM 81310542.903/-91354,8036-0W0.9Q]7.903790]6SQ42 RO1i9346.803641Z9057-9060.9:80.9067.9.�67•F7@5 5110116 251, apm 201. 8.79874 7 0e 6.900 0.28 3.205.2 D9LOIA 500214416811 0 640150 BBfl7-688a.BB894667 6131116 611 sw 196. mm.2a 393. 61!00 0A6 5.330.8 09-03A 500292020901 0 540180 86454/ul, "nru"u4a96,4i[i w5,e al of i-e/4o,"8484-ere[,a/5"ae60i,en"uSb-"e"eu/roou4,00L3-ooL e -'o o rnan 6979,8984-8982.8989-8996.8989-899a.B991-898B-8994-0992-8996-89988997-899489985004899943997 n aa.16 2657 SBHP 176-7 5.78327 '3,197- B,B00 DA4 3204. 02 -OSA 5002941121501 O 640150 6ti1146tiUB,116114811,.7. 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OTHER 119. g3D0. ►.XN CA2 4.0212 R49A $00282045701 WI 690150 2116 .8964 B940�EH47,89404g52,8947-B5872-AL7584a4d9g7 IWO% 168. OTHER 18. to 1117. &AM 9,42 38453 Nam 5 002 92 8 412 01 w 6401 aw-w-04.89404947.6S4D .a747465236724975.08da-11997 15110 28 AM OTHER 4069 9. aAOO 0A2 3.711.2 MOM S00292{N8m1 w 640150 SUF-8884 1287118 4DO. 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NGI-0B 500292021900 d 640750 :315 -a OO.B250-8255,6255-8274,B274-8282,B2B2-8290,8290-8297,8297-8305,8313-5319,8319-B327,B327-8340,8340-B346,834 8348,8346-6348,B34B-8361,8361-8369, 8369-8365,8385-0394,8385.8402,6394-8402,8402-8418,841 B-8435,8435-8452,8462- 947 9499-8502 5024576951 9537454285424553.8553 9564-�573.8573-85949fi01-96126616-9023 2/1 via 525. SEHP 153, 6300,29 1384 8,800 0.0➢ 3429. P -05A 500292254501 O 640150 6569018-9DDi-0DD i, u9 ui$u iu,9uur-duu09,9009-yuiD,9Diu9Dii,yuil yuD9,yuii-yui2,9ui[yui3,9u14-9u 149u 8017901 B-9015 4/19/16 78. OTHER 7,315-15 2,649. 8,800 0.43 3,293- 0 A 1 0 Rtl156 49744954.90084985 4n4I6 72 OTHER 4790,116 2,409, 6-806 0,44 S.M. P.111L1 5002877DB750 O 640550 eH6Nom 900 -6 0 1015f1a 1 g92. 55HP 211 &150.51 3.261. aa00 0.39 3.44. P51-01 500243]76400 w 6/0190 62444717,357437467814&'4075426.6-S5Gd4562 7030)16 7 7 EO. OTHER 3D. 6A00 0.44 3816. p 5 S6v257317400 w 040750 85x8-8567 7,-30116 7819. GTHM 250, b,a00 0.44 JIM I m 440150 .03304 a4841A•84378442446. Y4&16 2, OTHER 140. AA60 0.44 3 P5147 500787317700 W$ 640150 115034530 7gy18 zgw. OTHER G. a 044 P&:M 500IM11480 VA s40150 7130'18 ME OTHER 50. =0 3,7x1. P51.Og $pG2933pg5D0. m 1116150 82§5-92¢9.93-87-8335.43603719.53972J048416-Bs640474-0CEIAA 44S+2 U44Y 16 2.$20. EITHER 240, amu]5H7- P51-10 500202311000 9H WI$O 62ar4%4.835ad991.6{iy-54$75:78.6467 7Mp11H 2.496. OTHER 110. 5&76 0.4-1 97846 R-02 2035400 Al 640150 es •BS,B77 e7_a m7.6a361e+D.aa4e 5e6e,66+a 16sa,6A4641a9,seas 6a7o 12 - 8919,8912 -8934,8919 -8923,8919 -8924,8919 -8934,:923 -8924,8924 -6934,8942 -B944,8942 -8945,8942 -8971,8944 -8945,8945 -OTHER 022 B95d B95d-8955 9518971,8955-8.971 B9B4-901SB994-99015-9022 B72W16 6,432 -21-61 1, 8,800 0.30 2.5w -05A 500292038001 WI 640150 1^25-58?7 BES"S�e45,69,56824866.1644.6597.5901;B07,591G4B176,4$19-1g11,e824i9I1.5•'4'! ao3B4o3t Bv4 8946 81281161 912. OTHER -2143 3.10,38 8,800 3,319 R.DaA 36501 m 646156 476S4M 6467x5 5 ereelfe 836, a R 37 5 MA= 0.79 7.210. RJOA 500292061802 O 0403150 89144915JM-9923 913$18 91. sow 2CE 8.7N." 7143,61 61-80 on ] 141. R -15A 500289081 1 w 640130 11624.8813.86211.1621 118111111 720. OTHER -22D2 S. Edo 0.36 3,216. R.25A 5002i72xKi m 50 68048000 UN4M05.9914i610,6a16-8B 135617.8516,e617-a6±4,6620.6116,tlfi2088:7.8633-863p,B5yFad35. 5657.58$: 11!29116 911 r3YHBR ,2:, 5, 11,5]0 0,36 3.18@- •3 1 t WI 6401 8849.85B6.dq 295��84ki63,B%$Aa6B Ti -0870,69784267 d%6.1964,g014A077,9 0.86729027.9.TM &]915 1176. 9 ,25.1 3. 11,111111 9.35 3.154, R D 500282.7929M O 6401 6517-8 1711176 1.059. OTHER ea00 035 2000. R. A 5002923587110 O7 640$50 ea63.1655 8a7d-6Ee5 6695 NM 9211-6007 699'-6g7] 6000-6➢95.90114009 1210116 157. 69HP 1817.76 a S 4.111 a,m0 0.11$ 1 1 5-33 500292229300 O 640150 x747.06548908.5027.8917.4627.89274831, 51-0932,BtlT2E596,a932.82iS.8S12.8987.BB3Sd44S.694j.E3W.B96S2957A95i 3987 103/16 BBS SBHP 222 B 931-19 5 51 B,BOo 0.43 3.3491 U-10 50CX3u28D0 w 5401503 6r94.1675.89954e60 $$6.b8B@•WB9.896D B076.699Lua999.89994M 1011Ma 24387. S0KP 159.54 879965 31 5.02 41,00 0.41 33452 V-02 �� SE02300 0 640150 8949 -8940,8949 -8966,8950 -8948,8950 -8949,89518950,0954 -8953,8954-8954,8955-8953,8955-8954,8955-8955,8958-8961,8961 695:,8962-8969,8965-9958,8967-8966, 8969497 D, 8971496:,8971-8959,8972-8972,8973-0971, 8973-8973, 8974-8973,8974- 99769975-99746975-99759976-999090764996 7749748979-8➢698➢7➢-8977.8980-B9B1.B➢B1d➢7➢9➢9LB➢90 9982 1021116 2163 SBHP 233.36 a. Boo 05 3787.33 B,800 0.36 3,7873 STA 5007)12166'601 0 S Oi60 689d497ia9224931 10.717/16 528: SBHP 206 61& 53 1159 11,00 40 3 1124 W - 15A 5007971D4d01 O 640t5p 6-87949)13 111via i704 SaHP V 53635 3720, a 0,60 34$3. V49A 500782165701 O 6d0150 6764.87a06T67;770661g4621.6820.661B ➢35177-3 174 18 S.W. OTTER 860997 16": a 03,037 1,573, Y-238 00292158102 v 640750 60124MM g01&80229021 1B.WaSO•BO19A912.B00d,%459042.9044.9D0.1,90459044 47T9N 59. OTi1ER 6.556-73 7.476 8,600 0,44 3.405. r -3i 1fi1v0 0 640+50 6d604d878a6046e5.a66241e45Bda a%-8911/,5%-90T2.8814A00,9001.9822 w 4 s, 64HP 221.90 a. .95 3.1.4 36 AAM 9.40 E361A 2-228 500292195002 0 640150 88604$85.68-87¢991-8916-0617,4$16-q�0,4910.5p22,5g17$413,6417�tpyl,Si:S$818.5921{1g10,69ZB-8S25.B9Z9•eB57,1g12 4999.99994001 912 16 31 fig2 SBHP 2]5 5600.16 3 701. B,BOD 0,44 3 700 5I Z40 5002923452W 0 Gat 5p 58564921.89034927.69254)156680549156952-3970655149-6169714951.595�n.0296-CM ZRH6 69& MMP 218 630➢& 311. 8-800 9,35 ),4 , Z49 900282347100 0 640t5a 61171.8380.6664-0651.6d914s09.5900480 Iv20f.6 80 6. &010 27448 A506•G1 7.661.19 9.600 0.42 3.5613 =I. 02-23-8 500252079$01 0 446tA2 I 623947&1, 90334037 SDV-9974 ! 5 g4]. 50)10 171,71 7.099.86 ]529.3 6,1[m 0.34 3 5289 Al■M rn ftd11565 Men ma44 11 aee4f04r+pa v4L1 aH►pw bk rtes. n40e'a m 111rtuaieir 4Nee A OW sin G. c444ely Cern4ruwr. Olher' above indicates a bottom hale pressure calculated 1-wrface data the fallowing well pressure measurements were exclutled for the average pressure map wmpumtion: 02-148, 1230, 12-84, 17-12A, 17-13A, 8-26C, C-0BC, F -00A, F -37A, GNI-02A, GNI-03, G%F , J-16 B, L-51, L-51, N-29, 1 hereby certify that the hregoing is true and correct to the best of my knowledge, ignature Printetl NAR14 di': 5reekr P -05A, P51-07, R-02, R -05A, R -25A, R -32A, R-00, R-04, W-1 SA, Y-1 RA, V -23B, H -09A Tile Alaska Ras... it Development Date 10 -Mar -2017 -ignature Printed Name 9111 Oredar Till. Alaska Data R...-ir Development 10.Mar-2017 Exhibit 11-1 GCWI 2015 Surveillance GCM Surveillance Wells ID GCW Observed (2015) 41 GCW Not Observed (2015) 10 GCW Observed (Pr 2015) 0 GCW Not Ob -d (Poor 2015) 40 Anomalous Water Production 0 Inc dusive+No Data GCWl Extent (Year) GC i 2x05 2008 2009 2011 2012 2013 M4 2015 .. F] .-1 Q N �h11py t 0 0 4- 0 z 4- c� v 4- 0 V) 0 4- 4- 0 - s0 Exhibit 11-2 GCWI Cross -Sections 13.17 06.21A 06.24 02.24 02.25 0237 02.28 02.18A 16-01A05-236L2.43AL2Al L2.24 L230 L238 L2-32 P81-00 PSI -10 L$46 LS -17 L5.13 �II PSI— Tei W I P., , 1,3.11 L; 04.21 04.20 04.19A 04.1004-02A 04.14 0935 09.07 Exhibit 12 Put River Sandstone Distribution Note: Current producers at Ds -02 are 02-23A and 02-27A
