The URL can be used to link to this page

Home My WebLink About2001 Prudhoe Oil Pool April 1, 2002 Commissioners Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL - 2001 BP Exploration (Alaska) Inc., as the Operator of the Prudhoe Bay Unit, submit herewith a consolidated Surveillance Report for the Prudhoe Bay Waterflood Project, Miscible Gas Project, and Field Gravity Drainage Area in accordance with the requirements of Conservation Order 341C (originally CO 279). This report covers the time period January 1 through December 31, 2001. This is the tenth consolidated Gravity Drainage Area and Water/Miscible Flood report prepared under Conservation Order 279. As requested, this report contains analyses of surveillance data for 2001. As per Administrative Approval 341C.01, dated June 22, 1999, data from pressure surveys run during 1999 are now included as part of the annual report to satisfy the requirements of 20 AAC 25.115. This data can be found in Section 8. Also included in this year’s report is a table of wells shut-in for the entire 2001 calendar year. This table can be found in Section 9. 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 Lori Mushovic at 564-5329. Sincerely, Francis Sommer PBU Fieldwide Manager BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Telephone (907) 561-5111 April 1, 2002 This letter is to confirm that the office of the Alaska Oil and Gas Conservation Commission, has received a copy of the ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL - 2001 Received by: ___________________________________________ ______________ Alaska Oil & Gas Conservation Commission Employee Date ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL JANUARY THROUGH DECEMBER 2001 2001 ANNUAL RESERVOIR SURVEILLANC E REPORT PRUDHOE BAY UNIT Page 2 TABLE OF CONTENTS 1. INTRODUCTION………………………………………………………5 2. OVERVIEW…………………………………………………………….5 3. PRESSURE UPDATE………………………………………………...6 3.1 Pressure Monitoring ..................................................................6 3.2 Pressure Plan............................................................................8 4. PROJECT SUMMARIES….…………………………………………..8 4.1 Flow Station Two Water / MI Flood Project ............................8 4.2 Eastern Peripheral Wedge Zone Water / MI Flood Project...9 4.3 Western Peripheral W edge Zone Water / MI Flood Project 10 4.4 Northwest Fault Block Water / MI Flood Project...................11 4.5 Eileen West End Waterflood Project ....................................11 5. GAS MOVEMENT SURVEILLANCE………………………………12 5.1 Gas Movement Summary .......................................................12 5.2 GOR Mechanisms ..................................................................12 6. EXHIBITS……………………………………………………………..14 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 3 LIST OF EXHIBITS 1-A. Prudhoe Bay Unit Field Area Schematic 1-B. Overview Statistical Summary 1-C. PBU Pressure Map 1-D. Areally Weighted Pressure Summary and Trends 1-E. Average Monthly CGF MI Rates and Compositions 2-A. FS2 Water / MI Flood Base Map 2-B. FS2 Summary of Pertinent Data 2-C. FS2 Reservoir Balance 2-D. FS2 Areal Average Reservoir Pressure 2-E. FS2 Daily Average RMI 3-A. EPWZ Water / MI Flood Base Map 3-B. EPWZ Summary of Pertinent Data 3-C. EPWZ Reservoir Balance 3-D. EPWZ Areal Average Reservoir Pressure 3-E. EPWZ Daily Average RMI 4-A. WPWZ Water / MI Flood Base Map 4-B. WPWZ Summary of Pertinent Data 4-C. WPWZ Reservoir Balance 4-D. WPWZ Areal Average Reservoir Pressure 4-E. WPWZ Daily Average RMI 5-A. NWFB Water / MI Flood Base Map 5-B. NWFB Summary of Pertinent Data 5-C. NWFB Reservoir Balance 5-D. NWFB Areal Average Reservoir Pressure 5-E. NWFB Daily Average RMI 6-A. EWE Waterflood Base Map 6-B. EWE Summary of Pertinent Data 6-C. EWE Reservoir Balance 7-A. Gross Gas Influx Map (2000) 7-B. Wells Surveyed for Gas Movement 7-C. Gas Production Mechanisms 8. Reservoir Pressure Report 9. SI Well List 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 4 1. INTRODUCTION As required by Conservation Order 341C, approved June 12, 1997, this report provides a consolidated waterflood and gas oil contact report summary of the surveillance activities for the Waterflood Project, Miscible Gas Project, and the Gravity Drainage Area within the Prudhoe Oil Pool. The time period covered is January through December 2001. In keeping with the requirements of the Conservation Order 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 • Voidage balance by month of produced and injected fluids • Data on Minimum Miscibility Pressure (MMP) of injected miscible gas • Summary of Returned Miscible Injectant (RMI) volumes • Results of gas movement and gas-oil contact surveillance efforts. • Results of pressure monitoring efforts • Table of wells shut-in during 2001 calendar year Separate sections are provided for the five major flood areas: Flow Station 2 (FS-2), Eastern Peripheral Wedge Zone (EPWZ), Western Peripheral Wedge Zone (WPWZ), North West Fault Block (NWFB) and Eileen West End (EWE). Information on the Gravity Drainage region is included also. Consistent with last year’s report, data from the Eastern Operating Area (EOA) and Western Operating Area (WOA) have been combined. Waterflood, miscible gas flood, and tracer survey surveillance efforts, as applicable, are described in each section. Also, a separate section has been provided with detailed information on gas-oil contact surveillance. 2. OVERVIEW Exhibit 1-A identifies the five flood areas and gravity drainage areas in the Prudhoe Oil Pool as follows: FS-2, EPWZ, WPWZ, NWFB, EWE, WOA GD and EOA GD. The Waterflood Project encompasses all five flood areas. The Prudhoe Bay Miscible Gas Project (PBMGP) is currently active in only portions of the waterflood areas. The Eileen West End waterflood pilot concluded in March 1999, after successfully establishing EWE injection potential. Waterflood startup began on September 29, 2002 and thus EWE information has been included in this report. Exhibit 1-B provides well, production, and injection statistics for the major project areas included in this report. As in last years’ report, wells do not share project boundaries, but belong to a single project area. The well counts therefore reflect the total number of wells actually contributing to production and injection. Similar to last year, only wells that actually produced or injected during the year were included. 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 5 During the report period of January through December 2001, field production averaged 457 MBOD, 7556 MMSCFD (GOR 16,542 SCF/STB), and 1,089 MBWD (watercut 70%). Waterflood project injection during this period averaged 1011 MBWD with 437 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2000 was 7,963 MMSTB, while cumulative MI injection was 2,256 BCF. Cumulative production since waterflood startup was 2,418 MMSTB oil, 6,166 BCF gas, and 4,691 MMSTB water. As of December 31, 2001, cumulative production exceeded injection by 2,406 MMRB compared to 2,184 MMRB at the end of 2000. Similar to last year, production and injection values have been calculated based upon the waterflood start-up dates for the project areas rather than of each injection pattern. The values also reflect the differences in the project boundaries. Exhibit 1-C provides analysis of pressure static, buildup, and falloff data extrapolated to July 1, 2001 at a datum of 8,800 ft, subsea for the Full Field Dominant Zone. As in the past, abnormal pressures, such as pressures taken in fault compartments, some injectors and in the Sag Formation, have been removed. The project areas’ pressures are continuing to decline. As of 7/1/01, average pressure in the PBU reservoir was 3,260 psia by volumetric weighting and 3,280 psia by areal weighting. Average areal pressure decline was 30 psi/yr, based on pressures at the start of the report period (1/01), and mid year (7/01). The areally averaged pressures within the 50’ Light Oil Column (LOC) fell 15 psi from January 1 to July 1, 2001. In general, pressure decline in the waterflood areas parallels the Gravity Drainage Area’s pressure decline trend. Confirmed MI breakthrough has occurred in 180 wells across the waterflood. For this analysis, breakthrough is defined as an average RMI production rate greater than 200 MCFD in the report year. Because of this method, wells included in the breakthrough category one year may be excluded the next. Breakthrough is determined by a combination of well test analysis and lab testing of oil and gas samples. Reported RMI rates are yearly averages. Exhibit 1-E shows the 2001 average monthly CGF MI rates and compositions for the field. 3. PRESSURE UPDATE 3.1 Pressure Monitoring Exhibit 1-C provides analysis of pressure static, buildup, and falloff data extrapolated to July 1, 2001 at a datum of 8,800 ft, subsea for the Full Field Dominant Zone. For this report and 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 do not appear to be in communication with the rest of the reservoir have been excluded. Although Zone 1 and Zone 4B are in poor communication with the rest of the reservoir and therefore have low pressures, these pressures are included in the map and calculations. Due to the move to single operator, the methodology for calculating the pressure map has undergone revision. Procedures from EOA and WOA have been merged and result in some slight fluctuation in regional pressures from past reports. These fluctuations should not affect overall trends. Unless otherwise noted, all pressure calculations are areally weighted, bound by the main field 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 6 original 50' LOC contour, and are referenced to a pressure datum of 8800' SS. As of 7/1/01, average pressure in the PBU reservoir was 3260 psia by volumetric weighting and 3380 psia by areal weighting. Average areal pressure decline was 30 psi/yr, based on pressures at the start of the report period (1/01) and mid year (7/01). 3.1.1 Northwest Fault Block (3205 psia) Average pressure decline for this area was 38 psi/yr, based on pressures at the start of the report period, and mid year 2001. The pressure decline is less than last year. Recently, injection has been cut back from the main reservoir, as the focus is to improve injection conformance in Zone 4. As injection increases in this zone, the pressure is increasing. 3.1.2 Western Peripheral Wedge Zone (3309 psia) Average pressure decline for this area was 32 psi/yr, based on pressures at the start of the report period, and mid year 2001. The pressure decline is slightly less than last year. It is believed to be related to improved injector conformance due to better injection management. 3.1.3 Eastern Peripheral Wedge Zone (3310 psia) Average pressure decline for this area was 30 psi/yr, based on pressures at the start of the report period, and mid year 2001. The EPWZ receives pressure support from water/WAG injection. Faulting influences some isolated areas and the eastern patterns show lower pressure due to out of zone injection. Remedial action includes production to injection well conversions and fixing broken injectors to limit out of zone injection. Recent Injector work has contributed to the leveling of pressure in this area. 3.1.4 Flow Station Two (3360 psia) Average pressure decline for this area was 12 psi/yr, based on pressures at the start of the report period, and mid year 2001. Due to the presence of areally extensive, sealing shales in the FS2 area, pressure tends to be transmitted predominately in the horizontal plane, within hydraulic flow units. This hydraulic unit behavior has led to the development of localized pressure sinks in the lower Romeo sands of Drill Sites 4 and 9 and in the Zulu sands of the Drill Site 3 area. These are especially pronounced on the eastern border where the LCU truncates the formation. To the south, it is now understood that the high pressures seen are a result of complex, large- scale sealing faults. Typically pressures in small-scale isolated compartments are removed when mapping, however, this large-scale phenomenon comprises a large portion of FS-2, and therefore these pressures have been included. 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 7 3.1.5 Gravity Drainage (3254 psia) Average pressure decline for the Gravity Drainage area is 30 psi/yr, based on pressures at the start of the report period, and mid year 2001. This is roughly the same as last year. For most of the EOA GD area, pressure is supported by the gas injection in the gas cap. The pressure decline in WOA GD is less than last year. Several new pressures were taken in the C, F, and G pad area, which helped define the areas of low-pressure as smaller in area than originally mapped. 3.1.6 Eileen West End (3696 psia) Average pressure decline for this area was 6 psi/yr, based on pressures at the start of the report period, and mid year 2001. 3.2 Pressure Plan Per C. O. 341C, Rule 6b, a pressure plan containing the number of proposed surveys for the next calendar year is required to be filed with this report. Prudhoe Bay reservoir depletion strategies are defined, and the goal of the pressure program is to optimize areal coverage and provide sufficient data for well safety. The proposed plan for 2002 calls for collection of 120 pressure surveys fieldwide. Per administrative approval 341C.01, dated June 22, 1999, a summary of pressure surveys run during 2001 is presented in Exhibit 8. 4. PROJECT SUMMARIES 4.1 Flow Station Two Water / MI Flood Project The Flow Station Two area, which comprises the eastern third of the Eastern Operating Area, is shown in Exhibit 2-A. The locations of production and injection wells are shown with the EOR injection patterns identified. It also identifies the Initial PBMGP Area, along with the PBMGP expansions. There were 118 producing wells and 60 injection wells that contributed to production/injection during 2001 within the FS-2 flood area. Production/injection data was calculated with the polygon boundaries consistent with last year’s report. The FS-2 waterflood area oil production averaged 43 MBOD for 2001 compared to 54 MBOD in 2000. This represents an oil production decline of 19% in 2001. Cumulative production since waterflood start-up through the end of 2001 is 928 MMSTB of oil, 2,757 BCF of gas, and 2,341 MMSTB of water. Waterflood injection rates averaged 560 MBWD and 125 MMSCFD (MI) in 2001. Since December of 2000, the waterflood balance has increased from a cumulative under injection of 785 MMRB to 834 MMRB under injected. During the report period, production exceeded injection by 50 MMRB. Under-injection results from the inability of tighter intervals to compete for injection (i.e. Romeo/Victor). Waterflood strategy is to replace voidage on a zonal basis while 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 8 limiting injection rates in wells with multiple zones to avoid over injection in primary waterflood zones. Because the reservoir balance (Exhibit 2-C) doesn't identify support from the gas-cap or aquifer, under injection is overstated. Cumulative water injection since waterflood start-up through the end of 2001 is 4021 MMSTB. (Production and injection values have been calculated based upon the start-up date for the project area, 6/14/84, rather than of each injection pattern and using the new polygon boundary.) The flood area's GOR increased from an average of 9,166 SCF/STB in 2000 to 9,725 SCF/STB in 2001. Gas influx continues upstructure across Drill Sites 4, 9, and 11. Gas breakthrough continues to be present wherever gas is underrunning shales in all of the Upper Romeo and Tango. Increases in RMI also contribute to the increased GOR. Watercuts remained steady at 91% in 2001. Exhibit 2-B presents a data summary of the pertinent production information for the waterflood. A breakdown of the production and injection data is provided in Exhibit 2-C for the report period. See Exhibit 1-B for a comparison of the cumulative figures with last year’s AOGCC report. Exhibit 2-D presents the areal average waterflood pressure decline over time. Exhibit 2-E is a presentation of 2001 average returned MI (RMI) rates. Miscible gas breakthrough has been confirmed in 48 wells by gas compositional analysis (RMI>200 MSCFD). 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 3-A. In 2001, oil production averaged 27 MBOD at an 88% water cut and an 12,201 SCF/STB Gas Oil Ratio. Injection averaged 215 MBWD and 61 MMSCFD of miscible injectant (MI). There are a total of 76 producers and 36 injectors in the flood area that contributed to production/injection during 2001. Of the 36 injectors, 35 alternately injected miscible gas and water (WAG injectors); the remaining wells injected water only. Production/injection data were calculated with the 1998 polygon boundaries. Exhibit 3-B is a summary of the production and injection data since waterflood startup. Production and injection values have been calculated using the new polygon boundary. Two waterflood start-up dates have been used, 12/30/82 for the DS13 flood and 8/20/84 for the downdip sections, rather than the start-up dates of each injection pattern. A total of 546 MMSTB of oil, 1,596 BSCF of gas, and 962 MMSTB of water have been produced. About 1,435 MMSTB of water and 522 BSCF of miscible gas have been injected in the EPWZ area. Exhibit 3-C shows the monthly injected and produced volumes on a reservoir barrel basis during 2001 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 85 MMRB. Because the reservoir balance (Exhibit 3-C) doesn’t identify support from the gas-cap or aquifer, under injection is overstated. Exhibit 3-D shows the trend of reservoir pressure decline in the EPWZ flood area with time. The area receives pressure support from water/WAG injection. Faulting and out of zone injection 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 9 influences the pressure in some areas. Additionally, areas of low pressure are being addressed by strategic conversions of producers to injectors. As cumulative MI gas injection rises, increasing gas saturations in the reservoir means larger amounts of Returned MI (RMI) are produced in the wells. Exhibit 3-E shows the 2001 average of estimated RMI rates in producers, as calculated from well tests and from numerous produced gas sample analyses. Miscible gas breakthrough has been confirmed in 38 (RMI <200 MSCFD). 4.3 Western Peripheral Wedge Zone Water / MI Flood Project Exhibit 4-A is a map of the WPWZ water and miscible gas flood areas. During the report period oil production averaged 34 MBOD at a gas/oil ratio of 4,852 SCF/STB and a watercut of 80%. Injection averaged 119 MBWD of water and 106 MMSCFD of miscible injectant. Miscible injection was significantly reduced in the WPWZ from last year. Production/injection data have been calculated with the 1998 polygon boundary definition. For the WPWZ project, 41 injectors (33 WAG injectors and 9 water injectors), and 106 producers contributed to the production and injection during 2001. The well counts reflect the number of wells actually contributing to production/injection 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 2001 was 1,223 MMSTB while cumulative MI injection was 452 BSCF as detailed in Exhibit 4-B. Cumulative production since waterflood start-up is 423 MMSTB oil, 903 BSCF gas, and 708 MMSTB water. As of December 31, 2001 cumulative production exceeded injection by 293 MMRB. Exhibit 4- C provides the monthly injection and production data from 01/01 through 12/01. During the report period, production exceeded injection by 41 MMRB. During 2001, WPWZ injection targets were modified to take into account aquifer influx occurring along the GDWFI boundary, and superpattern management of the WPWZ waterflood to stabilize the GOC. The reservoir balance in Exhibit 4-C doesn’t identify support from the aquifer, thereby overstating under- injection. The areally-weighted average pressure as of July 1, 2001 was 3309 psia. This represents an average decline rate of 32 psi/yr, based on pressures at the start of the report period, and mid year 2001. Exhibit 4-D depicts the reservoir pressure history for the WPWZ area. The pressure decline is believed to be related to poor injection conformance in Zone 4, which reduces pattern throughput. Activity is underway to improve conformance through injector sidetracks. Exhibit 4-E indicates wells with MI breakthrough and the 12-month averaged returned MI rates. Miscible gas breakthrough has been confirmed in 50 wells by gas compositional analysis. 4.4 Northwest Fault Block Water / MI Flood Project Exhibit 5-A is a map of the NWFB water and miscible gas flood areas. During the report period, oil production averaged 27.4 MBOD at a gas/oil ratio of 6,038 SCF/STB and a watercut of 80%. Injection averaged 106 MBWD and 103 MMSCFD of miscible injectant. 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 10 For the NWFB project, 36 injectors (32 WAG injectors and 4 water injectors), and 83 producers contributed to the production and injection during 2001. The well counts reflect the number of wells actually contributing to production/injection Production and injection values have been calculated based upon the start-up date for the project area, 8/13/84, rather than of each injection pattern and using the new polygon boundary. Cumulative water injection from waterflood start-up in August 1984 through December 2001 was 1,288 MMSTB while cumulative MI injection was 574 BCF as detailed in Exhibit 5-B. Cumulative production since waterflood start-up was 519 MMSTB oil, 897 BSCF gas, and 677 MMSTB water. As of December 31, 2001 cumulative production exceeded injection by 150 MMRB. Exhibit 5-C provides the monthly injection and production data from 01/01 through 12/01. During the report period, production exceeded injection by 34 MMRB. The improved voidage reflects the recent injector conformance work performed in the area. The areally-weighted average pressure as of July 1, 2001 was 3,205 psia. Average pressure decline for this area was 39 psi/yr, based on pressures at the start of the report period, and mid year 2001. Exhibit 5-E indicates wells with MI breakthrough and the 12-month average returned MI rates. Miscible gas breakthrough has been confirmed in 44 wells by gas compositional analysis. 4.5 Eileen West End Waterflood Project Exhibit 6-A is a map of the EWE waterflood area. During the report period, oil production averaged 18.6 MBOD at a gas/oil ratio of 7,212 SCF/STB and a water cut of 61%. Injection averaged 1.5 MBWD and 43 MMSCFD of gas. Neither injection rate represents a full year of injection. For the EWE project, 4 injectors (3 WAG injectors and 1 water injectors), and 54 producers contributed to the production and injection during 2001. The well counts reflect the number of wells actually contributing to production/injection Cumulative water injection from waterflood start-up in September 2001 through December 2001 was 1 MMSTB as detailed in Exhibit 5-B. Cumulative production since waterflood start-up was 2 MMSTB oil, 13 BCF gas, and 3 MMSTB water. As of December 31, 2001 cumulative production exceeded injection by 12 MMRB. Exhibit 5-C provides the monthly injection and production data from 10/01 through 12/01. During the report period, production exceeded injection by 12 MMRB. The areally-weighted average pressure as of July 1, 2001 was 3,696 psia. Average pressure decline for this area was 11 psi/yr, based on pressures at the start of the report period, and mid year 2001. 5. GAS MOVEMENT SURVEILLANCE The report on gas movement surveillance activities and interpretations is broken into two major sections. The first section provides a summary of gas influx movement and the second section summarizes gas movement mechanisms. 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 11 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 (GDA) 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. Fieldwide GOC estimates were made in 2000 and a gas influx map is presented in Exhibit 7-A. 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 GDA 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 GDA 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 regional shales. Such lenses have been identified from neutron logs. These lenses occur on Zulu (Zone 4B) shales, and above Tango (Zone 2B) shales. Many lenses continue to exhibit oil drainage over time. Exhibit 7-B lists the open and cased-hole neutron logs, as wells as RST logs, run in the Prudhoe Bay Unit during the gas-influx reporting period from January 2001 through December 2001. A total of 96 gas-monitoring logs, all cased-hole logs were run in the PBU. 5.2 GOR Mechanisms Exhibit 7-C lists the primary gas production mechanism for active producing. Mechanisms are divided initially by GOR production, (L) low GOR (< 2050 scf/stb) and high GOR (> 2050 scf/stb) production. The high GOR wells are further subdivided by mechanism; (G) high GOR production directly from the expanded gas cap (i.e. coning), (U) high GOR production from underruns and/or solution gas pockets, (O) high GOR production due to cement channeling, high GOR production due to commingled Sag River production, or high GOR production from returned MI production. A more detailed discussion of each GOR mechanism is provided below: Low GOR Low GOR (< 2050 scf/stb) production is primarily limited to recently drilled development wells, peripheral wells, and from waterflood project wells. 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 12 Expanded GOC High GOR production directly from the expanded GOC occurs in numerous wells in the PBU. As cumulative liquid voidage increases, gas influx occurs both vertically and areally. The vertical and areal (within hydraulic layer) expansion of the original GOC gives rise to the expanded GOC gas production mechanism. Gas Underruns Gas underrunning and free solution gas production contribute to high GOR production in many PBU wells. Both underrunning and solution gas production are facilitated by continuous and semi-continuous shale intervals. In underrunning, gas tongues connect to the expanded GOC. Underrunning occurs upstructure in the lower formations of the reservoir and downstructure in the upper formations. Other Channeling of gas via cement channels contributes high GOR and occurs in isolated cases throughout the field. Remedial squeeze programs and sidetracking / re-drilling of compromised wellbores has reduced the significance of this mechanism. High GOR also occurs due to commingled production with the Sag River Formation. Miscible gas production contributes to high GORs, but not appreciably to the movement of free gas within the reservoir. This occurs in the gravity drainage waterflood interaction (GDWFI) and waterflood areas and is associated with the WAG injectors. 2001 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 13 6. EXHIBITS Exhibit 1-B Prudhoe Bay Oil Field 2001 OVERVIEW STATISTICAL SUMMARY WELL STATISTICS WELL COUNT BY FIELD AREA WPWZ NWFB EWE FS2 EPWZ GD 2000 AOGCC Report Producers 98 77 49 116 73 534 Injectors 41 32 3 62 35 37 -WAG 32 28 0 37 32 3 -Water Only 9 4 0 21 3 1 -Gas 0 0 3 4 0 33 2001 Producers 106 83 54 118 76 561 Injectors 42 36 4 60 36 35 -WAG 33 32 3 37 35 2 -Water Only 9 4 1 23 1 1 -Gas 0 0 0 0 0 32 Production Well Status in 2001 -Newly Drilled 0 0 0 0 0 0 -Sidetracked or Redrilled 15 3 4 2 3 40 Gas Injection Well Status in 2001 -Newly Drilled 0 0 0 0 0 0 -Sidetracked or Redrilled 0 0 0 0 0 0 WAG Injection Well Status in 2001 -Newly Drilled 0 0 0 0 0 0 -Sidetracked or Redrilled 0 3 0 1 0 0 Water Injection Well Status in 2001 -Newly Drilled 0 0 0 0 0 0 -Sidetracked or Redrilled 0 0 0 1 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. Exhibit 1-B (continued) 2001 OVERVIEW STATISTICAL SUMMARY PRODUCTION/INJECTION STATISTICS Waterflood Total WPWZ NWFB FS-2 EPWZ EWE Cumulative Production from WF Start-Up through 12/31/01 Oil (MMSTB)423 519 928 546 2 2418 Gas (BCF)903 897 2757 1596 13 6166 Water (MMSTB)708 677 2341 962 3 4691 Cumulative Injection from WF Start-Up through 12/31/01 Water (MMSTB)1223 1288 4016 1435 1 7963 MI (BCF)452 574 708 522 0 2256 Cumulative Balance from WF Start-Up through 12/31/00 Cum Production (MMRB)1757 1693 5097 2774 0 11321 Cum Injection (MMRB)1505 1580 4312 1741 0 9138 Over/Under (MMRB)-252 -113 -785 -1033 0 -2183 Cumulative Balance from WF Start-Up through 12/31/01 Cum Production (MMRB)1868 1793 5390 2955 13 12018 Cum Injection (MMRB)1576 1643 4555 1837 1 9612 Over/Under (MMRB)-292 -150 -835 -1118 -12 -2406 MI Breakthrough in Producing Wells > 200 mcfd 50 44 48 38 0 180 < 200 mcfd 36 22 27 23 0 108 AVERAGE RATE DATA 2001 Production Oil (MBD)34.1 27.4 43.0 27.1 18.6 150.2 Gas (MMSCFD)165.3 165.3 417.9 330.9 134.1 1213.5 Water (MBD)138.0 107.2 456.4 195.3 29.6 926.5 Injection Water (MBD)119.2 105.5 560.3 215.4 1.5 1001.9 Gas (MMSCFD)106.3 102.8 124.6 60.6 43.0 437.3 AVERAGE RESERVOIR PRESSURE (psia) GD WPWZ NWFB FS-2 EPWZ EWE FIELDWIDE Beginning of report period 1/01 3271 3325 3225 3366 3325 3699 3295 Mid report period, 7/01 3254 3309 3205 3360 3310 3677 3280 Pressure Decline (psi/6 month period)17 16 20 6 15 22 15 Estimated Annual Decline (psi/yr)34 32 40 12 30 44 30 Waterflood Project Area Exhibit 1-C Pressure Map EXHIBIT 1-D AREALLY WEIGHTED AVERAGE PRESSURES DATE FS2 EPWZ EOAGD WPWZ NWFB WOAGD PBMGP 12/31/77 3935 4005 4021 4016 3944 3977 3968 7/1/78 3870 3967 3987 3978 3909 3939 3914 12/31/78 3832 3930 3957 3944 3875 3908 3873 7/2/79 3813 3895 3924 3911 3843 3877 3844 12/31/79 3791 3861 3891 3879 3799 3850 3816 7/1/80 3799 3831 3891 3848 3770 3821 3798 12/31/80 3852 3819 3845 3822 3781 3800 3818 7/1/81 3881 3821 3833 3799 3814 3784 3840 12/31/81 3880 3815 3818 3799 3820 3768 3842 7/2/82 3872 3806 3803 3800 3812 3753 3833 12/31/82 3850 3795 3785 3797 3804 3739 3818 7/2/83 3831 3784 3768 3792 3787 3722 3804 1/1/84 3814 3771 3751 3783 3772 3704 3790 7/1/84 3796 3758 3735 3777 3756 3686 3774 1/1/89 3779 3743 3719 3771 3736 3670 3755 7/1/89 3760 3730 3703 3763 3723 3653 3740 1/1/90 3732 3708 3685 3731 3704 3631 3713 7/1/90 3708 3693 3668 3716 3687 3613 3695 1/1/91 3680 3676 3650 3694 3655 3595 3666 7/1/91 3642 3657 3633 3673 3628 3576 3635 1/1/92 3617 3641 3617 3652 3602 3558 3615 7/1/92 3591 3626 3600 3632 3577 3540 3593 1/1/93 3561 3600 3576 3619 3544 3522 3582 7/1/93 3543 3595 3560 3598 3515 3502 3565 1/1/94 3539 3555 3542 3578 3483 3482 3537 7/1/94 3523 3536 3527 3555 3456 3457 3516 1/1/95 3496 3524 3517 3555 3507 3447 3506 7/1/95 3473 3507 3503 3536 3489 3428 3486 1/1/96 3466 3485 3485 3497 3478 3407 3463 7/1/96 3450 3467 3470 3472 3461 3390 3443 1/1/97 3446 3484 3435 3460 3444 3373 3441 7/1/97 3429 3467 3416 3438 3427 3357 3421 1/1/98 3452 3417 3413 3417 3421 3344 3430 7/1/98 3435 3409 3397 3394 3402 3328 3415 1/1/99 3445 3391 3376 3382 3343 3302 3443 7/1/99 3429 3378 3361 3360 3317 3285 3426 1/1/00 3406 3361 3356 3372 3268 3231 3418 7/1/00 3390 3351 3342 3353 3240 3203 3395 1/1/01 3366 3325 3323 3325 3225 3224 3358 7/1/01 3360 3310 3309 3309 3205 3205 3347 1/1/02 3353 3295 3295 3293 3186 3185 3335 Exhibit 1-D Areally Weighted Average Pressures EOA PRESSURE TRENDS (areally wtd avgs) 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 12/31/82 12/31/83 12/31/84 12/31/85 12/31/86 1/1/88 12/31/88 12/31/89 1/1/91 1/1/92 12/31/92 1/1/94 1/1/95 1/1/96 1/1/97 1/1/98 1/1/99 1/2/00 1/1/01 1/1/02 1/2/03 P S I A FS2 EPWZ EOAGD WOA PRESSURE TRENDS (areally wtd avgs) 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 12/31/82 12/31/83 12/31/84 12/31/85 12/31/86 1/1/88 12/31/88 12/31/89 1/1/91 1/1/92 12/31/92 1/1/94 1/1/95 1/1/96 1/1/97 1/1/98 1/1/99 1/2/00 1/1/01 1/1/02 1/2/03 P S I A NWFB WPWZ WOAGD AREAL AVG. P in the PBMGP (FS 2,EPWZ,WPWZ,NWFB) 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 12/31/82 12/31/83 12/31/84 12/31/85 12/31/86 1/1/88 12/31/88 12/31/89 1/1/91 1/1/92 12/31/92 1/1/94 1/1/95 1/1/96 1/1/97 1/1/98 1/1/99 1/2/00 1/1/01 1/1/02 1/2/03 P S I A Exhibit 1-E 2001 Average Monthly CGF MI Rates and MI Compositions EOA MI Rate *MMP MW **Average Monthly Mole% MCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+ 01/01 281,247 3,543 31.05 18.23%39.69%17.46%20.67%1.82%2.11%0.02% 02/01 252,439 3,546 31.46 21.23%35.92%20.09%20.79%1.10%0.87%0.01% 03/01 262,338 3,507 31.35 19.56%37.74%18.51%20.97%1.57%1.64%0.03% 04/01 236,975 3,353 31.92 20.26%35.05%19.60%22.13%1.55%1.40%0.02% 05/01 255,420 3,523 31.48 20.80%36.37%19.32%21.30%1.23%0.97%0.01% 06/01 241,251 3,444 31.28 18.06%38.47%17.88%22.04%1.83%1.71%0.01% 07/01 191,623 3,404 31.78 20.38%35.57%19.43%21.72%1.38%1.51%0.01% 08/01 186,463 3,536 30.71 16.30%41.27%16.46%22.36%1.74%1.84%0.03% 09/01 210,037 3,361 31.70 18.92%36.91%18.33%21.93%2.02%1.88%0.01% 10/01 172,545 3,620 30.84 18.66%39.55%17.85%21.59%1.33%0.85%0.17% 11/01 200,086 3,480 31.36 19.35%37.39%18.56%22.04%1.47%1.19%0.01% 12/01 202,876 3,429 31.45 19.13%36.88%18.69%22.90%1.39%1.00%0.01% Average 224,237 3,479 31.45 19.33%37.64%18.58%21.70%1.55%1.44%0.02% WOA MI Rate *MMP MW **Average Monthly Mole% MCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+ 01/01 217,416 3,280 31.79 17.92%37.07%17.94%22.68%2.12%2.25%0.03% 02/01 224,099 3,368 31.95 20.52%35.34%19.13%21.71%1.63%1.65%0.03% 03/01 227,287 3,310 32.08 20.36%34.65%19.52%22.23%1.60%1.59%0.05% 04/01 212,927 3,268 32.25 20.56%34.01%19.54%22.71%1.65%1.51%0.02% 05/01 187,796 3,307 32.08 20.35%34.45%19.61%23.02%1.29%0.82%0.45% 06/01 177,523 3,114 32.85 21.07%31.84%20.15%23.20%1.76%1.97%0.01% 07/01 177,923 3,154 32.32 19.01%34.07%19.28%24.12%1.79%1.72%0.02% 08/01 226,083 3,146 32.46 19.08%34.36%18.96%23.81%1.85%0.86%1.08% 09/01 205,921 3,197 32.38 19.59%34.70%18.78%22.19%2.20%2.52%0.01% 10/01 187,184 3,111 32.62 20.10%32.40%19.83%24.70%1.66%1.31%0.01% 11/01 239,341 3,155 32.52 20.30%32.67%20.00%24.10%1.61%1.32%0.00% 12/01 226,847 3,141 32.49 20.10%32.32%20.40%24.79%1.42%0.97%0.00% Average 209,076 3,213 32.40 19.95%34.11%19.47%23.33%1.72%1.53%0.15% * MMP data from 1986 Zick Correlation ** Composition data from averaged EOA and WOA MI line laboratory samples Exhibit 2-B Flow Station 2 SUMMARY OF PERTINENT DATA (as of December 31, 2001) AREA WATERFLOOD START-UP DATE(S):14-Jun-84 AREA PRODUCTION* Prior to Waterflood Start-Up: Oil (MMSTB)493 Since Waterflood Start-Up: Oil (MMSTB)928 Gas (MMSCF)2757 Water (MMSTB)2341 AREA WATER INJECTION* Prior to Waterflood Start-Up: Produced Water (MMSTB)5 Since Waterflood Start-Up: Injection Water (MMSTB)4016 Miscible Injectant (MMSCF)708 AREA RESERVOIR PRESSURE @ 8800' TVD ss July 1, 2001 Pressure (psia)3360 AREA WELL COUNT (Wells in Operation)** Production Wells 118 Water Only Injection 23 WAG Injection 37 NOTES: *Reflects new polygon boundary and single start-up date rather than individual injection patterns as done previously. **Reflects ONLY those wells which contributed to production or injection during 2001. Exhibit 2-C FS-2 Water/MI Project RESERVOIR BALANCE SINCE WATERFLOOD START-UP January - December 2001 Cumulative Produced Fluids (MMRB)12/31/2000 January February March April May June Oil 1,198.4 2.133 1.777 2.088 2.025 1.896 1.078 Free Gas 1,639.9 11.051 9.463 11.261 10.603 11.520 6.845 Water 2,258.9 18.499 15.859 18.269 17.400 16.130 8.150 TOTAL 5,097.2 31.683 27.099 31.618 30.028 29.546 16.073 Injected Fluids (MMRB) Water 3,870.3 22.442 19.035 21.602 20.028 20.314 10.329 Gas 442.1 2.859 2.994 3.040 2.479 2.781 2.262 TOTAL 4,312.4 25.301 22.029 24.641 22.507 23.095 12.591 Net Injection Volumes = Injection - Production (MMRB) TOTAL -784.8 -6.4 -5.1 -7.0 -7.5 -6.5 -3.5 Produced Fluids Cumulative (MMRB)July August September October November December 12/31/2001 Oil 1.078 1.347 1.450 1.335 1.486 1.794 1,217.9 Free Gas 6.845 8.801 8.523 8.129 7.390 9.623 1,749.9 Water 8.150 10.175 10.844 9.903 12.429 17.063 2,421.8 TOTAL 16.073 20.323 20.817 19.367 21.305 28.480 5,389.6 Injected Fluids (MMRB) Water 13.287 13.816 14.550 16.132 19.895 21.271 4,083.0 Gas 1.829 1.774 2.356 2.327 2.734 2.619 472.1 TOTAL 15.117 15.590 16.905 18.460 22.629 23.890 4,555.1 Net Injection Volumes = Injection - Production (MMRB) TOTAL -1.0 -4.7 -3.9 -0.9 1.3 -4.6 -834.5 Exhibit 2-D FS-2 Areal Average Reservoir Pressure versus Time 3300 3400 3500 3600 3700 3800 3900 4000 1/1/87 1/1/88 12/31/88 12/31/89 1/1/91 1/1/92 12/31/92 1/1/94 1/1/95 1/1/96 1/1/97 1/1/98 1/1/99 1/1/00 1/1/01 1/1/02 1/1/03Reservoir Pressure @ 8800' SSTVD (psia) Exhibit 3-B Eastern Peripheral Wedge Zone SUMMARY OF PERTINENT DATA (as of December 31, 2001) AREA WATERFLOOD START-UP DATE(S): Drill Site 13 30-Dec-82 Downdip 20-Aug-84 AREA PRODUCTION* Prior to Waterflood Start-Up: Oil (MMSTB)184 Since Waterflood Start-Up: Oil (MMSTB)546 Gas (MMSCF)1596 Water (MMSTB)962 AREA WATER INJECTION* Prior to Waterflood Start-Up: Produced Water (MMSTB)6 Since Waterflood Start-Up: Injection Water (MMSTB)1435 Miscible Injectant (MMSCF)522 AREA RESERVOIR PRESSURE @ 8800' TVD ss July, 2001 Pressure (psia)3310 AREA WELL COUNT (Wells in Operation)** Production Wells 76 Water Only Injection 1 WAG Injection 35 NOTES: *Production and Injection values reflect new polygon boundary and are provided based upon the start-up dates of initial water injection into Drill Site 13 and Downdip. **Reflects ONLY those wells which contributed to production or injection during 2001. Exhibit 3-C EPWZ Water/MI Flood Project RESERVOIR BALANCE SINCE WATERFLOOD START-UP January - December 2001 Cumulative Produced Fluids (MMRB)12/31/2000 January February March April May June Oil 705.5 1.202 1.052 1.158 1.106 1.229 1.046 Free Gas 961.7 8.082 7.635 8.235 8.030 8.184 7.582 Water 1,106.7 7.014 6.288 6.850 6.576 6.758 6.244 TOTAL 2,774.0 16.298 14.974 16.244 15.711 16.171 14.872 Injected Fluids (MMRB) Water 1,410.4 6.988 6.135 6.742 6.895 7.161 7.066 Gas 330.6 2.143 0.699 1.392 1.236 1.187 1.257 TOTAL 1,740.9 9.131 6.834 8.134 8.131 8.347 8.323 Net Injection Volumes = Injection - Production (MMRB) TOTAL -1,033.1 -7.2 -8.1 -8.1 -7.6 -7.8 -6.5 Produced Fluids Cumulative (MMRB)July August September October November December 12/31/2001 Oil 1.046 1.137 1.076 0.958 0.952 0.965 718.4 Free Gas 8.384 8.455 7.601 6.536 7.531 7.700 1,055.7 Water 6.174 6.283 5.365 5.371 5.443 5.764 1,180.9 TOTAL 15.604 15.875 14.041 12.865 13.926 14.429 2,955.0 Injected Fluids (MMRB) Water 6.950 7.037 6.570 6.651 7.196 6.389 1,492.1 Gas 1.371 1.041 0.996 0.907 0.951 1.550 345.3 TOTAL 8.321 8.078 7.566 7.558 8.147 7.939 1,837.4 Net Injection Volumes = Injection - Production (MMRB) TOTAL -7.3 -7.8 -6.5 -5.3 -5.8 -6.5 -1117.6 Exhibit 3-D EPWZ Areal Average Reservoir Pressure versus Time 3200 3300 3400 3500 3600 3700 3800 3900 4000 1/1/87 1/1/88 12/31/88 12/31/89 1/1/91 1/1/92 12/31/92 1/1/94 1/1/95 1/1/96 1/1/97 1/1/98 1/1/99 1/1/00 1/1/01 1/1/02 1/1/03Reservoir Pressure @ 8800' SSTVD (psia) Exhibit 4-B Western Peripheral Wedge Zone SUMMARY OF PERTINENT DATA (as of December 31, 2001) AREA WATERFLOOD START-UP DATE(S):September-85 AREA PRODUCTION* Prior to Waterflood Start-Up: Oil (MMSTB)169 Since Waterflood Start-Up: Oil (MMSTB)423 Gas (MMSCF)903 Water (MMSTB)708 AREA WATER INJECTION* Prior to Waterflood Start-Up: Produced Water (MMSTB)3 Since Waterflood Start-Up: Injection Water (MMSTB)1223 Miscible Injectant (MMSCF)452 AREA RESERVOIR PRESSURE @ 8800' TVD ss July 1, 2001 Pressure (psia)3309 AREA WELL COUNT (Wells in Operation**) Production Wells 106 Water Only Injection 9 WAG Injection 33 NOTES: *Production and Injection values reflect the new polygon boundary and are based upon the start-up date of the Main Pattern Area (MPA) rather than of the individual injections patterns. **Reflects ONLY those wells which contributed to production or injection during 2001. Exhibit 4-C WPWZ Water/MI Flood Project RESERVOIR BALANCE SINCE WATERFLOOD START-UP January - December 2001 Cumulative Produced Fluids (MMRB)12/31/2000 January February March April May June Oil 547.5 1.157 1.086 1.381 1.373 1.300 1.263 Free Gas 525.0 3.743 3.314 3.926 3.910 3.681 3.228 Water 684.2 3.923 3.408 4.067 4.276 4.318 4.681 TOTAL 1,756.8 8.822 7.807 9.374 9.559 9.298 9.172 Injected Fluids (MMRB) Water 1,226.4 3.703 3.313 4.409 4.477 4.057 4.212 Gas 278.0 1.595 1.983 3.028 2.460 1.850 1.601 TOTAL 1,504.5 5.297 5.295 7.437 6.937 5.906 5.813 Net Injection Volumes = Injection - Production (MMRB) TOTAL -252.3 -3.5 -2.5 -1.9 -2.6 -3.4 -3.4 Produced Fluids Cumulative (MMRB)July August September October November December 12/31/2001 Oil 1.263 1.380 1.489 1.428 1.323 1.503 563.5 Free Gas 3.273 3.146 2.021 3.080 5.145 4.918 568.4 Water 4.415 4.842 4.152 4.203 4.874 5.214 736.6 TOTAL 8.950 9.368 7.662 8.711 11.343 11.636 1,868.5 111.7 Injected Fluids (MMRB) Water 3.751 3.605 2.769 3.207 3.659 4.090 1,271.7 Gas 1.798 2.490 2.685 2.015 2.325 2.022 303.9 TOTAL 5.548 6.095 5.453 5.222 5.985 6.112 1,575.6 71.1 Net Injection Volumes = Injection - Production (MMRB) TOTAL -3.4 -3.3 -2.2 -3.5 -5.4 -5.5 -292.9 40.6 Exhibit 4-D WPWZ Areal Average Reservoir Pressure versus Time 3200 3300 3400 3500 3600 3700 3800 3900 4000 1/1/87 1/1/88 12/31/88 12/31/89 1/1/91 1/1/92 12/31/92 1/1/94 1/1/95 1/1/96 1/1/97 1/1/98 1/1/99 1/1/00 1/1/01 1/1/02 1/1/03Reservoir Pressure @ 8800' SSTVD (psia) Exhibit 5-B North West Fault Block SUMMARY OF PERTINENT DATA (as of December 31, 2001) AREA WATERFLOOD START-UP DATE(S):13-Aug-84 AREA PRODUCTION* Prior to Waterflood Start-Up: Oil (MMSTB)144 Since Waterflood Start-Up: Oil (MMSTB)519 Gas (BSCF)897 Water (MMSTB)677 AREA WATER INJECTION* Prior to Waterflood Start-Up: Produced Water (MMSTB)3 Since Waterflood Start-Up: Injection Water (MMSTB)1288 Miscible Injectant (MMSCF)574 AREA RESERVOIR PRESSURE @ 8800' TVD ss July 1, 2001 Pressure (psia)3205 AREA WELL COUNT (Wells in Operation)** Production Wells 83 Water Only Injection 4 WAG Injection 32 NOTES: *Reflects new polygon boundary and single start-up date rather than individual injection patterns as done previously. **Reflects ONLY those wells which contributed to production or injection during 2001. Exhibit 5-C NWFB Water/MI Flood Project RESERVOIR BALANCE SINCE WATERFLOOD START-UP January - December 2001 Cumulative Produced Fluids (MMRB)12/31/2000 January February March April May June Oil 657.7 1.241 1.144 1.178 1.105 1.107 1.063 Free Gas 418.8 3.827 3.395 4.125 4.133 3.868 3.405 Water 616.3 3.791 3.421 3.590 3.299 3.411 3.539 TOTAL 1,692.9 8.859 7.960 8.894 8.536 8.386 8.008 Injected Fluids (MMRB) Water 1,247.4 2.967 2.824 3.433 3.224 3.114 3.642 Gas 329.7 2.942 2.233 1.702 1.835 2.104 1.938 TOTAL 1,577.1 5.909 5.057 5.135 5.058 5.219 5.579 Net Injection Volumes = Injection - Production (MMRB) TOTAL -115.7 -2.9 -2.9 -3.8 -3.5 -3.2 -2.4 Produced Fluids Cumulative (MMRB)July August September October November December 12/31/2001 Oil 1.063 1.052 1.031 0.752 1.008 1.110 670.6 Free Gas 3.500 3.420 2.345 3.365 5.451 5.204 464.9 Water 3.810 3.569 2.672 3.227 3.197 3.182 657.0 TOTAL 8.373 8.040 6.048 7.345 9.655 9.496 1,792.5 99.6 Injected Fluids (MMRB) Water 3.381 4.235 2.747 3.229 3.645 3.621 1,284.4 Gas 1.947 2.140 1.560 1.789 2.487 2.722 355.1 TOTAL 5.328 6.374 4.306 5.017 6.132 6.343 1,642.6 65.5 Net Injection Volumes = Injection - Production (MMRB) TOTAL -3.0 -1.7 -1.7 -2.3 -3.5 -3.2 -149.9 34.1 Exhibit 5-D NWFB Areal Average Reservoir Pressure versus Time 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 1/1/87 1/1/88 12/31/88 12/31/89 1/1/91 1/1/92 12/31/92 1/1/94 1/1/95 1/1/96 1/1/97 1/1/98 1/1/99 1/1/00 1/1/01 1/1/02 1/1/03Reservoir Pressure @ 8800' SSTVD (psia) Exhibit 6-B Eileen West End SUMMARY OF PERTINENT DATA (as of December 31, 2001) AREA WATERFLOOD START-UP DATE(S):September-01 AREA PRODUCTION* Prior to Waterflood Start-Up: Oil (MMSTB)150 Since Waterflood Start-Up: Oil (MMSTB)2 Gas (MMSCF)13 Water (MMSTB)3 AREA WATER INJECTION* Prior to Waterflood Start-Up: Produced Water (MMSTB)0 Since Waterflood Start-Up: Injection Water (MMSTB)1 Miscible Injectant (MMSCF)0 AREA RESERVOIR PRESSURE @ 8800' TVD ss July 1, 2001 Pressure (psia)3696 AREA WELL COUNT (Wells in Operation**) Production Wells 54 Water Only Injection 1 WAG Injection 3 NOTES: *Waterflood startup was September 29, 2001 **Reflects ONLY those wells which contributed to production or injection during 2001. Exhibit 6-C EWE Water/MI Flood Project RESERVOIR BALANCE SINCE WATERFLOOD START-UP January - December 2001 Cumulative Produced Fluids (MMRB)12/31/2000 January February March April May June Oil 0.0 0.000 0.000 0.000 0.000 0.000 0.000 Free Gas 0.0 0.000 0.000 0.000 0.000 0.000 0.000 Water 0.0 0.000 0.000 0.000 0.000 0.000 0.000 TOTAL 0.0 0.000 0.000 0.000 0.000 0.000 0.000 Injected Fluids (MMRB) Water 0.0 0.000 0.000 0.000 0.000 0.000 0.000 Gas 0.0 0.000 0.000 0.000 0.000 0.000 0.000 TOTAL 0.0 0.000 0.000 0.000 0.000 0.000 0.000 Net Injection Volumes = Injection - Production (MMRB) TOTAL 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Produced Fluids Cumulative (MMRB)July August September October November December 12/31/2001 Oil 0.000 0.000 0.000 0.000 0.680 0.697 1.4 Free Gas 0.000 0.000 0.000 2.096 3.225 3.068 8.4 Water 0.000 0.000 0.000 0.969 0.899 0.933 2.8 TOTAL 0.000 0.000 0.000 3.065 4.803 4.697 12.6 Injected Fluids (MMRB) Water 0.000 0.000 0.000 0.030 0.261 0.280 0.6 Gas 0.000 0.000 0.000 0.000 0.000 0.000 0.0 TOTAL 0.000 0.000 0.000 0.030 0.261 0.280 0.6 Net Injection Volumes = Injection - Production (MMRB) TOTAL 0.0 0.0 0.0 -3.0 -4.5 -4.4 -12.0 *Note - EWE Waterflood startup was 09/29/01 Exhibit 7 -B Wells Surveyed for Gas Movement 01/01/2001 through 12/31/2001 CH Cased Hole Log OH Open Hole Log Well Name Log Date OH/CH 01-03A 04/05/01 CH 01-04A 08/31/01 OH 01-10 04/05/01 CH 01-14 03/18/01 CH 01-19 05/08/01 CH 01-20 04/08/01 CH 01-23 05/05/01 CH 01-34 08/30/01 CH 02-14 04/27/01 CH 03-09 12/21/01 CH 03-24A 05/10/01 OH 04-01 03/04/01 CH 04-02 02/14/01 CH 04-07 01/25/01 CH 04-26 01/06/01 CH 04-30 04/06/01 CH 04-31 12/11/01 CH 04-47 01/04/01 CH 04-48 02/13/01 CH 05-09A 05/12/01 CH 05-11A 03/08/01 CH 05-12B 12/16/01 OH 05-23A 10/17/01 OH 05-28A 10/30/01 OH 05-31A 01/30/01 CH 06-02 01/28/01 CH 07-14A 12/22/01 CH 07-16A 09/12/01 OH 07-19A 12/24/01 CH 07-35 12/07/01 CH 07-35 12/08/01 CH 09-04 10/18/01 CH Well Name Log Date OH/CH 09-42A 10/22/01 CH 11-01A 04/28/01 CH 11-11 01/05/01 CH 11-16 12/23/01 CH 11-18 12/26/01 CH 11-22AL1 12/08/01 CH 11-37 11/09/01 CH 12-28A 08/23/01 CH 12-29 08/24/01 CH 14-40A 12/05/01 OH 15-16A 11/20/01 OH 15-32A 11/08/01 OH 15-44 10/25/01 CH 15-46 12/27/01 CH 18-08A 12/04/01 CH 18-22A 05/14/01 CH A-09A 01/11/01 OH B-04 04/14/01 CH B-05B 06/29/01 OH B-12A 12/24/01 CH B-22A 05/05/01 OH B-29A 02/03/01 OH B-30A 06/26/01 OH C-37A 09/15/01 OH D-04A 10/22/01 CH D-14A 01/28/01 CH D-18A 11/08/01 CH D-18A 10/10/01 OH D-28A 05/02/01 CH F-05 09/11/01 CH F-21 09/08/01 CH F-22 09/14/01 CH Well Name Log Date OH/CH F-31 09/13/01 CH F-34A 09/06/01 OH F-34A 09/06/01 OH F-40 09/09/01 CH F-41 09/10/01 CH F-45 05/02/01 CH G-10A 02/25/01 CH G-13A 02/22/01 OH G-19A 11/07/01 OH G-29A 05/07/01 CH G-30A 04/09/01 CH H-04 12/07/01 CH H-13 08/08/01 CH H-17A 01/21/01 CH H-20 03/12/01 CH J-08 01/11/02 CH J-12 09/05/01 CH J-13 09/06/01 CH J-14A 09/01/01 OH K-10A 06/28/01 OH K-10A 09/09/01 CH K-10A 09/09/01 CH L-01 07/01/01 CH N-15 04/09/01 CH N-17 10/23/01 CH OWDW -NW 03/15/01 CH OWDW -SE 03/13/01 CH OWDW -SW 03/14/01 CH W -21A 11/10/01 OH X-15A 06/10/01 OH Y-01B 07/27/01 OH Y-15A 07/05/01 OH Exhibit 7 -C PBU Gas Production Mechanisms Well Name Gas Mechanism Well Name Gas Mechanism Well Name Gas Mechanism L – Gas Below 3050 scf/stb G – Gas entering perfs from GOC or above U – Gas entering perfs from an underrun O – Gas entering perfs from another mechanism (channel, Sag, MI) 01-02 U 01-03A U 01-04A G,U 01-06A U 01-07A G,U 01-10 G 01-11 G 01-12 G 01-13 G 01-14 G 01-15A G 01-16 G,U 01-18 G 01-19 U 01-21 G,U 01-22A U 01-23 G 01-24A G 01-25 G 01-26A G 01-28 G 01-29 G 01-31 U 01-32 G,U 01-33 G,U 01-34 G 02-01B G 02-02A G 02-03B U 02-04A U 02-05 U 02-06A U 02-07A U 02-08B U 02-09B U 02-10B U 02-11A U 02-12A U 02-13A U 02-14 U 02-15A G 02-16A U 02-17A U 02-18A G 02-19 U 02-20 G,U 02-21A G,U 02-22A G,U 02-23A G 02-24 G 02-25 U 02-26B U 02-27A U 02-28 U 02-29A G 02-30B U 02-31A G 02-33A G 02-34A U 02-35A U 02-36 U 02-37 G 02-38L1 U 02-39L1 U 03-01 G 03-02 O 03-03 O 03-08 L 03-09 U 03-14 L 03-15AL1 O 03-19 O 03-20A O 03-21 L 03-22 U 03-23 G,U 03-24A G 03-25A O 03-26 O 03-27 O 03-28 G,U 03-29 U,O 03-30 O 03-31 U 03-32A O 03-34B O 03-35 O 04-01 G 04-02A L 04-03 G 04-05A U 04-16A L 04-18 L 04-22A U 04-23A L 04-24 U 04-26 U 04-29AL1 L 04-30 G 04-31 U 04-32A U 04-33 U 04-35 G 04-36 U 04-37 U 04-38 U 04-40 U 04-41A L 04-46 U 04-47 L 04-48 U 05-01C L 05-03C G 05-04A U 05-05B O 05-06A U 05-07 G 05-08 G 05-09A G 05-11A G 05-12B G 05-13A L 05-14A G 05-16B L 05-17B G 05-18A O 05-19 G 05-20A G 05-21A U 05-22A G 05-23A G 05-24 G Exhibit 7 -C PBU Gas Production Mechanisms Well Name Gas Mechanism Well Name Gas Mechanism Well Name Gas Mechanism L – Gas Below 3050 scf/stb G – Gas entering perfs from GOC or above U – Gas entering perfs from an underrun O – Gas entering perfs from another mechanism (channel, Sag, MI) 05-25B G 05-26 G 05-27A U 05-28A G 05-30 G 05-31A U 05-32 U 05-33A G 05-34 G 05-36 G 05-38 G 05-39 G 05-40 U 05-41 G 06-01 G 06-02 U 06-03A U 06-04A G 06-05 G,U 06-07 G 06-08A U 06-09 U 06-10A U 06-11 G 06-12A G 06-13 G 06-14A U 06-15 G,U 06-16 G 06-17 G 06-18 G,U 06-19 U 06-20 G 06-21A G 06-23A G 06-24A G,U 07-01A U,O 07-02A U,O 07-03A U,O 07-04A G 07-05 U 07-07A G,O 07-08A U,O 07-09 G,O 07-10A U,O 07-12 U,O 07-13A U,O 07-14A U,O 07-15A U 07-16A U 07-17 U 07-18 G,O 07-19A U 07-20A U,O 07-21 G 07-22 G 07-23A G 07-24 G 07-25 G,O 07-26 G 07-28A U 07-29A G 07-30 G,O 07-32A G 07-33A G,O 07-34A U,O 07-35 U 07-36 U 07-37 U 09-01 O 09-02 O 09-03 O 09-04A O 09-05A O 09-06 L 09-07A O 09-09 O 09-11 O 09-13 O 09-21 O 09-23A O 09-24 O 09-26 O 09-27 O 09-28A O 09-29 O 09-30 O 09-31C U 09-32 U 09-33 U 09-34A O 09-35A U 09-36C O 09-41 O 09-42A O 09-43 O 09-44 O 09-45 O 09-46 O 09-47 O 09-49 O 09-50 O 09-51 O 11-01A U 11-03A O 11-04A U 11-05A U 11-06 U 11-11 L 11-13A G 11-16 G 11-18 U 11-22AL1 U 11-24A U 11-25A U 11-27 U 11-28A U 11-30 U 11-31A L 11-32 L 11-33 U 11-34 U 11-36 U 11-37 U 11-38A U 12-01 U 12-03 O 12-04A O 12-05 O 12-06A O 12-07A O 12-08B O Exhibit 7 -C PBU Gas Production Mechanisms Well Name Gas Mechanism Well Name Gas Mechanism Well Name Gas Mechanism L – Gas Below 3050 scf/stb G – Gas entering perfs from GOC or above U – Gas entering perfs from an underrun O – Gas entering perfs from another mechanism (channel, Sag, MI) 12-09 O 12-10A O 12-12 O 12-13B O 12-14A O 12-15 O 12-16A O 12-17 L 12-18 L 12-22 O 12-26 G 12-28A G 12-29 G 12-32 G 12-34 L 12-35 L 12-36 L 13-01 O 13-02BL1 O 13-03 O 13-04 O 13-08A L 13-11 O 13-12 O 13-14 O 13-27A L 13-29 O 13-30 O 13-33 O 13-34 O 14-02B G 14-03A G 14-04A G 14-05A G 14-06 L 14-07 G 14-08A O 14-09B L 14-10 L 14-11 L 14-12 G 14-15 U 14-16A G 14-19 O 14-20 G 14-22A O 14-23 G 14-24 G 14-26 G 14-28 G 14-29 G 14-30 G 14-31 U 14-32 G 14-33 U 14-34 G 14-37 O 14-40A L 14-41 U 14-43 L 14-44 L 15-01A U 15-02A U 15-04 U 15-05A U 15-06A U 15-07B G 15-08B U 15-09A G 15-11A U 15-12A G 15-13A G 15-14 G 15-15A G 15-16 G 15-16A L 15-17 G 15-18 U 15-19A O 15-20A G 15-21A G 15-22 G 15-23 G 15-25A G 15-26A G 15-27 G 15-28 G 15-29 G 15-30 G 15-31 G 15-32 G 15-32A L 15-33A G 15-34A G 15-35 O 15-36 G 15-36A L 15-37A G,O 15-38 G 15-40A G 15-41B U 15-42A G 15-43 G 15-44 G 15-45A G 15-46 U 15-47 U 15-49A G 16-04A O 16-06A O 16-07 O 16-08A L 16-09A O 16-12A L 16-13 L 16-15 L 16-17 O 16-18 L 16-19 O 16-20 O 16-21 O 16-22 L 16-23A L 16-25 L 16-26A O 16-27A O 16-28 L 16-29A L 16-30 O 17-01 L 17-02 O 17-03A L Exhibit 7 -C PBU Gas Production Mechanisms Well Name Gas Mechanism Well Name Gas Mechanism Well Name Gas Mechanism L – Gas Below 3050 scf/stb G – Gas entering perfs from GOC or above U – Gas entering perfs from an underrun O – Gas entering perfs from another mechanism (channel, Sag, MI) 17-04AL1 O 17-05 O 17-07 O 17-09 L 17-11 O 17-12 L 17-13 L 17-14 O 17-16 O 17-19A O 17-20 O 17-21 L 17-22 L 18-02A G 18-04B G 18-05 G 18-06A G 18-07A G 18-08A G 18-09B G 18-10A G 18-11DPN G 18-12A G 18-13A G 18-14A G 18-16B G 18-18A G 18-19 G 18-20 G 18-21A G 18-22A G 18-23A G 18-24AL2 G 18-25A G 18-26A G 18-27C G 18-28 G 18-29B G 18-30 G 18-31 G 18-32A G 18-33 G 18-34 G A-01 L A-02 L A-04 G A-07 G A-09A G A-10 G A-12 L A-13 G A-14 L A-15 L A-18A L A-19 L A-20 L A-22 L A-23 G A-24 G A-26 G A-28 G A-29 G A-30 L A-32A L A-33 L A-34A L A-37 L A-38 L A-39 G A-40 L A-42 L A-43 G B-01 G B-02A G B-03B G B-04 U,G B-05B U, G B-06 U,G B-07 U,G B-08 U B-10 U B-12A G B-14 G B-16 U,G B-18 U,G B-19A U,G B-20 U,G B-21 G B-22A G B-23A U B-25 G B-26B G B-27A U,G B-29A G B-30 G B-30A G B-33A G B-35 G B-36 U C-01 G C-02 G C-03A G C-04A G C-05A U C-06A G C-07A G C-08A G C-09 G C-10 G C-11 G C-12A G C-13A G C-15 G C-17A G C-18A G C-19B G C-20B G C-21 G C-22 G C-24 G C-25A G C-26A G C-27A G C-28 G C-29A O C-30 U C-31A G C-33A G C-34 U C-35A O C-36A G C-37A U Exhibit 7 -C PBU Gas Production Mechanisms Well Name Gas Mechanism Well Name Gas Mechanism Well Name Gas Mechanism L – Gas Below 3050 scf/stb G – Gas entering perfs from GOC or above U – Gas entering perfs from an underrun O – Gas entering perfs from another mechanism (channel, Sag, MI) C-39 U C-41 G C-42 G D-01A U D-03A U D-04A U D-05 U D-06A U D-07A U D-09A U D-10 G D-11A G D-12 G D-13A U D-14A U D-15A G D-16 U D-18A U D-19B U D-20 U D-21 U D-22A G D-23A G D-24 G D-25A U D-26A U D-27 U D-28AL1 G D-29 U D-30 G D-31A G D-33 U E-01 G E-02A G E-03 U E-04A G E-05A G E-06A L E-07A G E-08 G E-09A G E-10A G E-12 U E-13A G E-14A O E-15B G E-16 G E-17 G E-18A G E-19A G E-20 G E-21A G E-23B G E-24B G E-25 G E-26A O E-27A G E-28A G E-29 G E-31 G E-32A G E-33 G E-34 O E-35A G E-36 G E-37 G E-38 O E-39 O F-01 U F-02 G F-03A G F-04 G F-05 G F-08 G F-09 G F-11A U F-12 G F-13A U F-14 O F-15 G F-16A U F-17A G F-21 L F-22 G F-23A U F-24 U F-26A U F-27 U F-28 U F-29 G F-31 G F-32 O F-34A G F-35 G F-36 O,G F-37 G F-39 O,G F-40 U F-41 G F-42 G F-43L1 O,G F-44 G F-45 U F-46 G F-47A U F-48 O G-01A G G-02A G G-03A O G-04A O G-05 O G-07 O G-08 G G-09A U G-10A G G-11A O G-12A G G-13A G G-14A G G-15A O G-16 G G-17 G G-18A G G-19A G G-21 G G-23A G G-24 G G-25A G G-26A O G-27 G G-29A G G-30A O Exhibit 7 -C PBU Gas Production Mechanisms Well Name Gas Mechanism Well Name Gas Mechanism Well Name Gas Mechanism L – Gas Below 3050 scf/stb G – Gas entering perfs from GOC or above U – Gas entering perfs from an underrun O – Gas entering perfs from another mechanism (channel, Sag, MI) G-31A G G-32A G H-04 G H-05 G H-06 U H-07A G H-08 G H-11 U H-13 G H-14A U H-15 G H-16B O H-17A G H-19B G H-20 G H-21 G H-22A U H-23A G H-24 U H-25 G H-26 G H-27 G H-28 G H-29A G H-30 G H-32 U H-33 G H-34 U H-35 G H-36A G H-37A O J-01A G J-02A G J-03 G J-05B G J-09A G J-10 U J-11A G J-12 G J-13 G J-14 U J-14A G J-15A U J-16 G J-17A U J-18 G J-19 G J-20A U J-21 G J-22A G J-23 G J-24A G J-25 G J-26 G J-27 G J-28 G JX-02A G K-01 G K-02B O K-03A G K-04A O K-05A G K-06A G K-07C O K-08 G K-09B G K-10A G K-11 G K-12A G K-14 O K-16A G K-19A G K-20A G L-01 L L2-03A L L2-07 G L2-11 G L2-13A L L2-18A G M-04 O M-05A L M-06A O M-07 O M-08 O M-10 O M-11 O M-12A O M-15 O M-16 O M-17A L M-19A O M-21A O M-22 L M-23 O M-24 O M-24A O M-25 O M-26A L M-31 O M-32 O M-33 O M-34 O N-01 G N-04A G N-06 G N-09 G N-10A L N-11B O N-12 G N-13 U N-14A G N-15 G N-16 G N-17 U N-18 U N-19 G N-20A L N-21A O N-22A G N-24 G N-25 U N-26 O P-01 L P-04L1 O P-05A L P-06A L P-07A L P-08A L P-09L1 L P-11 L P-12B L P-15 L Exhibit 7 -C PBU Gas Production Mechanisms Well Name Gas Mechanism Well Name Gas Mechanism Well Name Gas Mechanism L – Gas Below 3050 scf/stb G – Gas entering perfs from GOC or above U – Gas entering perfs from an underrun O – Gas entering perfs from another mechanism (channel, Sag, MI) P-16 L P-17 L P-18 L P-19 L P-20B L P-21B L P-25 L P-26 L Q-01A U Q-02A U Q-03A U Q-04A U Q-05A U Q-06A G Q-07A U R-04 G R-08 L R-09A L R-10 O R-12 G R-14 O R-16 L R-17A O,L R-18B L R-19A L,O R-21 L R-23A L,O R-24 O R-26A L R-27 G R-28 O R-29A O R-30 O R-31 O R-35 O R-39A O R-40 O,L S-01B O,L S-02A L S-03 L S-05A O S-07A O S-08B O S-12A O S-13 O S-16 O S-17AL1 O S-19 O S-21 O S-23 L S-26 O S-28A O S-29A L S-30 O S-32 O S-33 O S-35 O S-36 O S-37 O S-38 O S-40A O S-41 O S-42 O S-43 L S-44L1 O U-02A L U-08A O U-09A O U-11B G U-13 O U-14 L W -01 U W -04 U W -05 L W -06A G W -07 L W -08 L W -09 L W -11 L W -12A L W -15 L W -16 L W -18 L W -19A L W -20 U W -21A L W -22 O W -23 L W -24 L W -25 U W -26A L W -27 L W -29 L W -31 U W -32 L W -35 G W -36 G W -38 L X-01 L X-02 G X-03A G X-04 G X-05 G X-07 L X-08 L X-10 L X-12 L X-13A L X-14A L X-15A L X-16 G X-17 G X-18 L X-19B L X-21A L X-22 L X-22A L X-25 L X-27 G X-30 L X-31 L X-32 L X-34 L X-35 L Y-01B O Y-02 O Y-02A O Y-04 O Y-09A L Y-13 O Y-14B O Y-15A O Exhibit 7 -C PBU Gas Production Mechanisms Well Name Gas Mechanism Well Name Gas Mechanism Well Name Gas Mechanism L – Gas Below 3050 scf/stb G – Gas entering perfs from GOC or above U – Gas entering perfs from an underrun O – Gas entering perfs from another mechanism (channel, Sag, MI) Y-16 O Y-17B L Y-19 O Y-20A O Y-21A L Y-23A O Y-25 O Y-26A O Y-28 O Y-29A L Y-30L1 O Y-32L1 O Y-33 O Y-36 L Y-37 O Y-38 L Z-01 L Z-03 G Z-05 L Z-06 G Z-08A L Z-11 G Z-12 G Z-13 L Z-15 G Z-16 L Z-17 L Z-18 L Z-21A L Z-22B L Z-23A L Z-24 L Z-25 L Z-26 G Z-27 L Z-28 L Z-29 U Z-30 U Z-32B L Z-32BL1 L Z-35 L Z-38 L Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum F-26A 500292198701 Oil Producer Flowing 05-Jan-01 1900 8800 10254 197 3097 3097 R-10 500292061800 Oil Producer Shut-in 07-Jan-01 1850 8800 10063 203 2771 2771 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 Unit or Lease Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 1 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum R-12 500292092100 Oil Producer Gas Lift 09-Feb-01 1800 8800 10718 211 3379 3379 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 2 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum 16-06 500292058400 Oil Producer Shut-in 17-Mar-01 725 8600 9347 194 3999 3999 G-13A 500292060001 Oil Producer Flowing 21-Mar-01 1825 8800 9179 194 2593 2593 Z-21A 500292193801 Oil Producer Gas Lift 22-Mar-01 1300 8799 10854 232 3763 3763 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 3 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum 01-10 500292016900 Oil Producer Flowing 05-Apr-01 1500 8802 9465 198 3281 3281 04-30 500292134500 Oil Producer Flowing 06-Apr-01 700 8600 9953 181 3316 3379 G-30A 500292161301 Oil Producer Flowing 06-Apr-01 2300 8800 9410 195 3224 3224 01-16 500292028800 Oil Producer Flowing 20-Apr-01 2400 8780 10121 189 3258 3261 01-28 500292159700 Oil Producer Flowing 20-Apr-01 2300 8801 10060 189 3268 3267 01-32 500292162200 Oil Producer Flowing 21-Apr-01 2350 8801 8955 193 3284 3283 09-51 500292232000 Oil Producer Gas Lift 28-Apr-01 2150 8800 11404 188 3353 3353 Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 4 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum R-14 500292090900 Oil Producer Shut-in 01-May-01 1890 8800 10136 206 3230 3230 05-10B 500292026302 Oil Producer Shut-in 04-May-01 1500 8514 8905 185 3126 3220 16-31 500292228000 Oil Producer Shut-in 07-May-01 1800 8820 11590 195 3407 3403 T-01 500292124100 Water Injector Shut-in 07-May-01 200 8800 10551 135 2672 2672 02-31A 500292222701 Oil Producer Flowing 08-May-01 2350 8700 9146 185 3293 3301 A-01 500292010800 Plugged Back for Redrill 08-May-01 1900 8800 8868 221 3240 3240 M-05A 500292019401 Oil Producer Gas Lift 09-May-01 1959 8800 12162 229 3355 3355 X-01 500292039000 Oil Producer Gas Lift 10-May-01 1900 8800 8935 226 3314 3314 X-10 500292046700 Oil Producer Gas Lift 10-May-01 2200 8800 10591 223 3395 3395 05-25B 500292198802 Oil Producer Flowing 11-May-01 2350 8800 9644 187 3279 3279 06-20 500292079900 Oil Producer Flowing 12-May-01 2200 8810 9608 203 3289 3284 A-14 500292060500 Oil Producer Gas Lift 15-May-01 1950 8800 9461 220 3344 3344 A-23 500292071600 Oil Producer Flowing 15-May-01 2200 8800 11388 224 3285 3285 A-30 500292137200 Oil Producer Gas Lift 15-May-01 1775 8800 10833 225 3337 3337 11-23A 500292161001 Oil Producer Flowing 19-May-01 1700 8605 11132 176 3348 3415 03-29 500292111800 Oil Producer Flowing 20-May-01 2000 8600 9490 179 3166 3193 03-32A 500292114101 Oil Producer Gas Lift 20-May-01 2100 8700 9341 164 3433 3468 04-24 500292150800 Oil Producer Flowing 21-May-01 2390 8600 11151 177 3358 3448 04-35 500292214700 Oil Producer Flowing 21-May-01 2350 8600 9968 176 3304 3382 H-28 500292180600 Oil Producer Shut-in 21-May-01 2650 8800 11886 207 3211 3211 04-07 500292018900 Oil Producer Shut-in 22-May-01 2500 8699 9166 137 3334 3360 N-06 500292009800 Oil Producer Shut-in 24-May-01 1060 8800 10720 10720 10720 J-03 500292002500 Oil Producer Flowing 31-May-01 700 8800 9894 210 3177 3177 Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 5 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum 02-14 500292044600 Oil Producer Flowing 02-Jun-01 2500 8800 9559 196 3301 3301 G-24 500292167100 Oil Producer Flowing 02-Jun-01 2250 8800 10105 195 3055 3055 03-09 500292036200 Oil Producer Flowing 07-Jun-01 1700 8614 11318 188 3310 3358 16-25 500292227000 Oil Producer Gas Lift 07-Jun-01 1600 8800 9138 198 3694 3694 16-22 500292204000 Oil Producer Gas Lift 08-Jun-01 1580 8800 13800 192 3339 3339 Y-32L1 500292214960 Oil Producer Gas Lift 08-Jun-01 0 8800 12357 216 3374 3374 03-01 500292018700 Oil Producer Gas Lift 09-Jun-01 1000 8700 9518 190 3322 3365 03-30 500292112200 Oil Producer Gas Lift 10-Jun-01 340 8800 9302 185 3292 3293 09-34A 500292132901 Oil Producer Gas Lift 10-Jun-01 1720 8790 11047 185 2511 2513 11-34 500292251600 Oil Producer Flowing 10-Jun-01 2420 8500 10325 177 3288 3318 17-03A 500292049201 Oil Producer Gas Lift 11-Jun-01 1960 8800 10745 207 3362 3362 17-09 500292061700 Oil Producer Gas Lift 11-Jun-01 1100 8800 9664 204 3249 3249 17-12 500292126000 Oil Producer Gas Lift 11-Jun-01 310 8850 11686 202 3265 3244 17-21 500292230800 Oil Producer Gas Lift 11-Jun-01 2020 8800 9734 202 3440 3440 09-26 500292109100 Oil Producer Gas Lift 12-Jun-01 1930 8700 9532 182 3325 3370 09-44 500292208700 Oil Producer Gas Lift 12-Jun-01 1500 8800 11005 187 187 3037 09-47 500292209800 Oil Producer Gas Lift 12-Jun-01 1980 8800 10486 179 3301 3301 17-14 500292119000 Oil Producer Gas Lift 12-Jun-01 1500 8800 11777 198 3138 3137 09-04A 500292021201 Oil Producer Flowing 13-Jun-01 2130 8721 9650 187 3236 3265 16-06A 500292058401 Oil Producer Gas Lift 15-Jun-01 1850 8799 9566 196 3875 3875 16-23A 500292205001 Oil Producer Gas Lift 15-Jun-01 1840 8766 11468 194 3444 3459 09-30 500292141100 Oil Producer Gas Lift 16-Jun-01 1200 8800 12152 188 3334 3334 17-22 500292300000 Oil Producer Gas Lift 16-Jun-01 650 8800 10869 202 3443 3444 09-24 500292142800 Oil Producer Flowing 18-Jun-01 1450 8811 12553 181 2827 2824 03-30 500292112200 Oil Producer Gas Lift 19-Jun-01 750 8800 9302 183 3341 3340 R-18B 500292063302 Oil Producer Gas Lift 20-Jun-01 1760 8700 9517 193 2334 2346 Y-23A 500292159001 Oil Producer Gas Lift 30-Jun-01 0 8800 11173 203 3398 3398 Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 6 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum 09-14 500292024900 Miscible Injector Operating 04-Jul-01 0 8749 10633 150 3376 3398 H-09 500292048200 Miscible Injector Operating 11-Jul-01 0 8800 9760 140 3371 3371 G-19A 500292159901 Oil Producer Flowing 24-Jul-01 2200 8800 11250 204 3186 3186 G-17 500292061900 Oil Producer Flowing 25-Jul-01 2300 8800 11088 198 3245 3245 S-17AL1 500292114860 Plugged Back for Redrill 25-Jul-01 1200 8800 10104 228 3370 3370 Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 7 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum G-14A 500292064601 Oil Producer Flowing 02-Aug-01 0 8800 9392 195 3214 3214 G-09A 500292058201 Oil Producer Flowing 04-Aug-01 2110 8800 10039 198 3204 3204 W-31 500292190000 Oil Producer Flowing 05-Aug-01 2700 8800 11494 232 3688 3688 15-31 500292228500 Oil Producer Flowing 06-Aug-01 2300 8700 10131 189 3293 3325 F-42 500292210800 Oil Producer Flowing 24-Aug-01 1900 8800 11156 198 3230 3230 H-14A 500292058001 Oil Producer Flowing 26-Aug-01 1950 8800 10495 213 3200 3200 W-44 500292197500 Water Injector Injecting 28-Aug-01 1900 8700 12300 168 3683 3722 F-15 500292065100 Oil Producer Flowing 04-Sep-01 1800 8800 9328 198 3216 3216 Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 8 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum F-15 500292065100 Oil Producer Flowing 04-Sep-01 1800 8800 9328 198 3216 3216 F-22 500292195100 Oil Producer Flowing 04-Sep-01 1850 8800 9498 195 3204 3204 F-40 500292221500 Oil Producer Flowing 04-Sep-01 2175 8800 10436 203 3173 3173 F-05 500292009500 Oil Producer Flowing 05-Sep-01 2340 8800 11170 197 3250 3250 F-24 500292103000 Oil Producer Gas Lift 05-Sep-01 2350 8800 11913 205 3211 3211 F-32 500292193000 Oil Producer Flowing 05-Sep-01 2060 8623 10075 186 2837 2852 F-39 500292210100 Oil Producer Gas Lift 06-Sep-01 1745 8800 13696 205 3204 3204 W-36 500292186500 Oil Producer Flowing 19-Sep-01 2740 8800 9411 224 3645 3645 W-06A 500292182201 Oil Producer Flowing 20-Sep-01 2300 8800 13049 220 3595 3595 W-18 500292188000 Oil Producer Gas Lift 22-Sep-01 1930 8800 9208 233 3489 3489 N-12 500292055700 Oil Producer Gas Lift 23-Sep-01 1510 8800 9638 222 3197 3197 W-12A 500292202301 Oil Producer Gas Lift 24-Sep-01 1590 8300 12818 219 2833 3033 W-26A 500292196401 Oil Producer Gas Lift 24-Sep-01 2330 8800 12502 230 3598 3598 Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 9 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum Y-01B 500292039402 Oil Producer Gas Lift 10-Oct-01 2050 8803 12444 218 3201 3201 Y-02A 500292039501 Oil Producer Gas Lift 10-Oct-01 1750 8798 10361 222 3073 3073 Y-30L1 500292213560 Oil Producer Gas Lift 10-Oct-01 1645 8800 9090 225 3293 3293 H-37A 500292277201 Oil Producer Gas Lift 12-Oct-01 1845 8800 10439 229 2811 2811 P-15L1 500292212060 Oil Producer Gas Lift 12-Oct-01 380 8800 12112 3343 3343 09-23A 500292106601 Oil Producer Gas Lift 14-Oct-01 1950 8800 15853 191 3136 3137 16-29A 500292227201 Oil Producer Gas Lift 15-Oct-01 1810 8799 11952 202 2959 2969 R-19A 500292063701 Oil Producer Gas Lift 16-Oct-01 1030 8800 13316 198 2130 2130 S-08B 500292077802 Oil Producer Gas Lift 16-Oct-01 540 8700 9129 222 3132 3176 09-04A 500292021201 Oil Producer Flowing 18-Oct-01 100 8721 9650 187 3301 3300 P-25L1 500292274260 Oil Producer Gas Lift 19-Oct-01 280 8796 9781 225 3456 3458 U-14 500292238600 Oil Producer Gas Lift 19-Oct-01 1440 8802 9178 232 3273 3273 09-42A 500292205901 Oil Producer Gas Lift 22-Oct-01 2300 8800 10488 182 3256 3256 B-22A 500292075901 Oil Producer Shut-in 22-Oct-01 625 8800 10464 215 3264 3264 D-04A 500292005601 Oil Producer Shut-in 22-Oct-01 250 8800 10414 202 3260 3260 C-05A 500292012601 Oil Producer Flowing 23-Oct-01 50 8800 11661 211 3202 3202 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 10 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum 13-30 500292076800 Oil Producer Gas Lift 06-Nov-01 1970 8800 9404 220 3421 3421 P-07A 500292253501 Oil Producer Gas Lift 06-Nov-01 60 8800 12764 226 3516 3516 J-27 500292173300 Oil Producer Flowing 07-Nov-01 2320 8800 9274 209 3205 3205 12-05 500292039100 Oil Producer Shut-in 09-Nov-01 1740 8800 10382 203 3363 3363 14-02B 500292031802 Oil Producer Flowing 09-Nov-01 1150 8800 11348 213 3262 3262 Y-17B 500292092002 Oil Producer Shut-in 15-Nov-01 100 8800 10101 218 3288 3289 L-01 500292301100 Oil Producer Gas Lift 18-Nov-01 1750 8800 9191 235 3935 3935 Pressure Test Data Name of Operator BP Exploration of Alaska I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Page 11 Exhibit 8 State of Alaska Alaska Oil Gas Conversation Commission Reservoir Pressure Report Gas Gravity Well Name API Number Well Status Test Date Final shut-in Tubing Pressure (PSIA) Depth Tool Ss Depth Tool Md Bh Temp Pres Tool Dpth (Pbar) Pres Datum H-04 500292010400 Oil Producer Shut-in 07-Dec-01 2400 8799 11616 211 3208 3208 Y-38 500292255300 Oil Producer Shut-in 20-Dec-01 1640 8800 10179 225 3310 3310 Oil Gravity 25.5 Address P.O. Box 196612, Anchorage, AK 99519-6612 I hereby cerify that the foregoing is true and correct to the best of my knowledge. Signed ______________________________________________________ Title______________________________ Date___________ Name Prudhoe Bay Field and Pool 11650/640149 Datum Reference 8800' TVDSS Pressure Test Data Name of Operator BP Exploration of Alaska Page 12 Exhibit 9 2001 Shut In Wells Sw Name Date Shut-In Reason for Well Shut-In 1 Current Mechanical Condition of Well 2 Future Utility Plans & Possibilities 3 Comments 01-01B Jun-93 E Coil cemented in liner & tubing 4 Poor economics to fix 01-05 Apr-98 D Annular com IAxOA xOOA 1 Evaluate for RWO/Sidetrack 01-17A Feb-97 A No known problems 1 Evaluate for Sidetrack 01-20 Jun-00 D Ann Comm 2 RWO Package Issued 01-30 Apr-97 D Annular com IAxOA 1 RWO or ST being evaluated 02-32A Jan-98 D CTD String cemented in well 2 Rig ST package issued 04-04A Apr-95 E No known problems 3 BHA stuck in window 04-07 Jan-97 B No known problems 6 MI inj/prod 04-21 Nov-99 D Tubing Leaks 2 RWO pending 04-34A Nov-97 B No known problems 6 May convert to inj 04-39 Apr-98 B No known problems 3 04-42 E Tbg X IA - Waivered 6 Did not need inj in '01 - waivered to inj in '02 - currently injecting 05-10B A No Known Problems 3 05-15B Dec-00 D TxIA Communication 2 Patch planned 05-35 D TxIA, IAxCretaceous leaks 3 06-06A Aug-96 D Coil tubing stuck in hole 1 Evaluating for sidetrack 06-22A Sep-99 D possible cretaceous leak 3 will evaluate in upcoming APE 07-06A May-00 D Severe tubing corrosion with multiple leaks 1 09-48 C No known problems 3 11-09A Aug-00 D Tbg X iA 3 May have utility as an injector 11-12 Jan-94 D Multiple tbg leaks 3 11-17 May-96 A Multiple tbg leaks 1 Will have sidetrack in '02 11-23A B No known problems 3 Possible future utility as injector 12-05 Feb-00 D TxIA Communication 2 RWO Package Issued 12-11 Feb-00 D IAxOA Comm 1 13-05 Nov-97 E T x IA & IA x OA communication 3 Well offsets reconfigured Z4 WAG injector, would thief MI from 13-06A 13-10 Sep-94 B T x IA X OA communication to A/L 3 May attempt to production test well in 2000 13-13 Aug-97 C T x IA and OA x Form communication 6 Evaluating well for production test 13-17 D No known problems - Repaired in 12/01 RWO Complete 12/01 13-26 Feb-97 B IA x OA communication to A/L 3 1990 fracced into acquifer, well may have SAG potential 13-28 May-94 D T x IA X Form, cretaceous leak 3 Periphery producer 13-33 A, D TxIAxOA Communication - Capable of FTS 1 Review in '02 APE 14-18A May-00 B No Known Problems 1 Review in '02 APE 14-39 Jan-97 D IA x OA x Formation surf csg failure 5 Evaluate well for P&A 15-03 Nov-93 D Known cretaceous leak - ia loaded with gel/brine 3 Fish in hole 15-10A Feb-91 D IAxOA Comm 3 Annular Communication 15-24 Jan-95 D TxIA, IAxCretaceous leaks 3 Annular Communication 15-39 May-98 D leaking tubing cemented in place 3 probable P&A 15-48 Nov-00 D Hole in tubing 1 16-24 C No known problems 3 16-31 Apr-95 C 13-CR No known problems 1 MIST vertical drive candidate 18-01A Dec-99 D annular communication 1 eval possible sidetrack 18-03A Nov-99 D annular communication 1 eval possible sidetrack 18-15B Jan-00 D annular communication 1 eval possible sidetrack 18-17 Oct-99 D annular communication 2 RWO issued 3-06 Jul-00 D collapsed tubing - plug in well 2 Rig WO in 2002 7-11A A No known problems 1 A-06 Dec-95 A & E Mechanically OK 6 No surface facilities- being used for A-43 A-25A C, D Not completed 3 A-41 Nov-00 D Cretaceous Leak 1 Evaluating for RWO / not high priority B-09 Aug-95 E Good Condition 1 SI for fault related injection. Well used for pit dewatering in the summer months. B-11 Nov-90 B, no flow line Good Condition-No surf. facilities 1 B-15 Nov-99 D tubing problems 1 B-17 May-00 A No known problems 1 B-24 Jan-93 D, and high WC Poor- tubing and packer problems 1 *Note - Wells were shut in 100% during 2001 Exhibit 9 2001 Shut In Wells Sw Name Date Shut-In Reason for Well Shut-In 1 Current Mechanical Condition of Well 2 Future Utility Plans & Possibilities 3 Comments B-28 E No known problems 1 Converted to MI inj in '99 - MI Pattern no longer injecting B-34 Nov-00 B No known problems 1 Evaluating conversion to injection C-16 Jan-98 D SI for H2O prod - leak detect log, hole in 9-5/8" csg, long term SI 3 C-36A sidetacked towards C-16 drainange area C-23A Oct-97 E CT and perf guns fish in hole, attempts to fish unsuccessful, no perforations, perf guns stuck following entire wellbore squeeze 3 C-06A sidetracked towards C-23A drainage area C-32A D Fish in hole 1 Evaluating sidetrack C-38 Nov-97 D Hole in 9-5/8" casing at 7575'3 D-04A Apr-96 A Flowline and Well House Removed 1 Evaluating sidetrack D-08 Nov-99 D collapsed tubing w/ possible hole 1 RWO/ST possiblility D-17A Nov-00 D Tbg x IA communication - FTS 3 E-11A Sep-00 D Collapsed Tubing 3 F-06 Dec-99 D hole in 9-5/8" needs new tubing 1 RWO Approved F-07 Jul-91 D collapsed tubing and casing - no flowline 3 F-10A Jun-00 C tubing problems 1 F-18 Sep-99 E No Known Problems 3 Old water injector - no plans F-19 Aug-97 E F-19 flowline corroded, tied into f-27/F- 28 flowline (only 2 can flow). converted to injector 3 Old water injector - no plans F-30 Aug-98 B Good Condition 1 Sag only F-33 Mar-98 C F-23 jumped over to F-33 flowlines. Must SI F-23 to flow F-33 3 F-38 May-00 D Corroded tubing 1 Evaluating sidetrack G-06 Dec-97 D Blown production packers 3 G-Pad LPA Frac'd well H-01A Jun-99 D CT fish in the tubing & a Cretaceous csg leak 3 H-02 Nov-93 E SSSV control line is broken. GLV is broken and leaking. 2 Sidetrack planned for 2002 H-12 May-91 D 9 5/8" casing is collapsed. Current tbg drift is < 2.5". 4 Cement plug pumped to isolate perfs on 7/22/94. H-18 Aug-00 D Tubing x IA Comm - OA leak to surface 1 Evaluating RWO J-04 Jan-87 D well has been cannabilized 5 should be on P&A list J-06 Aug-97 B Hydraulic problems 3 J-07A Jun-00 D Collapsed tubing 1 RWO Approved J-08 Nov-98 B Passed MIT/TIT 2 J-Pad GDWFI - Wellwork Plans K-05B E No known problems 6 Sidetrack in progress - came online Jan '02 K-13 Oct-97 D Casing Leak 3 K-17A Dec-98 B Good Integrity (new well)1 Handing over for Lisburne development M-27A Oct-98 D Frac fibers in tubing, 3 refracs attempted 1 N-03 Jan-96 D OA leaks, possible IAxOA communication 1 Marginal sidetrack opportunities N-07 Jul-00 C No known problems 2 Adperfs planned P-22 Dec-96 D Collapsed slotted liner 3 SI - Needs S-Riser. R-01 Nov-93 B, D Annulus leak 3 Replaced by R-39 R-13 Dec-00 A No Known Problems 1 S-10A --D No tubing 1 S-18 Sep-91 D Holes in tubing 3 S-25A Jun-00 D TxIA Communication 2 RWO Package Issued S-27A Apr-96 C OK Condition 3 T-01 Jul-99 E TxIA Communication 1 SI for res mgmgt T-07 Jul-99 E TxIA Communication 1 SI for res mgmgt U-06A B, C No known problems 3 U-07 Aug-93 B Moderate corrosion, no flowline 3 U-12 Feb-99 D Bad tubing and cement in hole 3 U-15A Sep-98 C Needs flowline.1 ST planned. W-02 Mar-99 E source water well for pilot 1 sidetracked in 12/01 W-03A Mar-99 E SI injector from pilot 2 evaluating wellwork potential W-10 Oct-94 B Good Condition 2 sidetracking in 2002 W-17 Feb-99 D mechanical problems 1 eval sidetrack potential W-30 Dec-98 A No known problems 1 possible sidetrack candidate in '02 W-34 Nov-96 A No known problems 6 converting to water injection in '02 W-37 Apr-98 D Tubing x IA Comm 1 possible wellwork opportunities *Note - Wells were shut in 100% during 2001 Exhibit 9 2001 Shut In Wells Sw Name Date Shut-In Reason for Well Shut-In 1 Current Mechanical Condition of Well 2 Future Utility Plans & Possibilities 3 Comments W-39 Dec-96 A Good Condition 6 waiting on WF start-up X-09A Nov-95 D Holes in tubing - no facilities 2 Sidetracked in 03/02 Y-07 Mar-98 D Failed casing integrity test - unidentified leak 3 Injector Y-08A Mar-94 C & D Failed tubing integrity test - unidentified leak 3 Not economic to troubleshoot/fix - no flowline, would need to twin Y-12 May-99 D Comm. From tbg to outer annulus 3 currently uneconomic Y-18 Mar-99 C Line Corrosion 2 Bringing back online in '02 Y-24 Aug-98 D Tubing or casing/packer leak 1 RWO in 2001 - Online in Feb '02 Y-31 Mar-94 B Good integrity 3 Swept when drilled Y-34A May-99 D No Known Problems 3 Y-35 D CT Cemented in Hole 3 Z-02A Nov-98 D Leaking liner lap and holes in tub 1 possible sidetrack/RWO and return to service as injector Z-04 Oct-98 D Holes in tubing 1 possible sidetrack Z-07A Oct-98 C No known problems 3 low pi - low priority sidetrack Z-09 Oct-98 B Liner & Tubing holes 2 RWO planned to convert to inj in '02 Z-10 Oct-98 D well head problems 1 Z-14A Oct-98 B No known problems 1 sidetracking in 2002 Z-19 Jul-96 B&D Tubing Leak 3 Z-20 Feb-98 A Failed packerD 3 *Note - Wells were shut in 100% during 2001