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Home My WebLink About2002 Endicott Oil Pool BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 31, 2003 Mr. Randy Ruedrich, Mr. Dan Seamount, Ms. Sarah Palin Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, AK 99501-3539 RE: Year End 2002 Endicott Oil Pool - Reservoir Surveillance Report Dear Commissioners: Attached is the 2002 annual Endicott Reservoir Surveillance Report. This report is a compilation of three reports tracking the Key Well Pressure Program, Gas-Oil contact Monitoring Program, and the Waterflood Surveillance Program. As in the past, BP Exploration extends an offer to brief the AOGCC regarding the reservoir depletion status and future plans for the pool. Please advise Jim Ambrose at 564-4375 concerning a convenient time for a meeting or if there are any other questions. Sincerely, Mark Weggeland Endicott Engineering and Development Team Leader bcc: Jim Ambrose Daryl Kleppin Madelyn Millholland Daniel Robertson Steve Schultz/ Jim Spearman Fernando Guitart Dick Powell/Henry Harrington Working Interest Owners 2 2002 Reservoir Surveillance Report Endicott Oil Pool March 31, 2003 Waterflood Surveillance Program Key Well Pressure Monitoring Program GOC Monitoring Program 1 2002 Endicott Reservoir Surveillance Report Table of Contents Page 1 Waterflood Surveillance Program: Introduction Page 2 Project Status Summary Page 2 Injection Well Performance Page 3 Waterflood Tracer Page 4 Future Waterflood/EOR Plans Page 4 Figure 1: Endicott Field Well Plat (highlighting injectors) Page 5 Table 1: Summary Of Pertinent Data Page 6 Table 2: Reservoir Balance For Waterflood Sands Page 7 Table 3: Injection Well Data Page 8 Figure 2: Waterflood Tracer Plat Page 9 Pressure Monitoring Program: Introduction Page 10 2002 Pressure Monitoring Program Page 10 2003 Pressure Monitoring Program Page 11 Figure 3: Endicott Field Well Plat (highlighting Key Wells) Page 12 Table 4: 2002 Key Well Pressure Monitoring Program Page 13 Table 5: 2002 Key Well Pressure Data Page 14 Table 6: 2003 Key Well Pressure Monitoring Program Page 15 GOC Monitoring Program: Introduction Page 16 2002 Gas-Oil Contact Monitoring Program Page 17 2003 GOC Monitoring Program Page 17 Appendices: 1. Production Rate vs. Time Plots 2. Cumulative Voidage & Reservoir Pressure vs. Time Plots 3. Injection Well Rate & Pressure vs. Time Plots 4. Historical Key Well Pressure Data 5. Reservoir Pressure vs. Time 6. Endicott Shut-in well list 1 Endicott Oil Field 2002 Waterflood Surveillance Program Introduction Conservation Order 202 Rule 12 approved a field wide waterflood project for the Endicott reservoir. The waterflood was to be implemented within two years of regular production and a waterflood plan submitted three months before actual water injection began. By letter, dated June 15, 1988, the plan to implement the field wide waterflood was approved and semi-annual pressure maintenance project reports stipulated. The Endicott Waterflood development was recognized as complete and fully operational by letter, dated January 11, 1991, and annual waterflood surveillance reporting was approved. This document constitutes the report for 2002. Project Status Summary Endicott Field production began in October 1987. From field start-up, produced gas has been reinjected back into the existing gas cap to provide pressure support. Water injection was initiated in February 1988, and a tertiary recovery process was initiated with the installation of a miscible injection compressor and commencement of miscible injection in March 1999. This report summarizes the cumulative effects of pressure maintenance since field start-up and details activities in 2002. The Endicott Field is generally described as having three areas. The three areas are fault blocks that are identified as the MPI (Main Production Island area), the SDI (Satellite Drilling Island area), and the NFB (Niakuk Fault Block). Vertically there are six subzones (3C, 3B, 3A, 2B, 2A, 1) that are the general geological subdivisions within the Kekiktuk formation. Initially produced gas was reinjected into the gas cap in the updip portion of MPI subzones 2A and 2B. Gas injection was extended into the MPI subzone 3A gas cap in May 1988, and into the subzone 3C gas cap in both the MPI and the SDI areas in 1993. Reservoir studies subsequently identified the SDI 3C area as a primary EOR target and supported the decision to halt immiscible gas injection in that subzone. As a result, SDI 3C gas injector 1- 15/P-25 was shut-in July 1998. In October 2000 well 1-15/P-25 was placed back on production when gas injector 2-06/J-22 was shut in with annular communication. Well 1- 15/P-25 was shut in during July 2001 upon completion of a workover to return 2-06/J-22 to gas injection. 2 Water injection is occurring in peripherally placed injectors in all subzones in all areas of the field with the exception of Zone 1, which is on primary depletion. Endicott’s EOR project began in March of 1999. The original EOR Phase I implementation plan consisted of 8 water-alternating-gas (WAG) injection wells, with two wells being on MI at any given time. This plan was based on an MI compressor design rate of 45 mmscfpd. In reality, the maximum sustainable MI rate achieved by the compressor has been closer to 20 mmscfpd, which can be handled by one well at a time. To date, miscible gas injection has occurred in 4 wells NFB 3A injector 2-22/L-14, SDI 3C injector 4-04/T-26, SDI 3C injector 3-47/Q-35 and SDI 3C injector 1-67/T-20. Produced gas samples have been collected in all of the producers offset from these injection wells to provide a baseline for use in MI breakthrough monitoring. Figure 1 shows a map of the field with well statuses as of December 31, 2002 including the existing water injectors, gas injectors and oil producers. No well service additions or changes have occurred since the last report date. Table 1 summarizes total production, injection, and well count data for the entire pool through December 2002. Table 2 details the reservoir balances by area and subzone through December 2002. The NFB is included in with the MPI on Table 2 for simplicity. Appendix 1 provides graphs of Production and Gas/Oil Ratio versus Time by area and subzone. Appendix 2 provides graphs of Cumulative Crude Production and Percent Original Oil in Place (OOIP) Recovered versus Time by area and subzone. Appendix 3 provides graphs of Cumulative Voidage and Reservoir Pressure versus Time by area and subzone. Appendix 7 lists the wells in the Endicott participating area that were shut in for the entire year of 2002. Injection Well Performance Table 3 provides an overview of the performance of each of the pressure maintenance injectors. Included in this exhibit are the start-up dates and cumulative injection volumes. 3 Appendix 4 provides graphs of the injection rates, injectivity index, and wellhead pressure versus time for each of the active injectors. Waterflood Tracer The waterflood tracer program was started in 1988. A total of 19 water injectors have been traced: 3 in 1988, 8 in 1989, 6 in 1991, and 3 in 1996 (well 2-44/R-12 was traced with two different tracers). The program has been very successful in identifying the progress of the waterflood as depletion matures. Numerous interventions have been implemented on producers and injectors to improve ultimate recovery. Figure 2 is an Endicott well plat showing the dates and types of tracers injected and the producing locations where the tracer has appeared. Future Waterflood/EOR Plans In 2002 there are no plans to trace additional water injectors. Twelve wells will be monitored for tracer. Samples of produced gas will continue to be obtained in the production wells that offset the EOR injection wells to monitor MI movement. Average MI injection rate in 2002 was 5.1 mmscfpd. This annual average rate is lower than 2001 due to repairs and modifications on the MI compressor that were performed in first half of 2002. Reservoir pressure and gas and water movement will continue to be closely monitored through logging, mechanical isolations, and well testing. Changing pressure maintenance needs will continue to be met by evaluating new well drilling locations, converting producers to injectors, profile modification of existing injectors, and target injection rate control. Offtake will continue to be optimized by evaluating new well drilling locations, remedial work on existing producers, and production rate control. 4 5 TABLE 1 ENDICOTT OIL POOL SUMMARY OF PERTINENT DATA (as of December 31, 2002) Water Injection Start-up: February 29, 1988 Miscible Gas Injection Start-up: March 24, 1999 Endicott Production since Field Start-Up: Black Oil and Condensate (MMSTB) 410.8 NGL's (MMSTB) 18.2 Gas (BSCF) 1,552.1 Water (MMB) 585.2 Endicott Injection since Field Start-Up: Gas (BSCF) 1,371.6 Miscible Injectant (BSCF) 11.5 Water (MMB) 953.5* Wells in Operation: Oil Producers 47 Gas Injectors 4 Water Injectors 21 Water-Alternating-Gas Injectors 1 Waste Water Disposal 1 ** Total 74 * Water injection volumes do not include Cretaceous injection ** Cretaceous injector not shown in Figure 1 6 7 MPI REGION by SUBZONE Produced Volume 3C 3B 3A 2B 2A 1 MPI TOTAL Oil 24.85 9.62 53.57 72.69 145.88 3.88 310.50 Free Gas 49.35 10.16 99.18 160.69 279.88 5.90 605.14 W ater 15.43 6.22 72.91 94.49 102.79 1.22 293.05 Total 89.63 26.00 225.65 327.87 528.55 11.00 1,208.70 Injected Volumes Gas 109.34 12.77 155.26 261.54 329.36 0.00 868.27 MI 3.41 2.47 26.98 23.07 20.10 0.00 76.03 Water 23.42 5.08 84.25 84.96 126.93 0.00 324.64 Total 136.18 20.32 266.49 369.57 476.39 0.00 1,268.94 Net Voidage Volumes Total -46.54 5.68 -40.84 -41.70 52.16 11.00 -60.25 SDI REGION by SUBZONE Produced Volume 3C 3B 3A 2B 2A 1 SDI TOTAL Oil 52.78 13.97 35.44 91.08 39.63 0.04 232.94 Free Gas 93.02 15.65 7.97 45.83 53.14 0.09 215.68 W ater 62.03 14.30 47.77 132.18 47.57 0.02 303.87 Total 207.83 43.92 91.18 269.08 140.33 0.15 752.49 Injected Volumes Gas 66.00 2.95 0.00 0.00 0.00 0.00 68.95 MI 4.39 0.00 0.00 0.00 0.00 0.00 4.39 Water 96.95 39.69 62.45 245.56 84.97 0.00 529.62 Total 167.34 42.64 62.45 245.56 84.97 0.00 602.95 Net Voidage Volumes Total 40.50 1.28 28.73 23.53 55.36 0.15 149.54 FIELD TOTALS by SUBZONE 3C 3B 3A 2B 2A 1 FIELD TOTAL Produced Volume Oil 77.64 23.59 89.01 163.77 185.51 3.92 543.44 Free Gas 142.37 25.81 107.14 206.52 333.01 5.99 820.83 W ater 77.46 20.52 120.68 226.67 150.35 1.24 596.92 Total 297.47 69.92 316.83 596.95 668.88 11.14 1,961.19 Injected Volumes Gas 175.34 15.72 155.26 261.54 329.36 0.00 937.21 MI 7.80 2.47 26.98 23.07 20.10 0.00 80.42 Water 120.38 44.77 146.70 330.52 211.90 0.00 854.26 Total 303.51 62.96 328.94 615.13 561.36 0.00 1,871.90 Net Voidage Volumes Total -6.05 6.96 -12.11 -18.17 107.52 11.14 89.29 NOTE: W ater injection volumes do not include Cretaceous injection TABLE 2 ENDICOTT OIL POOL RESERVOIR BALANCE FOR WATERFLOOD SANDS Through12/31/2002 (Values in MMRB) MPI Reservoir Area Cumulative Cumulative Cumulative Water Gas MI Start-Up Well Name MMBW BSCFG BSCFG Date 1-05/O-20 335.98 May-88 1-23/O-15 49.82 Mar-95 1-37/P-24 24.07 Dec-87 1-41/O-23 37.51 Dec-95 2-06/J-22 415.07 Oct-87 2-12/Q-16 160.02 Apr-93 2-16/M-16 62.93 Mar-89 2-22/L-14 43.66 3.29 May-89 2-24/M-12 4.69 Mar-95 2-34/P-14 57.31 Nov-89 *2-44/R-12 20.77 Mar-89 2-54/Q-12 59.99 Jan-92 2-64/U-10 4.08 Dec-90 2-70/U-15 18.57 Jul-89 5-01/SD-07 359.63 Oct-87 5-02/SD-10 49.97 Jan-88 SDI Reservoir Area Cumulative Cumulative Cumulative Water Gas MI Start-Up Well Name MMBW BSCFG BSCFG Date 1-15/P-25 100.90 Jun-93 1-43/P-26 112.42 Apr-89 1-51/V-20 9.68 Apr-93 1-67/T-20 12.92 May-99 1-69/V-19 15.46 Dec-90 **3-07/N-28 47.61 Apr-89 3-37/L-35 19.82 Aug-98 3-41/K-39 101.63 Apr-89 3-45/M-39 45.67 Sep-88 3-47/Q-35 14.61 1.88 Mar-95 3-49A/M-40 6.87 Apr-99 + 4-02/Q-28 8.48 May-88 4-04/T-26 30.63 6.36 Mar-90 4-08/P-27 37.25 May-93 4-14/R-34 38.10 Oct-89 4-40/P-43 7.09 Oct-92 ++ 4-48/K-43 11.85 Dec-90 Total 953.46 1371.60 11.53 Note: W ater injection volumes do not include Cretaceous injection. * Sidetracked in 9/97 ** Converted to production in 8/98 + Converted to production in 4/96 ++ SI since 4/97 Table 3 Endicott Oil Pool Injection W ell Data Through 12/31/2002 8 9 Endicott Oil Field 2002 Pressure Monitoring Key Well Program Introduction A pressure monitoring key well program was submitted to and approved by the AOGCC in Administrative Approval No. 202.5. This program supersedes the requirements of Conservation Order 202, Rule 6(c), and complies with Conservation Order 202, Rule 6(d). The pressure monitoring program key wells were chosen to provide a real coverage of reservoir pressure in each of the major subzones in the two production areas of the reservoir. Historically, the Key Well Program has included at least two points of pressure measurement for each of the producing subzones, one from each MPI and SDI area, to ensure that a valid picture of reservoir pressure behavior can be drawn. Seventeen wells were identified as key wells to track pressure variation within the five major subzones in each of the two main producing areas of the reservoir. Changes have been made through time as reservoir and well characteristics changed in order to provide representative data. Much more reservoir pressure data, other than the key well data, is gathered to address specific well and reservoir surveillance needs. Figure 3 is an Endicott well plot showing the location of the seventeen 2002 Key Well reservoir pressures. 2002 Pressure Monitoring Program Table 4 summarizes the wells included in the proposed 2002 Key Well Program. The 2002 program consisted of seventeen key wells. Table 5 summarizes the key well pressure data gathered in 2002. Several changes to the proposed plan occurred due to operational and production rate concerns. The zone 1 pressure was observed in well 1-09A/L-21 rather than the proposed well 1-25/K-22 and the Niakuk 3A pressure was observed in well 2-08/K-16 rather than the proposed well 2-18/L-16. In addition no pressure was obtained in the MPI 3B interval as the one well completed only in this interval, 2-42/P-13, has a series of tubing obstruction that operationally prevent gathering a reliable static pressure. Appendix 5 lists, by subzone, all current and former key wells with the reservoir pressures obtained since field start-up. These pressures are adjusted to a datum depth of 10,000 feet 10 TVDSS, as is customary in our state pressure reporting. Appendix 6 plots, by subzone and area, key well reservoir pressures along with all other reservoir pressure surveys. Generally speaking there is good agreement between the key well reservoir pressures and other pressure gathered around the field. There are a few exceptions where wells are in small pressure isolated regions. 2003 Pressure Monitoring Program The Endicott Key Well Pressure Monitoring Program has been successful in establishing and monitoring pressure trends within each of the major subzones. Changes in well service and configuration occasionally necessitate changes to the pressure monitoring program in order to obtain representative data. BPX plans to combine the MPI 3B and MPI 3C into a single pressure monitoring region. Only one well is completed in only the MPI 3B interval and historic pressure data indicated reservoir pressures in the two intervals share a similar performance. Table 6 summarizes the 2003 Endicott key well pressure monitoring program proposal consisting of 16 wells. As in past years, the amount of static pressure data obtained annually will likely exceed the sixteen wells included in the proposed 2003 Key Well Pressure Monitoring Program. At the operator’s discretion, representative reservoir pressures gathered in other wells during 2003 may be substituted for the proposed key wells to minimize production impacts or for operational necessity. As the field matures, we will be increasingly challenged with managing this need for additional pressure data while minimizing the cost and associated production impacts. 11 12 2002 Key Well Pressures Figure 3Pressures normalized to 10000’ ss datum 13 Well Area Subzone(s)Comments 1-25A/K-22 MPI Z1 1-01/J-19 Niakuk 2A/2B Commingled pressure 1- 2002 KEY WELL PRESSURE MONITORING PROGRAM PROPOSAL ENDICOTT FIELD TABLE 4 2-18/L-16 Niakuk 3A 2-26/N-14 Niakuk 3B/3C Commingled pressure 33B/L-24 MPI 2A 1-03/P-16 MPI 2B Single zone high angle well 1-39/P-17 MPI 3A Lower 3A monitor point 2-42/P-13 MPI 3B 2-52/S-14 MPI 3B/3C Commingled pressure 2-58/S-09 MPI 3C 3-39A/I-37 SDI 2A 3-33/K-37 SDI 2B 3-35/L-36 SDI 3A Upper 3A monitor point 4-32/K-38 SDI 3A Lower 3A monitor point 3-23/N-32 SDI 3B 4-18/S-30 SDI 3C Eastern area 1-57/R-23 SDI 3C Western area Well Area Subzone(s)Pressures 1-09A/L-21 *MPI Z1 2,308 psia 1-01/J-19 Niakuk 2A/2B 4,255 psia 2-08/K-16 *Niakuk 3A 4,306 psia 2-26/N-14 Niakuk 3B/3C 6,290 psia 1-33B/L-24 MPI 2A 4,286 psia 1-03/P-16 MPI 2B 4,566 psia 1-39/P-17 MPI 3A 4,720 psia 2-42/P-13 ✬MPI 3B 2-52/S-14 MPI 3B/3C 5,092 psia 2-58/S-09 MPI 3C 2,908 psia 3-39A/I-37 SDI 2A 4,242 psia 3-33/K-37 SDI 2B 4,587 psia 3-35/L-36 SDI 3A 5,000 psia 4-32/K-38 SDI 3A 4,334 psia 3-23/N-32 SDI 3B 4,567 psia 4-18/S-30 SDI 3C 4,171 psia 1-57/R-23 SDI 3C 4,367 psia DATUM: 10000' TVDss * Substituted well other than originally proposed due mechanical or production constraints 2002 KEY WELL PRESURE MONITORING PROGRAM DATA ENDICOTT OIL FIELD TABLE 5 ✬ No available substitute for well 2-42/P-13 to measure MPI 3B pressure. Historical pressure data indicates MPI 3B and MPI 3C pressures are equivalent. 14 15 Well Area Subzone(s)Comments 1-25A/K-22 MPI Z1 1-01/J-19 Niakuk 2A/2B Commingled pressure 2-18/L-16 Niakuk 3A 2-26/N-14 Niakuk 3B/3C Commingled pressure 1-33B/L-24 MPI 2A 1-03/P-16 MPI 2B Single zone high angle well 1-39/P-17 MPI 3A Lower 3A monitor point 2-52/S-14 MPI 3B/3C Commingled pressure 2-58/S-09 MPI 3C 3-39A/I-37 SDI 2A 3-33/K-37 SDI 2B 3-35/L-36 SDI 3A Upper 3A monitor point 4-32/K-38 SDI 3A Lower 3A monitor point 3-23/N-32 SDI 3B 4-18/S-30 SDI 3C Eastern area 1-57/R-23 SDI 3C Western area Change from the 2002 proposed program: Removed in MPI 3B pressure as only one well is completed only in this interval 2003 KEY WELL PRESSURE MONITORING PROGRAM PROPOSAL ENDICOTT FIELD TABLE 6 Endicott Oil Field 2002 GOC Monitoring Program Introduction A Gas - Oil Contact (GOC) Monitoring Key Well Program was submitted for the Endicott Field in October 1988, one year after field start-up in accordance with AOGCC Conservation Order 202, 9(c). At that time, BP Exploration sought, and received a waiver (Administrative Approval Order 202.5) from the State of Alaska, to initiate the key well program for Endicott on a subzone basis for each of the three distinct reservoir development areas of the field. Administrative Order No. 232.1 provided an exemption for key well GOC monitoring in Sections 1, 3, 7, 9, 10, and 35 of the field as being outside a real gas cap limits of the reservoir. The initial GOC Monitoring Key Well Program consisted of six wells: 1-01/J-19, 1-09/J-18, 1-27/P-20, 1-29/M-25, 2-04/M-19, 3-01/N-29. Table 7 details the history of pulsed neutron log observations in the six GOC key wells. The table identifies GOC movement and gas influx by under-running major shales within Subzones 3A and 2B. Conservation Order No. 462, rule 9 (b) revoked the Key Well Monitoring Program and allowed the operator to submit modifications to the Gas Oil Monitoring Program for Commission approval. The details of the 2003 GOC Monitoring Program as submitted by the operator are listed in the section below. The GOC monitoring program for Endicott is based on the understanding of a limited ability to monitor field-wide gas cap movement. A scarcity of wells and limited lateral offset from gas severely restricts the use of time lapse cased-hole logging as a viable tool to predict gas movements at Endicott. It is recognized that narrow hydrocarbon corridors caused by a relatively steep 6 degree structural dip combined with sands separated by thick laterally continuous shales promotes under-running as a common gas movement mechanism. In addition to the continuous shales that separate the reservoir into six vertically isolated subzones, major east-west trending fault offsets provide either lateral hydraulic isolation or partial pressure communication between the three main Endicott development areas. The more massive high quality sands of the 3A and 2B subzones are where more regional GOC effects are more easily noted. Monitoring region gas movement in the 2A subzone is more tenuous due to the close proximity to gas and likelihood of localized gas coning and 16 17 under runs. Monitoring gas movement in the 3B, and 3C subzones is not practical due to complex stratigraphy (shaliness). 2002 GOC Monitoring Program During 2002, a total of 11 cased - hole pulsed and compensated neutron logs (PNL / CNL) were acquired. These logs are routinely used for reservoir surveillance and diagnosing well problems in order to develop reservoir management plans and remedial interventions. Following is a list of the wells from which neutron logs were acquired during 2002: Well Location Well Location 1-01/J-19 Niakuk 2-14/O-16 MPI 1-03/P-16 MPI 2-54/Q-12 MPI 1-19/I-18 Niakuk 3-07A/L-29 SDI 1-27/P-20 MPI 3-29/J-32 SDI 1-29/M-25 MPI 4-10/M-28 MPI 1-33B/L-24 MPI 11 Wells Total The 2002 GOC monitoring program focused on the understanding the location of gas in the 2A and 2B subzones in the Niakuk fault block (1-01/J-19, 1-19/I-18), the MPI fault block 1-03/P-16, 1-27/P-20, 1-29/M-25, 1-33B/L-24, 2-14/O-16, 4-10/M-28) and SDI fault block (3-07A/L-29, 3-29/J-32). One log was obtained in well 2-54/Q-12 to evaluation gas movements in the MPI 3B/3C intervals. 2003 GOC Monitoring Program BPX proposes a 20032 GOC Monitoring Program that consists of a notional five well program focusing on the 2A and 2B intervals and to a lesser extent the 3B and 3C intervals. Gas movement in these intervals is the most active. The 2A and 2B intervals have the highest potential for monitoring depletion and improving recovery through effective reservoir management and the identification of potential infill drill locations. Production logging and down-hole mechanical isolation of gas prone intervals also provide a means to monitor gas influx. Together, these tools constitute an effective means to monitor gas movement at Endicott Appendix 1 Production Rate vs. Time Plots Book2.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - MPI Region - Zone K3C1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % Endicott - MPI Region - Zone K3B1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAY GORWater Cut % Endicott - MPI Region Zone K3A1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAY GORWater Cut % Book1.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - MPI Region - Zone K2B1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAY GORWater Cut % Endicott - MPI Region - Zone K2A1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAY GORWater Cut % Endicott - MPI Region - Zone K11.00E+001.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAY GORWater Cut % Book7.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - SDI Region - Zone K3C1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % SDIK3B.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - SDI Region - Zone K3B1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % Book9.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - SDI Region - Zone K3A1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % Book10.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - SDI Region - Zone K2B1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % Book16.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - SDI Region - Zone K2A1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAY GORWater Cut % Book11.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - Niakuk Fault Block - Zone K3C1.00E+011.00E+021.00E+031.00E+0486 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % Book12.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - Niakuk Fault Block - Zone K3B1.00E+011.00E+021.00E+031.00E+0486 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % Book13.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - Niakuk Fault Block - Zone K3A1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % Book14.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - Niakuk Fault Block- Zone K2B1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % Book15.xlsEndicott Oil Pool, BP (Alaska), Inc3/31/2003Endicott - Niakuk Fault Block - Zone K2A1.00E+011.00E+021.00E+031.00E+041.00E+0586 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03Oil Rate and GOR110100100010000WatercutOil Prod Rate STB/DAYGORWater Cut % Appendix 2 Cumulative Voidage and Reservoir Pressure vs. Time Plots Case 1=endHistory.layers.033103 -20000 -10000 0 10000 20000 30000 40000 50000 60000 70000 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBMPI_Sum VOID1 Case 1=endHistory.layers.033103 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 2000 3000 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBMPI_Sum VOID1 Case 1=endHistory.layers.033103 -10000 0 10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 210000 220000 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBMPI_Sum VOID1 Case 1=endHistory.layers.033103 -10000 0 10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBMPI_K2B VOID1 Case 1=endHistory.layers.033103 -10000 0 10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBMPI_Sum VOID1 Case 1=endHistory.layers.033103 -14000 -13000 -12000 -11000 -10000 -9000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBMPI_K1 VOID1 Case 1=endHistory.layers.033103 -70000 -60000 -50000 -40000 -30000 -20000 -10000 0 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBSDI_Sum VOID1 Case 1=endHistory.layers.033103 -17000 -16000 -15000 -14000 -13000 -12000 -11000 -10000 -9000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBSDI_Sum VOID1 Case 1=endHistory.layers.033103 -40000 -30000 -20000 -10000 0 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBSDI_Sum VOID1 Case 1=endHistory.layers.033103 -60000 -50000 -40000 -30000 -20000 -10000 0 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBSDI_K2B VOID1 Case 1=endHistory.layers.033103 -80000 -70000 -60000 -50000 -40000 -30000 -20000 -10000 0 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBSDI_K2A VOID1 Case 1=endHistory.layers.033103 -6000 -5000 -4000 -3000 -2000 -1000 0 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBNIAK_Sum VOID1 Case 1=endHistory.layers.033103 -5000 -4000 -3000 -2000 -1000 0 1000 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBNIAK_Sum VOID1 Case 1=endHistory.layers.033103 -10000 0 10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 210000 220000 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBMPI_Sum VOID1 Case 1=endHistory.layers.033103 -30000 -20000 -10000 0 10000 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBNIAK_K2B VOID1 Case 1=endHistory.layers.033103 -50000 -40000 -30000 -20000 -10000 0 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003Voidage Cum MRVBNIAK_K2A VOID1 Appendix 3 Injection Well Rate and Pressure vs. Time Plots Name: 1-11/SN-04 ID: 1-11/SN-04 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 1-11/SN-04 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 1-23/O-15 ID: 1-23/O-15 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 1-23/O-15 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 1-37/P-24 ID: 1-37/P-24 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 1-37/P-24 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 1-41/O-23 ID: 1-41/O-23 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 1-41/O-23 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 1-43/P-26 ID: 1-43/P-26 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 1-43/P-26 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 1-51/V-20 ID: 1-51/V-20 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 1-51/V-20 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 1-67/T-20 ID: 1-67/T-20 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 1-67/T-20 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 1-69/V-19 ID: 1-69/V-19 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 1-69/V-19 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 2-16/M-16 ID: 2-16/M-16 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 2-16/M-16 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 2-22/L-14 ID: 2-22/L-14 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 2-22/L-14 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 2-24/M-12 ID: 2-24/M-12 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 2-24/M-12 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 2-34/P-14 ID: 2-34/P-14 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 2-34/P-14 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 2-44/R-12 ID: 2-44/R-12 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 2-44/R-12 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 2-54/Q-12 ID: 2-54/Q-12 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 2-54/Q-12 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 2-64/U-10 ID: 2-64/U-10 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 2-64/U-10 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 2-70/U-15 ID: 2-70/U-15 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 2-70/U-15 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 3-07/N-28 ID: 3-07/N-28 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 3-07/N-28 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 3-37/L-35 ID: 3-37/L-35 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 3-37/L-35 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 3-41/K-39 ID: 3-41/K-39 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 3-41/K-39 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 3-45/M-39 ID: 3-45/M-39 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 3-45/M-39 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 3-47/Q-35 ID: 3-47/Q-35 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 3-47/Q-35 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 3-49A/M-40 ID: 3-49A/M-40 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 3-49A/M-40 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 4-02/Q-28 ID: 4-02/Q-28 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 4-02/Q-28 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 4-04/T-26 ID: 4-04/T-26 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 4-04/T-26 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 4-08/P-27 ID: 4-08/P-27 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 4-08/P-27 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 4-14/R-34 ID: 4-14/R-34 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 4-14/R-34 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 4-40/P-43 ID: 4-40/P-43 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 4-40/P-43 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 4-48/K-43 ID: 4-48/K-43 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 4-48/K-43 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 5-02/SD-10 ID: 5-02/SD-10 Type: Bore Format: [p] Inj Index BP ALASKA - ENDICOTT 5-02/SD-10 Daily Water Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10000 20000 30000 40000 50000 60000(L1) 0 500 1000 1500 2000 2500 3000(R1) (L1) Daily Water Inj (bbls)(L1) Daily Mi Inj (R1) Daily WHIP (psia) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 10.0 20.0 30.0 40.0(L1) (L1) Injectivity Index (scf/psi)(L1) Injectivity Index (scf/psi) VS Time Name: 1-05/O-20 ID: 1-05/O-20 Type: Bore Format: [p] Daily Gas Injection BP ALASKA - ENDICOTT NAME: 1-05/O-20 Daily Gas Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 12.0 24.0 36.0 48.0 60.0 72.0 84.0 96.0 108 120(L1) 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000(R1) (R1) Daily WHIP (psia)(L1) Daily Gas Inj (mmscf/d) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 6000 12000 18000 24000 30000(L1) Injectivity Index Gas(scf/psi)VS Time Name: 1-15/P-25 ID: 1-15/P-25 Type: Bore Format: [p] Daily Gas Injection BP ALASKA - ENDICOTT NAME: 1-15/P-25 Daily Gas Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 12.0 24.0 36.0 48.0 60.0 72.0 84.0 96.0 108 120(L1) 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000(R1) (R1) Daily WHIP (psia)(L1) Daily Gas Inj (mmscf/d) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 6000 12000 18000 24000 30000(L1) Injectivity Index Gas(scf/psi)VS Time Name: 2-06/J-22 ID: 2-06/J-22 Type: Bore Format: [p] Daily Gas Injection BP ALASKA - ENDICOTT NAME: 2-06/J-22 Daily Gas Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 12.0 24.0 36.0 48.0 60.0 72.0 84.0 96.0 108 120(L1) 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000(R1) (R1) Daily WHIP (psia)(L1) Daily Gas Inj (mmscf/d) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 8000 16000 24000 32000 40000(L1) Injectivity Index Gas(scf/psi)VS Time Name: 2-12/Q-16 ID: 2-12/Q-16 Type: Bore Format: [p] Daily Gas Injection BP ALASKA - ENDICOTT NAME: 2-12/Q-16 Daily Gas Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 12.0 24.0 36.0 48.0 60.0 72.0 84.0 96.0 108 120(L1) 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000(R1) (R1) Daily WHIP (psia)(L1) Daily Gas Inj (mmscf/d) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 6000 12000 18000 24000 30000(L1) Injectivity Index Gas(scf/psi)VS Time Name: 5-01/SD-07 ID: 5-01/SD-07 Type: Bore Format: [p] Daily Gas Injection BP ALASKA - ENDICOTT NAME: 5-01/SD-07 Daily Gas Injection 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 12.0 24.0 36.0 48.0 60.0 72.0 84.0 96.0 108 120(L1) 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000(R1) (R1) Daily WHIP (psia)(L1) Daily Gas Inj (mmscf/d) VS Time 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 030 8000 16000 24000 32000 40000(L1) Injectivity Index Gas(scf/psi)VS Time Appendix 4 Historical Key Well Pressure Data Appendix 5 Reservoir Pressure vs. Time Region: MPI Zone: 3CPressure vs. Time100020003000400050006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Key WellAll WellsBP Exploration, Endicott Region: MPI Zone: 3BPressure vs. Time35004000450050005500Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Key WellAll WellsBP Exploration, Endicott Region: MPI Zone: 3APressure vs. Time40004500500055006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Region: MPI Zone:2BPressure vs. Time40004500500055006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Region: MPI Zone:2APressure vs. Time30003500400045005000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Zone:1Pressure vs. Time2000250030003500400045005000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumMPI Key WellsMPI All WellsSDI All WellsBP Exploration, Endicott Region: SDI Zone: 3CPressure vs. Time200025003000350040004500500055006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Region: SDI Zone: 3BPressure vs. Time100020003000400050006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Region: SDI Zone: 3APressure vs. Time3000350040004500500055006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Region: SDI Zone: 2BPressure vs. Time40004500500055006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Region: SDI Zone: 2APressure vs. Time30003500400045005000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Region: NFB Zone: 3CPressure vs. Time100020003000400050006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Key WellAll WellsBP Exploration, Endicott Region: NFB Zone: 3BPressure vs. Time100020003000400050006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Key WellAll WellsBP Exploration, Endicott Region: NFB Zone: 3APressure vs. Time300035004000450050005500Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Region: NFB Zone: 2BPressure vs. Time35004000450050005500Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Region: NFB Zone: 2APressure vs. Time40004500500055006000Jan-87Jan-88Jan-89Jan-90Jan-91Jan-92Jan-93Jan-94Jan-95Jan-96Jan-97Jan-98Jan-99Jan-00Jan-01Jan-02Jan-03Pressure at 10,000 ft TVD ss DatumKey WellAll WellsBP Exploration, Endicott Appendix 6 Endicott Shut-in Well List Sw NameDate Shut-InReason for Well Shut-In1Current Mechanical Condition of Well2Future Utility Plans & Possibilities3Comments1-15/P-25Jul-01D. Tubing leakTubing leak, good casing integrity2. Remedial well work plannedNon rig tubing repair planned1-17A/I-17May-99A. -- High TGORNo known problems1. sidetrack candidate1-21/K-25Jan-00A, D -- High TGOR, tubing leakConfirmed tubing leak. Wireline plug in tubing1. Evaluating sidetrack or conversion optionsPotential for sidetrack or workover to convert to gas injector1-39/P-17Jul-01B. -- High TGORNo known problems1. Evaluating injection conversion optionsPotential for conversion to water injection1-45/Q-26Dec-01D. Tubing leakTubing leak 2. Remedial well work to repair tubing in progress2-26//N-14Oct-01B. High TGORNo known problems1. sidetrack candidate2-62/Q-17Oct-00A, B -- High GOR, High WatercutNo known problems1. Evaluating remedial optionspotential for cycle producer3-17D/M-31Mar-99A.-- High TGORNo known problems1. sidetrack candidateSidetrack in progress 3/023-19/R-28Aug-01B, D. High TGOR, possible mechanical problemSome indications of tubing leak2. Tubing leak detection diagnostics planned3-23/N-32Nov-01A. High TGORNo known problems1. Evaluating sidetrack or conversion options3-33/K-37Jul-97B. -- High TGOR Mechanical condition satisfactory.1. Evaluating sidetrack or conversion optionsPotential for sidetrack or workover to convert to water injector3-35/L-36Mar-97B. -- High TGOR Mechanical condition satisfactory.1. sidetrack candidateusing as 3A pressure monitor4-14/R-34Apr-00D. Casing leakCasing leak3. Long term shut in/ no immediate plansOffset injector inject adequately supports area4-26/O-34Oct-01B. -- High TGOR No known problems6. Otherreturn to production as future EOR producer4-28/N-37Oct-01B. -- High TGOR No known problems6. Otherreturn to production as future EOR producer4-40/P-43Apr-00C. -- Low rate injectorNo known problems6. OtherPossible MI injector or return to water injector to support infill locations4-42/P-38Nov-97B. -- High TGOR Mechanical condition satisfactory.6. Otherreturn to production as future EOR producer4-44/M-44Jan-93C. -- Poor Injectivity380' coiled tubing fish in hole1. sidetrack candidateCoiled tubing fish to recover prior to sidetrack4-48/K-43Apr-97E. -- WF ManagementMechanical condition satisfactory.1. sidetrack candidatenot providing useful WF support4-50/K-41May-98B. -- High TGOR 9 5/8" pack-off needs sealing6. Otherreturn to production as future EOR producerENDICOTT Shut-In Wells 2002