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Home My WebLink About2001 Greater Point McIntyre AreaBP Exploration (Alaska), Inc. 900 East Benson Boulevard Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 564 5111 March 28, 2002 Commissioners Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Pt. McIntyre Oil Pool Annual Reservoir Report Dear Commissioners: Enclosed is the Pt. McIntyre Oil Pool Annual Reservoir Report as required by Conservation Order 317B, for the year ended December 31, 2001. We look forward to discussing this report with you at our mid-year meeting. Please call Gordon Kidd 564-5492 if you have any questions regarding this report. Sincerely, Anne Shaw GPMA Resource Manager Attachments CC: M. Vela (ExxonMobil) J. Johnson (PAI) K. Griffin (Forest Oil) 1 Prudhoe Bay Unit 2001 Pt. McIntyre Oil Pool Annual Reservoir Report This Annual Reservoir Report for the year ending December 31, 2001 is being submitted to the Alaska Oil and Gas Conservation Commission in accordance with Conservation Order 317B for the Pt. McIntyre Oil Pool. This report summarizes surveillance data and analysis and other information as required by Rule 15 of Conservation Order 317B. Progress of Enhanced Recovery Project Implementation and Reservoir Management Summary (Rule 15 a) Enhanced Recovery Projects The Pt. McIntyre Working Interest Owners approved a hydrocarbon miscible EOR project at Pt. McIntyre in May 1998. Vapors generated in the LPC NGL plant downstream from the feed flash drum provide the enriching components for the miscible injectant (MI) solvent stream. MI is transported to the Pt. McIntyre drillsites via a distribution pipeline and is distributed and injected at the drillsites by means of trunk-and-lateral piping distribution systems at both Pt. McIntyre drillsites. Two wells at the PM-1 drillsite and six wells at the PM-2 drillsite have been equipped for MI injection. MI injection resumed into the Pt. McIntyre reservoir in October 2001 following repairs to the electric drive motor on the compressor that caused injection to be shut down in October 2000. During the last 6 months, the compressor has performed as forecasted and has incurred minimal downtime. Reservoir Management Summary Production and injection volumes for the year ending December 31, 2001 are summarized in Table 1. Current well locations are shown in Figure 1. A total of 83 Pt. McIntyre wells (including P&A’d wells) have been drilled as of December 31, 2001. No new wells were drilled in 2001. The dominant oil recovery mechanisms in the Pt. McIntyre field are waterflooding in the down-structure area north of the Terrace Fault (see Figure 1) and gravity drainage in the up-structure area referred to as the Terrace Fault Block. Gas injection commenced in the Terrace Fault Block with field startup to replace voidage and promote gravity drainage. Waterflood was in continuous operation during 2001 with 15 wells on water injection by year end. Voidage replacement through water and gas injection approximately balanced offtake during 2001. 2 Voidage Balance by Month of Produced and Injected Fluids (Rule 15 b) Monthly production and injection surface volumes are summarized in Table 1. A voidage balance of produced fluids and injected fluids for the report period is shown in Table 2. As summarized in these analyses, monthly voidage is routinely balanced with injection. Analysis of Reservoir Pressure Surveys within the Pool (Rule 15 c) Reservoir pressure monitoring is performed in accordance with Rule 12 of Conservation Order 317B. A summary of reservoir pressure surveys obtained during the reporting period is shown in Table 3. Figure 2 shows a map of reservoir pressures as of December 2001 at 8800 ft TVDss (true vertical depth subsea). Results and Analysis of Production & Injection Logging Surveys (Rule 15 d) Interpreted results of production logs are reported in Table 4. No injection logging surveys were conducted during the reporting period. Surveys were obtained using conventional cased hole production logging tools including spinner, temperature, pressure and fluid identification. A gas tracer was injected in the P2-42 injection well in December 2001, when P2-42 commenced miscible gas injection. Gas samples will be collected and analyzed from surrounding producing wells during 2002 in order to track the movement of the miscible gas injected. Results of Any Special Monitoring (Rule 15 e) Two cased hole formation resistivity logs were run during the reporting period to monitor fluid saturation in the reservoir. Interpreted results are summarized in Table 5. One cased hole neutron survey to monitor gas-oil contact (GOC) movement was performed during the reporting period. Interpreted results are summarized in Table 6. Future Development Plans and Review of Plan of Operations and Development (Rule 15 f & g) Production Forecast Oil production from Pt. McIntyre will continue to decline due to increasing water cuts at Pt. McIntyre and water handling constraints at the Lisburne Production Center. The expected average annual oil production rate for Pt. McIntyre in 2002 is 40 MBOPD, including NGLs and downtime impacts. Reservoir management strategies are in place to optimize oil rate and recovery. 3 Development Drilling Development drilling will be limited during 2002. Current expectations are for up to two additional penetrations through sidetracks of existing wells. Technical work continues to evaluate potential infill and peripheral drilling locations. Ultimate well count at Pt. McIntyre is envisioned to be as high as 81 wells (not including P&A’d wells), depending on the number of 80-acre infill wells and the extent of peripheral development. Present estimates are that DS-PM1 will have 20-22 wells, including four water/MI injectors and one gas injector, and that DS- PM2 will have 53-58 wells, including 10 water/MI injectors. An additional water/MI injector (P1-25) is located at the West Dock staging area. Pipelines Figure 3 shows the existing pipeline configuration together with the miscible solvent distribution pipeline from the LPC to the Pt. McIntyre drill sites. Lisburne Production Center Installation of the repaired electric drive motor for the MI compressor was completed during the summer of 2001. System testing and commissioning was successful and MI injection resumed into well P2-23 in October 2001. Major repair and maintenance work included the installation of a new pump case for produced water injection pump 15003 and the ten year vessel inspection of the slop oil tank. Drill Sites Options to improve the hydraulics of the 24” production common line from the Pt. McIntyre drill sites are under evaluation. These include further gas lift gas optimization, drill site separation and local fluid reinjection, as well as additional auger separation. Screening studies are in progress to identify and prioritize opportunities to reduce wellhead pressure for Pt. McIntyre waterflood area wells and/or debottleneck current facility constraints on water and gas handling. Support Facilities Pt. McIntyre will continue to share North Slope infrastructure with the Lisburne Participating Area ("LPA") and the IPA to minimize duplication of facilities. Production Allocation The production of oil and gas, including those hydrocarbon liquids reported as NGLs, will continue to be allocated to the Pt. McIntyre Participating Area in accordance with conditions approved by the Alaska Department of Natural 4 Resources, Alaska Department of Revenue, and Alaska Oil and Gas Conservation Commission. There is a test separator at Drill Site PM1 and two test separators at Drill Site PM2 in use. Gas Sales The timing of Pt. McIntyre gas sales is dependent upon market demands and the availability of a transportation system. Prior to initiation of gas sales, Pt. McIntyre produced gas will be used or consumed for Unit Operations, or injected into the Pt. McIntyre or another formation underlying the Unit Area. Fuel is provided to the LPC per the LPC facility sharing provisions. 5 Date Cum Cum Net Produced Produced Produced Injected Injected Injected Produced Produced Reservoir OIL GAS WATER Gas Water MI Oil Gas Voidage Mstb MMscf Mstb MMscf Mstb MMscf Mstb MMscf Mrvb ----- ---------- ---------- ---------- ---------- ---------- ---------- ---------- ---------- ---------- Jan-01 1755 4898 3941 4098 6045 0 318279 413372 -114 Feb-01 1463 4117 3153 3447 5368 0 319741 417489 -561 Mar-01 1657 4259 3735 3938 6016 0 321398 421747 -703 Apr-01 1572 4375 4049 3976 5091 0 322970 426122 537 May-01 1618 4946 3975 4132 6226 0 324588 431068 -369 Jun-01 1616 4967 3895 4077 5680 0 326204 436036 155 Jul-01 1447 4702 3740 3619 5784 0 327651 440738 -118 Aug-01 1542 5070 4362 4287 3702 0 329194 445808 2500 Sep-01 1375 5004 3602 4027 6221 0 330568 450811 -836 Oct-01 1309 4666 3719 3743 5729 330 331877 455478 -529 Nov-01 1345 4439 4113 4165 4813 810 333223 459917 69 Dec-01 1394 4807 4520 4318 5412 893 334617 464723 6 Table 1 - Pt. McIntyre Monthly Production & Injection Summary Net Date Res. Vol. Res. Vol. Res. Vol. Res. Vol. Res. Vol. Res. Vol. Res. Oil Gas Water Gas Inj. Wat. Inj. MI Inj. Voidage Mrvb Mrvb Mrvb Mrvb Mrvb Mrvb Mrvb ----- ---------- ---------- ---------- ---------- ---------- ---------- ---------- Jan-01 2442 2376 4000 2796 6135 0 -114 Feb-01 2035 2005 3200 2352 5448 0 -561 Mar-01 2304 1995 3792 2687 6107 0 -703 Apr-01 2187 2121 4110 2713 5168 0 537 May-01 2250 2485 4034 2819 6320 0 -369 Jun-01 2248 2501 3953 2782 5765 0 155 Jul-01 2013 2413 3796 2469 5871 0 -118 Aug-01 2145 2611 4427 2926 3758 0 2500 Sep-01 1912 2658 3656 2748 6314 0 -836 Oct-01 1821 2464 3775 2554 5815 220 -529 Nov-01 1871 2289 4175 2842 4885 539 69 Dec-01 1940 2513 4588 2947 5493 595 6 Table 2 - Point McIntyre Monthly Voidage Balance 6 Table 3 - Summary of Pressure Surveys Pressure Pressure Survey Survey @ 8800'SS Well Date Type* Datum P2-11 01/17/01 SBHP 4394 P2-27 02/03/01 SBHP 4325 P1-07 03/30/01 SBHP 3955 P1-02 04/21/01 SBHP 4260 P2-59A 04/25/01 SBHP 4319 P1-12 04/27/01 SBHP 4074 P2-51 05/08/01 SBHP 4348 P2-44 05/13/01 SBHP 4268 P2-29 08/16/01 SFO 4205 P2-28 08/16/01 SFO 4176 P2-34 08/16/01 SFO 4218 P1-14 08/16/01 SFO 4217 P2-46 08/16/01 SFO 4222 P2-09 08/16/01 SFO 4429 P2-47 08/16/01 SFO 4385 P1-16 08/16/01 SFO 4260 P1-01 08/16/01 SFO 4335 P1-21 08/16/01 SFO 4170 P2-16 08/16/01 SFO 4257 P2-42 08/16/01 SFO 4198 P2-10 11/13/01 SBHP 4234 P2-45A 11/13/01 SBHP 4354 P2-41 11/14/01 SBHP 4282 P2-19 11/26/01 SBHP 4168 P2-17 11/29/01 SBHP 4297 P1-24 11/29/01 SBHP 3966 * Survey Type Definition: • SFO = Surface Falloff Test • SBHP = Static Bottomhole Pressure Survey • PBU = Pressure Build Up Survey • LL = Liquid Level Survey 7 Table 4 – 2001 Production Profiles Splits Rates WELL NO.P2-13 Interval Zone % Water % Oil % Gas BOPD BWPD SPINNER DATE: 1/18/2001 11633 11663 UC2-3 21 0 0 0 35 TOOL OD: 1.6875 INCHES 11666 11686 UC1 8 48 37 211 14 OIL RATE: 443 STBPD 11730 11760 IB1-2 71 52 63 232 118 GOR: 745 SCF/STB WATER CUT: 30 % GLG RATE: 3264 MSCF/D FTP: 761 PSIG FBHP: 1774 PSIG SPINNER TYPE: PROD AVG. RES. P.: 4300 PSIA HOLE ANGLE: 34 ° RES. TEMP: 185 °F Splits Rates WELL NO.P1-03 Interval Zone % Water % Oil % Gas BOPD BWPD SPINNER DATE: 1/19/2001 12032 12054 UC2-3 0 0 0 0 5 TOOL OD: 1.6875 INCHES 12072 12112 UC1 16 0 1 0 726 OIL RATE: 815 STBPD 12130 12200 UB3/4 70 62 86 508 3070 GOR: 1772 SCF/STB 12218 12250 UB1-2 8 8 3 63 361 WATER CUT: 84 % 12260 12290 LC3/4 6 30 10 243 253 GLG RATE: 3371 MSCF/D FTP: 794 PSIG FBHP: 3690 PSIG SPINNER TYPE: PROD AVG. RES. P.: 4250 PSIA HOLE ANGLE: 19 ° RES. TEMP: 185 °F Splits Rates WELL NO.P2-60 Interval Zone % Water % Oil % Gas BOPD BWPD SPINNER DATE: 2/24/2001 12750 12820 UB3/4 100 100 100 1954 6385 TOOL OD: 1.6875 INCHES 12842 12862 LC4 0 0 0 0 0 OIL RATE: 1954 STBPD GOR: 691 SCF/STB WATER CUT: 77 % GLG RATE: 2277 MSCF/D FTP: 713 PSIG FBHP: 3792 PSIG SPINNER TYPE: PROD AVG. RES. P.: 4250 PSIA HOLE ANGLE: 22 ° RES. TEMP: 181 °F Splits Rates WELL NO.P2-35 Interval Zone % Water % Oil % Gas BOPD BWPD SPINNER DATE: 3/6/2001 11676 11686 UB3 1 18 17 440 18 TOOL OD: 1.6875 INCHES 11696 11776 LC4 / UB1-2 33 20 34 481 1147 OIL RATE: 2435 STBPD 11782 11802 LC3 16 8 11 206 570 GOR: 925 SCF/STB 11852 11862 LC2 6 32 22 779 208 WATER CUT: 59 % 11902 11922 LB2-4 44 22 16 529 1554 GLG RATE: 3524 MSCF/D FTP: 740 PSIG FBHP: 3298 PSIG SPINNER TYPE: PROD AVG. RES. P.: 4250 PSIA HOLE ANGLE: 44 ° RES. TEMP: 184 °F 8 Table 4 – 2001 Production Profiles Splits Rates WELL NO.P1-17 Interval Zone Water Oil Gas BOPD BWPD SPINNER DATE: 3/7/2001 9984 10004 UC2-3 0 25 63 473 0 TOOL OD: 1.6875 INCHES 10012 10022 UC2-3 0 0 0 0 0 OIL RATE: 1880 STBPD 10046 10079 UC1 0 0 0 0 0 GOR: 1780 SCF/STB 10094 **below UB3-4 100 75 37 1408 7635 WATER CUT: 80 % ** Tool stood up UB1-2 GLG RATE: 0 MSCF/D UA1-4 FTP: 753 PSIG LC3 FBHP: 3696 PSIG LB2-4 SPINNER TYPE: PROD AVG. RES. P.: 4260 PSIA HOLE ANGLE: 17 ° RES. TEMP: 186 °F Splits Rates WELL NO.P2-54 Interval Zone % Water % Oil % Gas BOPD BWPD SPINNER DATE: 4/9/2001 10794 10824 UB1-2 / UA4 6 24 20 117 253 TOOL OD: 1.6875 INCHES 10844 11008 LC3/2 / LB1 94 76 80 381 4287 OIL RATE: 498 STBPD GOR: 609 SCF/STB WATER CUT: 90 % GLG RATE: 2054 MSCF/D FTP: 753 PSIG FBHP: 3577 PSIG SPINNER TYPE: PROD AVG. RES. P.: 4250 PSIA HOLE ANGLE: 35 ° RES. TEMP: 184 °F Splits Rates WELL NO.P2-03 Interval Zone % Water % Oil % Gas BOPD BWPD SPINNER DATE: 4/30/2001 9626 9646 UC2-3 0 66 51 575 0 TOOL OD: 1.6875 INCHES 9770 9790 UB1-2 46 2 14 18 1460 OIL RATE: 870 STBPD 9804 9864 UA1-4 54 32 35 278 1699 GOR: 761 SCF/STB WATER CUT: 78 % GLG RATE: 3311 MSCF/D FTP: 792 PSIG FBHP: 3268 PSIG SPINNER TYPE: PROD AVG. RES. P.: 4250 PSIA HOLE ANGLE: 29 ° RES. TEMP: 187 °F Splits Rates WELL NO.P2-10 Interval Zone % Water % Oil % Gas BOPD BWPD SPINNER DATE: 5/3/2001 9850 9870 UC2-3 5 6 15 26 77 TOOL OD: 1.6875 INCHES 9885 9900 UC1 62 77 71 302 1028 OIL RATE: 394 STBPD 10000 10030 UB1-2 / UA4 33 17 14 67 557 GOR: 1271 SCF/STB WATER CUT: 68 % GLG RATE: 2252 MSCF/D FTP: 756 PSIG FBHP: 2089 PSIG SPINNER TYPE: PROD AVG. RES. P.: 4250 PSIA HOLE ANGLE: 5 ° RES. TEMP: 188 °F 9 Table 4 – 2001 Production Profiles Splits Rates WELL NO.P1-11 Interval Zone % Water % Oil % Gas BOPD BWPD SPINNER DATE: 6/9/2001 12248 12415 UB1-2 / UC23 100 97 99 692 5467 TOOL OD: 1.6875 INCHES 12425 12492 UA4 / UB1-2 031 241 OIL RATE: 716 STBPD GOR: 916 SCF/STB WATER CUT: 88 % GLG RATE: 3043 MSCF/D FTP: 793 PSIG FBHP: 3515 PSIG SPINNER TYPE: PROD AVG. RES. P.: 4250 PSIA HOLE ANGLE: 30 ° RES. TEMP: 187 °F 10 Table 5: 2001 Cased Hole Formation Resistivity Logs Well:P1-03 Date:6/12/2001 Original Sw Current Sw Zone from OH Rt from CHFR UC4 0.49 0.53 UC2-3 0.32 0.32 UC1 0.31 0.38 UB4 0.24 0.45 UB3 0.25 0.48 UB1-2 0.36 0.39 UA1-4 0.35 0.37 LC3 0.27 0.41 LC2 0.73 0.75 Well:P2-20 Date:6/13/2001 Original Sw Current Sw Zone from OH Rt from CHFR UC2-3 0.52 n/a** UC1 0.34 0.68* UB4 0.2 0.51 UB3 0.24 0.49 UB1-2 0.25 0.49 UA1-4 0.23 0.46 LC4 0.25 0.51 LC3 0.19 0.54 LC2 0.39 0.62 LB20.860.73 * partial log data ** no log data 11 Table 6 - 2001 Gas Cap Monitoring Surveys GOC Previous Previous Previous Well Log Date Type Log Depth Log Type Log GOC Depth Change ('SS) Date ('SS) P1-02 4/21/2001 RST 8623 3/17/1999 B/PNL 8619 4 Figure 1 -Point McIntyre Field Prudhoe Bay, Alaska 12Waterflood Patterns P1-01 P2-06 P1-11 P1-17 P1-12 P1-20 P1-21 P2-12 P2-07 P1-03 P1-04 P1-16 P1-14 P2-15 P2-16 P2-46 P2-59 P2-18 P2-21 P2-31 P1-05 P2-54 P2-30 P2-48 P2-23 P2-29 P2-42 P1-25 P1-08 P1-02 P1-13 P2-57 P2-56 P1-06 P1-07 P2-55 P2-40 P2-51 P2-01 P2-03 P1-09 P2-20 P2-44 P2-25 P2-28 P2-34 P2-35 P2-41 P2-37 P2-45 P2-50 P2-50B P2-47 P2-52 P2-53 P2-58 P1-G1 PTM-2 PTM-1 P1-23 P1-24 P2-13 P2-19 P2-36 Gravity Drainage Area P2-33 Production Well Injection Well Plugged and Abandoned/Suspended Well P2-22 P2-24 P2-33B P2-10 P2-09 P2-04 P2-49 P2-27 P2-32 P2-60 P2-17 P2-14 P2-11 P2-08 P2-59A Figure 2 -Point McIntyre Field December 2001 Pressure Map 13P1-01 P1-02 P1-03 P1-04 P1-05P1-06 P1-07 P1-08P1-08 ST1 P1-09P1-09TL P1-11 P1-12 P1-13 P1-14 P1-16 P1-17P1-20 P1-21 P1-23 P1-24 P1-25 P1-G1 P2-01 P2-03 P2-04P2-04 PB1 P2-06 P2-07 P2-08 P2-09 P2-10 P2-11P2-11 PB1 P2-12 P2-13 P2-14 P2-15 P2-16 P2-17 P2-18 P2-19 P2-20 P2-21 P2-22 P2-23P2-24 P2-25 P2-27 P2-28 P2-29 P2-30 P2-31 P2-32P2-32A P2-33P2-33A P2-33B P2-34P2-35 P2-36P2-37 P2-40 P2-41 P2-42P2-44 P2-45P2-45A P2-46 P2-47 P2-48 P2-49 P2-50 P2-50A P2-50B P2-51 P2-52 P2-53 P2-54 P2-55 P2-56P2-57 P2-58 P2-59 P2-59A P2-60 666000 671000 676000 681000 686000 691000 5990000 5995000 6000000 6005000 6010000 4325 3955 4260 4319 4074 4268 4205 4176 4218 4217 4222 4429 4385 4260 4335 4170 4257 4234 4354 4282 4168 4297 3966 4152 4250 4348 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 PM2 Approximate Scale 0 1Miles Prudhoe Bay Existing Pipelines Pipelines for EOR PM1 LG1 L1 CCP CGF L2 L3 L5 NK L4 LPC Figure 3 -Drill Site and Pipeline Configuration 14