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Home My WebLink About2004 Prudhoe Oil Pool March 9, 2005 John Norman, Chairman 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 - 2004 Dear Chairman Norman, 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, Gas Cap Water Injection Project and Field Gravity Drainage Area in accordance with the requirements of Conservation Order 341C (originally CO 279) and 341 D. This report covers the time period of January 1 through December 31, 2004. 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 Leslie Senden at 564-5488, sendenlb@bp.com. Sincerely, Carl Lundgren Reservoir Planning and Performance Team Lead Greater Prudhoe Bay 564-5256 Attachments: Exhibits 1 through 11 and Supplemental Information Cc: F. Sommer, BPXA S. Rix, ExxonMobil D. Kruse, CPAI G.P. Forsthoff, Chevron B. Brice, Forest Oil J. Williamson, AOGCC M. Kotowski, DNR T. Verseput, BPXA G. Beuhler, BPXA G. Pospisil, BPXA C. Lundgren, BPXA J. Buono, BPXA J. Rachford, BPXA L. Senden, BPXA D. Ronchetti, BPXA K. Binkley Sims, BPXA March 9, 2005 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 - 2004 Received by: ___________________________________________ ______________ Alaska Oil & Gas Conservation Commission Employee Date ANNUAL RESERVOIR SURVEILLANCE REPORT WATER AND MISCIBLE GAS FLOODS PRUDHOE OIL POOL JANUARY THROUGH DECEMBER 2004 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 2 CONTENTS SECTION PAGE 1.0 INTRODUCTION 5 2.0 OVERVIEW 6 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 11 4.6 Gas Cap Water Injection Project 12 4.6.1 Reservoir Pressure 4.6.2 Injector Status, Zonal Conformance, and Water Movement Surveillance 4.6.3 Reservoir Evaluation 4.6.4 2005 Surveillance Plans 4.6.5 Plans for Change in Project Operation 5.0 GAS MOVEMENT SURVEILLANCE 17 5.1 Gas Movement Summary 17 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 3 LIST OF EXHIBITS 1-A Prudhoe Bay Unit Field Schematic 1-B PBU Well Statistics 1-C PBU Production / Injection Statistics 1-D PBU Pressure Map 1-E Areally Weighted Average Pressure Plot 1-F Areally Weighted Pressure Pressure Data 1-G Average Monthly CGF MI Rates and Compositions 2 Fieldwide Reservoir Balance 3-A FS-2 Base Flood Map 3-B FS-2 Reservoir Balance 3-C FS-2 Areal Average Reservoir Pressure 3-D FS-2 Daily Average RMI 4-A EPWZ Base Flood Map 4-B EPWZ Reservoir Balance 4-C EPWZ Areal Average Reservoir Pressure 4-D EPWZ Daily Average RMI 5-A WPWZ Water / MI Flood Base Map 5-B WPWZ Reservoir Balance 5-C WPWZ Areal Average Reservoir Pressure 5-D WPWZ Daily Average RMI 6-A NWFB Base Flood Map 6-B NWFB Reservoir Balance 6-C NWFB Areal Average Reservoir Pressure 6-D NWFB Daily Average RMI 7-A EWE Base Flood Map 7-B EWE Reservoir Balance 7-C EWE Daily Average RMI 8 Wells Surveyed for Gas Movement 9 Pressure Surveys 10 SI Well List 11-1 PSI Daily Injection History 11-2 PSI Pressure Data 11-3 PSI Datum 11-4 Prudhoe Bay Pressure History-Ivishak 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 4 11-5 Prudhoe Bay Pressure History-GD 11-6 PSI-05 Perforations 11-7 PSI-07 Perforations 11-8 PSI-01 Injection Profile 11-9 PSI-06 Injection Profile 11-10 PSI-08 Injection Profile 11-11 PSI-09 Injection Proflie 11-12 PSI-10 Injection Profile 11-13 GCWI Water Movement Surveillance Supplemental Information: RST Logs for PSI-05, PSI-07, L2-32, L3-02, L3-05, L5-05, L5-09, and L5-15. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 5 1.0 INTRODUCTION As required by Conservation Order 341C (Approved June 12th, 1997) and 341 D (Approved November 30th, 2001) 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. The time period covered is January through December of 2004. 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, including the gas cap water injection project • Voidage balance by month of produced and injected fluids • Data on Minimum Miscibility Pressure (MMP) of injected miscible gas • Summary of Returned Miscible Injectant (RMI) volumes • Results of gas movement and gas-oil contact surveillance efforts. • Results of pressure monitoring efforts • Table of wells shut-in during 2004 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), Eileen West End (EWE). Information on the Gravity Drainage region is included also. Water and miscible gas floods are described in each section. Also, a separate section has been provided with detailed information on gas-oil contact surveillance. The wells in each polygon were reviewed during the preparation of this report. Some wells were moved from their previously reported polygon, to more closely match the polygons used in the Prudhoe full field model. As agreed with the Commission, the Gas Production Mechanisms section was removed from the report. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 6 2.0 OVERVIEW Exhibit 1A identifies the five flood areas and gravity drainage areas in the Prudhoe Oil Pool as follows: FS-2, EPWZ, WPWZ, NWFB, EWE, and GD. The Waterflood Project encompasses all five flood areas. The Prudhoe Bay Miscible Gas Project (PBMGP) is currently active throughout the waterflood areas. The Eileen West End waterflood pilot concluded in March 1999, after successfully establishing EWE injection potential. Waterflood startup began in September 2001, EWE information is included in this report. Exhibits 1-B and 1-C provide well, production, and injection statistics for the major project areas included in this report. As in last years’ report, wells do not share project boundaries, but belong to a single project area. The well counts therefore reflect the total number of wells actually contributing to production and injection. Similar to last year, only wells that actually produced or injected during the year are included. During the report period of January through December 2004, field production averaged 350 MBOD, 7,906 MMSCFD (GOR 22,589 SCF/STB), and 1,125 MBWD (water-cut 76%). Waterflood project injection during this period averaged 1107 MBWD with 271 MMSCFD of miscible gas injection. Cumulative water injection in the five major projects from waterflood startup through December 2004 was 9,100 MMSTB, while cumulative MI injection was 2,593 BCF. Cumulative production since waterflood startup was 2,584 MMSTB oil, 7,663 BCF gas, and 5,786 MMSTB water. As of December 31, 2004, cumulative production exceeded injection by 3,441 MMRB compared to 3,028 MMRB at the end of 2003. 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 during 2004 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 and in the Sag Formation have been removed. The historic pressure decline appears to have stabilized with about one-third of the repeat pressure surveys actually increasing in the past 2 years. For mid-year 2004, average pressure in the PBMGP project areas was calculated to be 3,290 psia by areal weighting, as compared to 3,283 in July 2003. The GD area actually showed a slight pressure increase from 3,213 psia in 2003 to 3,239 in 2004. This pressure stabilization can be attributed to several factors, including increased injection throughout the project areas and a change in the way the average pressure was calculated, which is explained on page 7. Confirmed MI breakthrough has occurred in 164 wells during the reporting period. RMI production is an indicator of EOR pattern performance and the presence of RMI is determined by gas sample analyses that show a separator gas composition richer in intermediate range hydrocarbon components. MI breakthrough in a well is considered to have occurred when the average RMI rate over the number of producing days in a well exceeds 200 mcf/d. The previous year showed MI breakthrough in 193 wells. Decrease in RMI can be attributed to the fact that MI is being injected into fewer and more efficient wells. Exhibit 1-G shows the 2004 average monthly CGF MI rates and compositions for the field. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 7 3.0 PRESSURE UPDATE 3.1 Pressure Monitoring Exhibit 9 provides pressure, buildup, and falloff data collected in 2004 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 don’t 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. 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 8800' SS. It was agreed with the commission that the polygon pressures would be calculated differently in the 2004 report than they have been calculated in the past. Exhibit 1-D shows the 2004 pressure map, which includes the pressure points only from the wells in which pressure data was gathered in 2004. 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 2005 calls for collection of 90 pressure surveys fieldwide. The number of surveys proposed is equal to last year. Per administrative approval 341C.01, dated June 22, 1999, a summary of pressure surveys run during 2004 is presented in Exhibit 9. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 8 4.0 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 3-A. The locations of production and injection wells are shown with the EOR injection patterns identified. There were 118 producing wells and 65 injection wells that contributed to production/injection during 2004 within the FS-2 flood area. Production/injection data was calculated with the polygon boundaries slightly different from last year’s report. The new polygon boundaries include 17 additional wells which contribute an additional 11 mbd of oil production, and 16 mbd of water injection. The FS-2 waterflood area oil production averaged 44 MBOD for 2004 compared to 42 MBOD in 2003. Cumulative production since waterflood start-up through the end of 2004 is 975 MMSTB of oil, 3,406 BCF of gas, and 2,916 MMSTB of water. Injection rates averaged 681 MBWD and 111 MMSCFD in 2004. Since 12/31/03, the waterflood imbalance has increased from a cumulative under injection of 1,023 MMRB to 1174 MMRB under injected. During the report period, production exceeded injection by 150.3 MMRB. Under-injection is related to PWI volumes being insufficient to replace all of the production volumes. Most of the increased under-injection occurred early in 2004 prior to conversion of DS11 to Sea Water Injection (SWI). The additional water from DS11 SWI improved flood balance from the second quarter of 2004 through, the remainder of the year. Waterflood strategy is to replace voidage on a zonal basis by obtaining additional SWI by converting DS04 to SWI in addition to DS11. Cumulative water injection since waterflood start-up through the end of 2004 is 4,725 MMSTB. The flood area's GOR increased from an average of 14,259 SCF/STB in 2003 to an average of 15,530 SCF/STB in 2004, with slight improvement seen after converting DS11 to SWI. Gas influx continues along the FS02/GD GDWFI area, and in the high permeability conglomerates in the Updip Victor area. Water-cuts remained steady at 92% in 2004. A breakdown of the production and injection data is provided in Exhibit 3-B for the report period. See Exhibit 1-C for a comparison of the cumulative figures with last year’s AOGCC report. Exhibit 3-C presents the areal average waterflood pressure decline over time. The pressure in the FS2 area was 3,277 psia in 2004. This is a decrease of 8 psi over the 2003 pressure. Exhibit 3-D is a presentation of 2004 average returned MI (RMI) rates. Miscible gas return has been confirmed in 42 wells by gas compositional analysis (RMI>200 MSCFD). 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 9 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 2004, oil production averaged 23.9 MBOD with an average 94% water cut and 17,008 SCF/STB Gas Oil Ratio. Injection averaged 186.4 MBWD and 49 MMSCFD of miscible injectant (MI). There are a total of 71 producers and 33 injectors in the flood area that contributed to production/injection during 2004. Of the 33 injectors, 8 injected miscible gas at some point throughout the year, while the remaining wells injected water only. Production and injection values have been calculated using polygon boundaries slightly revised from last year’s report. The net effect of the new polygon definitions resulted in nine wells moving in EPWZ and nine moving out. This resulted in an increase of 4 mbd of oil production, and a decrease of 7 mbd of water injection in the polygon. Two waterflood start-up dates have been used, 12/30/82 for the DS13 flood and 8/20/84 for the down-dip sections, rather than the start-up dates of each injection pattern. A total of 571 MMSTB of oil, 1,903 BSCF of gas, and 1,149 MMSTB of water have been produced with 1,628 MMSTB of water and 586 BSCF of miscible gas injected. Exhibit 4-B shows the monthly injected and produced volumes on a reservoir barrel basis during 2004 and provides cumulative volumes since injection began. During the report period, production exceeded injection by 121.9 MMRB. Exhibit 4-C shows the trend of reservoir pressure decline in the EPWZ flood area with time. The area receives pressure support from pattern injection, some aquifer influx, and GCWI. Faulting and out of zone injection can impair flood performance in some areas. Areas of low pressure are being addressed by flood management strategies designed to increase voidage replacement. The EPWZ pressure was 3,324 psia in 2004. This is an increase of 18 psi since 2003. Exhibit 4-D shows the 2004 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 37 wells (RMI <200 MSCFD). 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 10 4.3 Western Peripheral Wedge Zone Water / MI Flood Project Exhibit 5-A is a map of the WPWZ water and miscible gas flood areas. During the report period oil production averaged 27.7 MBOD at a gas/oil ratio of 8,310 SCF/STB and a watercut of 84%. Injection averaged 118.4 MBWD of water and 41.5 MMSCFD of miscible injectant. For the WPWZ project, 37 injectors (13 WAG injectors and 24 water injectors), and 101 producers contributed to the production and injection during 2003. 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 2004 was 1,339 MMSTB while cumulative MI injection was 514 BSCF. Cumulative production since waterflood start-up is 453 MMSTB oil, 1,124 BSCF gas, and 861 MMSTB water. As of December 31, 2004 cumulative production exceeded injection by 498 MMRB. Exhibit 5-B provides the monthly injection and production data from 01/03 through 12/03. During the report period, production exceeded injection by 80.8 MMRB. During 2001, WPWZ injection targets were modified to take into account aquifer influx occurring along the GDWFI boundary, and super pattern management of the WPWZ waterflood to stabilize the GOC. The reservoir balance in Exhibit 5-B doesn’t identify support from the aquifer, thereby understating voidage replacement. Exhibit 5-C shows that the pressure in the WPWZ was 3,281 psia in 2004. This is an increase of 36 psi over the pressure reported in 2003. This can be attributed to the fact that this area gained 14 wells in the current reporting period, mostly higher pressured wells that were previously included in the gravity drainage area. Exhibit 5-D indicates wells with MI breakthrough and the 12-month averaged returned MI rates. Miscible gas breakthrough has been confirmed in 53 wells by gas compositional analysis. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 11 4.4 Northwest Fault Block Water / MI Flood Project Exhibit 6-A is a map of the NWFB WAG flood areas. During the report period, oil production averaged 17.9 MBOD at a gas/oil ratio of 7,335 SCF/STB and a watercut of 84%. Injection averaged 113.4 MBWD and 48 MMSCFD of miscible injectant. For the NWFB project, 32 injectors (9 WAG injectors and 23 water injectors), and 76 producers contributed to the production and injection during 2004. 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, rather than of each injection pattern and using last year’s polygon boundary. Cumulative water injection from waterflood start-up in August 1984 through December 2004 was 1,393 MMSTB while cumulative MI injection was 638 BCF as detailed in Exhibit 61-C. Cumulative production since waterflood start-up was 560 MMSTB oil, 1,063 BSCF gas, and 783 MMSTB water. As of December 31, 2004 cumulative production exceeded injection by 276 MMRB. Exhibit 6-B provides the monthly injection and production data from 01/04 through 12/04. During the report period, production exceeded injection by 28 MMRB. However, this does not include support obtained from aquifer influx or gas cap expansion. The areally weighted pressure in the NWFB area was 3,296 psia in 2004. This is an increase of 178 psi over last year. This increase is largely due to the fact that this polygon’s boundaries were expanded to the northwest. The presense of the aquifer is now affecting the pressure of the northwest fault block. The historical pressure trend can be seen in exhibit 6-C. Exhibit 6-D indicates wells with MI breakthrough and the 12-month average returned MI rates. Miscible gas breakthrough has been confirmed in36 wells by gas compositional analysis. 4.5 Eileen West End Waterflood Project Exhibit 7-A is a map of the EWE waterflood area. During the report period, oil production averaged 16.4 MBOD at a gas/oil ratio of 4,287 SCF/STB and water cut of 68%. Injection averaged 7.2 MBWD and 21.1 MMSCFD of gas. For the EWE project, 10 injectors (2 WAG injector, 6 water injectors, 2 gas injectors), and 58 producers contributed to the production and injection during 2004. The well counts reflect only the active wells for the year. Cumulative water injection from waterflood start-up in September 2001 through December 2004 was 15 MMSTB. Cumulative production since waterflood start-up was 25 MMSTB oil, 166 BCF gas, and 75 MMSTB water. As of December 31, 2004 cumulative production exceeded injection by 124 MMRB. Exhibit 7-B provides the monthly injection and production data from January 1, 2004 through December 31, 2004. During the report period, production exceeded injection by 30 MMRB. The EWE pressure was 3,614 psia in 2004. Average pressure decline for this area was 31psi/yr, based on pressures at the start of the report period, and mid year 2004. Exhibit 7-D indicates wells with MI breakthrough and the 12-month average returned MI rates. Miscible gas breakthrough has been confirmed in 5 wells by gas compositional analysis. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 12 4.6 Gas Cap Water Injection Project Details of the Volume of Water Injected during 2004 are detailed below; units in thousands of barrels of seawater injected per month (MBWM): Month PSI-01 PSI-05 PSI-06 PSI-07 PSI-08 PSI-09 PSI-10 Total Jan 3387 0 3330 0 3471 0 3370 13,559 Feb 1640 0 2879 0 2774 0 2512 9,806 Mar 1224 0 2381 0 2307 1104 2658 9,673 Apr 2802 0 2740 0 2537 1071 2845 11,995 May 2419 0 2447 0 2819 2200 3076 12,961 Jun 1153 0 2219 0 755 1774 2374 8,273 Jul 2815 0 2582 0 896 2785 2837 11,915 Aug 2386 0 2481 0 1287 2709 2706 11,568 Sep 1329 0 504 0 1106 1563 1607 6,108 Oct 2978 0 1397 628 1821 1703 2718 11,245 Nov 2965 986 2878 2490 2875 2871 2924 17,988 Dec 3152 2596 2979 2432 2885 3070 2712 19,827 Total 28,250 3582 28,818 5550 25,532 20,850 32,337 144,920 Exhibit 11-1 shows the GCWI history since project start up. While rates have been constrained by water supply throughout most of the project, recent operating improvements in the Sea Water Treatment Plant (STP) and the Sea Water Injection Plant (SIP) have allowed GCWI rates to exceed 650 MBWPD in 2004. Injection volumes are expected to fall again as the water plants become constrained by limitations on dissolved oxygen and total suspended solids limitations during the summer months. 4.6.1 Reservoir Pressure Static bottom hole pressure surveys (SBHP) were taken on five of the seven injectors in 2004. Both the pressure at gauge depth and the extrapolated pressure at 8800’ SS datum are given in the table below. Gauge Data 8800’ SS Datum Well Date Depth ‘SS Press (psi) Press (psi) PSI-01 08/28/04 8400’ 3369 3475 PSI-05 08/19/04 8400’ 3398 3504 PSI-06 08/29/04 8160’ 3301 3512 PSI-07 08/20/04 8370’ 3335 3454 PSI-09 10/21/04 8400’ 3390 3496 Exhibit 11-2 shows a map with all the SBHP’s run to date in the PSI injectors. The 2002 pressures were taken either before or shortly after Gas Cap Water Injection began, and therefore 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 13 represent the local gas cap pressure prior to GCWI. Initial pressures ranged between 3,325 psi and 3,401 psi at 8,400’ SS which extrapolate to 3,431 psi to 3,507 psi at the 8800’ datum. 2004 plans called for a SBHPS in each well, however only five of the seven injectors were successfully completed due to scheduling conflicts. One of the two wells skipped in 2004 (PSI- 10) was done the first week in 2005 and is included on the map in exhibit 11-2. The last well (PSI-08) will be done in the first quarter of 2005. The 2004 SBHP’s showed pressures increased in each well from 12 psi to over 50 psi from 2002 pressures. Incremental pressures since 2002 are noted in Exhibit 11-2. Extrapolating the PSI pressures to the 8800’ pressure datum of the Prudhoe field is not a straight forward process since BSAD lies around 8500’ SS in the PSI injectors. It does not fall below 8,800’ until nearly 4,000 lateral feet away. Exhibit 11-3 shows a schematic of how the 8,800’ SS extrapolation was made. A gas gradient was assumed down to the estimated GOC in the DS 18 area which varies from 8,575’ SS to 8,660’ SS. The range of DS 18 GOC results in nearly a 25 psi range in the 8,800’ SS pressure. Adding further uncertainty to the extrapolation is the presence of injected sea water. An assumption has to made as to how many vertical feet of water are below the gauge depth so the pressure can be corrected with the water gradient. At this point in the project, no water gradient correction was made since all the gauge depths were near 8400’ SS and surveillance logs showed little water below this depth. As more water reaches deeper into the formation in the future, this effect will significantly effect the uncertainty of the 8,800’ SS correction. Gauge pressures were first corrected to 8,400’ SS since all the SBHP’s were made very close to 8400’ SS. This allowed a good comparison of pressures over time without introducing the uncertainty of extrapolating to 8,800’ SS. To be consistent, the same correction (106 psi) was made to each of the 8,400’ SS pressures to obtain the pressure at the 8,800’ SS datum. The overall goal of the GCWI project is to slow the Prudhoe field pressure decline. To see this effect, all SBHP’s were pulled and plotted as shown in Exhibit 11-4. Because local waterflood pressures are quite variable, they introduce a wide scatter in the field pressure plot making interpretation of pressure trends difficult. To get a clearer picture of recent pressure trends, Exhibit 11-5 was made showing only the GD pressures. In this plot only the GD pads are included. In addition GDWFI areas and the low pressure area (LPA) at G Pad have also been excluded to help give a tighter grouping of pressures. The change in slope at waterflood start up is very pronounced with declines of 80 to 90 psi/ year pre- waterflood, dropping to approximately 35 psi/year after start up. The slope change is apparent only because there are long term stable trends both before and after waterflood start-up. Can the effects of GCWI be seen in the pressure trends at this point in time? While there appears to be a general flattening of the curve after GCWI start-up, there is not enough data to state with confidence that field pressure has changed significantly. More time and pressure points are required. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 14 4.6.2 Injector Status, Zonal Conformance, and Water Movement Surveillance Injector Status All five of the original GCWI injectors are in good mechanical condition and continue daily injection. Pressure-rate plots for each well are routinely monitored and show injectivity is quite healthy. Each of the five wells is capable of injecting over 100 MBWPD at injection pressures between 1,400 psi and 1,800 psi. PSI-05 and PSI-07 were drilled in the Fall of 2003 but didn’t begin injection until Fall 2004. Despite shooting only a limited amount of Zone 1B perfs, both wells continue to inject strongly with rates of 90 MBWPD at injection pressures near 2,000 psi. There are no plans at present to add additional perfs in either of these two wells. The current perfs will provide Zone 1 injection which the other wells have shown to be impossible once other zones open. Fig 6 and 7 show the PSI-05 and PSI-07 completions. 4.6.3 Injection Profiles and Zonal Conformance Temperature warmback surveys and injection profiles were run in 4 of the original 5 injectors in 2004. The surveys were run over the Ivishak formation and up to the West Sak sands around 6,200’ SS. These sands are the first significant sands that would likely show a temperature response if taking water. Each of the temperature warmback surveys clearly showed injection was contained within the Ivishak formation and there was no injection out of zone. This was the third warmback survey for each of these four wells since GCWI start-up and all have shown injection contained within the Ivishak. Multi-rate injection profiles were run in PSI-01, PSI-06, PSI-09, and PSI-10 in 2004. A profile was first made near minimum stable rate (40-50 MBWPD) then a second done at 100 MBWPD. Multi-rate profiles were run to see if the injection profile changed at various rates. All four multi-rate profiles showed there was no significant difference between the low rate profile and the high rate profile. Exhibits 11-8 through 11-12 show the results of all four multi-rate profiles. As expected Zones 3 & 2C dominate the injection due to higher permeability. These zones typically take around 60% of the total rate but range as high as 80% in PSI-09. Even PSI-10 takes 60% in the upper interval despite the fact that Zone 3 is truncated. In this area the Tango shales (23N and 24N) are thick and extensive and locally provide strong vertical barriers to the high perm Zones 2C & 3 above. Each of the spinners showed that anywhere from 10% to 30% of the injection is entering the Zn 2B sands between these shales. Significant injection is entering Zn 2A in PSI-01 and PSI-10 but not in PSI-06 or PSI-09. None of the four wells has any significant Zone 1 injection. The last of the original five injectors (PSI-08) had a low rate profile done in May 2003. It also showed the upper interval to be dominant taking 90% of the rate with trivial Zone 2A and B injection. There was no injection into Zone 1. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 15 Observation Well RST Survey Baseline RST’s were run over the Ivishak formation in 11 observation wells prior to GCWI start- up. Since then the 6 observation wells closest to the GCWI injectors have been repeatedly logged with RST’s to monitor water movement. All 6 wells are Lisburne producers with the Ivishak above the production packer behind multiple casing strings. By comparing the RST logs with the baseline log, the presence of water can be readily observed. This procedure has provided a very clear picture of water in the Ivishak formation and allows monitoring how quickly the water column builds. The RST surveillance program is providing clear high quality data with confidence. A print out of the RST evaluation for each Lisburne observation well is included as part of the report. Each RST evaluation shows the baseline log with overlays of subsequent repeat passes and an interpretation of the presence of water. The blue columns show where water has been found and how it grows over time. In 2004 3 RST’s were run in each of the Lisburne observations wells. The short time between logs was necessary to observe the shape of the flood front as it passes by the observation well. Water was initially seen on top of the 24N shale in L3-05 and L2-32 after one year of injection. Since that time water has continued to build in each well as shown on the logs. L2-32 also has water in Zone 2A on top of a large shale. Water first appeared in L3-02 in early 2004 sitting on top of both the 23N and 24N shales. Each of the wells has shown that the water first appears on top of the 23N and 24N shales and begins to slowly build height climbing from Zn 2B into Zones 2C and 3. To date no water has been found in Zone 1 in any of the offset Lisburne wells. Along with the offset Lisburne wells, PSI-05 and PSI-07 were used as additional observation wells for the year they sat waiting for injection to begin. A total of 4 RST’s were run in PSI-05 with only 3 run in PSI-07. Water was already present at the time of drilling in both wells. In each case water was sitting on top of significant shales in Zones 2A, 2B, and 2C. Subsequent RST’s in 2004 showed the water quickly climbing until each zone was filled. In all cases the sands filled from the bottom up with no indication of thief zones in either well. By the time these two wells were put on injection in the Fall of 2004, both wells were full of water from Zone 2A and above. PSI-07 also had a small amount of water in Zone 1B. A map summarizing the log data and water movement shows the GCWI injection wells, the Lisburne observations wells, and the presence of water at the end of 2004. Water has not been seen in L5-05, L5-09, or L5-15 to date. That’s not surprising since these wells are up dip with several parallel faults between them and the injectors. In addition L5-05 is truncated down to Zn 2A. Water Movement A model is currently being built with a refined grid that will allow the detailed evaluation of water movement in the gas cap area. This will allow a more detailed simulation of water movement to compare with the observed data. To date the water is behaving as expected with no significant issues. The most important conclusion that can be made from the observed data is the water first appears on top of the shales and fills from the bottom up. There hasn’t been a single instance where water appears to be 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 16 fingering across a thief or perched up high. But rather than a perfect piston flood front, the water appears to be slumping slightly with a thin leading edge running out front on top of major shales. Each successive log has shown the flood front building height from the bottom up. While the infill injectors PSI-05 and PSI-07 filled quickly demonstrating a sharp flood front, the Lisburne observation wells are taking significantly longer to fill. In 2005 the RST survey will be extended out past the first ring of observation wells. Current plans call for RST’s in L-28 and L2-18A in the first half of 2005. This will be the first repeat RST’s in these wells which are located 5,000’-6,000’ away from the nearest GCWI injector. Gravity Survey Baseline gravity surveys were completed in 2002 and 2003. Due to sea water supply constraints and limited 2003 injection, a gravity survey was not completed in 2004. The limited injection did not put enough water into the formation for the gravity survey to see above the noise. A gravity survey of all 320 points is planned for 2005 and should be completed by mid April. Final processing, modeling, and analysis will be completed in the third quarter. 4.6.4 Reservoir Evaluation The current reservoir model is an extracted area of the Prudhoe Bay Full Field Model using 60 acre grid cells. This scaling doesn’t permit detailed evaluation of water movement over the small area of water injection to date. A revised model is being constructed with a refined grid down to 100’ in the GCWI injector area. The grid size will increase in steps back up to 60 acres along the periphery of the model. Along with the local grid refinements, a new reservoir description is being created. All the surveillance data to date will be used during the history matching phase. The model is expected to be complete by the 3rd quarter of 2005. 4.6.5 2005 Surveillance Plans GCWI Injectors A SBHP will be obtained in each of the 7 GCWI injectors during 2005. In addition to the SBHP’s, temperature warmback surveys will be made in PSI-05 and PSI-07 to verify injection is confined to the Ivishak. This will be the first temp warmbacks on either well since injection began last Fall. The original 5 injectors have had 3 warmback surveys each and all have shown confinement to the Ivishak. 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 well. Observation Well RST’s RST’s will be run in 6-12 observations wells in 2005. This program will continue as it has in the past by running RST’s in several of the wells in the first ring of observation wells. The monitoring program will be extended to the second ring of observation wells during the first half of 2005 to ensure the leading edge of water is identified. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 17 A second round of RST’s will be conducted in late 2005 with the locations to be based on the results to date. Gravity Survey A gravity survey of all 320 points is planned for 2005 and should be completed by mid April. Final processing, modeling, and analysis will be completed in the third quarter. 4.6.6 Plans for Change in Project Operation No changes to the Gas Cap Water Injection plan are expected in 2005. 5.0 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. 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. 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 regionally continuous shales. Such lenses have been identified from neutron logs. Many lenses continue to exhibit oil drainage over time, while others appear isolated. 2004 ANNUAL RESERVOIR SURVEILLANCE REPORT PRUDHOE BAY UNIT Page 18 Exhibit 8 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 2004 through December 2004. A total of 114 gas-monitoring logs, all cased-hole logs were run in the PBU. Exhibit 1-BPBU Well StatisticsWELL COUNT BY FIELD AREAWPWZNWFBEWEFS2EPWZGD2003 AOGCC ReportProducers104 87 67 121 61 589Injectors47 36 9 70 37 51 -WAG13 12 3 12 12 2 -Water Only34 24 6 58 25 17 -Gas00000322004Producers101 76 58 118 71 485Injectors37 32 10 65 33 46 -WAG1392871 -Water Only24 23 6 56 25 12 -Gas0021133Production Well Status in 2004 -Newly Drilled003000 -Sidetracked or Redrilled4064241Gas Injection Well Status in 2004 -Newly Drilled000000 -Sidetracked or Redrilled000010WAG Injection Well Status in 2004 -Newly Drilled000000 -Sidetracked or Redrilled000100Water Injection Well Status in 2004 -Newly Drilled000000 -Sidetracked or Redrilled110000NOTES:(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-C2004 PBU Production/Injection StatisticsWaterflood TotalWPWZNWFBFS-2EPWZEWECumulative Production from WF Start-Up through 12/31/04Oil (MMSTB)453 560 975 571 25 2584Gas (BCF)1124 1063 3406 1903 166 7663Water (MMSTB)861 783 2916 1149 78 5786Cumulative Injection from WF Start-Up through 12/31/04Water (MMSTB)1339 1393 4725 1628 15 9100MI (BCF)514 638 839 586 16 2593Cumulative Balance from WF Start-Up through 12/31/03Cum Production (MMRB) 2100 1981 6117 3246 111 13555Cum Injection (MMRB) 1683 1735 5094 1998 17 10527Over/Under (MMRB) -363 -199 -919 -1177 -55.4 -3028Cumulative Balance from WF Start-Up through 12/31/04Cum Production (MMRB) 2237 2064 6554 3451 149 14456Cum Injection (MMRB) 1739 1788 5381 2082 25 11015Over/Under (MMRB) -498 -276 -1174 -1370 -124 -3441MI Breakthrough in Producing Wells> 200 mcfd44 36 42 37 5 164AVERAGE RATE DATA 2004ProductionOil (MBD)27.7 17.9 43.5 23.9 16.4 129.4Gas (MMSCFD)230.2 131.3 710.5 406.5 70.3 1548.8Water (MBD)144.1 95.3 540.1 183.6 35.0 998.2InjectionWater (MBD)118.4 113.4 681.3 186.4 7.2 1106.8Gas (MMSCFD)41.5 48.0 110.9 49.0 21.1 270.6AVERAGE RESERVOIR PRESSURE (psia)GDWPWZNWFBFS-2EPWZEWEFIELDWIDEBeginning of report period 1/04 3211 3228 3116 3271 3296 3637 3272Mid report period, 7/04 3239 3281 3296 3277 3324 3614 3290Pressure Decline (psi/6 month period) 29 53 180 6 28 -23 18Estimated Annual Decline (psi/yr) 57 106 360 12 56 -46 36Waterflood Project Area Exhibit 1-D 2004 PBU Pressure Map 3000310032003300340035003600370038003900PSIAExhibit 1-EAreally Weighted Average PressurePBMGP areal avg PGravity Drainage Exhibit 1-F Areally Weighted Average Pressure Table DATE FS2 EPWZ WPWZ NWFB GD PBMGP Dec-77 3935 4005 4016 3944 3999 3968 Jul-78 3870 3967 3978 3909 3963 3914 Dec-78 3832 3930 3944 3875 3933 3873 Jul-79 3813 3895 3911 3843 3901 3844 Dec-79 3791 3861 3879 3799 3871 3816 Jul-80 3799 3831 3848 3770 3856 3798 Dec-80 3852 3819 3822 3781 3823 3818 Jul-81 3881 3821 3799 3814 3809 3840 Dec-81 3880 3815 3799 3820 3793 3842 Jul-82 3872 3806 3800 3812 3778 3833 Dec-82 3850 3795 3797 3804 3762 3818 Jul-83 3831 3784 3792 3787 3745 3804 Jan-84 3814 3771 3783 3772 3728 3790 Jul-84 3796 3758 3777 3756 3711 3774 Jan-89 3779 3743 3771 3736 3695 3755 Jul-89 3760 3730 3763 3723 3678 3740 Jan-90 3732 3708 3731 3704 3658 3713 Jul-90 3708 3693 3716 3687 3641 3695 Jan-91 3680 3676 3694 3655 3623 3666 Jul-91 3642 3657 3673 3628 3605 3635 Jan-92 3617 3641 3652 3602 3588 3615 Jul-92 3591 3626 3632 3577 3570 3593 Jan-93 3561 3600 3619 3544 3549 3582 Jul-93 3543 3595 3598 3515 3531 3565 Jan-94 3539 3555 3578 3483 3512 3537 Jul-94 3523 3536 3555 3456 3492 3516 Jan-95 3496 3524 3555 3507 3482 3506 Jul-95 3473 3507 3536 3489 3466 3486 Jan-96 3466 3485 3497 3478 3446 3463 Jul-96 3450 3467 3472 3461 3430 3443 Jan-97 3446 3484 3460 3444 3404 3441 Jul-97 3429 3467 3438 3427 3387 3421 Jan-98 3452 3417 3417 3421 3379 3430 Jul-98 3435 3409 3394 3402 3363 3415 Jan-99 3445 3391 3382 3343 3339 3443 Jul-99 3429 3378 3360 3317 3323 3426 Jan-00 3406 3361 3372 3268 3294 3418 Jul-00 3390 3351 3353 3240 3273 3395 Jan-01 3366 3325 3325 3225 3274 3358 Jul-01 3360 3310 3309 3205 3257 3347 Jan-02 3325 3334 3289 3163 3270 3358 Jul-02 3312 3324 3273 3144 3245 3347 Jan-03 3299 3316 3262 3121 3236 3297 Jul-03 3285 3306 3245 3118 3223 3283 Jan-04 3271 3296 3228 3116 3211 3272 Jul-04 3277 3324 3281 3296 3239 3290 Exhibit 1-G2004 Average Monthly CGF MI Rates and CompositionsEOA MI Rate *MMP MW Average Monthly Mole%MCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/04 200,745 3,277 32.26 21.01% 33.30% 20.27% 22.81% 1.42% 1.18% 0.00%02/04 188,571 3,291 32.19 21.09% 33.04% 20.63% 23.28% 1.19% 0.76% 0.00%03/04 190,857 3,293 32.22 21.10% 33.65% 19.39% 23.75% 1.26% 0.84% 0.01%04/04 174,453 3,268 32.28 21.19% 32.89% 20.08% 24.09% 1.09% 0.65% 0.00%05/04 172,027 3,232 32.39 21.12% 32.63% 20.18% 23.92% 1.21% 0.92% 0.01%06/04 145,675 3,124 32.57 20.06% 32.57% 19.71% 24.89% 1.40% 1.37% 0.00%07/04 57,982 3,254 32.11 19.74% 34.47% 19.25% 23.68% 1.41% 1.45% 0.01%08/04 129,976 3,200 32.42 19.98% 34.05% 19.64% 21.74% 2.21% 2.36% 0.02%09/04 179,499 3,169 32.74 21.73% 31.58% 20.33% 23.73% 1.40% 1.23% 0.01%10/04 154,967 3,283 32.32 21.55% 33.00% 19.76% 23.74% 1.11% 0.84% 0.00%11/04 155,239 3,270 32.37 21.79% 32.29% 20.34% 24.17% 0.94% 0.43% 0.04%12/04 173,547 3,232 32.27 20.21% 33.69% 19.73% 23.52% 1.49% 1.31% 0.06%Average 159,588 3,243 32.35 20.97% 33.01% 20.00% 23.61% 1.33% 1.06% 0.01%WOAMI Rate *MMP MW Average Monthly Mole%MCFD PSI Mol Wt CO2 C1 C2 C3 IC4 NC4 C5+01/04 156,055 3,301 32.17 20.95% 33.65% 20.16% 22.65% 1.41% 1.17% 0.00%02/04 178,771 3,360 31.94 20.89% 34.06% 20.30% 22.83% 1.17% 0.75% 0.00%03/04 164,861 3,279 32.24 21.04% 33.27% 19.97% 23.66% 1.24% 0.81% 0.01%04/04 161,245 3,214 32.47 21.33% 32.09% 20.35% 24.47% 1.11% 0.66% 0.00%05/04 143,079 3,159 32.66 21.33% 31.52% 20.54% 24.42% 1.24% 0.94% 0.00%06/04 110,317 3,139 32.53 20.06% 32.81% 19.58% 24.71% 1.44% 1.39% 0.00%07/04 163,168 3,135 32.48 19.60% 33.37% 19.33% 24.30% 1.63% 1.76% 0.01%08/04 114,711 3,194 32.43 19.96% 34.00% 19.64% 21.82% 2.20% 2.35% 0.02%09/04 139,304 3,133 32.88 21.86% 31.02% 20.50% 23.96% 1.42% 1.25% 0.00%10/04 208,955 3,231 32.49 21.56% 32.29% 20.25% 23.67% 1.24% 0.98% 0.00%11/04 223,403 3,264 32.40 21.85% 32.21% 20.26% 24.27% 0.94% 0.43% 0.04%12/04 257,037 3,232 32.27 20.21% 33.69% 19.73% 23.52% 1.49% 1.31% 0.06%Average 167,971 3,227 32.39 20.93% 32.86% 20.06% 23.70% 1.34% 1.10% 0.02%* MMP data from 1986 Zick Correlation Exhibit 2Fieldwide Reservoir BalanceJanuary - December 2004Produced Fluids (MMRB)JanuaryFebruaryMarchApril MayJuneOil 15.8 14.7 15.5 14.5 14.2 13.2Free Gas 232.5 221.1 235.5 217.0 216.0 186.4Water 38.3 34.8 36.1 35.9 36.6 35.1TOTAL 286.6 270.6 287.2 267.4 266.8 234.7Injected Fluids(MMRB)Water 48.2 42.6 45.9 48.4 51.9 44.2Gas 221.5 212.9 225.8 208.7 207.8 180.3TOTAL 269.7 255.5 271.7 257.1 259.7 224.5Net Injection Volumes = Injection - Production (MMRB)TOTAL -17.0 -15.2 -15.4 -10.2 -7.1 -10.2Produced Fluids1/1/2004 -(MMRB)JulyAugust September October November December 12/31/2004Oil 13.2 12.7 11.5 12.2 14.3 14.5 166.3Free Gas 177.0 177.2 185.1 193.1 217.9 230.1 2,489.2Water 33.3 28.2 32.0 37.9 37.8 38.2 424.1TOTAL 223.5 218.1 228.6 243.2 270.0 282.8 3,079.6Injected Fluids(MMRB)Water 48.6 43.7 39.9 50.3 58.3 61.8 583.8Gas 175.7 169.6 178.2 203.7 213.0 223.7 2,420.8TOTAL 224.3 213.3 218.0 253.9 271.3 285.5 3,004.7Net Injection Volumes = Injection - Production (MMRB)TOTAL 0.8 -4.8 -10.6 10.7 1.3 2.7 -75.0 01-01A01-01B01-0601-06A01-0801-0901-09A03-0103-0203-0303-0403-0503-0603-0703-07A03-0803-0903-1003-1103-1203-1303-1403-1503-15A03-15AL103-1603-16A03-1703-1803-18A03-1903-2003-20A03-2103-2203-2303-2403-24A03-2503-25A03-2603-2703-2803-2903-3003-3103-3203-32A03-3303-33A03-3403-34A03-34B03-3503-3604-0104-0204-02A04-0304-0404-04A04-0504-05A04-0604-0704-0804-0904-1004-1104-11A04-1204-1304-1404-1504-1604-16A04-1704-1804-1904-19A04-2004-2104-2204-22A04-2304-23A04-2404-2504-2604-2704-2804-2904-29A04-29AL104-3004-3104-3204-32A04-3304-3404-34A04-3504-3604-3704-3804-3904-4004-4104-41A04-4204-4304-4404-4504-4604-4704-4804-4905-0505-05A05-05B09-0109-0209-0309-0409-04A09-0509-05A09-0609-0709-07A09-0809-0909-1009-1109-1209-1309-1409-1509-1609-1709-1809-1909-2009-2109-2209-2309-23A09-2409-2509-2609-2709-2809-28A09-2909-3009-3109-31A09-31B09-31C09-3209-3309-3409-34A09-3509-35A09-3609-36A09-36BL09-36C09-3709-3809-3909-4009-4109-4209-42A09-4309-4409-4509-4609-4709-4809-4909-5009-5111-0111-01A11-0211-0411-04A11-0611-0711-0811-0911-09A11-1011-1111-1211-1311-13A11-1511-1611-1711-17A11-1811-2211-22AL111-2411-24A11-2511-25A11-2611-2711-2911-3111-31A11-3211-3311-3511-3611-3712-0612-06A12-3216-0116-0216-0316-0416-04A16-0516-05A16-0616-06A16-0716-0816-08A16-0916-09A16-1016-10A16-1116-1216-12A16-1316-1416-14A16-1516-1616-1716-1816-1916-2016-2116-2216-2316-23A16-2416-2516-2616-26A16-2716-27A16-2816-2916-29A16-3016-3117-0117-01A17-0317-03A17-0417-04A17-04AL117-04B17-0517-0617-0717-07A17-0817-0917-1017-10A17-1117-1217-1317-1417-1517-15A17-1617-1917-2017-2117-22Exhibit 3-AFS-2 Base Flood Area Map Exhibit 3-BFS-2 Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2003 January February March April May JuneOil 1,258.9 1.933 1.776 1.840 1.764 1.804 1.528 Bo (rb/stb) 1.316Free Gas 2,046.8 19.411 18.904 19.618 18.702 19.021 16.119 Bg (rb/mscf) 0.889Water 2,811.5 17.795 16.967 17.637 17.235 17.991 15.234 Bw (rb/stb) 1.040TOTAL 6,117.2 39.138 37.647 39.095 37.701 38.815 32.881 Bmi (rb/mscf) 0.700Rs (scf/stb) 602.8Injected Fluids(MMRB)Water 4,561.5 19.820 19.805 21.127 20.786 23.185 19.709Gas 532.3 2.921 2.035 2.394 2.111 2.303 1.826TOTAL 5,093.8 22.741 21.840 23.521 22.897 25.487 21.535Net Injection Volumes = Injection - Production (MMRB)TOTAL -1,023.4 -16.4 -15.8 -15.6 -14.8 -13.3 -11.3Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2003Oil 1.528 1.622 1.651 1.681 1.740 1.752 1,279.5Free Gas 16.119 17.719 17.394 18.948 14.403 18.286 2,261.5Water 15.234 15.057 16.295 16.806 17.782 17.986 3,013.5TOTAL 32.881 34.398 35.341 37.435 33.926 38.025 6,554.4Injected Fluids(MMRB)Water 21.866 21.777 20.760 22.792 22.872 24.135 4,820.1Gas 1.030 2.606 3.635 2.700 2.369 2.410 560.6TOTAL 22.896 24.383 24.396 25.492 25.241 26.546 5,380.7Net Injection Volumes = Injection - Production (MMRB)TOTAL -10.0 -10.0 -10.9 -11.9 -8.7 -11.5 -1,173.7Fluid Properties Used 30003100320033003400350036003700380039001/1/1987 9/27/1989 6/23/1992 3/20/1995 12/14/1997 9/9/2000 6/6/2003Reservoir Pressure @ 8800' SSTVD (psia)Exhibit 3-CFS-2 Areal Average Reservoir Pressure 01-01A01-01B01-0601-06A01-0801-0901-09A03-0103-0203-0303-0403-0503-0603-0703-07A03-0803-0903-1003-1103-1203-1303-1403-1503-15A03-15AL103-1603-16A03-1703-1803-18A03-1903-2003-20A03-2103-2203-2303-2403-24A03-2503-25A03-2603-2703-2803-2903-3003-3103-3203-32A03-3303-33A03-3403-34A03-34B03-3503-3604-0104-0204-02A04-0304-0404-04A04-0504-05A04-0604-0704-0804-0904-1004-1104-11A04-1204-1304-1404-1504-1604-16A04-1704-1804-1904-19A04-2004-2104-2204-22A04-2304-23A04-2404-2504-2604-2704-2804-2904-29A04-29AL104-3004-3104-3204-32A04-3304-3404-34A04-3504-3604-3704-3804-3904-4004-4104-41A04-4204-4304-4404-4504-4604-4704-4804-4905-0505-05A05-05B09-0109-0209-0309-0409-04A09-0509-05A09-0609-0709-07A09-0809-0909-1009-1109-1209-1309-1409-1509-1609-1709-1809-1909-2009-2109-2209-2309-23A09-2409-2509-2609-2709-2809-28A09-2909-3009-3109-31A09-31B09-31C09-3209-3309-3409-34A09-3509-35A09-3609-36A09-36BL09-36C09-3709-3809-3909-4009-4109-4209-42A09-4309-4409-4509-4609-4709-4809-4909-5009-5111-0111-01A11-0211-0411-04A11-0611-0711-0811-0911-09A11-1011-1111-1211-1311-13A11-1511-1611-1711-17A11-1811-2211-22AL111-2411-24A11-2511-25A11-2611-2711-2911-3111-31A11-3211-3311-3511-3611-3712-0612-06A12-3216-0116-0216-0316-0416-04A16-0516-05A16-0616-06A16-0716-0816-08A16-0916-09A16-1016-10A16-1116-1216-12A16-1316-1416-14A16-1516-1616-1716-1816-1916-2016-2116-2216-2316-23A16-2416-2516-2616-26A16-2716-27A16-2816-2916-29A16-3016-3117-0117-01A17-0317-03A17-0417-04A17-04AL117-04B17-0517-0617-0717-07A17-0817-0917-1017-10A17-1117-1217-1317-1417-1517-15A17-1617-1917-2017-2117-22Exhibit 3-DFS-2 Average Daily RMI 01-0701-07A 01-1001-13 01-18 03-1503-15AL1 03-2403-24A 06-0406-04A 06-0606-06A 06-09 06-1006-10A06-1106-12 06-12A 06-1306-1406-14A 06-17 06-18 07-24 12-01 12-02 12-0312-0412-04A 12-05 12-0612-06A 12-0712-07A 12-08 12-08A12-08B 12-08C 12-09 12-10 12-10A 12-11 12-12 12-1312-13A 12-13B 12-14 12-14A 12-14AL1 12-15 12-1612-16A 12-17 12-18 12-19 12-20 12-21 12-2212-23 12-25 12-2612-27 12-27A 12-2812-28A 12-29 12-3012-31 12-32 12-33 12-34 12-35 12-36 13-01 13-0213-02A 13-02B 13-02BL1 13-03 13-04 13-05 13-06 13-06A 13-07 13-08 13-08A 13-09 13-10 13-11 13-12 13-13 13-13A 13-14 13-15 13-16 13-17 13-18 13-19 13-20 13-21 13-2213-23 13-23A 13-24 13-25 13-26 13-27 13-27A 13-28 13-29 13-29L1 13-30 13-30A13-31 13-32 13-32A 13-33 13-34 13-35 13-36 13-98 14-01 14-01A 14-02A 14-02B 14-0514-05A 14-06 14-07 14-08 14-08A 14-08AL1 14-09 14-09A 14-09B 14-10 14-11 14-12 14-13 14-14 14-1514-1614-16A 14-17 14-17A 14-18 14-18A 14-19 14-20 14-21 14-2214-22A 14-23 14-24 14-25 14-26 14-27 14-28 14-29 14-30 14-32 14-3414-35 14-3614-37 14-38 14-39 14-40 14-40A 14-41 14-43 14-44 14-44A 17-02 17-03 17-03A 17-05 17-12 17-13 17-19 17-19A X-03A X-07X-08 X-08A X-09 X-09A X-15 X-15A X-16 Exhibit 4-A EPWZ Base Flood Area Map Exhibit 4-BEPWZ Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2003 January February March April May JuneOil 739.3 1.018 0.957 1.015 0.969 0.967 0.988 Bo (rb/stb) 1.320Free Gas 1,200.4 10.707 10.095 10.594 10.193 10.513 9.741 Bg (rb/mscf) 0.876Water 1,306.4 6.369 5.702 5.833 5.666 6.108 5.914 Bw (rb/stb) 1.040TOTAL 3,246.1 18.094 16.754 17.441 16.828 17.588 16.643 Bmi (rb/mscf) 0.700Rs (scf/stb) 611.4Injected Fluids(MMRB)Water 1,622.1 5.376 4.733 5.898 6.165 6.454 6.222Gas 376.3 1.436 1.654 1.747 1.544 1.430 1.233TOTAL 1,998.4 6.812 6.387 7.645 7.709 7.884 7.454Net Injection Volumes = Injection - Production (MMRB)TOTAL -1,247.7 -11.3 -10.4 -9.8 -9.1 -9.7 -9.2Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2003Oil 0.988 0.836 0.948 0.932 0.967 0.918 750.8Free Gas 8.525 10.040 11.094 9.451 11.043 11.949 1,324.3Water 5.005 5.691 5.282 6.098 5.741 6.304 1,376.1TOTAL 14.518 16.567 17.325 16.480 17.751 19.171 3,451.2Injected Fluids(MMRB)Water 5.052 5.135 5.203 6.702 6.769 7.043 1,692.9Gas 0.223 0.215 0.134 0.663 0.889 1.355 388.8TOTAL 5.275 5.349 5.337 7.364 7.658 8.399 2,081.7Net Injection Volumes = Injection - Production (MMRB)TOTAL -9.2 -11.2 -12.0 -9.1 -10.1 -10.8 -1369.6Fluid Properties Used 30003100320033003400350036003700380039001/1/1987 9/27/1989 6/23/1992 3/20/1995 12/14/1997 9/9/2000 6/6/2003Reservoir Pressure @ 8800' SSTVD (psia)Exhibit 4-CEPWZ Areal Average Reservoir Pressure 01-0701-07A 01-1001-13 01-18 03-1503-15AL1 03-2403-24A 06-0406-04A 06-0606-06A 06-09 06-1006-10A06-1106-12 06-12A 06-1306-1406-14A 06-17 06-18 07-24 12-01 12-02 12-0312-0412-04A 12-05 12-0612-06A 12-0712-07A 12-08 12-08A12-08B 12-08C 12-09 12-10 12-10A12-11 12-12 12-1312-13A 12-13B 12-14 12-14A 12-14AL1 12-15 12-1612-16A 12-17 12-18 12-19 12-20 12-21 12-2212-23 12-25 12-2612-27 12-27A 12-2812-28A 12-29 12-3012-31 12-32 12-33 12-34 12-35 12-36 13-01 13-0213-02A 13-02B 13-02BL1 13-03 13-04 13-05 13-06 13-06A 13-07 13-08 13-08A 13-09 13-10 13-11 13-12 13-13 13-13A 13-14 13-15 13-16 13-17 13-18 13-19 13-20 13-21 13-2213-23 13-23A 13-24 13-25 13-26 13-27 13-27A 13-28 13-29 13-29L1 13-30 13-30A13-31 13-32 13-32A 13-33 13-34 13-35 13-36 13-98 14-01 14-01A 14-02A 14-02B 14-0514-05A 14-06 14-07 14-08 14-08A 14-08AL1 14-09 14-09A 14-09B 14-10 14-11 14-12 14-13 14-14 14-1514-1614-16A 14-17 14-17A 14-18 14-18A 14-19 14-20 14-21 14-2214-22A 14-23 14-24 14-25 14-26 14-27 14-28 14-29 14-30 14-32 14-3414-35 14-3614-37 14-38 14-39 14-40 14-40A 14-41 14-43 14-44 14-44A 17-02 17-03 17-03A 17-05 17-12 17-13 17-19 17-19A X-03A X-07X-08 X-08A X-09 X-09A X-15 X-15A X-16 Exhibit 4-D 2004 EPWZ Average Daily RMI 14-06 14-37 14-38 14-44 A-01 A-01A A-02 A-03 A-04 A-05 A-06 A-07 A-08 A-09A-09AA-10 A-11 A-12 A-13 A-14 A-15A-16 A-16A A-17A-18 A-18A A-19 A-20A-21A-22 A-23 A-24 A-25A A-26A-26L1 A-27 A-27A A-29 A-30A-30L1 A-31A-31A A-32 A-32A A-33 A-34 A-34A A-35 A-37 A-38A-38L1 A-38L2 A-39 A-40 A-41 A-42 A-43 B-01 B-03B-03A B-03B B-09 B-10B-11 B-12B-12AB-13 B-13A B-17 B-19 B-19A B-21 B-24 B-25 B-26 B-31 B-32B-32AB-33B-33A B-34 B-35 C-05 C-26 H-01 H-01A H-02A H-03H-06 H-09H-10H-10A H-11H-12 H-21H-22 H-22A H-23 H-23A H-31 H-32 H-34 H-37H-37A M-17A N-03 N-10 P-01 P-02 P-02A P-03 P-03A P-04P-04L1 P-05P-05A P-06 P-06A P-08 P-08A P-09 P-11 P-12P-12AP-12B P-13 P-14 P-15 P-15L1 P-16 P-17 P-18P-18L1 P-19 P-22 P-23 P-24 P-24PB1 P-25 P-25L1 P-26 U-02 U-02A U-03 U-04 U-04A U-05 U-06 U-06A U-07 U-08 U-08A U-09 U-09A U-10 U-11U-11AU-11B U-12 U-13 U-14 U-15 X-01 X-02 X-03X-03A X-04X-05X-06 X-07X-08 X-09 X-09A X-09B X-10 X-11X-11A X-12X-13X-13A X-14X-14A X-15 X-15A X-17 X-18 X-19X-19A X-19B X-19BL1 X-20 X-21X-21A X-22X-22A X-23 X-24X-24A X-25 X-26 X-27 X-28X-29 X-30 X-31X-31L1 X-32 X-33 X-34 X-35 X-35L1 X-36 Y-01 Y-02 Y-02A Y-03 Y-04 Y-05 Y-05A Y-06 Y-07 Y-08Y-08A Y-09 Y-09A Y-10 Y-11Y-11A Y-11B Y-12 Y-13 Y-14 Y-14AY-14B Y-15 Y-15A Y-16 Y-17 Y-17A Y-17B Y-18 Y-19 Y-20A Y-21Y-21A Y-22 Y-23Y-23AY-23B Y-25 Y-26Y-26A Y-27 Y-28 Y-29 Y-29A Y-30 Y-30L1 Y-31 Y-32Y-32L1 Y-33 Y-34 Y-34A Y-35 Y-35A Y-37 Y-37A Y-38 Exhibit 5-A WPWZ Base Flood Area Map 14-06 14-37 14-38 14-44 A-01 A-01A A-02 A-03 A-04 A-05 A-06 A-07 A-08 A-09A-09AA-10 A-11 A-12 A-13 A-14 A-15A-16 A-16A A-17A-18 A-18A A-19 A-20A-21A-22 A-23 A-24 A-25A A-26A-26L1 A-27 A-27A A-29 A-30A-30L1 A-31A-31A A-32 A-32A A-33 A-34 A-34A A-35 A-37 A-38A-38L1 A-38L2 A-39 A-40 A-41 A-42 A-43 B-01 B-03B-03A B-03B B-09 B-10B-11 B-12B-12AB-13 B-13A B-17 B-19 B-19A B-21 B-24 B-25 B-26 B-31 B-32B-32AB-33B-33A B-34 B-35 C-05 C-26 H-01 H-01A H-02A H-03H-06 H-09H-10H-10A H-11H-12 H-21H-22 H-22A H-23 H-23A H-31 H-32 H-34 H-37H-37A M-17A N-03 N-10 P-01 P-02 P-02A P-03 P-03A P-04P-04L1 P-05P-05A P-06 P-06A P-08 P-08A P-09 P-11 P-12P-12AP-12B P-13 P-14 P-15 P-15L1 P-16 P-17 P-18P-18L1 P-19 P-22 P-23 P-24 P-24PB1 P-25 P-25L1 P-26 U-02 U-02A U-03 U-04 U-04A U-05 U-06 U-06A U-07 U-08 U-08A U-09 U-09A U-10 U-11U-11AU-11B U-12 U-13 U-14 U-15 X-01 X-02 X-03X-03A X-04X-05X-06 X-07X-08 X-09 X-09A X-09B X-10 X-11X-11A X-12X-13X-13A X-14X-14A X-15 X-15A X-17 X-18 X-19X-19A X-19B X-19BL1 X-20 X-21X-21A X-22X-22A X-23 X-24X-24A X-25 X-26 X-27 X-28X-29 X-30 X-31X-31L1 X-32 X-33 X-34 X-35 X-35L1 X-36 Y-01 Y-02 Y-02A Y-03 Y-04 Y-05 Y-05A Y-06 Y-07 Y-08Y-08A Y-09 Y-09A Y-10 Y-11 Y-11A Y-11B Y-12 Y-13 Y-14 Y-14AY-14B Y-15 Y-15A Y-16 Y-17 Y-17A Y-17B Y-18 Y-19 Y-20A Y-21Y-21A Y-22 Y-23Y-23AY-23B Y-25 Y-26Y-26A Y-27 Y-28 Y-29 Y-29A Y-30 Y-30L1 Y-31 Y-32Y-32L1 Y-33 Y-34 Y-34A Y-35 Y-35A Y-37 Y-37A Y-38 Exhibit 5-D 2004 WPWZ Average Daily RMI Exhibit 5-BWPWZ Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2003 January February March April May JuneOil 589.2 1.264 1.111 1.206 1.151 1.224 1.128 Bo (rb/stb) 1.317Free Gas 670.3 6.159 5.716 6.483 5.799 6.379 6.131 Bg (rb/mscf) 0.888Water 840.7 4.824 4.632 5.001 5.065 4.814 5.133 Bw (rb/stb) 1.040TOTAL 2,100.2 12.248 11.459 12.689 12.014 12.416 12.391 Bmi (rb/mscf) 0.700Rs (scf/stb) 603.5Injected Fluids(MMRB)Water 1,348.0 3.549 3.378 3.456 3.862 4.136 4.320Gas 335.2 0.898 0.607 0.748 0.623 0.561 0.406TOTAL 1,683.2 4.447 3.986 4.204 4.485 4.698 4.726Net Injection Volumes = Injection - Production (MMRB)TOTAL -417.1 -7.8 -7.5 -8.5 -7.5 -7.7 -7.7Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2003Oil 1.128 1.041 0.657 0.961 1.193 1.161 602.5Free Gas 5.119 3.744 5.056 5.440 5.766 6.692 738.8Water 4.016 2.588 4.159 4.736 4.870 4.875 895.4TOTAL 10.262 7.374 9.872 11.137 11.829 12.728 2,236.7136.4Injected Fluids(MMRB)Water 4.004 2.348 3.183 3.919 4.429 4.378 1,393.0Gas 0.728 1.164 0.950 0.903 1.321 1.700 345.8TOTAL 4.732 3.512 4.133 4.822 5.750 6.077 1,738.755.6Net Injection Volumes = Injection - Production (MMRB)TOTAL -5.5 -3.9 -5.7 -6.3 -6.1 -6.7 -497.9Fluid Properties Used 30003100320033003400350036003700380039001/1/1987 9/27/1989 6/23/1992 3/20/1995 12/14/1997 9/9/2000 6/6/2003Reservoir Pressure @ 8800' SSTVD (psia)Exhibit 5-CWPWZ Average Reservoir Pressure F-07 F-24 F-30 F-36 F-37 F-39 F-41F-43F-43L1 F-48 M-01 M-02 M-03 M-03A M-04 M-05M-05A M-06M-06A M-07 M-08 M-09 M-09A M-09B M-10 M-11 M-12 M-12A M-13M-13A M-14 M-15 M-16 M-17 M-18M-18A M-18B M-19M-19A M-20 M-20A M-21 M-21AM-22 M-23 M-24M-24A M-25 M-26 M-26A M-27 M-27A M-28 M-29M-29A M-30 M-31 M-32 M-33 M-34 M-38M-38A N-04 N-05 N-08 N-08A N-11 N-13 N-15 N-17N-18 N-19 N-23 N-23A N-25 N-26 R-01 R-02 R-03 R-03A R-04 R-05 R-05A R-06 R-06A R-07R-07A R-08 R-09 R-09A R-10 R-11 R-11A R-12 R-14R-14A R-15 R-15A R-16R-17 R-17A R-18 R-18A R-18B R-19 R-19A R-20 R-20A R-21 R-22 R-23 R-23A R-24 R-25 R-25A R-26 R-26A R-28 R-29 R-29A R-30 R-31R-31A R-32 R-32A R-34 R-35R-36 R-39R-39A R-40 S-01 S-01AS-01B S-02 S-02A S-03 S-04 S-05 S-05A S-06 S-07 S-07A S-08 S-08A S-08BS-09 S-10S-10A S-11 S-11A S-11B S-12 S-12A S-13 S-14 S-15S-16 S-17 S-17AS-17AL1S-17BS-17C S-18 S-18A S-19 S-20S-20A S-21 S-22 S-22A S-22B S-23 S-24 S-24A S-24B S-25 S-25A S-26 S-27S-27A S-27B S-28S-28AS-28B S-29S-29AS-29AL1 S-30 S-31 S-31A S-32 S-33 S-34 S-35 S-36 S-37 S-38 S-40S-40A S-41S-41L1 S-42 S-43S-43L1 S-44 S-44L1 T-01 T-07 Exhibit 6-A NWFB Base Flood Area Map Exhibit 6-BNWFB Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2003 January February March April May JuneOil 693.0 0.905 0.777 0.788 0.763 0.602 0.810 Bo (rb/stb) 1.318Free Gas 556.6 3.883 3.523 3.707 3.559 2.968 3.485 Bg (rb/mscf) 0.884Water 731.5 3.781 2.807 2.773 2.957 2.527 3.801 Bw (rb/stb) 1.040TOTAL 1,981.0 8.569 7.106 7.269 7.278 6.098 8.095 Bmi (rb/mscf) 0.700Rs (scf/stb) 606.2Injected Fluids(MMRB)Water 1,345.9 4.368 3.541 4.305 4.012 3.300 4.087Gas 387.0 1.224 1.534 1.125 1.058 0.943 0.779TOTAL 1,732.8 5.592 5.075 5.430 5.070 4.244 4.866Net Injection Volumes = Injection - Production (MMRB)TOTAL -248.2 -3.0 -2.0 -1.8 -2.2 -1.9 -3.2Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2003Oil 0.810 0.845 0.302 0.435 0.816 0.769 701.6Free Gas 3.411 1.212 1.980 3.503 3.416 3.628 594.9Water 4.010 1.261 1.866 3.665 3.595 3.128 767.6TOTAL 8.231 3.319 4.149 7.603 7.828 7.525 2,064.183.1Injected Fluids(MMRB)Water 4.252 1.128 2.944 3.767 3.806 3.534 1,385.6Gas 1.173 0.312 0.501 0.885 1.072 1.648 399.2TOTAL 5.424 1.440 3.445 4.652 4.878 5.182 1,788.1Net Injection Volumes = Injection - Production (MMRB)TOTAL -2.8 -1.9 -0.7 -3.0 -2.9 -2.3 -276.0Fluid Properties Used 30003100320033003400350036003700380039001/1/1987 9/27/1989 6/23/1992 3/20/1995 12/14/1997 9/9/2000 6/6/2003Reservoir Pressure @ 8800' SSTVD (psia)Exhibit 6-CNWFB Areal Average Reservoir Pressure F-07 F-24 F-30 F-36 F-37 F-39 F-41F-43F-43L1 F-48 M-01 M-02 M-03 M-03A M-04 M-05M-05A M-06M-06A M-07 M-08 M-09 M-09A M-09B M-10 M-11 M-12 M-12A M-13M-13A M-14 M-15 M-16 M-17 M-18M-18A M-18B M-19M-19A M-20 M-20A M-21 M-21AM-22 M-23 M-24M-24A M-25 M-26 M-26A M-27 M-27A M-28 M-29M-29A M-30 M-31 M-32 M-33 M-34 M-38M-38A N-04 N-05 N-08 N-08A N-11 N-13 N-15 N-17N-18 N-19 N-23 N-23A N-25 N-26 R-01 R-02 R-03 R-03A R-04 R-05 R-05A R-06 R-06A R-07R-07A R-08 R-09 R-09A R-10 R-11 R-11A R-12 R-14R-14A R-15 R-15A R-16R-17 R-17A R-18 R-18A R-18B R-19 R-19A R-20 R-20A R-21 R-22 R-23 R-23A R-24 R-25 R-25A R-26 R-26A R-28 R-29 R-29A R-30 R-31R-31A R-32 R-32A R-34 R-35R-36 R-39R-39A R-40 S-01 S-01AS-01B S-02 S-02A S-03 S-04 S-05S-05A S-06 S-07 S-07A S-08 S-08A S-08BS-09 S-10S-10A S-11 S-11A S-11B S-12 S-12A S-13 S-14 S-15S-16 S-17 S-17AS-17AL1S-17BS-17C S-18 S-18A S-19 S-20S-20A S-21 S-22 S-22A S-22B S-23 S-24 S-24A S-24B S-25 S-25A S-26 S-27S-27A S-27B S-28S-28AS-28B S-29S-29AS-29AL1 S-30 S-31 S-31A S-32 S-33 S-34 S-35 S-36 S-37 S-38 S-40S-40A S-41S-41L1 S-42 S-43S-43L1 S-44 S-44L1 T-01 T-07 Exhibit 6-D 2004 NWFB Average Daily RMI L-01 L-02 NWE1-01 NWE2-01 V-03 W-01W-01A W-02 W-02A W-03 W-03A W-04 W-05W-06W-06A W-07 W-08 W-08A W-09 W-10W-10A W-11 W-12 W-12A W-15W-15A W-16W-16A W-17W-18 W-19 W-19A W-19AL1 W-20 W-21 W-21A W-22 W-23 W-23A W-24W-25 W-26W-26A W-27 W-29 W-30 W-31 W-32 W-32AW-34W-34A W-35 W-36 W-37W-37A W-38 W-38A W-39 W-40 W-42 W-44 Z-01 Z-02 Z-02A Z-03 Z-04 Z-05 Z-06 Z-07Z-07A Z-08Z-08A Z-09 Z-10 Z-11 Z-12 Z-13 Z-14 Z-14A Z-15 Z-16 Z-17 Z-18 Z-19 Z-20 Z-21Z-21A Z-22Z-22A Z-22B Z-23Z-23A Z-24 Z-25 Z-26 Z-27 Z-28 Z-29 Z-30 Z-30AZ-31 Z-32 Z-32A Z-32B Z-32BL1 Z-33 Z-33A Z-35Z-38 Z-39 Exhibit 7-A EWE Base Flood Area Map L-01 L-02 NWE1-01 NWE2-01 V-03 W-01W-01A W-02 W-02A W-03 W-03A W-04 W-05W-06W-06A W-07 W-08 W-08A W-09 W-10W-10A W-11 W-12 W-12A W-15W-15A W-16W-16A W-17W-18 W-19 W-19A W-19AL1 W-20 W-21 W-21A W-22 W-23 W-23A W-24W-25 W-26W-26A W-27 W-29 W-30 W-31 W-32 W-32AW-34W-34A W-35 W-36 W-37W-37A W-38 W-38A W-39 W-40 W-42 W-44 Z-01 Z-02 Z-02A Z-03 Z-04 Z-05 Z-06 Z-07Z-07A Z-08Z-08A Z-09 Z-10 Z-11 Z-12 Z-13 Z-14 Z-14A Z-15 Z-16 Z-17 Z-18 Z-19 Z-20 Z-21Z-21A Z-22Z-22A Z-22B Z-23Z-23A Z-24 Z-25 Z-26 Z-27 Z-28 Z-29 Z-30 Z-30AZ-31 Z-32 Z-32A Z-32B Z-32BL1 Z-33 Z-33A Z-35Z-38 Z-39 Exhibit 6-D EWE Average Daily RMI Exhibit 7-BEWE Reservoir BalanceCumulativeProduced Fluids (MMRB)12/31/2003 January February March April May JuneOil 20.6 0.716 0.659 0.718 0.638 0.574 0.590 Bo (rb/stb) 1.343Free Gas 62.0 2.086 1.731 1.556 1.548 1.054 1.565 Bg (rb/mscf) 0.804Water 28.4 1.413 1.017 1.028 1.118 1.129 1.114 Bw (rb/stb) 1.040TOTAL 111.0 4.216 3.407 3.302 3.304 2.757 3.269 Bmi (rb/mscf) 0.700Rs (scf/stb) 664.6Injected Fluids(MMRB)Water 12.2 0.074 0.069 0.055 0.070 0.070 0.078Gas 5.0 0.000 0.000 0.000 0.178 0.454 0.503TOTAL 17.2 0.074 0.069 0.055 0.248 0.525 0.581Net Injection Volumes = Injection - Production (MMRB)TOTAL -93.8 -4.1 -3.3 -3.2 -3.1 -2.2 -2.7Produced FluidsCumulative(MMRB)JulyAugust September October November December 12/31/2003Oil 0.590 0.677 0.352 0.474 0.889 0.850 28.4Free Gas 1.382 0.527 0.808 1.426 1.660 1.742 79.1Water 1.012 0.424 0.796 1.842 1.327 1.081 41.7TOTAL 2.984 1.628 1.956 3.742 3.876 3.673 149.1Injected Fluids(MMRB)Water 0.080 0.032 0.512 0.180 0.667 0.852 14.8Gas 0.418 0.211 0.305 1.194 0.965 1.172 10.4TOTAL 0.499 0.242 0.817 1.375 1.633 2.023 25.3Net Injection Volumes = Injection - Production (MMRB)TOTAL -2.5 -1.4 -1.1 -2.4 -2.2 -1.6 -123.8Fluid Properties Used Exhibit 8 2004 Wells Surveyed for Gas Movement Well Log Date OH / CH Well Log Date OH / CH Well Log Date OH / CH 01-10 11/3/04 CH D-11A 12/16/04 CH PSI-07 4/20/04 CH 01-10 11/5/04 CH D-25A 8/27/04 CH R-13 6/6/04 CH 01-17B 2/8/04 CH E-07A 6/5/04 CH W-30 9/28/04 CH 02-07A 4/7/04 CH E-07A 6/6/04 CH W-30 10/5/04 CH 02-27A 4/10/04 CH E-07A 6/7/04 CH W-30 10/8/04 CH 02-29C 5/4/04 OH E-08A 1/1/04 CH W-30 10/9/04 CH 02-33A 5/22/04 CH E-10A 6/16/04 CH W-30 9/27/04 CH 02-33A 5/23/04 CH E-10A 6/17/04 CH X-15A 7/7/04 CH 03-22 7/20/04 CH E-15B 6/5/04 CH X-16 5/31/04 CH 05-07 4/1/04 CH E-15B 6/30/04 CH X-27 3/10/04 CH 05-21A 8/26/04 CH E-15B 7/1/04 CH Z-01 2/25/04 CH 05-26A 8/19/04 CH E-17 4/9/04 CH Z-12 7/6/04 CH 07-01A 8/18/04 CH E-18A 5/19/04 CH 07-03A 6/3/04 CH E-18A 5/22/04 CH 07-03A 6/2/04 CH E-21A 8/22/04 CH 07-29C 6/3/04 CH E-21A 8/23/04 CH 07-29C 6/4/04 CH E-21A 8/21/04 CH 07-30A 12/9/04 CH E-24B 6/20/04 CH 09-30 5/6/04 CH E-24B 6/19/04 CH 14-41 5/30/04 CH E-25 8/21/04 CH 15-13A 10/1/04 CH E-39A 9/2/04 CH 15-13A 10/3/04 CH E-39A 3/27/04 CH 15-13A 10/4/04 CH E-39A 9/13/04 CH 15-18 6/6/04 CH E-39A 9/12/04 CH 15-18 6/7/04 CH E-39A 9/14/04 CH 15-33B 4/2/04 CH F-21 12/28/04 CH 15-33B 4/3/04 CH F-28 3/24/04 CH 15-33B 4/4/04 CH F-28 3/23/04 CH 15-38A 12/11/04 CH F-29 11/6/04 CH 18-02A 2/21/04 CH F-46A 3/17/04 CH 18-02A 2/23/04 CH F-46A 3/16/04 CH 18-04B 3/5/04 CH G-02A 8/23/04 CH 18-13A 4/16/04 CH G-12B 3/20/04 CH 18-13A 4/15/04 CH G-12B 3/21/04 CH 18-27C 6/13/04 CH G-15A 2/3/04 CH 18-27C 6/12/04 CH G-15A 2/2/04 CH 18-31 7/4/04 CH H-04A 7/31/04 CH 18-31 7/5/04 CH H-04A 7/29/04 CH C-08A 1/4/04 CH H-04A 7/30/04 CH C-08A 1/3/04 CH H-18 2/17/04 CH C-16A 4/13/04 CH K-09C 7/15/04 CH C-17B 8/10/04 CH K-10B 5/16/04 CH C-25A 10/2/04 CH K-10B 5/15/04 CH C-29A 8/19/04 CH N-07A 8/4/04 CH C-29A 8/20/04 CH N-11C 8/28/04 CH C-34 7/9/04 CH N-21A 8/28/04 CH C-39 8/19/04 CH OWDW-NW 3/28/04 CH C-39 8/18/04 CH OWDW-SE 5/3/04 CH D-07A 8/24/04 CH OWDW-SW 3/27/04 CH D-11A 12/14/04 CH PSI-05 4/25/04 CH D-11A 12/15/04 CH PSI-05 8/15/04 CH OH - Open Hole Log CH - Cased Hole Log Exhibit 92004 Pressure SurveysWell NameAPI Number Test DateTool Depth MdPressure at Tool DepthDatum Depth (TVD)Pressure at DatumCommentsS-30 500292205100 1/2/2004 11,948 3,326 8,800 3,373grad=0.422 psi/ftW-11 500292198100 1/2/2004 13,190 3,454 8,800 3,454.00UNABLE TO REACH STOP # 1 @ 13342' MD (8900 TVD) DUE TO FILL. Grad=0.422 psi/ftY-26A 500292219101 1/8/2004 10,638 3,279 8,800 3,279.00Grad=0.389 psi/ftA-38L1 500292234760 1/9/2004 11,560 3,258.00 8,800 3,258.00PDS RAN LDL LOGGING UP AFTER SBHPS; Grad=0.442 psi/ft15-17 500292112600 1/28/2004 10,641 3,309.00 8,800 3,337.30GRAD=0.44 PSI/FT12-12 500292061000 1/31/2004 10047 3156 8,800 3,167STATIC STOP IN SLM, NO WAY TO CORRECT BACK TO ELMD OR MD. Grad=0.44psi/ftH-37A 500292277201 2/1/2004 10,239 3,009.00 8,800 3,037.80GRAD=0.289 PSI/FTZ-17 500292200100 2/24/2004 12,762 3,472.00 8,800 3,467.30GRAD=0.406 PSI/FTF-28 500292164900 3/4/2004 9,040 3,204.00 8,800 3,204.00GRAD=0.08 PSI/FTR-14A 500292090901 3/7/2004 9,534 3,025.00 8,800 3,195.30GRAD=0.341 PSI/FT06-04A 500292017901 3/11/2004 9,162 3,270.00 8,800 3,252.00grad=0.451 psi/ft06-08A 500292030001 3/17/2004 10,854 3,245 8,800 3,245Grad=0.417 psi/ft09-20 500292026100 3/17/2004 8,800 3,43706-12A 500292045601 3/18/2004 10,987 3,260.00 8,800 3,260.00Grad=0.410 psi/ftZ-38 500292287300 3/18/2004 11,748 3,755 8,800 3,755 Grad = 0.414 psi/ft15-20B 500292113302 3/20/2004 8,700 3,232.00 8,800 3,255Grad=0.08 psi/ftZ-07A 500292204601 3/24/2004 12,758 3,747 8,800 3,747Grad=0.42 psi/ftZ-28 500292187900 3/25/2004 9,856 3,584.00 8,800 3,590.00 Grad=0.37 psi/ftW-44 500292197500 3/29/2004 12,300 3,493.00 8,800 3,540.00Grad = 0.47 psi/ftW-40 500292177600 3/30/2004 10,236 3,442 8,800 3,442Grad = 0.27 psi/ftW-42 500292181600 3/30/2004 9,763 3355 8,800 3,445Grad = 0.45 psi/ftD-22B 500292073702 4/2/2004 9,275 3,163.00 8,800 3,163.00Grad = 0.34 psi/ftC-23B 500292077502 4/3/2004 9,876 3,222.00 8,800 3,222.00Grad = 0.08 psi/ftE-03A 500292018101 4/5/2004 12,335 3,291.00 8,800 3,291.00Grad = 0.33 psi/ft06-22A 500292080601 4/6/2004 10,292 3,266.00 8,800 3,253Grad = 0.21 psi/ftE-26A 500292178101 4/7/2004 9,020 3,185.00 8,800 3,204.80Grad = 0.086 psi/ftD-07A 500292016201 4/9/2004 11,528.00 3,191.00 8,800 3,191.00Grad = 0.08 psi/ftE-05A 500292019701 4/10/2004 9,847.00 3,291.00 8,800 3,291.00Grad = 0.13 psi/ftW-29 500292183400 4/14/2004 10,577 3,446.90 8,800 3,447.00Grad = 0.425 psi/ftW-35 500292179900 4/15/2004 10,218 3,471 8,800 3,471Grad = 0.271 psi/ftW-03A 500292195301 4/16/2004 12,359 3,360 8,800 3,360Grad = 0.139 psi/ftW-20 500292180800 4/16/2004 9,680 3,385 8,800 3,334.50Grad = 0.44 psi/ftX-16 500292068400 4/16/2004 10,508 3,235.40 8,800 3,235.40Grad = 0.108 psi/ftW-24 500292183300 4/24/2004 9,130 3,378.00 8,800 3,400Grad = 0.326 psi/ftA-33 500292141000 5/9/2004 11,112 3,306 8,800 3,305.80Grad = 0.408 psi/ftW-20 500292180800 5/10/2004 9,546 3,325.00 8,800 3,317.30Grad = 0.497 psi/ft01-14 500292028100 5/12/2004 10,393 3265 8,800 3,249Grad = 0.411 psi/ft. ALL SPECIFIC DATA FOR PRESSURE AND TEMP ON REPORT FROM PETREDAT.W-11 500292198100 5/13/2004 13,232 3,492.00 8,800 3,479.20Grad = 0.47 psi/ftM-04 500292010500 5/14/2004 11,343 3,200.30 8,800 3,235.22( CORRECTED TO RIG ELEVATION, KB 44' - BF 24' = 20' ) WELL STABLE; Grad = 0.348 psi/ftM-10 500292056700 5/15/2004 9,499 3,192.00 8,800 3,192.00Grad = 0.44 psi/ft Exhibit 92004 Pressure SurveysWell NameAPI Number Test DateTool Depth MdPressure at Tool DepthDatum Depth (TVD)Pressure at DatumCommentsR-21 500292099700 5/15/2004 10,352 3,224.00 8,800 3,224.00LOCATE TT @ 9873' SLM, (+ 33' = 9906' ELMD). TAG TD @ 10360' + 33' = 10393' CORRECTED DEPTH. PUH. Grad = 0.43 psi/ftR-24 500292123200 5/15/2004 9,453 3,133 8,800 3,133.00LOCATE TT @ 9067' SLM (+ 34' = 9101' ELMD). TAG TD @ 9452' SLM + 34' = 9486' CORRECTED DEPTH.R-02 500292035400 5/16/2004 9,549 3,237.00 8,800 3,262.30Grad = 0.46 psi/ftH-11 500292048500 5/17/2004 9,269 3,184.00 8,800 3,184.00Grad = 0.419 psi/ftM-11 500292058900 5/17/2004 9,048 3,115.00 8,800 3,170.30IN LUB START TIME IS ON LINE # 5 START DATE FOR THAT STOP IS 05-16-04. Grad = 0.429 psi/ftM-15 500292061200 5/17/2004 9,014 3,155.00 8,800 3,256.50Grad = 0.829 psi/ftE-06A 500292020201 5/18/2004 9,383 3,226.00 8,800 3,226.00Grad = 0.09 psi/ftM-23 500292093700 5/18/2004 9,764 3,202.00 8,800 3,201.80Grad = 0.419 psi/ftM-26A 500292200401 5/18/2004 11,288 3,253 8,800 3,261.00Grad = 0.419 psi/ftN-25 500292248100 5/19/2004 9,514 2,982 8,800 2,999Grad = 0.09 psi/ftS-03 500292069500 5/19/2004 12,010 3,465.00 8,800 3,465.00Grad = 0.427 psi/ft07-20A 500292090201 5/20/2004 10,115 3,248.00 8,800 3,248Grad = 0.08 psi/ftZ-12 500292197700 5/20/2004 11,079 3,630 8,800 3,630.00Grad = 0.419 psi/ftZ-20 500292185900 5/20/2004 11,292 3,560.00 8,800 3,519.00Grad = 0.44 psi/ft; The tools were stuck for 34 days. According to the team that fished them out, the tools were found at 11292' MD14-24 500292097000 5/21/2004 9210 3255 8,800 3,255Grad = 0.341 psi/ftJ-28 500292172100 5/22/2004 10,747 3,148.00 8,800 3,148.00Grad = 0.431 psi/ftX-04 500292041200 5/23/2004 9,486 3,239 8,800 3,275.60Grad = 0.368 psi/ft01-17B 500292028902 5/28/2004 9,338 3,168.00 8,800 3,191.03Grad = 0.33 psi/ftB-20 500292084200 6/2/2004 9,658 3,210.00 8,800 3,210.20Grad = 0.385 psi/ftR-02 500292035400 6/4/2004 9,405 3,677.00 8,800 3,759.75Grad = 0.457 psi/ftE-18A 500292065401 6/14/2004 11,120 3,218.90 8,800 3,218.80Grad = 0.459 psi/ftE-18A 500292065401 6/15/2004 11,120 3,217.00 8,800 3,217.00Grad = 0.461 psi/ft TOOL STRING STOPPED TO DEVIATION AT 11317' MDE-33 500292242200 6/15/2004 9,953 3,207.00 8,800 3,206.90Grad = 0.275 psi/ft06-03A 500292018601 6/22/2004 9,900 3,050.00 8,800 3,249.00Grad = 0.44 psi/ftZ-20 500292185900 6/22/2004 11,292 3,560.00 8,800 3,519.00Grad = 0.44 psi/ft DEPTH IS ESTIMATED FROM INITIAL REPORTS OF FISHING DEPTH ON MAY 20TH, NOT CORRECTED DEPTH. GAUGE SHUT DOWN BY THE 22ND.Q-03A 500292032201 7/2/2004 9,100 3,122 8,800 3,122.50Grad = 0.318 psi/ftJ-17B 500292096902 7/10/2004 10,600 3,150 8,800 3,150.00Grad = 0.25 psi/ftQ-05A 500292034401 7/13/2004 9,945 3,153 8,800 3,135.30Grad = 0.39 psi/ftS-05A 500292086901 7/13/2004 10,161 3,190 8,800 3,280.70Grad = 0.302 psi/ftA-34A 500292133901 7/16/2004 8,926 3,204.00 8,800 3,236.50Grad = 0.337 psi/ft03-36 500292234000 7/19/2004 8,800 3,423.00Y-14B 500292183202 7/19/2004 10,179 3,322 8,800 3,322.00Grad = 0.26 psi/ftZ-25 500292190200 7/19/2004 11,385 3,570.00 8,800 3,570Grad = 0.39 psi/ft15-23A 500292222501 7/27/2004 9,580 3,021.00 8,800 3,054Grad = 0.33 psi/ft15-34A 500292247401 7/27/2004 11,061 3,273.00 8,800 3,303Grad = 0.30 psi/ftB-20 500292084200 7/28/2004 9,577 3,143.00 8,800 3,171.00RUN STATIC BUILD UP FOR ONE HOUR @ 9577'SLM15-36A 500292248001 7/29/2004 11,488 3,297.00 8,800 3,314.50Grad = 0.09 psi/ft18-10B 500292081802 7/31/2004 12,111 3,254.00 8,800 3,350.00Grad = 0.32 psi/ft18-18B 500292187202 7/31/2004 8,917 3,239.00 8,800 3,287.00Grad = 0.08 psi/ft Exhibit 92004 Pressure SurveysWell NameAPI Number Test DateTool Depth MdPressure at Tool DepthDatum Depth (TVD)Pressure at DatumCommentsU-04A 500292119101 8/3/2004 10,865 3,298 8,800 3,298.00Grad = 0.437 psi/ftU-06A 500292111701 8/3/2004 8,967 3,264 8,800 3,264.00Grad = 0.44 psi/ftGNI-02 500292285100 8/10/2004 7,432 3,165.00 8,800 4,172.00Grad = 0.44 psi/ft14-25 500292098100 8/11/2004 1338 8,800 3,322Per PE B Carlson09-03 500292020900 8/13/2004 9030 3228 8,800 3,275Grad = 0.417 psi/ft09-32 500292137100 8/14/2004 10969 3265 8,800 3,265Grad = 0.12 psi/ft02-29C 500292201103 8/19/2004 9,620 3,282.00 8,800 3,282.00Grad = 0.428 psi/ftPSI-05 500292317400 8/19/2004 10,844 3,442 8,800 3,578.00Grad = 0.454 psi/ftPSI-07 500292317700 8/19/2004 11,272 3,390 8,800 3,459Grad = 0.23 psi/ftX-28 500292239400 8/19/2004 10,580 3,437 8,800 3,420Grad = 0.47 psi/ftV-02 500292320900 8/20/2004 9,450 3,791 8,800 3,791Grad = 0.381 psi/ftM-24A 500292093901 8/21/2004 9,132 3,011.30 8,800 3,098.00Grad = 0.433 psi/ftR-26A 500292154700 8/21/2004 9,242 3,127 8,800 3,127Grad = 0.37 psi/ftH-32 500292244900 8/22/2004 10,176 3,194.00 8,800 3,194.00Grad = 0.421 psi/ftS-42 500292266200 8/22/2004 9,360 3,255 8,800 3,299Grad = 0.44 psi/ftJ-06 500292024600 8/23/2004 11,190 3,181.00 8,800 3,181.00Grad = 0.45 psi/ftS-21 500292203600 8/23/2004 10,067 3,116.00 8,800 3,116.00Grad = 0.42 psi/ft03-19 500292097100 8/24/2004 10,755 3,248.00 8,800 3,266.00RAN STATIC AS PER PROCEEDURE ONLY TWO STOPS. OK'ED BY CO REP. Grad = 0.181 psi/ft03-32A 500292114101 8/24/2004 9,442 3,443.10 8,800 3,443Grad = 0.48 psi/ftJX-02A 500292145501 8/24/2004 9,673 3,136.10 8,800 3,136.50Grad = 0.32 psi/ftS-38 500292231000 8/24/2004 9259 3201 8,800 3,201Grad = 0.833 psi/ftM-14 500292051200 8/25/2004 26 130.00 8,800 3,908.00Grad = 0.39 to 2170' TVD, 0.44 to 8800' SSTVD.N-17 500292089800 8/25/2004 8,952 3,148 8,800 3,156.00Grad = 0.08 psi/ftP-25L1 500292274260 8/25/2004 9,685 3,091 8,800 3,120.00Grad = 0.33 psi/ftS-36 500292230100 8/26/2004 9,857 3,273 8,800 3,273.00Grad = 0.43 psi/ftZ-15 500292184900 8/26/2004 11,499 3,468 8,800 3,468.00R-20A 500292064101 8/27/2004 19 250.00 8,800 4,028Grad = 0.39 to 2170' TVD, 0.44 to 8800' SSTVD.R-22 500292100500 8/27/2004 32 150 8,800 3,934Grad = 0.39 to 2170' TVD, 0.44 to 8800' SSTVD.R-32A 500292241301 8/27/2004 32 20 8,800 3,792Grad = 0.39 to 2170' TVD, 0.44 to 8800' SSTVD.PSI-01 500292310400 8/28/2004 9,515 3,369 8,800 3,549.00Grad = 0.45 psi/ftPSI-06 500292308200 8/29/2004 11,744 3,305 8,800 3,434Grad = 0.202 psi/ftW-38A 500292180701 9/13/2004 14,450 3,522 8,800 3,522.00 Grad = 0.41 psi/ft. MADE 30 MIN. STOP @ 14,450' MD 8,800' SS 20 MIN. STOP @ 14,185' MD 8,700' SSW-06A 500292182201 9/16/2004 13,049 3,409 8,800 3,409.00Grad = 0.09 psi/ftW-10A 500292189301 9/16/2004 14,082 3,390 8,800 3,419.00Grad = 0.29 psi/ftS-41L1 500292264560 9/18/2004 11,202 2,929 8,800 3,032Grad = 0.32 psi/ftW-12A 500292202301 9/18/2004 13,868 3,500.00 8,800 3,491.40Grad = 0.44 psi/ft01-32A 500292162201 9/19/2004 9,060 3,247.00 8,800 3,247.0012-28A 500292108601 9/22/2004 11900 3265 8,800 3,241Grad = 0.44 psi/ftG-29A 500292165001 9/25/2004 9,690 3,230 8,800 3,230.00Grad = 0.06 psi/ftG-15A 500292064701 10/2/2004 9,910 3,217.00 8,800 3,217.00Grad = 0.09 psi/ftG-32A 500292163601 10/2/2004 9,269 3,192.00 8,800 3,192.00Grad = 0.35 psi/ftG-31A 500292161601 10/3/2004 8,964 3,212.00 8,800 3,212.00Grad = 0.08 psi/ftZ-13 500292206900 10/5/2004 12,432 3,563 8,800 3,600.60Grad = 0.41 psi/ft Exhibit 92004 Pressure SurveysWell NameAPI Number Test DateTool Depth MdPressure at Tool DepthDatum Depth (TVD)Pressure at DatumComments04-29AL1 500292145360 10/10/2004 12,205 3,283.00 8,800 3,313.00Grad = 0.30 psi/ft04-35 500292214700 10/10/2004 9,967 3,344.00 8,800 3,417.00Grad = 0.36 psi/ft18-14B 500292161402 10/19/2004 9,859 3,216.00 8,800 3,307.00Grad = 0.37 psi/ft18-16B 500292174902 10/20/2004 9,346 3,272.00 8,800 3,334.00Grad = 0.31 psi/ftM-38A 500292251901 10/21/2004 8,950 3,129.00 8,800 3,205.00Grad = 0.381 psi/ftPSI-09 500292309500 10/21/2004 10,150 3,390 8,800 3,570.00Grad = 0.45 psi/ftF-29 500292162700 10/30/2004 9,880 3,167.00 8,800 3,167.00Grad = 0.33 psi/ftZ-04 500292199000 11/4/2004 9,438 3,637 8,800 3,637Grad = 0.831 psi/ftZ-22B 500292203702 11/5/2004 13,376 3,696 8,800 3,703.00Grad = 0.27 psi/ftF-21 500292194900 11/6/2004 11,300 3,176.00 8,800 3,176.00Grad = 0.36 psi/ft11-23A 500292161001 11/8/2004 11124 3303 8,800 3,369Grad = 0.33 psi/ft14-09B 500292053402 11/9/2004 11203 3297 8,800 3,297Grad = 0.32 psi/ftK-07C 500292104503 11/9/2004 9,637 3,299.00 8,800 3,307.00Grad = 0.08 psi/ft03-24A 500292101501 11/10/2004 12,630 3,183.00 8,800 3,267.00Grad = 0.28 psi/ftR-15A 500292091701 11/10/2004 9,123 3,147 8,800 3,187.00Grad = 0.40 psi/ft15-41B 500292249202 11/19/2004 10,225 2,945.00 8,800 3,272.00Grad = 0.409 psi/ft01-14 500292028100 12/18/2004 9,850 4,057.00 8,800 4,235.00Grad = 0.428 psi/ft Exhibit 102004 Shut In Wells#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments1 01-01B Mar-99 7 5 CT cemented high in production tbg in 19932 01-05 May-98 6 5 Ann Comm: RWO Uneconomical3 01-08 Aug-02 5 5 Water injection out of zone- conformance problem4 01-16 Dec-03 7 6 Choke change needs DS shut down to fix5 01-25 Aug-02 6 4 Conversion to PWI6 01-30 Apr-97 6 4 Conversion to PWI; has Cretaceous & small TxIA leaks7 02-31A Aug-03 6 5 TxIA Comm - Secured with LTTP, low IOR (20)8 02-36 May-02 6 5 Holes in tbg. Requires 6500' patch or RWO. No economic options9 03-05 Mar-91 6 5 Temp P&A, BHL replaced10 03-28 Apr-02 3 5 TxIA, IAxOA, low PI11 03-32A Nov-01 2 5 IAxOA on AL; not a good WSO candidate12 04-04A Jan-95 6 5 CTD BHA stuck in a window, junked13 04-07 Jan-97 2 5 Will BOL w/ UDVW project, Don't know test data14 04-12 Jun-94 6 5 LTSI: geophones cemented in hole15 04-23A Aug-03 2 5 High WC. No ID utility.16 04-29AL1 Dec-03 2 5 High WC. No ID utility.17 04-30 Jun-02 1 5 High GOR. Cycle Well18 04-33 Feb-03 6 5 Cret leak19 04-34A Mar-94 2 5 High WC. No ID utility.20 04-35 Mar-03 2 5 High GOR.21 04-36 Nov-01 2 5 High WC. No ID utility.22 04-39 Apr-98 2 5 High WC. No ID utility.23 04-40 Aug-01 6 1 Tbg leak, eval options.24 04-41A Jun-03 1 5 High GOR.25 04-42 Oct-03 5 5 Allow more water to 04-19 & 04-45 (Triple)26 04-46 Nov-01 2 5High WC. No ID utility.27 04-47 Feb-03 6 5SI due to Cret leak28 05-01C Jan-03 1 5Graben Well w/ no current value or ww/sidetrack options29 05-11A May-01 6 5Ann Comm. Bad tbg and leak in wellhead.30 05-15B Jan-02 6 5Cret. Leak, 1st patch failed, likely dump flooded for several months, will evaluate sidetrack in 200431 05-17B Nov-02 6 5Low existing value - collapsed tbg32 05-18A Feb-03 1 5Graben Well w/ no current value or ww/sidetrack options33 05-19 Dec-02 6 74 holes in tbg. RWO package submitted34 05-20A Jun-02 6 5 Low existing value - Parted tbg. Will probably not support a RWO ($5.20/bbl), difficult de-complete35 05-23A Apr-03 1 5 IBP to secure well for LTSI Aug 2003 - PC Leak. Competitive only when MGOR is above 7500036 05-28A Aug-03 6 5Cret leak, 1st patch failed, 2nd patch successful but well produced only water, will evaluate sidetrack in 200437 05-35 Feb-96 6 2 Need to remove blind and POP to evaluate, blind removal req's DS shutdown38 05-40 Nov-02 6 2 11 Leaks in tbg, needs RWO ($4.50/bbl), will evaluate sidetrack in 200439 06-06A Aug-96 7 5 CTD BHA left in hole, sidetrack aborted, no flowline40 06-09 Jan-02 6 1 Ann Comm; Rig ST cancelled; patch program being written41 06-12A Feb-02 2 3 low oil rate; CTD for attic oil target42 06-16 Jun-01 6 2 TxIAxOA communication, evaluate for wellwork or ST43 07-09 Aug-03 6 7 Multiple tubing leaks. RWO package approved. * Note - Wells shut in for all of 2004. Exhibit 102004 Shut In Wells#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments44 07-27 Aug-90 7 5 8900' of coil stuck in hole. Well is suspended. No surface facilities or manifold slot.45 09-03 May-01 2 5 IAxOA small. High water and low oil rate46 09-31C Aug-03 3 2 Convert to inj47 09-42A Dec-02 6 5 Cret Leak; No Rig ST target48 09-51 Jun-03 2 4 Convert to inj49 11-06A Apr-03 6 3 Well will be sidetracked in 200550 11-09A Aug-00 6 2 LTSI; TxIA, obstruction51 11-12 Jan-94 6 2 Severe mech integrity. Evaluating RWO.52 11-15 Jan-90 6 5 P&A'd53 11-18 Nov-02 6 7 Holes in tbg. RWO planned.54 11-23A Feb-98 2 2 High WC (twinned & can't compete w/ HP well. Uneconomic de-twin. Potentially an UDVW injection 55 11-25A May-02 6 5 Cret Leak. Need RWO.56 11-38A Jan-01 6 1 Tbg leaks. Uneconomic RWO. Conversion to wtr only injector approved57 12-05 Feb-00 6 7 Ann Comm: RWO Required, issued 5/27/04. On schedule for 1Q 0558 12-11 Feb-00 3 5 Ann Comm, High TGOR, low oil rate, Possible RST59 12-23 Sep-02 6 2 State Approved AA. Wireline to pull TTP60 12-28A Mar-03 4 1 gravel pack to be set with 4ES early 1Q 0561 12-32 Sep-02 6 7 AnnComm: RWO approved, on schedule for 1Q 05.62 13-05 Nov-97 7 5 LTSI. Replaced by 13-06Ai MI injector63 13-07 Jul-91 7 5 No flowline, fraced into H2O, T x IA comm64 13-09 Jun-91 6 2 Recent patch failed. Evaluating additional patch/need AA/ on hold until WI risk assessment complete65 13-10 Jun-94 2 5 Ann Comm: uneconomic RWO66 13-26 Feb-97 2 5 Ann Comm: uneconomic RWO67 13-27A Aug-02 6 2 Ann Comm: RWO or RST required68 13-28 May-94 2 5 bubbles in the cellar. Replaced by 13-13A69 13-33 Dec-94 3 5 Low oil High TGOR, Ann Comm70 14-02B Apr-00 1 2 Waiting for response to planned PWI conversion nearby71 14-08A Dec-02 7 5 No production from parent of lateral 14-08AL172 14-09B Aug-03 6 1 Ann Comm Work ongoing.73 14-11 Aug-98 6 5 LTSI. Eval for Rig ST74 14-15 Sep-01 6 7 TxIA. RWO for SWIPE(likely late '04)75 14-18A May-00 3 3 Eval for ST ongoing76 14-20 Feb-00 6 7 TxIA. Hole 5588. RWO pkg approved77 14-21 Jul-03 6 2 IAxOA communication. Needs waiver. Wait until new process landed.78 14-23 Apr-03 6 7 TxIA. FTS well. RWO pkg approved79 14-30 Oct-03 3 2 Low fluid rate and AC. Working sidetrack package80 14-38 Nov-94 3 5 TxIA and low PI (SI 11/94). No flowline. Eval ST81 14-39 Jun-94 6 5 IAxOAxForm. Leak @ 81'. No flowline.82 15-03 Jun-94 6 5 Cret leak, leaking sqz perfs, major fish in tubing; surface facilities given to another well83 15-10A Jan-91 6 5 Major leaks and a channel; no surface facilities; bottom hole location developed by 15-4984 15-17 Mar-03 6 1 TxIA comm; waiting on long patch installation85 15-22 Dec-02 6 7 Tubing shot; looking at RWO vs. RST86 15-24 Mar-95 6 5 Collapsed tubing, cret leak.87 15-39 May-98 6 2 RWO not feasible; RST very expensive; we are looking at an extended patch w/cement pkr.* Note - Wells shut in for all of 2004. Exhibit 102004 Shut In Wells#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments88 15-42A Dec-02 6 3 Tubing shot; coil plus package issued89 15-47 Oct-02 6 5 Tbg very rotten, IA cemented. Well secured w/ sand plug--chunks of tbg falling down on plug.90 15-49A Jul-03 6 5 12/03 LDL found five tubing leaks--can't justify repairs or ST at this time.91 16-06A Jun-03 3 2 SI for low rate, Under evaluation, May be part of 2006 Coil ST program92 16-24 Aug-00 2 5 Was MIST injector; changed over to a producer; now SI for high watercut93 16-31 Apr-95 6 2 Was possible MIST candidate but tbg leaks on gas94 17-13 Jun-01 3 3 RST on 2005 Rig Schedule, Will be converted from Producer to Injector95 18-01A Dec-99 6 7 Multiple holes in tbg. On RWO summary list.96 18-12A Dec-99 1 3 Evaluating ST target area.97 18-28 Nov-00 6 5 Hole in tbg and casing. CTU fish in well. Low remaining value and very high risk WW opportunity.98 18-31 Apr-03 1 5Thin LOC in this area. Low value. Does see some swing production on-time in winter. No plans at this time.99 A-02 Sep-03 6 7 Patch failed. Working on RWO for long term fix.100 A-17 Jul-03 5 2 Injects into fault. Evaluating injector sidetrack.101 A-18A Jun-03 6 2 Bubbling in cellar. Evaluating - low IOR.102 A-20 Apr-03 6 7 RWO approved. On schedule for January.103 A-23 Jan-03 4 2 Gravel pack procedure awaiting results from 12-28 (2005)104 A-25A Nov-97 7 5 LTSI - no tubing in well105 A-30A Jun-03 4 1 RST complete and AFE revision approved. Work on the 9 day schedule.106 A-34A May-04 6 7 RWO approved. On schedule for January.107 A-41 Sep-00 6 5 LTSI - cretaceous leak. Evaluating RST.108 B-09 Sep-95 5 5 Injects into fault. Used for pit dewatering.109 B-11 Jan-91 2 5 T&A. LTSI - No FL ; surface facilities given to B-35110 B-15 Nov-99 6 5 Potential for UZI conversion 2005/6111 B-20 Aug-02 6 1Prod log on WBL to determine source of gas and Extended patch program pending on the slope. Possible for GSO. 112 B-22A Jul-01 2 5 potential re-drill candidate - wish we still had the parent well today…potential UZI conversion 2005/6113 B-23A May-03 6 7 RWO on schedule for November 2004 - keeps getting pushed back on the schedule114 B-24 Jan-93 6 5 Abandoned in early 90's.Surface equipment being used by B-33A. 115 B-25 Nov-03 6 1 Cellar liner installed. Evaluating SC waiver potential. 116 B-26B Jun-03 1 5 Not healing anymore - under evaluation117 B-28 Feb-00 5 5 GDWFI-MI pilot. Sidetrack candidate - would need production facilities/tie in also118 B-29A Oct-01 1 5 Gas production from liner lap. Needs more IOR for GSO.119 B-36 Jun-03 6 7 RWO approvals obtained - not on drilling schedule???120 C-05A Feb-02 3 1 Low PI well will not flow. Evaluating additional adperf potential.121 C-12A Apr-03 7 2Well is twinned with C-11A, which is a prolific well. Due to velocity constraints C-12 must remain SI until C-11A is SI.122 C-14 May-91 7 5 Well was P&A'd in 1991 and has no facilities. Reserves captured by offset wells123 C-38 Nov-97 6 5 Cretaceous leak, flowline taken, eval ST.124 D-06A Aug-03 6 7 TxIA Comm. Well Secured w/ TTP 09/04/03. Tbg in poor condition. RWO package issued.125 D-14A Sep-02 6 1 Working on new Patch. First Patch failed and new leak found.126 D-20 Nov-02 6 1 Plan to run patch 1Q 2005. If patch fails RWO.127 E-11A Sep-00 6 3 hole/collapsed tubing, ann comm issues - planned as Pavlov target* Note - Wells shut in for all of 2004. Exhibit 102004 Shut In Wells#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments128 E-18B Nov-04 6 2 Rates from AFE pkg- well never popped- liner obstruction; needs new CST129 E-38 Nov-03 6 7 TxIA comm - RWO pending in 1/05.130 F-07 Jul-91 6 5 Abandoned during RWO. Flowline removed. No forward plans.131 F-12 Oct-03 6 1 Ann Comm. Leaking POGLM has been pulled. Rerun POGLM on WBL.132 F-18 Sep-99 6 5 Old injector / Producer. No value. Flowline removed.133 F-19 Aug-96 6 5 Old injector / Producer. No value. Flowline removed.134 F-30 Nov-03 3 2 Low productivity. Evaluating options to increase productivity and return to production.135 F-33 Apr-98 3 5 Low rate Sag-only well, SI since '98 due to low potential. No flowline.136 F-34 Nov-03 3 2 Low productivity. Evaluating options to increase productivity and return to production.137 F-38 Jan-02 6 2 Rotten tubing. RWO under evaluation.138 G-03A Dec-04 6 1 No POGLM over tubing punches. Patch procedure on Slope.139 G-09A Oct-02 6 2 Patch is in works, IOR is low- no patch is on WBL yet140 G-17 Mar-03 6 2 TxIA communication. High GOR141 G-19A Jul-03 6 2 Well is secured w/ L&K for IAxOAxCond - crude in cellar. High GOR142 G-32A Jul-03 3 2 Won't flow post CIBP mill143 H-01A Jun-99 6 7 RWO package ready, w/o response from Y-18i.144 H-08 Jan-03 6 2 Low value currently, might use for UZI.145 H-10A Oct-97 6 5 P & A'd.146 H-12 May-91 6 5 Csg collapse appx 2000 ft, completion replaced.147 H-15 Jul-02 6 2 RWO unsuccessful, evaluating RST options; liner obstruction148 H-21 May-03 6 2 Dummy glv's didn’t work, low prior patch eval.149 H-28 Apr-01 6 5 Last target cheaper to drill from another well.150 H-31 Apr-01 6 2 Shallow outer casing leak. Investigating excavate and repair.151 J-03 Nov-04 6 2 Well head problem. Ongoing diagnostics.152 J-04 May-69 6 5 Well abandoned during RWO. No surface facilities.153 J-18 Jan-03 6 7 Rotten tubing. RWO package is approved.154 K-13 Oct-97 6 5Leaks from tbgxIAxOA. Makes oil to cellar. Risked economics of repair strategy look poor. Worked on RST Pkg. The decomplete and subsequent fix is too complex and very high risk. 155 K-17A Oct-97 6 7 Safed out with TTPlug. Small leak produces oil to cellar.156 L2-08A Jul-99 3 5 No current plans for this wellbore.157 L2-18A Sep-01 6 3 Tbg and casing damaged. Evaluating repair options and TT CTD options.158 M-01 Aug-87 7 5 suspended159 M-02 Oct-88 7 5 abandoned160 M-09B Apr-03 7 6 Now twinned with M-12A and can't compete161 M-27A Jul-97 3 5 LTSI, low rate, money pit162 M-38A Dec-03 6 2 Evaluating for leak waiver163 N-02 Jul-88 6 5 Replaced by N-24, wellhouse & flowline gone.164 N-03 Jan-96 6 5 Makes water in cellar.165 N-05 Aug-84 6 5 Replaced by N-23.166 N-06 Feb-05 6 7 Ann comm. Working RWO package.167 N-14A Oct-02 6 2 Evaluating RWO vs sidetrack. Ongoing diagnostics.168 P-03A Nov-02 6 4 Needs patch for MI inj. GC2 H2O shortage169 P-06A Aug-03 3 2 Programs for injectivity test on the WWBL. Will likely convert to injection post sidetrack.170 P-13 May-02 5 4 SI for GC2 H2O shortage - trying to get back on line.* Note - Wells shut in for all of 2004. Exhibit 102004 Shut In Wells#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments171 P-14 Mar-03 5 4 LTSI for TxIA communication. GC2 H2O shortage172 P-21B May-03 6 2 Evaluating long patch, RWO or S/T conversion to injection opportunity173 P-22 Dec-96 3 5 LTSI. No oil. Sidetrack candidate.174 P-23 Jun-02 6 4 Need to patch 2nd hole for MI. GC2 H2O shortage. Caliper prgm on slope175 Q-04A May-01 6 5 Rotten tubing. No ST targets evident.176 R-01 Nov-93 6 5Suspended with Ann Comm issues. No flowline or wellhouse. Replaced by R-39. Maybe has utility as an injector but costs are high177 R-13 Aug-99 1 4 LTSI, high GOR, waiting on conversion to injection178 R-28 Apr-03 5 2Shut in to test for Ann Comm waiver - passed, needs FCO due to fill in tubing and needs TTP pulled but will leave LTSI for now since it competes with R-39A179 R-36 Feb-95 2 5 Abandoned - saw less than expected LOC, never completed180 S-10A Nov-91 2 5 Never completed, No tbg. Eval ST181 S-118 Jul-04 5 4 Aur Booster pump182 S-13 May-04 6 1 SI for high WC, has failed pkr, ST candidate183 S-23 Sep-04 6 2 awaiting POP after br.head repair184 S-24B Mar-01 2 7 SI for high WC, has failed pkr, ST candidate185 S-25A May-00 2 7 Needs new RWO estimate, ~1mmbo, SOR to drlg 5-26-04186 S-29A May-00 2 7 RWO pending (tech pkg approved)187 S-30 May-00 2 7 SI for high WC, pattern mgt.188 S-31A Aug-01 7 2 SAG inj-failed ESP pump, awaiting AuroraBooster189 S-44L1 Aug-01 7 2 RWO pending (tech pkg approved)190 T-01 Jul-99 7 5 LTSI Injector, not an effective injector191 T-07 Jul-99 7 5 LTSI Injector, not an effective injector192 U-02A Jul-99 7 5 Hole in tubing and PC leak193 U-05 Jun-01 5 5 Not an effective injector194 U-06A Jun-01 5 5 High water cut, low productivity, Has add perf potential195 U-07 Jun-01 5 5 LTSI. No flowline, U-14 drains area, Could POP to see if it would support the cost of a flowline196 U-08A Jun-01 5 5 High watercut, flowlines given to U-15A.197 W-07 Aug-03 6 3 Tubing severely corroded, Rig sidetrack planned198 W-09A Aug-03 6 5 Unable to access liner to perforate post sidetrack199 W-11 Jul-04 6 2 Converted to injection200 W-17 Aug-03 4 1 IAxOAxTbg lk. Maybe future ST201 W-24 Feb-99 6 2 Converted to injection202 W-29 Feb-99 6 2 Converted to injection203 W-40 Mar-03 6 2 Failed MITIA204 X-16 Aug-03 4 1 RWO failed. ST drilled 12/04. Needs RST log and perforations to POP.205 X-27 Sep-04 6 2 TxIA, FTS (3 leaks). Needs RWO. Evaluating reserves.206 Y-03 Jan-03 5 3 GC2 injector SI. Evaluating pattern reconfiguration.207 Y-07 Apr-98 5 5 Injects into isolated fault block. Sidetrack candidate.208 Y-08A Apr-98 5 5LTSI since 1993No Facilities - Candidate CST/Conversion as part of Y-24i Pat reallignment (under evaluation).209 Y-11B Nov-02 5 5 Injects into fault.210 Y-12 Nov-02 5 5 failed NFT - will secure for LTSI with CaCO3 L&K211 Y-17B Nov-02 5 5 Gel squeeze of fault. Future ST candidate* Note - Wells shut in for all of 2004. Exhibit 102004 Shut In Wells#Sw NameShut-inDateReason for WellShut-InAFuture Utility Plans & PossiblitiesBCurrent Mechanical Condition/ Additional Comments212 Y-22A Nov-02 5 5 LTSI…suspended & BHL re-drilled as Y-25213 Y-26A Nov-02 5 5 SI for high WC; also has TxIA comm.214 Y-28 Jan-00 6 5 SI and secured - needs bradenhead weld & sidetracked.215 Y-31 Jan-00 6 5 Low GFR. Evaluating sidetrack.216 Y-34A Jan-00 6 5 Low GFR. No S riser. Sidetrack candidate.217 Y-37A Jan-00 6 5Coil cemented in hole. RST/Conversion candidate as part of Y-24i Pat reallignment. Optional Vs Y-07Ai RST which one more economic.218 Y-38 Dec-01 3 2 Low GFR and collapsed tbg. Sidetrack candidate.219 Z-02A Nov-00 6 7 RWO planned 220 Z-04 Oct-98 6 3 Sidetrack planned221 Z-05 Dec-05 2 1 Acid stim done 1/05222 Z-09 Dec-02 6 3 Sidetrack planned223 Z-11 May-05 6 3 Sidetrack planned224 Z-12 Oct-98 2 5 Injection conversion planned225 Z-14A Nov-00 7 3 Sidetrack planned226 Z-19 Jul-96 6 5 Injection conversion planned227 Z-20 Feb-98 7 6 No Flowline228 Z-25 Aug-03 7 1 Converted to injection229 Z-28 Mar-03 4 1 Injection test pending230 Z-35 Apr-01 3 5 Low PI, completion problems also, poor rock QA. Reasons for Well Shut-In1. High GOR, curently uncompetitive to produce due to facility constraints, no known mechanical problems2. High water, currently uneconomic to produce, no known mechanical problems3. Low production rate, no known mechanical problems4. Wellwork5. Reservoir Management6. Mechanical Problem7. Other (Specify under comments)B. Future Utility1. Wellwork Planned2. Under Evaluation3. Sidetrack Planned4. Reservoir Management5. No Current Utilization6. Surface Facilities7. RWO Candidate* Note - Wells shut in for all of 2004. Exhibit 11 1PSI Daily Injection History Cum Injection 01/30/05 01/30/05 300 300 Cum Injection 01/30/05 300 MMBW PSI Daily Injection History 0 100 200 300 400 500 600 700 800 08/02 11/02 04/03 08/03 12/03 03/04 07/04 11/04 04/05Injection Rate (MBWPD)Daily Rate Monthly Rate 2004 Ave Inj Rate = 395 MBWPD 02/01/05 Cum Inj = 301 MMBW Exhibit 11-2 PSI Pressures 3431 3507 3484 3459 2002 PSI-01 11/19/02 PSI-06 11/19/02 PSI-08 10/15/02 Bad data PSI-09 07/30/02 PSI-10 10/15/02 3427 2003 PSI-07 10/13/03 MDT PSI-08 07/17/03 Failed PFO 3496 3529 3475 3454 3512 35042004 PSI-01 08/28/04 PSI-05 08/19/04 PSI-06 08/29/04 PSI-07 08/20/04 PSI-09 10/21/04 PSI-10 01/04/05 +22 psi +44 psi +53 psi +12 psi +27 psi All pressures at 8800’ SS Datum Exhibit 11-3 PSI Datum Water Gradient DS 18 PGOC = 8580' SS ±? BSAD ~8500’ SS ~4000’ Horizontal 8800’ SS Datum Oil Gradient Gas Gradient PSI DS 18 Well Date 8400’ SS 8800’SS PSI-01 08/28/04 3368 3504 PSI-05 08/19/04 3398 3534 PSI-06 08/29/04 3425 3561 PSI-07 08/20/04 3352 3488 PSI-09 10/21/04 3390 3526 PSI-10 01/04/05 3423 3559 Exhibit 11-4Prudhoe Bay Pressure Hisory- Ivishak Exhibit 11-5Prudhoe Bay Pressure History- GD Exhibit 11-6 PSI-05 Perforations Exhibit 11-7 PSI-07 Perforations Exhibit 11-8 PSI-01 Injection Profile 50 MBWPD 08/24/040% 13% 62%100 MBWPD 08/24/040% 5% 62% 13%21% 12%12% Exhibit 11-9 PSI-06 Injection Profile 50 MBWPD 08/27/040% 3% 17% 59%100 MBWPD 08/27/040% 4% 14% 61%40 MBWPD Nov 20020% - 80% 20%6%7% 15%14% - - Exhibit 11-10 PSI-08 Injection Profile 40 MBWPD May 20035% 90% 5% 0% Exhibit 11-11 PSI-09 Injection Profile 50 MBWPD 10/17/040% 4% 4% 73%100 MBWPD 10/17/040% 3% 4% 79% 6%3% 13%11% Exhibit 11-12 PSI-10 Injection Profile 50 MBWPD 01/01/050% 34% 8% 58%100 MBWPD 01/01/050% 30% 11% 59% Obvious cross flow up from Zn 2A to 2C when shut-in