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2019 Prudhoe Oil and Put River Oil Pools
me BP Exploration (Alaska) Inc 900 East Benson Boulevard P O Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 17, 2020 Mr. Jeremy Price, Chairman Alaska Oil & 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 — 2019 Annual Reservoir Properties Report -Prudhoe and Put River Oil Pools -2019 Dear Chair Price, BP Exploration (Alaska) Inc., as the Operator of the Prudhoe Bay Unit, submits herewith a consolidated Surveillance Report for the Prudhoe Bay Waterflood Project, Miscible Gas Project, Gas Cap Water Injection Project, Field Gravity Drainage Area and Put River Oil Pool in accordance with the requirements of Conservation Orders 341C (originally CO 279), 341D, 341F.007, 341I and 559A. This report covers the time period of January 1 through December 31, 2019. The Annual Reservoir Properties Report -Prudhoe and Put River Oil Pools -2019 is also being submitted under this cover and to aogcc.reporting@alaska.gov. The Operators of the Prudhoe Bay Field reserve the right to alter the content of the analyses contained in this report at any time based upon the most recent surveillance information obtained. Any questions can be directed to the undersigned or to Bill Bredar at 564-5348, william.bredar@bp.com. Respectfully, Katrina Garner West Area Manager/Reservoir Management, Prudhoe Bay Unit Alaska Reservoir Development, BPXA 564-4212 Attachments: Exhibits 1 through 12 Cc: Jeff Farr, ExxonMobil Alaska, Production Inc. Eric Reinhold, CPAI Dave White, Chevron USA Dave Roby, AOGCC Justin Black, Division of Oil & Gas March 17, 2020 This letter is to confirm that the office of the Alaska Oil and Gas Conservation Commission, has received an electronic copy of the ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL and PUT RIVER OIL POOL - 2019 Annual Reservoir Properties Report -Prudhoe and Put River Oil Pools -2019 Received by: Alaska Oil & Gas Conservation Commission Employee Date Please email a scanned, executed copy of the above to William.bredar@bp.com ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL AND PUT RIVER OIL POOL ANNUAL RESERVOIR PROPERTIES REPORT PRUDHOE AND PUT RIVER OIL POOLS JANUARY THROUGH DECEMBER 2019 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS CONTENTS SECTION PAGE 1.0 INTRODUCTION 4 2.0 OVERVIEW 5 3.0 PRESSURE UPDATE 7 3.1 Pressure Monitoring 7 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 4.6.2 2020 Surveillance Plans 14 4.6.3 Plans for Change in Project Operation 14 4.7 Put River Pool 15 5.0 GAS MOVEMENT SURVEILLANCE 17 5.1 Gas Movement Summary 17 6.0 REVIEW OF POOL PRODUCTION ALLOCATION FACTORS 18 Page 2 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS LIST OF EXHIBITS ]-A Prudhoe Bay Unit Field Schematic 1-B PBU Well Statistics 1-C PB U Production /Injection Statistics 1-D PBU Pressure Map I -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 Areal Average Reservoir Pressure 7-D EWE Daily Average RMI 8 Wells Surveyed for Gas Movement 9 Pressure Surveys (Form 10-412) 10-A GCWI Surveillance and Extent 2019 10-B GCWI 2019 Extent: Southwest —Northeast Section 10-C GCWI 2019 Extent: North — South Cross Section H -A Annual Reservoir Properties Report -Prudhoe and Put River Oil Pools (AK 20 AAC 25.270) 12 Put River Sandstone Distribution Page 3 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 1.0 INTRODUCTION As required by Conservation Order (CO) 341I and CO 559A, 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 2019. 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 The Annual Reservoir Properties Report -Prudhoe and Put River Oil Pools is being submitted under cover of this report as Exhibit 11-A. (AK 20 AAC 25.270). The Excel version is also being submitted -electronically to avgcc.repyrting@alaska.gov. A report of completed development or service wells that have been shut-in for 365 days or longer as of January 1, 2020, will be separately filed with the Commission by March 31, 2020, 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 Oil 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 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 2.0 OVERVIEW Exhibit IA identifies the five flood areas and gravity drainage areas in the Prudhoe Oil Pool as follows: FS -2, EPWZ, WPWZ, NWFB, EWE, and GD. The Waterflood Project encompasses all five flood areas. The Prudhoe Bay Miscible Gas Project (PBMGP) is currently active throughout the waterflood areas. The Eileen West End waterflood pilot concluded in March 1999, after successfully establishing EWE injection potential. EWE information since waterflood startup in September 2001 is included in this report. Exhibits 1-B and 1-C provide well, production, and injection statistics for the major project areas included in this report. As in last 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 2019, field production averaged 165 MBOD, 7030.4 MMSCFD (GOR 42601 SCF/STB), and 985.3 MBWD (water -cut 85.65%). Overall Waterflood injection during this period averaged 1490 MBWD with 154 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2019 was 13587 MMSTB, while cumulative MI injection was 3369 BCF. Cumulative production in these same areas (not including Gravity Drainage) since waterflood startup was 3077 MMSTB oil, 15333 BCF gas, and 9974 MMSTB water. As of December 31, 2019, cumulative production exceeded injection by -10447 MMRB compared to -10020 MMRB at the end of 2018. 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 2017 through 2019 at a datum of 8,800 ft, subsea for the Ivishak Formation. 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 River Formation have been removed. As shown in Exhibit IE, the historic pressure decline appears to have stabilized due to gas -cap water injection. For 2019, average pressure in the PBMGP project areas using three years of pressure static measurements was calculated to be 3369 psia by areal weighting, as compared to 3360 psia in 2018 (Exhibit 1F). The GD area pressure was stable increasing 33 psi from 3286 psia in 2018 to 3319 psia in 2019. This subtle pressure increase is within the expected statistical variation with a different annual pressure sampling data sets. Interpreted MI breakthrough has occurred in 59 wells during the reporting period. The previous year showed interpreted MI breakthrough in 78 wells. RMI production is an indicator of EOR pattern performance and the presence of RMI is best determined by primarily gas sample analyses that show a separator gas composition richer in intermediate range hydrocarbon components but also proximity to WAG injectors in known MI patterns. MI breakthrough in a WAG pattern well is considered to have occurred when the average RMI rate over the number of producing days in a well exceeds 200 MCF/D. Page 5 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS AOGCC Conservation Order No. 341I, Rule 12 (c) specifies that "The minimum miscibility pressure (MMP) of the Miscible Injectant must be maintained at least 100 psi below the average reservoir pressure in the Prudhoe Bay Miscible Project area. When the Operator demonstrates that the reservoir pressure is no longer declining within the Prudhoe Bay Miscible Project Area (as evidenced by reservoir pressure measurements), the MMP may be maintained at or below the average reservoir pressure in the Prudhoe Bay Miscible Project area." As MMP became the constraint on NGL production in the winter of 2018, and the reservoir pressure has stabilized with the gas cap water injection project, the MMP limit was increased from 3150 psi to 3200 psi in March of 2019. Further adjustments may be made to MMP, but the setpoint will continue to be set below the average reservoir pressure in the Prudhoe Bay Miscible Project area. The raw compositional data used to calculate MMP are reviewed and engineering judgement is applied to remove poor data associated with 0 or very low MI volumes and brief upset periods to provide the monthly average MMP provided in Exhibit 1-G. Exhibit 2 provides monthly and annual fieldwide reservoir balance figures. On March 5, 2020 the Commission approved the Seawater Optimization Project (SWOP) which is planned to be implemented in the 2020 plan year in DS -1 and DS -12 of the Eastern Peripheral Wedge Zone (EPWZ). The Commission specified the following two conditions: Condition 1 states that BPXA is required to include in the Annual Reservoir Surveillance report for the POP and PROP: "a detailed description of the progress towards returning the PROP to production". As the SWOP project was not implemented during the plan year of this report (January — December 2019), no action to shut-in the Put River Oil Pool was taken so no description of such progress is due. As the SWOP project is planned to be implemented in 2020, it is expected that a description of progress toward returning the PROP to production will be in the 2020 ASR. Condition 2 states that the ASR is to also include "the evaluation of the potential to improve ultimate recovery by ceasing water injection elsewhere in the POP". An initial evaluation considering a more extensive shut-in of injection within the Prudhoe Bay Miscible Gas Project (PBMGP) area including assessment of potential feasibility, scope, and any potential benefits began in 2019 and is expected to continue in 2020. Page 6 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 3.0 PRESSURE UPDATE 3.1 Pressure Monitoring Exhibit 9 (Form 10-412) provides pressure, buildup, and falloff data collected in 2019 at a datum of 8,800 ft, subsea used for the Ivishak Formation. During 2019, per CO 341I, 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, confirms 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 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 report, 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 2019 pressure map using 2017 through 2019 data points. 3.2 Pressure Plan Per CO 341I Rule 6a, the following pressure surveillance plan information is provided. 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 and reservoir management. The plan for 2020 calls for collection of a minimum of 40 pressure surveys fieldwide. In accordance with the rule (5% clause), a minimum of 2 pressure surveys will be collected in each of the seven development areas: Gas Cap, Gravity Drainage, Flow Station 2 Water/MI Flood (MWAG) Project, Eastern Peripheral Wedge Zone MWAG Project, Western Peripheral Wedge Zone MWAG Project, Eileen West End Waterflood Project, and the Northwest Fault Block MWAG Project. Given Commission approval for Seawater Optimization Project (SWOP), focus will be placed on obtaining pressure measurements in the vicinity of DS -1 and 12 areas in order to obtain baseline data before project execution. Page 7 2019 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 109 producing wells and 54 injection wells that contributed to production/injection during 2019 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 24.6 MBOD for 2019 compared to 28.1 MBOD in 2018. Cumulative production since waterflood start-up through the end of 2019 is 1130 MMSTB of oil, 6955 BCF of gas, and 4978 MMSTB of water. Injection rates averaged 346.3 MBWD and 68.7 MMSCFD in 2019. Since 12/31/18, the waterflood imbalance has increased from a cumulative under injection of 3747 MMRB to 3956 MMRB under -injected. During the report period, production exceeded injection by -208 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 2019, is 7089 MMSTB and 1157 BCF respectively. The flood area's GOR increased from an average of 27990 SCF/STB in 2018 to an average of 28278 SCF/STB in 2019. Gas influx continues along the FS-2/GD GDWFI area, and in the high permeability conglomerates in the Updip Victor area. Water -cut was 93 %. 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 FS -2 areal average waterflood pressure change over time. The pressure in the FS -2 area was 3381 psia in 2019. This is a decrease of 15 psi under the 2018 pressure. Exhibit 3-D is a presentation of 2019 average returned MI (RMI) rates. Miscible gas return has been confirmed in 19 wells by gas compositional analysis (RMI>200 MSCFD). Page 8 2019 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 2019, oil production averaged 14.4 MBOD, as compared to 14.9MBOD in 2018, with an average 94% water cut and 19463 SCF/STB Gas Oil Ratio. Injection averaged 174 MBWD and 0 MMSCFD of miscible injectant (MI). There is a total of 68 producers and 25 injectors in the flood area that contributed to production/injection during 2019. Of the 25 injectors, none injected miscible gas at some point throughout the year, all 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 669 MMSTB of oil, 3880 BSCF of gas, and 2038 MMSTB of water have been produced with 2482 MMSTB of water and 691 BSCF of miscible gas injected. Exhibit 4-13 shows the monthly injected and produced volumes on a reservoir barrel basis during 2019 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 106 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 3364 psia in 2019. This is an increase of 36 psi as compared to 2018. Exhibit 4-D shows the 2019 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 7 wells (RMI >200 MSCFD). Page 9 2019 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 14.4 MBOD compared with 14.7 MBOD in 2018, with a gas/oil ratio of 20283 SCF/STB and a watercut of 91%. Injection averaged 130 MBWD of water and 34.52 MMSCFD of miscible injectant. For the WPWZ project, 38 injectors (4 WAG injectors and 31 water injectors, 3 gas injectors), and 89 producers contributed to the production and injection during 2019. 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 2019 was 1991 MMSTB while cumulative MI injection was 679 BSCF. Cumulative production since waterflood start-up is 561 MMSTB oil, 2552 BSCF gas, and 1585 MMSTB water. As of December 31, 2019 cumulative production exceeded injection by -1829 MMRB. Exhibit 5-13 provides the monthly injection and production data from 01/19 through 12/19. During the report period, production exceeded injection by 94 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 3,334 psia in 2019. This is an increase of 14 psi over the pressure reported in 2018. Exhibit 5-D indicates wells with MI breakthrough and the 12 -month averaged returned MI rates. Miscible gas breakthrough has been confirmed in 19 wells by gas compositional analysis. Page 10 2019 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 8.8 MBOD, as compared to 9 MBOD in 2018, with a gas/oil ratio of 10124.2 SCF/STB and a watercut of 89%. Injection averaged 82.4 MBWD and 19.7 MMSCFD of miscible injectant. For the NWFB project, 27 injectors (6 WAG injectors, 20 water injectors, and 1 gas injector), and 61 producers contributed to the production and injection during 2019. 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 2019 was 1766 MMSTB while cumulative MI injection was 718 BCF as detailed in Exhibit 1-C. Cumulative production since waterflood start-up was 617 MMSTB oil, 1543 BSCF gas, and 1128 MMSTB water. As of December 31, 2019 cumulative production exceeded injection by 703 MMRB. Exhibit 6-13 provides the monthly injection and production data from 01/19 through 12/19. During the report period, production exceeded injection by 22 MMRB. However, this does not include support obtained from aquifer influx or gas cap expansion. The areally weighted pressure in the NWFB area was 3401 psia in 2019. This is an increase of 21 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 12 wells by gas compositional analysis. Page 11 2019 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 8.5 MBOD, as compared to 8.7 MBOD in 2018, with a gas/oil ratio of 4407 SCF/STB and water cut of 85%. Injection averaged 48 MBWD and 15.8 MMSCFD of miscible gas injectant. For the EWE project, 18 injectors (5 WAG injectors, 11 water injectors. 2 gas injectors), and 61 producers contributed to the production and injection during 2019. The well counts reflect only the active wells for the year. Cumulative water injection from waterflood start-up in September 2001 through December 2019 was 259 MMSTB and cumulative MI injection was 124 BCF. Cumulative production since waterflood start-up was 100 MMSTB oil, 403 BCF gas, and 245 MMSTB water. As of December 31, 2019 cumulative production exceeded injection by 333 MMRB. Exhibit 7-13 provides the monthly injection and production data from January 1, 2019 through December 31, 2019. During the report period, production exceeded injection by 10 MMRB. The averaged EWE pressure was 3593 psia in 2019, representing a pressure decrease of 26 psi from 2018. The historical pressure trend can be seen in exhibit 7-C. Exhibit 7-D indicates wells with MI breakthrough and the 12 -month average returned MI rates. Miscible gas breakthrough has been confirmed in 9 wells by gas compositional analysis. Page 12 2019 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 2019 are shown below; units in thousands of barrels of seawater iniected ner month fMBWPMI-. PSI -01 PSI -05 PSI -06 PSI -07 PSI -08 PSI -09 PSI -10 Total 1/1/2019 1,560 1,511 1,819 1,400 1,651 0 1,649 9,589 2/1/2019 1,648 1,599 1,779 1,418 1,640 0 1,687 9,771 3/1/2019 3,176 3,009 3,189 3,094 3,092 0 3,105 18,665 4/1/2019 3,105 2,985 3,122 2,763 3,104 0 3,074 18,153 5/1/2019 3,238 3,108 3,216 2,698 3,235 0 2,933 18,428 6/1/2019 3,134 3,009 3,127 2,915 2,991 0 2,947 18,124 7/1/2019 2,810 1,247 2,754 655 2,797 550 2,730 13,542 8/1/2019 779 589 824 0 783 684 752 4,409 9/1/2019 1,237 1,257 1,311 822 1,270 1,305 1,306 8,508 10/1/2019 2,380 2,387 2,513 1,137 2,327 2,328 2,177 15,249 11/1/2019 2,137 2,143 2,478 1,758 2,215 2,229 2,210 15,172 12/1/2019 3,373 J 3,127 3,838 1,124 3,112 3,000 2,922 20,496 The 2019 volume of sea water injected in the PSI wells was 170.1 million barrels. The cumulative volume injected at the end of 2019 was 2.8 billion barrels of sea water since the project startup in 2002. 4.6.1 Observation Cased hole 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 10-A is the locator map for the GCWI area and shows the PSI injectors along with the observation wells. The turquoise polygon indicates the interpreted current GCWI waterfront, which has very minimal change since 2018. Well 02-38A, south of the mid -field graben, started producing water in late 2017, and chemistry analysis suggests it is likely GCWI. It was this datapoint in 2017 that resulted in the slight extension of the polygon across the mid field graben. A log was run in this well in 2019, with data collected down through Z 1 A, and there was no evidence of water. It is likely that the perforations near the toe, which are closer to the mid field graben, are the source of the GCW production. The information from all the neutron logs was used to develop the updated northwest -southeast and north -south cross sections (Exhibits 10-B and 10-C) showing the interpretation of the surveillance data for the current time period. Page 13 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS The most recent round of neutron log surveillance included the following wells: 02-38A, 18- 05A, 18-0813, 18-17, 18-35, L2-0713, L2-0813, L3-06, L3 -22A, L5-27, 11-11A, 11-37A, 11-01A, and 11-05A. As the areal and vertical extent of the water mass becomes larger, the rate of incremental advancement both laterally and vertically has become noticeably slower. At this point, the changes in the waterfront have followed a relatively predictable pattern established in recent surveillance, where the largest extent of incremental waterfront coverage appeared in Zone 2C, owing to significant lateral continuity of the 24N shale. Surveillance wells for 2019 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 lA and 1B. Several wells, notably 18-35 which was completed in late 2015, have logged GCW from Z3 down to bottom of Z1B. A repeat log was run in 2019 in this well across the production zone IA, and no evidence of water was seen in the unperforated sections. Many wells in the DS 18 area are producing GCW. Understanding the water pathway to Zone 1, which is the oil bearing interval in this far upstructure area of the field, is a continued focus for future logging and analysis. Integrating production evidence with log evidence is an important part of the 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 2020 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 Cased hole Saturation Logs This program will continue as it has in the past by running cased hole 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 2020. 4.6.3 Plans for Change in Project Operation No changes to the Gas Cap Water Injection operation are planned for 2020. Page 14 2019 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. On December 19, 2019, the AOGCC granted BPXA's request to: (1) to administratively amend Conservation Order 559A to contract the Put River Oil Pool (PROP) to the area encompassed by the Southern Lobe of the Put River sandstone; (2) to modify rule 18 of C0341H to ensure that the downhole commingling ruled authorization that currently allows downhole commingling of any well in the PROP with the Prudhoe Oil Pool will continue to apply to wells completed within the currently established bounds of the PROP when the affected area of the PROP is contracted; and (3) a gas oil ratio exemption to wells completed in the Central and Western lobes of the Put River sandstone for the purposes of collecting data to develop a reservoir development strategy for those sands in accordance with 20 AAC 25.240(b)(3). 2019 Production and Injection For the year 2019, over 85% of the production, and all of the injection, occurred in the Southern lobe, with the remaining production from well 15-41B which has perforations in the Western and Central lobes. Production from the Put River Oil Pool in 2019 averaged 356 BOPD for the days the reservoir was on production and 315 BOPD averaged across calendar days. The total 2019 production of the Put River Pool comes from two Put River producers: wells 02-27A and 15-41B. Injection in the Southern Lobe of the Put River averaged 2,303 BWPD for the days the injector was online and 1,884 BWPD averaged across calendar days. Cumulative Put River water injection is 13.6 MMBW, of which 688 MBW was injected in 2019. The 2019 cumulative production for the Put River Oil Pool was 115 MBO, 673 MBW and approximately 521 MMSCF formation gas. The full life cumulative production for the Put River Oil Pool through December 31, 2019 was 4.2 MMBO, 8.74 MMBW, and approximately 6.48 BSCF formation gas. (Note that these cumulative volumes include a technical estimate, based on material balance calculations, of Southern lobe production from a casing leak in 02-27 between 1994-1997. The cumulative gas volume reported in this report is reflective of the best technical estimate of the formation gas production from the PROP; the volume reported in previous ASRs may differ due to accounting for the estimated casing leak volumes and gas lift volumes.) For this report (and also for last year's 2018 ASR), the reservoir properties in Exhibit 11 for the PROP pertain to the Southern lobe only. Southern lobe properties are reflective of over 99% of production in 2019. 2019 Pressures Put River Oil Pool affected area pressures taken during 2019 are listed in Exhibit 9. The PROP Southern Lobe pressure obtained in 02-23A producer in February 19, 2019 measured 3,862 PSI at -8,100' SSTVD. Another pressure obtained on November 24, 2019 measured 3,765 PSI at - Page 15 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 8,100' SSTVD. The fairly stable pressure was a result of a voidage replacement ratio of approximately 1 on average for the year. 2020 Surveillance Plan PROP affected area (Southern Lobe) — A fairly stable pressure trend has been observed in 2019 as a result of injection near VRR of 1. That will be the continued strategy in 2020. A static bottom hole pressure survey is planned in 2020 in producer 02-23A. Page 16 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 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 2019 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). In many areas of the GD a distinct GOC no longer exists. Rather the data suggest that there is a continuous gradation of gas saturation throughout this part of the reservoir. Gas influx is essentially absent in the southern peripheral regions as a result of water and WAG injection in the waterflood areas. There are areas downdip of the GDWFI area that are affected by gas. 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 213. 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 Oil Pool (POP) during the gas -influx reporting period from January 2019 through December 2019. A total of 37 gas -monitoring logs were run in the POP of which 30 were cased -hole, 5 were open -hole, and 2 were both cased and open hole. On July 20, 2016 the Commission modified the neutron log requirements in CO 341F Rule 7 (341F.002 (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. On January 9, 2018 the commission further modified the neutron log requirements in CO 341F (.007) Rule 7 to have the Annual Reservoir Surveillance Report contain the number and approximate locations of neutron log surveys anticipated for the next calendar year. The 2018 ASR committed to a minimum of 30 neutron saturation logs. For plan year January 1, 2020 until December 31, 2020, a minimum of 30 neutron saturation logs will be obtained with the following approximate distribution (minimums): Gas Cap — 0, , Gravity Drainage -8, Gravity Drainage Waterflood Interaction -12, Downdip Areas Affected by Gas -10. Page 17 2019 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY AND PUT RIVER OIL POOLS 6.0 REVIEW OF POOL PRODUCTION ALLOCATION FACTORS Prudhoe Oil Pool (POP) and Put River Oil Pools Monthly Average Oil Allocation Factors: 2019 Jan 0.93 Feb 0.92 Mar 0.91 Apr 0.93 May 0.94 Jun 0.95 Jul 0.95 Aug0.93 Sep 0.93 Oct 0.95 Nov 0.94 Dec 0.94 The table contains monthly averages of oil allocation factors from the 7 facilities that receive production from these two pools: GC -1 (POP only), GC -2 (POP only), GC -3 (POP only), FS -2 (POP & PUT), FS -2 (POP only), FS -3 (POP only) LPC (POP only). Any days of allocation factors of zero were excluded. These allocation factors range from 0.91 to 0.95. Daily allocation data and daily test data are being retained. Page 18 2018 AOGCC Report Producers Injectors -WAG -Water Only -Gas 2019 Producers Injectors -WAG -Water Only -Gas Production Well Status in 2019 -Newly Drilled -Sidetracked or Redrilled Gas Injection Well Status in 2019 -Newly Drilled Sidetracked or Redrilled WAG Injection Well Status in 2019 -Newly Drilled -Sidetrcaked or Redrilled Water Injection Well Status -Newly Drilled Sidetracked or Redrilled Exhibit 1-13 WPWZ NWFB FS2 EPWZ EWE GD 98 58 100 71 67 440 38 29 58 26 18 57 3 2 0 0 4 2 31 22 49 26 12 24 4 5 9 0 2 31 89 61 109 68 61 438 38 27 54 25 18 56 4 6 2 0 5 0 31 20 45 25 11 23 3 1 7 0 2 33 0 0 1 0 0 1 2 0 8 0 0 7 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 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 2019 Oil (MMSTB) Gas (BCF) Water (MMSTB) Cumulative Injection from WF Start -Up thru 2019 Water (MMSTB) MI (BCF) Cumulative Balance from WF Start -Up thru 2018 Cum Production (MMRB) Cum Injection (MMRB) Over/Under (MMRB) Cumulative Balance from WF Start -Up thru 2019 Cum Production (MMRB) Cum Injection (MMRB) Over/Under (MMRB) MI Breakthrough in Producing Wells > 200 mcfd AVERAGE RATE DATA 2019 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 561 617 1130 669 100 3077 2552 1543 6955 3880 403 15333 1585 1128 4978 2038 245 9974 1991 1766 7089 2482 259 13587 679 718 1157 691 124 3369 4164 2831 11516 5997 624 25131 2428 2150 7768 2917 301 15565 -1735 -681 -3747 -3080 -323 -9566 4316 2890 11873 6169 655 26674 2487 2186 7917 2983 323 16227 -1829 -703 -3956 -3186 -333 -10447 19 14 19 7 9 68 14.4 8.8 24.6 14.4 8.5 70.7 293.0 892 694.4 2798 37.5 13939 145.6 71 0 3468 207.4 484 819.2 130.3 824 3463 174.0 480 781.0 34.5 197 687 158 138.8 GD WPWZ NWFB FS -2 EPWZ EWE PBMGP 3286 3320 3380 3396 3328 3619 3360 3319 3334 3401 3381 3364 3593 3369 33 14 21 -15 36 -26 9 + by Exhibit 1-D - -........Prudhoe Oil Pool 2019 Regional Reservoir Pressure Map • a tr1- EWE _ e,r SAVwpwz + Gas Cap lr.M +rte O auo °a _A •.!a ��Or J� •' `a.� T2��e.��.'w� err •rte � � a + - } l.11 ■ °HA2 i + iar + + I 2018 Reserviw Pressure r 2017 SBHP at 8600 SS Damm r 2010 SBHP 3,050 - 3 150psi 3,150 - 3.225 psi 2019 SSHP 3,225-3300 psi 2017 Calculatetl _ 3,300 -3.420 psi from Surface Data 3,420 -3,550 psi • 2016 Calculated 3.550 -3 660 psi from Surface Data 3,660 • 3 790 psi r 2019 Calculated 3.790 -3 B90 psi from Surface Data Prudhoe Bay 3 890 -4,000 psi LUnit Boundary Depletion Polygons NOTE, Engineered control points have been added to the field perimeter to provide a a more accurate contouring - tomo m:w w:>u ra.r + Gas Cap lr.M +rte O auo °a _A •.!a ��Or J� •' `a.� T2��e.��.'w� err •rte � � a + - } l.11 ■ °HA2 i + iar + + Exhibit 1-E Areal Average Pressure —*--PBMGP Gravity Drainage 3906 3800 3700 3600 ; P 36W S I A 3400 3300 3200 3100 3000i I I... .. T:--., . ,, Dec -82 Jan -87 Jan -91 Jan -95 Jan -99 Jan -03 Jan -07 Jan -11 Jan -15 Jan -19 Jan -23 C C C C C C C C C C C C C C C C d C d C d C d C d C� C d C d C d C d C d C d C� C� C d C d C� C CD C CD C N C CD C N C CD W - - - - - - — —'L6666666 -r 7 -r :3 -r 7 -r7 -r7 -r 7 6 6 6 6 6 6 0 0 0 0 0 0 CO co (O CO (O (D CO CO f0 CO CO CO CO CO (6 p CD (D CD 6 W pp W pp W �' V V W V W 0 0 0 0 6 w W W W CT A W N O O W V W CT A A W W N N O O O CO W W V V W W W A A w W N � 6 CO CD A A W N N m a W O W CO W W J M WW W co W CDNOVO-4 W VWACNNMO ON CONOOWCWWWWT VVAWVTWNMOWOWWTTCOWOWWAWwWVNOOOWWAO N CO W N O T N w W w w w w w w w w w w w w w w w w w w w w w w w w w w w w w w w ca w w w w w w w w w w w w w w w w w w w w w w w w w w w A W W W W W W W W W W N W N W W N W W W W W W W W W A' A A A4 O CTO Mtn W W W O W 0-4 V V V V V V W W OD W W W W W O O m V CA A —"W—"M N O W W N W W A N— CD W CO A "COO N W— N CT W V CO O W M CA W O "W M CO O "40 V CO O W A CT V W t0 O N� W W CO W W O W A N O A W W CT CO O CO O W A A W W W A A O CT W CO V V A V (T V A W Cn U1 O W V W W W O W W A CT CT W CO W O V CT W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W A C� G W A W W W W W W W V V W W W CO CO CO O WW N N N N N N N N N N W W W W W W W j A A -A,4 n n T T 000 W W A V V -4-4 V V V -4M-4 —O V V OD W M A W V W O N V W Co COW W V CO W CT T V CO W CT V CO 0) W T V V WCO O CO N A V SA V_ �OCTWWAWOWVWWCTWNLWCnNWOCOCTWNONAVWONVW(T(TWWCDNNWAW—W—VW"VOWf0NWCOAW W W W w W W W W W W W W W w co W W W W w W W W W w W W W W W W W W W W W W W W W w W W W W W W W W W W W W W W W W W W W W Z A O W W W W W W W W W N N N N N N— N N N N W W A A A A A A A W A A CT CT CT W W W W V V V V V V W W W W V V V OD W CD CO OD N W W N N O N N V W A CO W W— — N A W O N A W A O N N A W V W O CT W— A V Co N Cn W O N W CT V W O— N W V W A V O A T O V N M N CO N N CO — CO W W CO W W W— A W CT M O OD V W N V A— W CO V W W CT A V N W CT V A W W W N V A N O A— O W W Cn W A W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W NN N N N N NN N N N N N NNNN NN W W w W W AAAAAA TW W W W W W V V V V V W W OOOCWNV WWODWOC_AvAWCWV-4AOWN—W4h,WOWAVOjAVOW-WMDCCO V T O W W n CD OD A W CD W W W T O A W CD CO W N N CO O OO CT W OT — W T N OW O W - O W Cn W W W W W W W W W W W W W W W W W -- W W W M W W W W W W W W CT W W W M W W W CT A CT CA N 00 W A A (.nn CO W W A W CO V O CT N W N O CA W CA W CA N A CT coO CA W W W W W W C W W W W W W W W W W W W W W W W W W W W W W W W W W C W W W W W W W W W co W W W co W W Cl) W W W W W W W W W W Cal N W N N N N co W W W W W W W W W W W W N CYI W W A AA A A A A A CT T T W W W V V V V V W W W W CO W V W W CO CO CDA W A A A A A W W M CD CO O V W CO A T A CT COjN A -W N A A W W O- W W W W W W W A T V fO O M W A A MCO M A V W CJI j 3 CDC) AWOWWWWOT (OOWA O NWV V W VWTWWWT O --WW WAA V T NWOT WT WOT A O A W W N O W W W A W A W G) I Exhibit 1-G EOA MI Rate MCFD MMP PSI MW Mol Wt CO2 C1 Average Monthly C2 C3 Mole% IC4 NC4 C5+ 1/1/2019 92, 505 3,135 32.97 21.91% 33.01% 16.18% 25.25% 2.01% 1.49% 0.00% 2/1/2019 78,811 3,174 32.57 20.91% 33.14% 18.06% 25.00% 1.78% 0.97% 0.00% 3/1/2019 61,781 3,157 32.57 20.93% 32.22% 19.26% 25.37% 1.48% 0.61% 0.00% 4/1/2019 86,524 3,151 32.57 20.81% 32.62% 18.42% 25.59% 1.69% 0.64% 0.00% 5/1/2019 102,224 3,156 32.62 21.10% 32.51% 18.72% 24.52% 1.80% 1.10% 0.00% 6/1/2019 163,978 3,068 32.63 20.11% 30.82% 21.69% 24.75% 1.63% 0.78% 0.00% 7/1/2019 39,962 3,034 32.68 19.35% 32.82% 18.05% 25.81% 2.02% 1.59% 0.00% 8/1/2019 63,175 3,303 31.93 20.02% 35.33% 17.30% 24.34% 1.76% 0.85% 0.00% 9/1/2019 96,554 3,162 32.38 20.31% 32.15% 20.56% 24.46% 1.54% 0.72% 0.00% 10/1/2019 100,953 3,235 32.45 21.55% 33.22% 17.74% 25.38% 1.37% 0.55% 0.00% 11/1/2019 119,650 3,197 32.49 21.56% 31.60% 20.20% 24.95% 1.11% 0.38% 0.00% 12/1/2019 102,554 3,203 32.44 21.62% 31.06% 21.14% 25.00% 0.79% 0.18% 0.00% Average 69,055 3,177 32.52 21.00% 32.63% 18.75% 25.08% 1.54% 0.78% 0.00% WOA MI Rate MCFD MMP PSI MW Mol Wt CO2 C1 Average Monthly C2 C3 Mole% IC4 NC4 C5+ 1/1/2019 130,394 3,132 32.98 21.94% 32.97% 16.17% 25.27% 2.02% 1.49% 0.00% 2/1/2019 138,381 3,115 32.76 20.98% 32.16% 18.65% 25.42% 1.78% 0.88% 0.00% 3/1/2019 142,677 3,118 32.72 21.03% 31.70% 19.40% 25.51% 1.60% 0.63% 0.00% 4/1/2019 142,706 3,122 32.67 20.87% 32.18% 18.63% 25.76% 1.72% 0.63% 0.00% 5/1/2019 173,635 3,085 32.79 20.85% 31.65% 19.24% 25.16% 1.81% 1.04% 0.00% 6/1/2019 163,978 3,068 32.63 20.11% 30.82% 21.69% 24.75% 1.63% 0.78% 0.00% 7/1/2019 105,042 3,038 32.68 19.48% 32.18% 19.33% 25.33% 1.92% 1.44% 0.00% 8/1/2019 23,572 3,309 31.87 20.02% 35.07% 17.83% 24.27% 1.61% 0.76% 0.00% 9/1/2019 57,824 3,158 32.38 20.29% 32.23% 20.23% 24.76% 1.51% 0.70% 0.00% 10/1/2019 97,094 3,204 32.55 21.60% 32.78% 17.87% 25.62% 1.37% 0.55% 0.00% 11/1/2019 116,377 3,200 32.50 21.63% 31.71% 19.91% 25.03% 1.12% 0.38% 0.00% 12/1/2019 117,659 3,187 32.50 21.72% 30.77% 21.23% 25.09% 0.78% 0.19% 0.00% Average 117,242 3,144 32.59 20.89% 32.17% 19.19% 25.17% 1.57% 0.79% 0.00% Exhibit 2 Fieldwide• Fieldwide Reservoir Balance Producing Fluids (MMRB) January February March April May June Oil 7.3 6.4 7.0 6.9 70 6.2 Free Gas 212.7 182.2 192.4 198.3 1976 176.3 Water 33.7 29.6 31.8 31.6 343 26.5 TOTAL 253.7 2183 231.2 236.7 2389 209.0 Injected Fluids (MMRB) Water 40.5 378 49.7 499 520 45.5 Gas 2095 1789 188.3 1952 1935 172.0 TOTAL 2500 2168 238.1 245.2 2455 217.5 Net Injection Volumes = Injection - Production (MMRB) TOTAL -3.6 -15 6.9 8.4 6.6 8.5 July August September October November December Totals Producing Fluids (MMRB) Oil 6.2 53 6.0 6.8 7.0 7.1 79.3 Free Gas 158.0 153.5 167.5 184.4 201.3 208.1 2232.3 Water 29.7 26.3 28.8 31.4 34.1 36.2 373.9 TOTAL 194.0 185.1 2023 222.6 2424 2514 2685.5 Injected Fluids (MMRB_) Water 41 6 28.0 350 46.1 45.9 527 524.8 Gas 1546 150.7 1646 180.7 1979 203.4 2189.3 TOTAL 1962 178.6 1996 226.8 243.8 2561 2714.1 Net Injection Volumes = Injection - Production (MMRB) TOTAL 22 -6.5 -26 4.2 14 47 28.6 Exhibit 3-A FS2 UGM L3-19 Gas Injector �� Gas Injector Shut-in oa-2o _27 L o4.25 L 5 - Miscible Injector 230 11-10A 1.04 04- Ni cible Injector Snut-m 04. 04- 1 - 18.21 r 11-33-27 • Oil Producer Flowtn 9 17_37A 71- 11.0$ 44-,7 - A 04 11 L3 NGUT-IXX 1 Oil PFoducer Shut -In 19A 11_25 71-05- 11.11 ,1 �� Od- Water Injector 1-06A 11.Q 04-10 - _ 28 04 - water Injector Shut -1n 1 24A 11-37A• 04-08 Abandoned fl2A a0 04.41A 1 14-29AL1 0437 04- 09.4 _ Plugged sack 11-38A 04-13 04-14 04-11A - - 04.4 - -43 Ambiguous Status CA O9 71-05A 1,• 04--og -s8 • 11-29 1-18 -04A 09-06 4 -51 04.15 04-09■ 04- 0" 09,39 11-02• 19,39" 6 09-52■ .3009 .35A 09.42A 11-17A 04.85 04 -17A 09-14 09.27. 04-03 09-10 -21 04-0fi 29A 009-4 05-47 {19-37 09-38 11- - s88 �s09-16 A 09-1T 09.22 6 09-18A 0.3r09 9-A -50A ' 1A 03�10A 09-20 09-12 03-1 03-18A i 9 -23A 01- 23 A 03 1A 3A [T3-248 ?3 -1 0 03 r 09-25 19 03V8 03-17.,, - I , - ^63- &,q 09.51A •13 032 03.150 30A 6- 24 IS - 13;- 01- 03.1 007.328E r -20A 09-01A 1A 12-32 033 A 03-06 03- 16-01 -07A r 03-05 ' Q3 -34B -145 16. _6 A -03-04 is � • 17-140 17.46 17- 14 7 1602 03-11 03-13 17 -2 t 16- -07 .18 1 A N 17-08 16-16 16-11 16.03 17-10 17' i6 -12A 16- "25 16-05A ■ 1 A - b I7 7-15A 1 17.04 17-01A 16 r08A I6 -23A 1 0 1 16 -TOA ' Miles Exhibit 3-13 1 FS2 7,016.0 752.4 7.768.3 -3,747.3 11.901 1 855 13.757 -203 10 330 1 024 11.354 -183 10.854 1 315 12 169 -175 11.679 1.737 13.416 -192 12 304 1 217 13 521 -17.9 7 285 7 285 -123 Produced Fluids (MMRB) July Produced Fluids (MMRB) 12/31/2018 January February March Aril May June Fluid Properties Used 0.929 Oil 1,472.5 1 089 0.926 1.041 1 047 1 001 0.636 Bo (rb/stb) 1.324 Free Gas 5,016.1 21.486 18 627 17 935 20 116 18 503 11.976 Bg (rb/mscf) 0.862 Water 5,026.9 11 466 10 138 10 724 11 480 11 889 6 962 *Bw (rb/stb) 1.040 TOTAL 11,515.6 34 041 29 691 29 701 32 642 31 393 19.574 Bmi (rb/mscf) 0.700 11.975 12 646 13 870 7,147.4 Gas 0 462 1.444 1 841 Rs (scf/stb) 620.8 Injected Fluids (MMRB) Water Gas TOTAL Net Injection Volumes (Injection - Production (MMRB) TOTAL 7,016.0 752.4 7.768.3 -3,747.3 11.901 1 855 13.757 -203 10 330 1 024 11.354 -183 10.854 1 315 12 169 -175 11.679 1.737 13.416 -192 12 304 1 217 13 521 -17.9 7 285 7 285 -123 Produced Fluids (MMRB) July August September October N_ Qvember December Cumulative Oil 0 836 1.004 0.929 1 065 1 134 1 159 1,4844 Free Gas 15 027 17 512 15 640 18.428 19.071 19 451 5,229.9 Water 8 685 10 853 9.649 11 960 13 466 14 391 5,1586 TOTAL 24 548 29 368 26.217 31.452 33 670 35 000 11,8729 Injected Fluids (MMRB) Water 7.941 10.791 9 882 11.975 12 646 13 870 7,147.4 Gas 0 462 1.444 1 841 1 987 2 496 2 186 769.9 TOTAL 8 403 12 235 11.723 13.962 15 142 16 056 7.9174 Net Injection Volumes (Injection - Production (MMRB) TOTAL -161 -171 -145 -175 -185 -189 -3.9555 Exhibit 3-C FS -2 Areal Average Reservoir Pressure 3900 3800 3700 Ag .y d 3600 N N 0 3500 ------ co co 3400 --- — Y! N O n a 'o 3300 Z m N Ir 3200 MIX 3000 Jan -87 Jan -91 Jan -95 Jan -99 Jan -03 Jan -07 Jan -11 Jan -15 Jan -19 Exhibit 3-D FS2 LECEMD L3.19 Gas Injector 04- GN A 04.20 Gas Injector Shut-in 27 L 0 04-25 L 5 - Miscible Injector .236 11-10A 1.04 04- Miscible Injector Shut-in 04 04 1 - 18.21 •11.33 04-27 , 11' • Oil Producer Flowin g 11-31A 11-00 04-17 p4- 11 L3 GUT- 1)0( 1 Oil Producer Shut-in 11-26 _ -19A 11-1 1 A i1 Water Injector 1135 _ 04-404-. 1 1-06A 11-0 04-10 � > Water Injector Shut-in 4A 11-37A• �04-01A > Abandoned 2A .4Q t6 04-29AL1 04-37 04- 09-4 Plugged -Back 11-38A 04-1304-404-14 04-11A - .d3 Ambiguous Status 11- 8 09 11-05A Od. _09• 1-18 ■ d 11-29 04-090 - 3.1A 09-08 _jl 04.15 04. 04-4 09-19- 09-52■ 11-020 09-d2A 08-05 35A 11-17A 04-Z 04 .OTA _ 09-27A 09-10 Q9.18 04-43 -21 0 04 -De 29A ■ 09.4 09-47 Oy} 7 11- 09-38 09-22 286 x-09-16 A 09-18A 09-17.. -48 03-09 sA s 50A 011L 03-2 09- 1A 09.12 -25A 09-20 09 6 03-10A 03-1 i 9 03-18A -�3A 01- 22 0 1A 3A Q3-2ds 09 25 03-22A 03 a ai 09-79 03-17 , , - 1 13 - 03 6-19 Q - 09-51A 03-i3213 _ 03.15C 73 24 7 01- 03-1 03-32B09.01A - 1A L • 20A 12-32 03'3 A 03-05 0 16 01 -07A ■ 03-05 03.346 '48 ■ ■ 16 i6_ A -03-04 , • • 17-14 17- 14 1 16.02 17-06 16- 03-11 ' 03-13 17- 21 16- -07 -18 , A N 17-08 16-16 16-11 16-03 17• 16-12A 25 17.10 16. 16-05A ■ i6• - 1 17-15A 1 w�•N v 17.04 17-01A 16-08A0 16-23A 1 16-10A 0 1 Mlles Exhibit 4A 07 x -04A 1i 14 14-15 14-24A 14-35 14-13 14 14-25 05A $4-02 1 EPWZ LEGEND Gas Injector Gas Injector Shut-in Miscible Injector Miscible Injector Shut-in • Oil Producer Flowing Oil Producer Shut-in Water Injector Water Injector Shut-in Abandoned Plugged -Back Ambiguous Status TI- 4.37 14- 13- 13-17 13 A 01-25 01-30 _ oi- • 4.36 -04B • r 1 .14 1 ■ 14.0 • 06 -SSA 01"1 � -10 01-11 13-37 06. 1 0rr1 05-1 13-19- • I2'l 1 -19' 1-07A 1 t2- -� 14-27 -06-17 1. 14 13-24A •12BL1 13-0 _12- 2-05AL1 12-21 _ -11a •26 12-2TA -01 12-02 14.1 • - t 13-01 13-22 13 12.2 14-17A 9 13-14 13-25 13-21A _• 12.16 12 !� I OA 13-31A 1 • 1 17• 12 • 14-21A 31 PR1310 13.05 12-23 12 12-25 14-0 •1 � 13- ■ 13- 1398 12-1 PR'f 7107 -13A 13-16 P S0 1712 14-44A 13.1 13.1 13 -11 12-07A 17-M 13.28 12-33 12-1 12-31 - •30 31014X71 - M35 13-09 p 15XX• 1 12-M 13-36 by 0 1 0 S Exhibit 4-B EPWZ Produced Fluids (MMRB) 12/31/2018 January February March April May June Oil Free Gas Water TOTAL Injected Fluids (MMRB) Water Gas TOTAL Net Injection Volumes (Injection - Production (MMRB) TOTAL Produced Fluids (MMRB) Oil Free Gas Water TOTAL Injected Fluids (MMRB) Water Gas TOTAL Net Injection Volumes (Injection - Production (MMRB) 8736 0 626 0 557 0.641 0.610 0 611 0 506 Fluid Properties Used 0 599 2,900.7 8 229 7 380 7.990 7.217 6 576 6 800 Bo (rb/stb) 1.321 2,222.5 6 988 6 020 7.106 6 797 7 083 5 737 Bg (rb/mscf) 0.872 5,996.8 158 140 15.7 146 143 130 Bw (rb/stb) 1.040 5 153 5 316 5 601 4 609 5 075 2,5297 Bmi (rb/msco 0.700 4535 5.3 5.2 53 Rs (scf/stb) 614.0 2,463.7 5 774 5 111 5 658 6.101 6 497 5 825 453.5 2,917.1 58 51 57 61 65 58 -3,079.7 -101 -88 -10.1 -85 -7.8 -72 July Au ust September October November December Cumulative 0.558 0 599 0 594 0 571 0.522 0.538 880.6 6.785 7 431 7 723 6 764 6.440 6.902 2,986.9 6 455 6 986 7 093 6 455 5 803 6.207 2,301 2 138 15.0 154 138 128 13.6 6,1687 5 318 5 153 5 316 5 601 4 609 5 075 2,5297 4535 5.3 5.2 53 56 46 5.1 2,9832 TOTAL -85 -99 -101 -82 -82 -8.6 -3,1856 3900 3800 -'- ^„ 3700 N _a 3600 N N 6 3500 W m 7 3400 N N m a c 3300 — Z m N 3200 -- 3100 3000 --f— Jan-87 Jan -91 Exhibit 4-C EPWZ Areal Average Reservoir Pressure Jan -95 Jan -99 Jan -03 Jan -07 Jan -11 Jan -15 Jan -19 Jan -23 Exhibit 4-D K_ X .4A I • 19 14-43 15 14-24A %4-35 14-13 14 14-25 45A 14-02 Lt PR02101 PRO 14 Q1.31 14 13 14-36 14--1 132 14 13-17 -048 1358 1-24A 01-25 01-30 01. a • • 1 7• 14-0 06.1 06-1aA 01-1 1-13 -10 01-11 • 06- dB �'1 1 13-19" • 1 -19- • 12A 32-23 -29 01 36 14-27 14 _ 1 06.129 .01 i -12A 3028 12-05AL1 1 12.37 1 B 12-0 12-02' 1.8 .26 A 12 12.27 i241 141 • 1 13-22 -18 14-17A 13.14 13-25 - 13-21A 12- 1 14 13-31 A ' 13 JA A 1 17 1 • 14-21A c, 13.1 PR '- 13-05 12 23 12- 12-25 13-29• 13- •13 13-98 PR191015A 34 14 13 L1 13-16 P .07A 14-44AA 12) 1 13 12.1 PR171 12-31 17-19A 13 12-33- 12-10A 31014XX - 13.35 13-09 201015xx 12-14A• Ll 12-34 SA 1336 12-36 LEGAND Gas Injector Gas Injector Shut-in Miscible Injector Miscible Injector Shut-in • Oil Producer Flowing Oil Producer Shut-in - Water Injector Water Injector Shut-in Abandoned Plugged -Back Ambiguous Status Daily RMI < 200 mscf/d r 200 - 2000 mscf/d > 2000 mscf/d N I 0 1 Moes by A U - Y -07A P -02A FP -01A Y -23B Exhibit 5-A �? -11 • 1 H-32 FI -10A H -22A H H-026 H -01A4 75 H -09A y Y -06A Y Y-39 A-44 7 -il A♦ 6-17 • • �A A -29A 1 24A 26 •A 1 A� W A .344 B-15 A- '4 P A -t0 A -21 EUEMU Gas Injector Gas Injector Shut-in Miscible Injector Miscible Injector Shut-in Oil Producer Flowing Oil Producer Shut-in Water Injector Water Injector Shut-in Abandoned Plugged -Back Ambiguous Status ,.S A- A-08 6-01 8-2 5-22A A! 01A B-136 • -27 A 0 A 27 — B- B• c B-31 A -18A A -31A - A- �B_ - A A-15 B-11AX( 7C-17 B-34 }AB -03A A. X X - A A -17A x-24 •A -38L1 A-21 '" A -30A -IB X • X26 x,61 X. " x-asLs x 2 A A-38 I X.29 X-1 A 3Ax 1)0(X -21A A-42 X-35 - 1 • 31 X_28 X. , x-nA X-23 p X -10A B1 1 X tiB • 4.3 N X-36 X j9B X -WA X-33 1 0 1 Miles �5A Y-�' Y -30Y Y30L1 Y -I1925 P-14V-�C ly-20AOL1 • Y -2Y-055 Y -11C -V_g1. P -15•Y4 A _ 29A Y Y-39 A-44 7 -il A♦ 6-17 • • �A A -29A 1 24A 26 •A 1 A� W A .344 B-15 A- '4 P A -t0 A -21 EUEMU Gas Injector Gas Injector Shut-in Miscible Injector Miscible Injector Shut-in Oil Producer Flowing Oil Producer Shut-in Water Injector Water Injector Shut-in Abandoned Plugged -Back Ambiguous Status ,.S A- A-08 6-01 8-2 5-22A A! 01A B-136 • -27 A 0 A 27 — B- B• c B-31 A -18A A -31A - A- �B_ - A A-15 B-11AX( 7C-17 B-34 }AB -03A A. X X - A A -17A x-24 •A -38L1 A-21 '" A -30A -IB X • X26 x,61 X. " x-asLs x 2 A A-38 I X.29 X-1 A 3Ax 1)0(X -21A A-42 X-35 - 1 • 31 X_28 X. , x-nA X-23 p X -10A B1 1 X tiB • 4.3 N X-36 X j9B X -WA X-33 1 0 1 Miles Exhibit 5-B Net Injection Volumes (Injection - Production (MMRB) TOTAL -1,735.1 -97 -8.4 -8.4 -76 -90 -91 Produced Fluids (MMRB) Oil Free Gas Water TOTAL Injected Fluids (MMRB) Water Gas TOTAL Net Injection Volumes (Injection - Production (MMRB) July August September October November December Cumulative 0.632 0 371 0 433 0 597 0.650 0.650 WPWZ-Exhibit 7.601 5195 5148 6.609 8.033 wPWZ 1,921.9 5.370 3 601 4 164 4 798 4.868 1,648.5 13.603 Produced Fluids (MMRB) 12/31/2018 January February March April Mav June Fluid Properties Used Oil 7385 0.645 0.579 0 605 0.570 0.628 0 611 Bo (rb/stb) 1.322 Free Gas 1,831.8 8.616 7.703 8 128 7.504 8.636 8 688 Bg (rb/mscf) 0.869 Water 1,5932 5 141 4 604 4 328 4.205 5.211 4.913 Bw (rb/stb) 1.040 TOTAL 4,1636 14 403 12.886 13 061 12 279 14 474 14 212 Bml (rb/msco 0.700 Rs (scf/stb) 616.2 Injected Fluids (MMRB) Water 1,982,5 3.979 3.797 3.994 3 913 4.149 3.934 Gas 446.0 0.741 0 703 0.655 0 731 1 305 1.139 TOTAL 2,428.5 4.720 4 499 4.648 4 644 5 454 5.074 Net Injection Volumes (Injection - Production (MMRB) TOTAL -1,735.1 -97 -8.4 -8.4 -76 -90 -91 Produced Fluids (MMRB) Oil Free Gas Water TOTAL Injected Fluids (MMRB) Water Gas TOTAL Net Injection Volumes (Injection - Production (MMRB) July August September October November December Cumulative 0.632 0 371 0 433 0 597 0.650 0.650 745.5 7.601 5195 5148 6.609 8.033 8.225 1,921.9 5.370 3 601 4 050 4 164 4 798 4.868 1,648.5 13.603 9.166 9 630 11.370 13.480 13 742 4,315.9 4201 3 632 4 048 4 407 4 613 4 797 2,031 9 0 840 0 432 0.683 0.612 0 615 0 365 4549 5 041 4 064 4 732 5.020 5 228 5 162 2,4868 TOTAL -8.6 -5.1 -49 -64 -83 -8.6 -1.8291 3900 3800 3700 y a e 3600 ca c1 c 3500 m m 49) m 3400 w N d c 3300 Z m N m � 3200 Exhibit 5-C WPWZ Average Reservoir Pressure 3100 3000 Jan -87 Jan -91 Jan -95 Jan -99 Jan -03 Jan -07 Jan -11 Jan -15 Jan -19 Jan -23 P�Y -07A P-02A Y -23B Exhibit 5-D 1T2 -11 • I H-32 H -IDA H -22A H_ H -D26 H-fltA• 7$ H -m - Y-1 7A Y -06A Y P-111- i P -05A Y -25A Y Y-30 -13 P -03A P 23— Y -30L1 P-129 P-22 Y. P-1 13L1 P-14 _ 1 I Y -14C P-191-1 • Y-27 • -18 Y-21 P-3 1. P�5 Y-11 C - P -i Y-24 Y 2 AL1 Y Y -_JA of39 X-23 10A X-1 1 X -19B -SDA N r ,4 X -3b x -cm -30A X-33 1 0 1 Miles WPWZLEGEND Gas Injector Gas Injector Shut-in ' Miscible injector Miscible Injector Shulan • Gb Producer Flox7rlg • Git Producer Shut-in Water injector D -01A -08A - Water ln*lor Shut -In 3A Abandoned Y- Plugged -Back A Aid Ambiguous Status Daily RMI =1 • A- & 17 � 200 mscVd A 24A i0 200 - �A4 A35 - 2000 msciia A- A-1 A -34A • B-15 * y 2000 mscfM A-39A A A-33 A 21 .f6A 07-26 _35 14 A A-06 A- B-01 8-2 B 22A Y -10B A 4 A -27A A -01A B-138 9-1 B ' -27 _ , B-31 '4 '0`A' A -18A A -31A-- A- 7A B-25 ,:B-0 - � 3A Y-35 A-15 B-11AXX X-17 5.37 X "A as 532A .5 X A -16A-: A. A -17A -05 X -24A14- 4 • A-38 A-21 A -30A -18 X-26 .32 • X-1 ` I X-351-1 - X - X-01 i 38 X -1 -21A A 38 A-426 X 29:.3 X-2 X -21A -14A 14-37 x- 01 X -11A X-23 10A X-1 1 X -19B -SDA N r ,4 X -3b x -cm -30A X-33 1 0 1 Miles Exhibit 6-A Gas Injector Gas Injector Shut-in Miscible Injector Miscible Injector 51)ut-m o Oil Producer Flowing 5-103 A R 1�' Oil Producer Shut-in S ■■5 u Water Injector _ t 3• 2L4 R 2 6 �' 5.43X1 ' Wafer Injector Shut -In S4DAS S 5- 1A F.37AL1 - S-1108 S25o - R AL1 '9-07 F-36 Abandoned S-120 5-226 - 8.38 1AL1'•5 09 R . R -10B - A T-01 W,• Plugged -Back 5.35. 5-11 .5-112 R.g:A R419A R-22ALl � R -06A t=.gg Ambiguous Status ~ s -30 1 R-21 R- 3$ R -22A t R -08 E S- 17C S-04. • F9 R-44 R-34 S • 118 123 1 M- R -26B R. • ■ 5;100A S-2 S- S. - SA. - .35A F 5-21; 30 R -11A R- _ A 8B M-31 i5 R 76 R-24 7 5-217 5.128 R-39AL1 p` • 5-216 -06 ' M- 32 R-13 5-07_ .186 lA R S• NHp}A • S 30 M-28 1 R-0 A W-202 S•29A Li 36 h1- M -33 -N-06 . S-29AL 1 -27 N -23A 9 -18A N-2 23A M -29A -26 N 7_ B N-13 N N N -01A 7A IN 25 N 9 N -20A - -02q N-27 GC -2E N-1 17A N-1 N-12 •N-09 M-17AL1 USA - 1 N-27 N-28 ■ G 1 N-24 N-226 ' -2c N by 0 1 0 1 Miil!giiiiiiiiia Miles Exhibit 6-13 NWFB-Exhibit NWFB Produced Fluids (MMRB) 12/31/2018 January February March Aril May June Fluid Properties Used Oil 772.6 0.421 0.374 0.391 0.329 0.397 0 367 Bo (rb/stb) 1.318 Free Gas 959.6 2.914 2.692 2.848 2.248 2.629 2 328 Bg (rb/mscf) 0.882 Water 1,099.2 2.428 2.249 2.634 2.256 2.653 2.272 Bw (rb/stb) 1.040 TOTAL 2,831.4 5.763 5.315 5.873 4.834 5.679 4.967 Bmi (rb/mscf) 0.700 TOTAL -1.5 -0.5 -1.8 -1.5 -2.4 -2.6 Rs (scf/stb) 6073 Injected Fluids (MMRB) -7033 Water 1,700.9 2.849 2.718 3.181 3.125 3.118 2.889 Gas 449.1 0.484 0.279 0.408 0.480 0.600 0.764 TOTAL 2149.9 3.333 2.997 3.589 3.604 3.719 3.653 Net Injection Volumes (Injection - Production (MMRB) TOTAL -681 4 -24 -2.3 -23 -1 2 -20 -1.3 Produced Fluids (MMRB) July August September October November December Cumulative Oil 0.375 0 128 0.314 0.372 0 384 0.389 776.8 Free Gas 2.282 0 652 1.791 2.067 2 292 2 255 986.6 Water 2 460 0.559 1.889 2000 2.744 2 803 1,126.1 TOTAL 5.117 1 339 3 994 4 438 5.420 5.447 2,889.5 Injected Fluids (MMRB) Water 3206 0.818 1.947 2.516 2.579 2.337 1,7321 Gas 0.439 0.019 0.198 0.452 0A34 0.489 4541 TOTAL 3.645 0.837 2.145 2.968 3.014 2.826 2,1863 Net Injection Volumes (Injection - Production (MMRB) TOTAL -1.5 -0.5 -1.8 -1.5 -2.4 -2.6 -7033 3900 3800 3700 Ag 4n CL F 3600 N 0 3500 m m m 3400 m h IL c 3300 Z m N m 3200 Exhibit 6-C NWFB Areal Average Reservoir Pressure 3100 3000 . Jan -87 Jan -91 Jan -95 Jan -99 Jan -03 Jan -07 Jan -11 Jan -15 Jan -19 Jan -23 Exhibit 6-D NWFBC.F"° Gas Injector Gas Injector Shut-in Miscible Injector Miscible Injector Shut-in ■ Oil Producer Flowing 510.s A R -19A Oil Producer Shut-in S_1 5-2 a $ Y ' 2A Water Injector $ . •S -44A s-2 1 S- SAX 1 R-20 F•31AL1 Water Injector Shut-in ' 3-25A 51106 A R- AL1 •07 F-36 Abandoned S-120 S -22B S38 1AL1 '•g 09 R_ F •37A T--01 �r_36 ° Plugged -Back 5 5.36. S-11 L1 5112 h1 R 1 R-O&A 9L1 R -31A• R-21 R 35 R -089R -08A Ambi uous Status g S -17C S-04 .S118 , i96• R.22A R-1 1 1` R-26fi F R- 4 R -3a Daily RMI 5- S 4w .2 S116 � A R- • F -35A < 200 mscf/d S 6.215 S M• -114-14R_ 200 - 2000 mscf/d M-31 16 R-39AL1 Rt76 7 > 2000 mscf/d S-217 5216 S1 OA • M• 32 39A• -24 R-13 S-07_ -186 1A R -034 . S-30 M-28 M- I R-0 A 33 W-202 5-29A 1 34 hy,3 N-06 S•29AL1 27 M-07 N -23A N-29 .IgA M-0 -26 ry. R-14 23A _ 26 N-13 •.14 -29A NN N-01 7A 25 N 9 N -20A- .02A N-10 N•27 GC -2E 17A N-16 N-12 H 0 • M-17AL1 0-04A (}_ L1 N-Ofl I N-28 ■ N -21A G N-24 N -22B 2r. • "• N by 1 0 1 Miles Exhibit 7-A EWE 22 Z-31 Z '0 27 Z-3 Z-29 HY RATE -01 117. _ W.2 W-25At_1 • �7$-2+4 Z-1130 WSW-� -196L� V-4 2 Z-1413. W-214 • 7SI. 24 J Gas Injector Gas Injector Shut -In Miscible Injector Miscible Injector Shut • Oil Producer Flowing Oil Producer Shut-in Water Injector Water Injector Shut-in Abandoned Plugged -Back Ambiguous Status -- - Z-1 Z -02A -� W A W-35 .- 38 --. Z -37W •400 .207 7-87 Z-708 .51 * ' W.2 W -03A 2-16 Z0 Z-05 s W-4 -04* W -01A • 28 Z-3 18 . Z, VY -1 L2 Z W i W-i78A W_ W- • Z -3d i 38A N Z. 18 w-11 J by ;10A 1 00 1 Miles Exhibit 7-13 Net Injection Volumes (Injection - Production (MMRB) TOTAL -3229 -1 0 -0.5 -04 -06 -1 0 -1.0 Produced Fluids (MMRB) July August September October November December Cumulative Oil 0.388 0.105 0 196 0.308 0.356 0.379 1334 Free Gas 0.819 0.202 EWE 0.541 0.681 0.849 268.5 Water 1.842 0.464 1077 1.375 Produced Fluids (MMRB) 12/31/2018 January February March April May June Fluid Properties Used 3.082 Oil 129.3 0 402 0 360 0 416 0.420 0 446 0.401 Bo (rb/stb) 1.344 Free Gas 259.2 1 043 0 884 0 953 0.961 1 033 0.897 Bg (rb/mscf) 0.800 Water 2352 1 753 1 486 1 570 1.565 1 861 1 771 Bw (rb/stb) 1.040 TOTAL 623.6 3 198 2 730 2 938 2 946 3.340 3 070 Bmi (rb/msco 0.700 Rs (scf/stb) 667.8 Injected Fluids (MMRB) Water 223.3 1.698 1598 1961 1949 2.003 1806 Gas 77.4 0 506 0 616 0 609 0 408 0.339 0262 TOTAL 300.7 2203 2 214 2 570 2 357 2 342 2.069 Net Injection Volumes (Injection - Production (MMRB) TOTAL -3229 -1 0 -0.5 -04 -06 -1 0 -1.0 Produced Fluids (MMRB) July August September October November December Cumulative Oil 0.388 0.105 0 196 0.308 0.356 0.379 1334 Free Gas 0.819 0.202 0.437 0.541 0.681 0.849 268.5 Water 1.842 0.464 1077 1.375 1.738 1.854 253.5 TOTAL 3.050 0.771 1 710 2.224 2.775 3.082 6554 Injected Fluids (MMRB) Water 1.680 0.509 1007 1.402 1.389 1.219 241.5 Gas 0 110 0 041 0 246 0.419 0.474 81.4 TOTAL 1 790 0 509 1.047 1.648 1.808 1.693 322.9 Net Injection Volumes (Injection - Production (MMRB) TOTAL -1 3 -03 -07 -06 -1.0 -1.4 -332.5 3900 3800 3700 O N a 3600 N N 0 3500 CO SO m 3400 w IL -63300 Z m m m 3200 3100 3000 Sep -02 Exhibit 7-C EWE Areal Average Reservoir Pressure May -05 Feb -08 Nov -10 Aug -13 Mav-16 Feb -19 Oct -21 Exhibit 7-D EWE LEGEND Gas Injector Gas Injector Shut-in ' Miscible Injector Miscible Injector Shut -Irl L 3AL ■ Oil Producer Flawing los V-04 L-213 031-1 Oil Producer Shut-in ■ V_12120 Water Injector V_ 5 Water Injector Shut-in Y-21 V-03 V 33 i - Abandoned V- L I V-1 1 Plugged -Sack Ambiguous Staw-; _ Daily RMl • 22 •S r 200 msefld Z- Z -31 '• 27 200 - 2000 mscf d, Z.3 2000 m9aUd Z-29 H RATE -01 W-1 117 - W- •25A Z. _ _ 6A GA W-59 •W-26 • Z-07$ _ Z•24 W- W 19 V -t Z. Z• 148 Z.11 W-29 . • W-214 23A • - Z-09 _24 21 T -05A - W-3 -1 W 1A�1 -21 -21A W- 12 % W D Z ■ Z 1 .1 02A W. A v4�3� YY W-35 W_ - 7A Z-108 Z -WE -37A• 51 •' • 1 4� .2 W-� X76 �Z-67 Z • W d .114• W -01A ■ -P-28 2'3 .10 ' Z •W 12 4y.�gA W08A -40 W- 5 • Z. • 34 2 38A N Z•18 W-11 by -.10A 1 0 1 Miles Exhibit B 2019 Wells Surveyed for Gas Movement OH -Open Hole Log CH - Cased Hole Log * wellbore crossed GOC at multiple depths Not present over logged Interval all fluid Not present over logged Interval 'allgas 2019 Drilling 9 Well LogAate OH/CH GOC {MD) G0C(71ID5S) 1 1-07B 28 -Jan -19 CH 12.260 8.854 2 07-25B i 10 -Feb -19 OH/CH 9,927/11,022 8,867/8,8T O- 3 L2 -07B 14 -Apr -19 OH 11,061 8493 4 F -34C 11 -Jun -19 CH 10,729 8,701 5 1.5-27 19 -Jun -19 OH 11,594 8,508 6 15-27B t 24 -Jun -19 CH 12,235/12,510/14,467 8,661/8,664/8,663 7 L3 -22A 27 -Jul -19 OH 9,672 8,546 8 11-11A 11 -Aug -19 CH 9,351 8,469 9 1-3-06 20 -Aug -19 OH 8,753 8,601 10 11-37A 29 -Aug -19 CH 8,712 8,536 11 01-26B 15 -Sep -19 CH 10,575 8,730 12 01-37 # 22 -Sep -19 OH/CH 10,347/12,974/13,656 8,726/8,707/8,703 13 1.2-0813 23 -Se -19 CH 11,636 8,576 14 03-30A 5 -Feb -19 OH Not present over lo edlnterval 15 09-0513 14 -Mar -19 CH Not present over logged interval OH -Open Hole Log CH - Cased Hole Log * wellbore crossed GOC at multiple depths Not present over logged Interval all fluid Not present over logged Interval 'allgas 2619 Surveillance N Well Log Date OH / CH GOC )MD) GOC (TVDSS) 1 F-38 17 -Apr -19 CH 10,521 8,994 2 B-21 19 -Apr -19 CH 9,580 8,732 3 H -26A 25 -Apr -19 CH 9,752 8,828 4 N-30 1 -May -19 CH 9,449 8,688 5 11-01A 4 -Aug -19 CH 11..199 8,535 6 03-36A 15 -Aug -19 CH 11.045 8,875 7 14-16B * 18 -Aug -19 CH 9,669/10,713 8,707/8,697 8 11-05A 20 -Aug -19 CH 9,719 8,525 9 04-14 27 -Aug -19 CH 8,920 8,557 10 D-35 31 -Aug -19 CH 9,492 8,952 11 18-05A 10 -Sep -19 CH 12,192 8,709 12 02-07B 12 -Sep -19 CH 10,471 8,964 13 X -16A 14 -Sep -19 CH 10,668 8,888 14 04-40 27 -Sep -19 CH 9.180 8,536 15 18-35 12 -Oct -19 CH 9,408 8,380 16 18-08B 14 -Ott -19 CH 10,138 8,649 _ 17 N -20A 29 -Oct -19 CH 9,678 8,681 18 R -12A 31 -Oct -19 CH 10,767 8,709 19 02-38A 27 -Nov -19 CH 9,933 8,740 20 02-41 1 -Dec -19 CH 10,171 8,964 21 18-17 19 -Dec -19 CH 10,956 8,710 22 03-29A I 10-Mav-191 CH I Not present over logged interval Exhibit 9 I Opaa[w: 8P -tin Alaska Inc 2 Address: PO BD:,9865 900E 9tlrwsr. .9%14-6619 3 uns w I..®e name: arudhce Bev Unit 4 R.Id end Pkadvaa Pod:6 few. Prldnue 0l Ped 176717 m ae0➢TVGm 8 Di u -my 7 cmas Grevsy: 09 SG -AN 09 8 007!74[71 end N -Ml -n 9 API N-ber tl%7cx700V,xxx1{ x WDASKS 10 Typa Sae Natrua4ena 15. AOGCC Z Pml Code 13 Pa.14�rae Bi4draN Tbp-B om 1vus 9 i Ise! Dale 15 Shut- In Time, Hours TS Press S., Type (sce in"cho/s kr taxes) 1 Bim T mp !8 Depen Tool NDSS Observed Pressure at Tap, Deplh - Nc ND55 (input) 7, P Gredienl, psUB u Presvlre ffi Delum (-I) 02,18-0 $13132¢727080100 O 840150 8588.8&34-sea7.8635.a6S5-88.73 &MMM lif2w"78 7-076 su+ its 87170 329[ &* 03242 137696 0320A 50029209800100 0 640150 61,-------- /�i89D, 6-112626,6744-B7S6,B7b5-8756,B7B22791,875"773,8876-0895,8865-8870,8744-8755,8792- BB02 BB45-0851,8802-8804-8735$739-8734-07358677-8887 8739-8740 8876-0877 B89MB95-BB04-BB11-8876-8890 12112/1019 140. SBHP 178. B 800 3282 B'� 0 2797 328,991 0474-0 500292218130700 O 7iow a67rB729 7167$014 122915. SBHP 17161 96% 3278 saw 038 3378. 04-06 OSJO 500202243400130 5141747•n 130000 0 D 610150 $47156 872007388742-07488075-BB➢48690.9674,Bag2•g701,8B.51.aa58,B61 i.6020-662020717-a806$B}2@$56•1975.L 0009 5003-a 8&0063--01471 271 713 11 /2014 449 3363 SBHP seB ?76 175.08 8E00 a.600 3155 3294 8.800 Saw 027 Oda 5708439 337918 00.10-0 50029200$70100 0 640100 6671$67986442861 wmalill 264. SBHP 180 $-009 7371 a800 0.3398 2.89897 99-3fl 5002921➢1➢0000 WI 640150 67413-tlTi 3,8847-966-2, 90i792l 13!8,8802-BtlYb,B%BV-8n'L,,9U19-BULB,tlB/L-1960,BUl9-9058, BUl tl-B019,89-6935,9064- B0859057 -9058-8847-8696_B830-8&449025-9057 1/212019 67,780 SBHP 15461 8,800 3315 8'800 04423 331513 09�0 50029221180000 WI 640150 8852-0883,8863-8877,88882889,8852-8903,8863-8865,8878-0BBB,BB54$863,BB85-8877,8877-BBBB,B::8-8903,:852- BB5488772:67 BB52-8877 BBB9A903 9202019 2615 SBHP 16624 5 70 3139 B'� 0x404 319353 11.07 500287776870000 497 6-0170 8881-0i65,8B20�035.87$j-B7'� y2wol8 W. 96HP 15222 8.235 3124 aADO 0.4368 357038 13-11 50029206040000 0 640150 8990-9049,8890-0909 8/21/2059 114249 SBHP 21028 9800 3313 8.8000.3323 3-3126 13-14 5002 08450000 O 640150 6'17 i2 yv:3,y�f 2-913x2, yc uo-9Dua,517b7-tly/C,tl891o,nyo,BYI/,tlY/L�lyv//,91392-91341,tlB�////-61ltlE,tlyBtl-911fIJ,BfILB- 9042.39 3 gu9B 9012-9029 ] 19 1.316 SBHP 215 94 0,500 3266 B'� 0 2931 255 81 13-3pC St141'/97078u0300 0 640150 aa"vc BB97-0BB98B0129018W1-9893 49871079 1490. SDHP 212.37 5.[00 1740 Saw D -as 1,71030 15.17 500287112BOOp0 0 640150 082613060798-5a358038�864I imeml0 711 SaHP 173. 5747 3928 6-000 1 01383 3=..85 16-14C 500292057130300 a, 6402'0 fi905A965,$88029a6 4712019 SBHP 18298 P801 3225 8x00 0.4320 372385 16-30 50029222810000 0 640150 o,,e�f69023.90Q1.9098-B490L%7-9C8i•9086.5996.9008-9000.9082-9082.17088.9080.17066.L98F 9002,8985$9969068-9061.1997-9002 5/12019 21,726 SBHP 1137 8800 3296 B'� 03203 3.29804 17-05 500292175080000 0 "0150 8034 -9040,8907$917,9034 -9047,8955 -8957,8971$978,8917$925,8949 -8957,8985-8997,8803-8820,8980-8997,8949- 8955-8963-8971-8938-8949-8980$9:5 8900-8907-8B20-8821.9009-9022-9040-9047-SB03-Sfl21-8957.8963 7/2a=19 674 SBHP 2047.9 8,800 3572 SAW 04318 3 572 36 18.118 500"9211810200 0 840150 98838891X76-8876$642.06846678.06(416071.8677-8695$695-86{9664 i-8617$643.8687$6$1-11693.97038643-0843 11 12019 589. SBHP 5600 3673 a870 0.22 371 S T0�14C 50029210140300 0 $461--0 675427 .9749.57513859.57598]49$7495]53-07540371-03 67558757 72911019 1$64. SBHP 1]C 44 95IXw '5254 8800 03197 334963 A•30A 500297737201 DO O "0150 6936-x9418937$8368867-6832 10%4!20;9 70275 SBHP 216 SAW 3335 a0m 044 3194.86 E40M SOMMA190100 0 64019297$ 1 5411079 Sa+P W5 9D00 ]606 8a00 4415 35975: E3a �2LSnMW 0 640150 _ 6775-05068791-07868763.87730731-0766 19 321. 9&1P 103.41 6844 $On 88130 Dsma 304181 1�'i4C 500292198OD300 O 540150 9751$75887$2.8 671a11019 58HP 168.5 9-7130 2510 $.500 04321 256108 F- 5002020930nD 0 6401W 074}874 6735.5794x740.5743 /2/1191019 SBHP 191 u-778 1125 8800 0.08i9 3x996 S}07A 5=292OWN1130 0 "0170 8985-89579018.901590099802-9015.9017 V171�14 1.600 WO 905 779 X70 atm Ci -14C D $x01$0 9054.9136151344.906 17000.0030 7792010 7 $30, SBHP 768 a.254 3105 8870 a" 7,Jw04 G -32A 5002921 6360100 0 640150 5040-917^.,0, 9171 o-y"v1'p,9u�30004,y�14-y cu 0,5474-5407,917„3-904D,9uu""o-9DTT,yum-yW" - 9DG4-9Di'u,9DT7- 9018,9029 -9026,9013 -9012,90059008,8437 -8465,9014-9027,9014-9024,9036-9038,9014-9021.901 B-9015,9018-9019,9023- B024 992-9998 033-9034 03590409003-9002.9000-8998 9034-9036 12/132019 1 387 SBHP 16522 0 475 2728 B,Soo 02667 2 214 9 J-152 5oC2B7Je610200 O $0150 9002. -9097- 9023.9016 9.71772310 879. SBHP 187.45 8900 3105 Sam 077 1104.71 x,27-0 S0e292i6a601W O $+0191 059/•0594 [[[4.6[57 5,52019 25. 55HP 179 5.500 ?546 8800 0.9009 f-7383 J•28A SODMI721131130 0 640150 804 aa852B82.8620•a011-9681.8675 4/2111079 1 8BHA 1160" 6735 2711 sam 0.3185 73711 K -WD 10390400 O 64mm 9172$2049174- 1 1/517019 111. M. 179 9151 331D Sam 01 3.375 K27F 5002921067 0 "0150 8751-07538753-0730A727A 771872{1.87x1 -5705.575D 1136/X178 040 59HP 780 5.773 3236 8.800 01 3287 K -0a9 50D2B214000200 0 640150 9041.90469045.9040 14 -5 5BI1P t73 8-261 3258 80W D44 3x9610 L2 -0B6• ?7810x00 0 6401513 86742671895426]55001.98946880-5690 iwi S*015 SBHP 162-19 5400 7219 a500 0.4713 4"fi 70 M-14 50029205120000 WI 640150 8932-8953,8832$044,8702-1778,9002-9030,89172989,8702$739,8789-.820,8.30-B832,B92B-8932,8928-8953,8832- 8847 8844-8847 8905-8921 BB74-0895 BB20-:824 8953-8987 8739-8779-8779-8782 7/82019 52439. SBHP 174 8-600 3425 8,800 03981 3.50443 M -20A 501220MV0100 %M UM50 87662738.873"-87$2.8761$744-5982.6999-8720$723-6723-0730.571 717 2454019 548. OTHER 2 357 850 6800 0032 3.637 M•7311 SaImmuivulW 0 $40'147 8700-0569$690-0695:736.5725 a7-0aA7d3 994019 305 SBHP 22097 8600 1717 9887 042 330146 1.28 50029215/00000 m 6401[2 8914-0924-877427$3-8724.6797-57895559-5929-8999-6724.6859672R•57748BB7-0979 91401079 M0. OTI �A 1,413 140 8x00 0. 149 3.483 N -01A 790100 WI $40150 8837.964080.72-06468537-08460566-064 895221167584026466612x857 wsml9 720. OTHER 0800 8800 0.1707 3� N477A 50/320201 7130 114 6401' 8956.0500 8970291;! 872➢-fl93B 8712$128.894]-8953 00&/1019 '7211. OTHER 688 12 a DA07 3.3a1 N -?3 50029205560000 0 640150 - tlY-9DD%,97352/93$71$-57$1,$738.5745,�19-tltl�ti3,IfaD6-aB9L,11tf,1-1!692,6%411-a%b,,aBti,-Ify111,tlI1B'I- 6905,8806-8B31,B763-8773,8806-8854,8604-8630,8806-81376,8806-BB60,B860-8876,B763-8797,8722-8736,8773-8797,8854- 8860 8842-8854 .8773-8775 9/142019 2-371 SBHP 22019 8.700 3237 8'em 043 3,27925 N-19 50029209220000 0 640150 tltlB1-0BUB,tltlIU-tltl1 B,tl 2U -8/34,8/4/-e lS5,66078629,B62B-8871,8717-8720,1828-8877,87552816,88752177,tl720- 6723,8734 -8738,8738 -8747,8755 -8810,8004 -8810,0755 -8758,8917-0982,8755-8804,8717-8734,8715-8717,8723-8734,0758- 8804 9/102019 76B OTHER 8020 2130 8.800 010306 3.262 N-25 Sougr4olcow 0 643150 am-117""I"i 5977641735-87;5.974$-5754.6714-8758.05131-8597.9598 9719/21018 7.035 SBM+ 22030 100 W26 41M 043 .1 N.28 $0028224ajDOW 0 540150 a 55.87 58752-87268890-55946894-08068595-05995686-0772 2113+7015 016 OTHER 7867 7010 5800 0109 3050 111125 5GD2M5ZtD00G I 6-0150 I0556-0695,6001.8807- fl738270.15 3.8779 0052019 720 OTHER 836 B P G 3.396 Nds 52113000 WI 110150 $77421838 !981119 729 13TkER 694 8 5 DW7 3.375 PSI -01 50079Z3ip40000 9A 150150 65134.67828426.5785-878x-64070284-83136357-037-0 0356$I06 19 257 5&w 72-i4 0400 1404 mom A4 71 9 51 PSF45 SOD'1923174D000 m 6401W 8347-038785240!-0967-0357.8316 8r?611019 88. SBHP 70 BBDO 3427 H.fiW 045 360701 PSr-0B 5002923 m $40150 9915.6437. 045442.646'•-0.736.8296533"349849.6-M13a369.5384 5!7711019 749 Sump 7267 250 3371 Aam 8.44 3.811.5 P61-07 50024231770000 w 940150 8503.9530 W1 59 16 S&P 7301 8.500 3802 WO 04409 373416 PBI -M I14DOM WI 540150 8422.8.5.78,0384•&784-0279.67fl7 571091018 208 SBHP 7157 0300 3403 0.000 .4342 3,52040 P8129 50620i30850D00 991 940150 &177.948417283.53959496 -642.463131.0{06528&62936494{6426360-0379 648/1/319 4 Saw 7D 5400 3591 8 D.443 3770 Psr-113 5431329231700000 m 643150 8358A387a2B72344 741.0497-6413-845] 9+1012019 710 "HP ea15 9400 Mfg 6.000 045 3599.10 -02A 50072XOSS40L00 01 640150 a7W27t3-8888.670157a326aa $7/372019 a 150 6894 7571 Dom D5015 7 U R -OSA 50029203800100 W "0150 8yl9byL1,5y,C �5,fl!lL4aYLL,BB%UdtlOp, 11944-11996,tltl7fy4-tltl�BL,tltlYL-tltltltl,tltlLB�ltlLl,tlYU1-tlB�UJ, 6ylU-tlyUO,tltfJJ- 8848.8927 -MN 9/82019 552 OTHER 855 48 8,800 00149 3,422 R -F 10700 0 601$0 8775$780900490019076.9027-8765.8770.800}•9W5877027725820.98R4 1001146$9 1.175 SBHP 210 aa09 3287 6800 0.43 328203 1 500297099]0000 0 540150 87236742,8723 -8759,8848 -8985,9898 -8910,8849 -0911,1846-8848,8742-0759,9723-8726,8753-8759,8930-9967,8720- 8]23 6]59-0762 8746-5763.8725-0742 BB4&8899-EBBS-8899 8747-2746 1023201➢ 250 SBHP 205 29 61700 2425 8,800 0 4170 2 466 53 R -22A 50 02 921 0 0 5 0100 m 547150 a676•asm 11472079 11790 5&7P T87 321 B.BDD 21W 6,000 01488 2.755]7 W-72 50079218640000 O 540150 BB94-BB99,902&9061,9012-9012,89013-8925,89582981,89322940,8992-9012.8947-8952,8952-8981,8925-8927,8930- 8940 8902-8927 BB77-0885 8902-8908 8864-0873 0952-8956 8930-8932 4282019 11 352 SBHP 255 B 336 3531 B,B00 04 27171 %-29 SOC2=4040000 m 6431$47 69872270-6985.9007 0015+9000 29742688 a9$7.9p07 9970298/7 1111711019 2-904 OTHER Sam 0 385 3 550 2.11A SOD7972053D 500 0 Palm 8872.8990-9013• 88112910 908&9045 8925-6934 x942-0954 a9�90-9004 58x6-0905 11M%2 1298 55HP 716 9 800 3673 a8m LA- 220 3 673 96 Z -2a 50029218790000 ten 80150 a780- 5G86d72458452859.97452769206490078951-uB66887'2DB68019•50121 a90129¢5590B-2931 9792019 64D OTHER 32 613 6 -em O.W7 9044 2.35 S0D7923WW00W 0 6[0150 9D154M 52701-9019-90219009-89929008-90156982-9012 111050 107974 SsmP 752 D5 am 81393 8800 N. 0./64 407723 2-57 S 19296450000 m 800150 8002.69638984-6928 9191018 a4D OT.7ER d9 20 0007 9.503 Exhibit 9 a Well Nama 9API WMu 10.1ypa as f1AOGC-, i2 Zone 13fylp veersa Top - BcdomTVDSS 14R-lTest 15. 1TeH ie.Depm NDamm 21 esaure 22. aw lJuaRa �%]C Inerucdom x 1h3 DASHES pay Code Dee Shu[- In Sury Type (see Temp Tool NDSS Observed Pressure NDSS (inpu0 Grddiard, p.A Pressure a Datum Time, Hours idorrm f. - fa codes) eTad Deplh (®I) Prh Rlvpr Pl•Z3A SOOi9-,(8795D1 O 610162 E238 -e254 8033-9033 8035-9025, 9036-9034, 90375034 yt912019 9aa SBHP 176 8 1eD 7867 a 100 0.93 1 e62 OR7,L4 5W282079501 6s0f e711221411",9033 -0W3. 90�6.9V269036:9034-8137-9134 1'124C,t1f9 19468 $9RP i74 a100 3785 aster 039 3.765 23 Aatele ty r. rw1+l .eemlda a.amel�ee ae1w rwR .4r4eaa,"mv dery Avusaw Gas C� C- -%W 60-s rocs a beton hole pr®aure ®kulated from surface des; unless dhermse doled the vale pramed Ind'cAee pressure 9radieM a—se the Peds Bal l:: depth of bxd, in the case of "Odd' (BHPcakuWed from surface dale), Ne dejAh sated is the top of fluid leve abMired by the lad ISM 19:'Odwf iMPI=laled from surface data) the value prmded a the well head pressure TM Me eo4ww.sa wee alWdR Cwr wage seeewa �Pdmww xw J -24A 13-300, FJB, 06-1BA R-21, F -34C, Rd1AJ-2BA, R -22A, G32A, R-02, EJB, Z-35 P hereby certify that the Rveong is bue and cenect to the beat of my knowledge Tek I.esd Ge --artist Dee 10 -Mar -2020 84p+aXa TNe e4d �ei Printed IN— Dee 10 -Mar -2020 William L. Bredar Jr. Exhibit 10-A GCWI Surveillance and Extent 2019 680000 6114000 688000 692000 696000 700000 704000 70Lfih0 772000 716000 720000 A A* t h 2019 Water Breakthro�h i$ GCW positive login 2019 — -- 'ti f • � � � GCW negative login 2019 f�• � - � � _ �.__ - i � pre -2019 Water Breakthrough Water logged pre 2019 i GCW Extent 2005 GCW Extent 2008 j S in m I ■A e a $ , GCW Extent 2011 i I a / \ . GCW 2014 * CX Extent 2017 $f, • at ' GCW Extent 2018 GCW Extent 2019 g __� r ��� * ~ • Previous year polygons updated \ '` 1 l slightly to reflect new data. minimal observed change in GCWI aerial extentfrom 2017- ] Cmd bad f 2019. GCW is slowlyfilling zones 1 and ` 1`1 l f , vertically and moreZlA wells are breaking water. See XSA-A'. �- . �~ . •. ! �� - �� l �, 8000 horizon (below BSAD) ®.vanon awn lmUsl 0 2000 4000 6000 1000MUS 690000 684000 608000 692000 698000 Y 700000 704000 706000M 716000 728000 1,49381 rare Exhibit 10-B GCWI 2019 Extent: Southwest— Northeast Cross -Section A Southwest r t ',rrna�nnrwwn coar.ai� a : �- wtsn.t�5.etwa �{ cps lnaR ae ]A and 'ell In IA Ex M.WMW Jnteltllad e - ai/YR OGOC -8,575' Methodology: GCWI Zonal E. - in le"ret,tio, rteninterpretation made by Zone for Z1A, ZIB, ZZA, ZZB, ZZC, Z3, Z4 SUing and historical 1 rvelllance logs If eny water seen via logs pr production zo glvena positive GC W I Interp retatlon, Polygons drawn by zone for GCW Northeast A' cul, GCWI Water First Year MM Observed x.� tem Waterflood Water Gas Oil Shale/Low N:G Sag River SS 1:25 Vertical Exaggeration Exhibit 10-C GCWI 2019 Extent: North— South Cross -Section B Northwest Southeast B' L is L&M f -ss7s Methodology: GCWI Zonal Extent 4 interpretation made by Zonefor ZlA, Z113, 1 Z2A, Z213, Z2C, Zi, Z4 using wment and r historical surveillance logs if any water NoT'' WV61111ood mJ.[t/on seen via logs orproduction, zone given h rwt tha r.—of thls wtaq ------ ___positive _ positiveGCWI interpretation. Polygons mution. Wabrflood drawn by zone for GCW extent waq'+hawn hereb 1.23 Vertical Interpretation mapped by polygon/zonepn�Monhl for Illustratlw into FFM grid, shown here. EKaggeratfon 2019 AW 2015 GCWI Water First Year ao+v Observed X700 w: Waterflood Water Gas Oil Shale/Low N:G Sag River SS Exhibit 11-A to 2019 Annual Reservoir Surveillance Report Prudhoe Oil Pool, Put River Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PROPERTIES REPORT 1 Operator: BP Exploration Alaska Inc 2 Address: 900 E Benson Blvd. Anchors e, AK 99519-6612 3 Field and 4 Pool 5 Reference S. i Porosity e Pool Code: Name Datum (ft G. slur? M Permeability TVDSS) (`F) (md) 9 Swi(%) 10 Oil 11 Oil 12 Original 13 Bubble ib Current 15 Oil i6 Gas 17. Gross Viscosity (8 Viscosity @ Pressure Point or Dew Reservoir Gravity Specific Pay (ft) Original Saturation (psi) PointPressure ('API) Gravity (Air Pressure Pressure Pressure (psi) = 1 0) (cp) (cp) (psi) i8 Net Pay 19 Original (ft) Formation Volume Factor (RBISTB) 20 Bubble Point Formation Volume Factor (RB/STB) 21 Gas 22 Original Compresstbii GOR ity Factor (Z) (SCFISTB) 23 Current GOR (SCF/STB) 640150 Prudhoe Oil 8800 200 22 265 30 081 081 4335 4335 3369 28 077 600 475 1.4 14 0.854 730 42 601 640182 Put River Oil 8100 182 19 173 146 1.84 NA 4163 2815 38135 269 NA 30 20 1 293 NA NA $48 2,888 I hereby certify that the Foregoing is true and correct to the best of my knowledge signature Gerda Stechauner anted Name Gerda Slechauner Title Reservoir Engineer Date 2I21I2020 Exhibit 12 Put River Sandstone Distribution rexnmrtwH..a _ �. WGlGR055 PUT RIVER 55 WGf ■ & " CI=lO N te .v N -0 n 1 16- Ab w. D s -V, OS42 2-14 D507 22 Sou ern D[�S-D1 .... 1-140 { ► _ ... ©S06 5 Note: Current producers at DS -02 are 02-23A and 02-27A. 15-41 B is a commingled Put and Ivishak producer, starting in August 2019.
