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Home My WebLink About2019 Greater Point McIntyre Area ELECTRONICALLY FILED June 9, 2020 Jeremy Price, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Re: Prudhoe Bay Unit GPMA Annual Reservoir Reports, Annual Reservoir Property Reports April 1, 2019 – March 31, 2020 Dear Chair Price: BP Exploration Alaska Inc. (BPXA), as operator of the Prudhoe Bay Unit, submits the enclosed Annual Reservoir Surveillance Reports for Greater Point McIntyre Area (GPMA) Oil Pools covering the time period from April 1, 2019 through March 31, 2020. These Annual Reservoir Reports were prepared in accordance with the latest conservation orders for each pool. In addition, as required by 20 AAC 25.270 (effective Feb 10, 2018), BPXA is simultaneously electronically filing the Annual Reservoir Properties Reports (ARP) to agocc.reporting@alaska.gov. If you have any questions regarding these reports please contact Bill Bredar through email at william.bredar@bp.com. Respectfully, Katrina Garner Area Manager cc: John Schultz, ConocoPhillips Alaska, Inc. Jeffry Farr, ExxonMobil Alaska, Production Inc. Dave White, Chevron USA John Barnes, Hilcorp Alaska Aaron O’Quinn, Division of Oil and Gas Dave Roby, Alaska Oil and Gas Conservation Commission BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Lisburne Oil Pool Page 1 ASR for Apr ’18 – Mar’19 Prudhoe Bay Unit Lisburne Oil Pool 2020 Annual Reservoir Surveillance Report This Annual Reservoir Report for the period ending March 31, 2020 is submitted to the Alaska Oil and Gas Conservation Commission for the Lisburne Oil Pool in accordance with commission regulations and Conservation Order 207D. This report covers the period from April 1, 2019 through March 31, 2020. A. Reservoir Management 1. Summary Oil production and reservoir management activity in the Lisburne Oil Pool continues under gas cap expansion supported by gas injection at LGI pad and water injection at L5-29. In the Central area, pressure support is supplemented by weak aquifer influx. Pilot seawater injection projects have been on-going in the central Alapah (NK-25), the southern periphery Wahoo (04-350) and the mid-field Wahoo (L5-15) area. Production and injection volumes for the 12-month period ending March 31, 2020 are summarized in Table 1. Oil production volumes include allocated crude oil, condensate and NGL production. 2. Reservoir Pressure Surveys Within the Pool A summary of reservoir pressure surveys obtained during the reporting period is shown in Table 2. The proposed number of Lisburne reservoir pressure surveys to be obtained in the coming plan year April 1 2020 to March 31, 2021 is six total. One apiece at each of the major Lisburne pads (L1, L2, L3, L4 & L5) and one in the Lisburne West Alapah accumulation (well NK-25 or NK-26A). 3. Results and Analysis of Production Logging Surveys There were two production logs obtained from Lisburne wells during the reporting period. Production logs for April 1, 2019 through March 31, 2020 are shown in Table 3. Lisburne Oil Pool Page 2 ASR for Apr ’19 – Mar’20 B. Development and Production Activity 1. Enhanced Recovery Projects a. L5 Gas Cap Water Injection Surveillance (C.O. 207C) The L5 GCWI pilot project commenced injection in July of 2008. The initial injection rate was 2 mbd, and over time has been gradually increased to approximately 17 mbd. As of March 31, 2020, the cumulative volume of seawater injected in L5-29 was 25,087 mbbls. The L5-29 pilot injection demonstrated positive results with likely injection water breakthrough occurring in four offset producer wells (L5-28A, L5-32, L5-33 & L5-36). Pressure response has also been observed in offset wells. The GCWI Pilot was approved for permanent injection under AOGCC Conservation Order 207B.16. The injector was on-line for a majority of the time (239 days) during the reporting period. Three pressure fall-off (PFO) tests have been conducted in the L5-29 gas cap water injection well. The PFO analyses show a constant pressure boundary, and skin values of between -3.6 and -3.8. Based on these results, it is inferred that no fracture extension is occurring. Offset well annuli pressures are reported monthly to the Commission by the BP North Slope Well Integrity Engineer via the Monthly Injection Report sent to the AOGCC. b. Waterflooding Pilot Projects A review of the Lisburne development plan identified water injection as a mechanism to provide additional pressure support in the Lisburne reservoirs. A grass roots injection well, 04-350, was completed on the southern periphery of the Wahoo Formation in November 2011 and has injected 7,679 mbbls of seawater as of March 31, 2020. Seawater production has been observed in offset producers L3-22, L3-22A, L3-24 and L3-30. Another pilot water injection project has been undertaken in the mid-field area. Wahoo production wells L5-15 and L5-13 were converted to seawater injection service in March 2013. As of March 31, 2020 the cumulative volume of seawater injected in both these wells was 10,370 mbbls. Confirmed seawater production has occurred in offset L5 -16A and L5-17A. L5-13 developed mechanical integrity issues and was plugged and abandoned in November 2017. In addition, a pilot water injection project into the Alapah Formation has been initiated from the Niakuk Heald Point pad. Alapah producer NK-25 Lisburne Oil Pool Page 3 ASR for Apr ’19 – Mar’20 was converted to seawater injection service in March 2013 and has injected 8,626 mbbls of seawater as of March 31, 2020. Offset producer well pressure response and seawater production have been observed. 2. Well Activity: Drilling Rig Three new wells (L3-06, L5-03 and L5-27) and one new sidetrack (L3-22A) were drilled & completed into the Lisburne Formation during the reporting period. Lisburne producing well L1-31 was worked over and new tubing run during the reporting period. 3. Well Activity: Non-Rig Twenty one Lisburne wells had a total of fifty five rate-adding non-rig interventions performed during the reporting period. These rate-adding interventions included perforations, hydrate & paraffin removal, hot oil treatment (HOT) jobs, acid stimulations, gas-lift work, profile modifications, fill cleanouts, well integrity repairs, SSSV replacements and surface component repairs. 4. Other Activity a. Plant and Pipelines Various scheduled minor plant and pipeline repairs and modifications were completed to protect or enhance production from the Lisburne during the reporting period. b. Support Facilities Lisburne shares North Slope infrastructure with the Point McIntyre and Niakuk Fields. Nine wells from the IPA can produce to the LPC as part of the L2 Re-route Project: L2-03A, L2-07A, L2-08A, L2-11, L2-13A, L2-14C, L2-18A, L2-21B and L2-29A. c. Production Allocation The production of oil and gas, including those hydrocarbon liquids reported as NGLs, is allocated to the Lisburne Participating Area in accordance with conditions approved by the Alaska Department of Natural Resources, Alaska Department of Revenue, and Alaska Oil and Gas Conservation Commission. There is a test separator at each Lisburne Drill Site. Lisburne Oil Pool Page 4 ASR for Apr ’19 – Mar’20 5. Future Development Plans (C.O. 207) Lisburne Pool oil is predominantly processed at the Lisburne Production Center, which began permanent operation in December 1986. There are currently 83 development wells in the Lisburne Oil Pool. Future development plans are discussed in the 2019 Lisburne Plan of Development filed with the Division of Oil and Gas of the Alaska Department of Natural Resources, which the Commission received on June 20, 2019. The Commission will be copied when the 2020 update of the Lisburne Plan of Development is filed with the Division. Lisburne Oil Pool Page 5 ASR for Apr ’19 – Mar’20 Tables & Figures Table 1 - Lisburne Monthly Production & Injection Volumes Monthly Production Cumulative Production Gas Injection Water Injection Oil + NGL Gas Water Oil + NGL Gas Water Monthly Cum Monthly Cum Date mstbo mmscf mbw mstbo mmscf mbw mmscf bscf mbw mbw 4/1/2019 359.5 7,587 319 197,703 2,203,689 70,555 5,732 2,137,904 458 54,521 5/1/2019 338.673 6,391 348 198,041 2,210,080 70,902 4,754 2,142,658 317 54,838 6/1/2019 308.202 5,903 335 198,349 2,215,983 71,238 3,457 2,146,115 314 55,151 7/1/2019 248.246 5,348 390 198,598 2,221,330 71,628 3,462 2,149,576 652 55,803 8/1/2019 247.499 4,679 416 198,845 2,226,009 72,044 4,213 2,153,789 218 56,021 9/1/2019 318.553 6,111 422 199,164 2,232,120 72,466 4,451 2,158,240 427 56,448 10/1/2019 396.159 6,809 546 199,560 2,238,929 73,012 5,105 2,163,345 637 57,085 11/1/2019 425.326 8,066 457 199,985 2,246,995 73,468 5,310 2,168,655 813 57,897 12/1/2019 439.635 8,347 419 200,425 2,255,342 73,887 5,671 2,174,326 805 58,702 1/1/2020 428.754 7,856 489 200,854 2,263,198 74,376 6,050 2,180,375 692 59,395 2/1/2020 401.427 7,117 535 201,255 2,270,315 74,911 5,851 2,186,226 594 59,989 3/1/2020 397.843 7,138 509 201,653 2,277,453 75,420 5,753 2,191,979 628 60,617 Table 2 - Lisburne Pressure data April 1, 2019 to March 31, 2020 Well Name Survey Date Pressure (psi) (Datum = 8900' SS) 04-350 2/29/2020 3362 L1-31 9/19/2019 3356 L2-20 1/10/2020 2770 L3-06 8/22/2019 3223 L3-22A 8/3/2019 3263 L4-30 1/15/2020 3271 L5-03 6/4/2019 2903 L5-27 7/31/2019 3691 NK-26A 3/5/2020 1957 Lisburne Oil Pool Page 6 ASR for Apr ’19 – Mar’20 Table 3 - Lisburne Logging Comments/Interpretation Production logs obtained for the following wells: L1-23 L3-22A Lisburne Oil Pool Page 7 ASR for Apr ’19 – Mar’20 Figure 1 - Lisburne Location and Status Map Niakuk Oil Pool Page 1 ASR for Apr ’19 – Mar ‘20 Prudhoe Bay Unit Niakuk Oil Pool 2020 Annual Reservoir Surveillance Report This Annual Reservoir Surveillance Report is submitted to the Alaska Oil and Gas Conservation Commission for the Niakuk Oil Pool in accordance with commission regulations and Conservation Order No. 329A. This report covers the period from April 1, 2019 through March 31, 2020. A. Reservoir Management 1. Summary Oil production and reservoir management activity in the Niakuk Oil Pool continues under waterflood. Reservoir management activity in the Niakuk Oil Pool includes: 1) selective perforating and profile modifications to manage conformance of the waterflood, 2) production and injection profile logging to determine current production and injection zones for potential profile modifications, material balance calculations, and effective full field modeling, 3) pressure surveys to monitor flood performance and 4) analysis of production, Gas Oil Ratio, and Water Oil Ratio trends to highlight poorer performing wells for possible intervention activity. Production and injection volumes and resultant voidage data by month for the 12-month period ending March 31, 2020 are summarized in Tables 1 and 2. 2. Reservoir Pressure Surveys Within the Pool A summary of reservoir pressure surveys obtained during the reporting period is shown in Table 3. The proposed number of Niakuk reservoir pressure surveys to be obtained in the coming plan year April 1, 2020 to March 31, 2021 is three total. One survey apiece in each of the major Niakuk reservoir sector delineations (Segments 1, 2/4 and 3/5) 3. Results of Production Logging, Tracer and Well Surveys (C.O. 329A Rule 9d) No production logs were run during the reporting period. No tracer surveys were performed during this reporting period. Niakuk Oil Pool Page 2 ASR for Apr ’19 – Mar ‘20 B. Development and Production Activity 1. Enhanced Recovery Projects a. Progress of Niakuk Waterflood Project Implementation and Reservoir Management Summary (C.O. 329A Rule 9a) The Niakuk waterflood was started in April 1995, in conjunction with the commissioning of permanent facilities at Heald Point, using water from the Initial Participating Area Seawater Treatment Plant. Produced water from the Lisburne Production Center was used between August of 2000 and May 2004. Conversion to seawater injection was completed in September 2004, and seawater injection continues throughout this reporting period. All producing segments (1, 2/4 and 3/5) are receiving pressure support from water injection. There were 4 active injectors in the Niakuk Pool with an average total injection rate of approximately 14,000 bwpd for the reporting period. There were three injectors completely off-line during the reporting period (NK-16, NK-17 and NK-28). All three off-line injectors have well integrity issues. The current injection strategy is to maintain balanced voidage replacement in each segment, however current voidage is slightly less than 1.0. The producer to injector interactions are being evaluated with decreased injection to monitor production impacts in order to better evaluate depletion options. b. Voidage Balance of Produced and Injected Fluids (C.O. 329A Rule 9b) Tables 1 and 2 detail hydrocarbon production, water injection and resultant voidage data by month for the reporting period. c. Analysis of Reservoir Pressure Surveys Within the Pool (C.O. 329A Rule 9c) Table 3 shows results from the reservoir pressure surveys taken during the reporting period. The pressures in Segments 2/4, 1, and 3/ 5 are generally managed with the original reservoir pressure of approximately 4500 psi as a target/maximum, and the bubble point pressure of 4200 psi as a minimum. Niakuk Oil Pool Page 3 ASR for Apr ’19 – Mar ‘20 2. Special Monitoring: NK-43 Well (C.O. 329A Rule 9e) NK-43 is a commingled producer which produces from both the Kuparuk and Sag River reservoirs. The AOGCC approved co-mingled production in NK-43 with production allocated to each reservoir via geochemical analysis in Conservation Order 329B on December 7, 2006. Three oil samples were taken from NK-43 during the reporting period (4/19, 10/19 and 1/20) for geochemical analysis to confirm production allocation splits between the Sag River and Kuparuk reservoirs. The analyses showed that ~96% of oil production in NK-43 is from the Kuparuk during the reporting period. 3. Well Activity: Permanent production facilities at Niakuk were commissioned in March 1995. There have been 29 development wells drilled into the Niakuk Oil Pool through the end of the reporting period. During the reporting period, the Niakuk field focused on optimization of producers and scale management to which two inhibition treatments were performed. Six Niakuk wells had a total of nine rate-adding non-rig interventions performed during the reporting period. These rate -adding interventions included perforations, hot oil treatment (HOT) jobs, gas-lift work, SSSV replacements and surface component repairs. 4. Future Development Plans (C.O. 329A Rule 9f) Future development plans are discussed in the 2019 Niakuk Plan of Development filed with the Division of Oil and Gas of the Alaska Department of Natural Resources, which the commission received on June 20, 2019. The commission will be copied when the 2020 update of the Niakuk Plan of Development is filed with the Division. Niakuk Oil Pool Page 4 ASR for Apr ’19 – Mar ‘20 5. Review of Pool Production Allocation Factors (per Administrative Approval Docket Number: CO-15-013 Done January 7, 2016) LPC monthly average oil allocation factors are supplied below. The Niakuk Oil Pool and Raven Oil Pool will have the same allocation factors as LPC. Any dates with zero allocation factor were excluded. Allocation factors range from 0.87- 0.97. Daily allocation data and daily test data are being retained. Month Year LPC Allocation Factor April 2019 0.92 May 2019 0.91 June 2019 0.93 July 2019 0.95 August 2019 0.88 September 2019 0.92 October 2019 0.91 November 2019 0.87 December 2019 0.90 January 2020 0.90 February 2020 0.94 March 2020 0.97 Niakuk Oil Pool Page 5 ASR for Apr ’19 – Mar ‘20 Tables and Figures Table 1 - Niakuk Monthly Production & Injection Volumes Monthly Production Gas Inject Water Inject MI Inject Cumulative Oil Gas Water Monthly Monthly Monthly Oil Gas Date mstbo mmscf mbw Mmscf mbw mmscf mstb mmscf 4/1/2019 31 42 195 0 443 0 95,817 87,478 5/1/2019 33 62 380 0 579 0 95,849 87,541 6/1/2019 30 38 376 0 494 0 95,879 87,579 7/1/2019 16 52 384 0 536 0 95,895 87,631 8/1/2019 18 21 248 0 167 0 95,913 87,652 9/1/2019 20 18 298 0 339 0 95,933 87,669 10/1/2019 33 24 367 0 475 0 95,965 87,694 11/1/2019 33 27 403 0 559 0 95,998 87,721 12/1/2019 36 35 350 0 468 0 96,034 87,756 1/1/2020 30 29 370 0 369 0 96,064 87,785 2/1/2020 21 23 345 0 343 0 96,085 87,808 3/1/2020 18 20 300 0 358 0 96,103 87,828 Table 2 - Niakuk Monthly Voidage Balance Monthly Production Gas Inject Water Inject MI Inject Net Res. Oil Gas Water Monthly Monthly Monthly Voidage Date mrvb mrvb mrvb mrvb mrvb mrvb mvrb 4/1/2019 40 14 197 0 447 0 -196 5/1/2019 42 27 384 0 585 0 -132 6/1/2019 39 12 379 0 499 0 -69 7/1/2019 20 28 388 0 541 0 -105 8/1/2019 23 6 250 0 169 0 111 9/1/2019 26 3 301 0 342 0 -12 10/1/2019 42 1 371 0 480 0 -66 11/1/2019 43 3 407 0 564 0 -111 12/1/2019 46 7 354 0 473 0 -65 1/1/2020 39 6 374 0 373 0 46 2/1/2020 27 6 348 0 346 0 35 3/1/2020 24 5 303 0 361 0 -30 Note: Monthly Production/Injection/Voidage/Pressure data (Tables 1 & 2) do not include the production results from NK-38B, NK-14B or NK-08B wells (Raven) or injection from the NK-65A injector. They are subject to a separate Raven Oil Pool Annual Reservoir Report. Niakuk Oil Pool Page 6 ASR for Apr ’19 – Mar ‘20 Table 3 – 2018 – 2019 Pressure Survey Data Table 3 - Niakuk Pressure data April 1, 2019 to March 31, 2020 Well Name Survey Date Pressure (psi) (Datum = 9200' SS) NK-12C 12/6/2019 4307 NK-20A 6/15/2019 3661 NK-21 12/7/2019 5587 NK-22A 4/1/2019 4627 NK-22A 8/15/2019 4711 NK-27 3/28/2020 4080 NK-61A 3/18/2020 4122 Point McIntyre Oil Pool Page 1 ASR for Apr ’18 – Mar ‘19 Prudhoe Bay Unit Pt. McIntyre Oil Pool 2020 Annual Reservoir Surveillance Report This Annual Reservoir Report for the period ending March 31, 2020 is submitted to the Alaska Oil and Gas Conservation Commission for the Pt. McIntyre Oil Pool in accordance with Commission regulations and Conservation Order 317B. This report covers the period between April 1, 2019 and March 31, 2020. A. Reservoir Management 1. Summary Production and injection volumes for the 12-month period ending March 31, 2020 are summarized in Table 1. Total Pt. McIntyre hydrocarbon liquid production (oil plus NGL) averaged 13.8 mbd. Current well locations are shown in Figure 1. The dominant oil recovery mechanisms in the Pt. McIntyre Oil Pool are waterflooding and miscible gas injection in the down-structure area north of the Terrace Fault and gravity drainage in the up-structure area referred to as the Gravity Drainage (GD) Area. Gas injection commenced in the gas cap with field startup to replace voidage and promote gravity drainage. The waterflood was in continuous operation during the reporting period with 16 wells on either water injection or miscible gas injection, supporting 15 patterns (one pattern has two injectors). 2. Progress of Enhanced Recovery Project Implementation and Reservoir Management Summary (Rule 15 a) During the 12 month period from April 2019 – March 2020, a total of 15.5 BCF of MI (miscible injectant) was injected into: P1-01 (2.1 BCF), P1-21 (2.6 BCF), P1-25 (0.6 BCF), P2-15A (3.7 BCF), P2-16 (4.2 BCF), P2-46 (0.6 BCF), and P2-47 (1.7 BCF). All of the fifteen waterflood patterns have had MI injection. 3. 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 targeted to be balanced with injection. Negative net reservoir voidage values in Table 2 indicate Injection Withdrawal Ratios greater than 1. Point McIntyre Oil Pool Page 2 ASR for Apr ’19 – Mar ‘20 4. 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. The proposed number of Pt McIntyre reservoir pressure surveys to be obtained in the coming plan year April 1 2020 to March 31, 2021 is ten total. Eight reservoir pressure surveys are proposed for the waterflood/MI pattern dominated parts of the field and two pressure surveys are proposed for the Gravity Drainage / Gravity Drainage Water Flood Interaction (GD/GDWFI) dominated part of the field. 5. Results and Analysis of Production & Injection Logging Surveys (Rule 15 d) There were no production logs or no injection logs obtained from Pt McIntyre wells during the reporting period. Production and injection logs for the reporting period are shown in Table 4. 6. Results of Any Special Monitoring (Rule 15 e) No special monitoring was performed during the reporting period. B. Development and Production Activity 1. Well Activity There are a total of 26 well penetrations drilled from DS-PM1 including sidetracked, P&A and suspended wells. There are a total of 76 well penetrations drilled from DS-PM2. An additional water/MI injector (P1-25) is located at the West Dock staging area. During the reporting period, the scale management program continued for Pt Mac wells and included regular scale inhibition treatments. No new Pt Mac wells were put on MI for the first time. 2. Other Activities a. Pipelines i. Figure 2 shows the existing pipeline configuration together with the miscible injectant distribution pipelines from LPC and CGF to the Pt. McIntyre drill sites. Point McIntyre Oil Pool Page 3 ASR for Apr ’19 – Mar ‘20 ii. Pt. McIntyre production is processed at LPC and GC-1. PM1 wells can only flow to the LPC. Between March of 2004 and November 2011 all wells at drill site PM2 could be flowed to either the LPC (high pressure system) or to GC-1 (low pressure system) via a 36” three phase line from PM2 to GC-1. As a result of this connection, wellhead pressures were lowered for the PM2 wells flowing to GC-1 by approximately 400 psi and utilized approximately 80 MB/D of available water handling capacity at GC-1. On November 12th 2011, the 36” line from PM2 to GC-1 was shut-in due to the integrity status of the line. Repair of the pipeline was completed October 2016, and all PM2 production now flows to GC-1, no production from PM2 flows to LPC. With reduced backpressure, increased water and gas handling capacity at GC1, and optimization of the well sorts, production from PM2 has been increased. b. Produced Water During the 12-month reporting period, the LPC continued to provide produced water for injection at Point McIntyre. Additional produced water is provided from FS1 to LPC for injection at Pt. McIntyre. c. Support Facilities Pt. McIntyre will continue to share North Slope infrastructure with the Lisburne Participating Area ("LPA") and the Initial Participating Areas to minimize duplication of facilities. 3. Future Development Plans (rule 15 f) Permanent production facilities at Pt. McIntyre were commissioned in 1993. There have been 97 development wells drilled into the Pt. McIntyre Oil Pool through the end of the reporting period. Future development plans are discussed in the 2019 Pt. McIntyre Plan of Development filed with the Division of Oil and Gas of the Alaska Department of Natural Resources, which the Commission received on June 29, 2019. The Commission will be copied when the 2020 update of the Pt. McIntyre Plan of Development is filed with the division. Point McIntyre Oil Pool Page 4 ASR for Apr ’19 – Mar ‘20 Tables and Figures Table 1 - Pt McIntyre Monthly Production & Injection Volumes Monthly Production Gas Inject Water Inject MI Inject Cumulative Oil Gas Water Monthly Monthly Monthly Oil Gas Date mstbo mmscf mbw mmscf mbw mmscf mstb mmscf 4/1/2019 397 5,528 2,975 4,112 4,109 1356.401 475,927 1,522,778 5/1/2019 414 5,083 3,533 4,572 4,893 1636.536 476,342 1,527,861 6/1/2019 359 3,296 3,102 4,434 3,973 1900.158 476,701 1,531,157 7/1/2019 286 2,826 2,532 3,807 4,353 1603.102 476,987 1,533,983 8/1/2019 382 4,966 3,168 3,713 5,054 945.697 477,369 1,538,948 9/1/2019 370 4,008 3,337 3,517 5,204 961.803 477,739 1,542,957 10/1/2019 364 4,260 3,201 3,763 4,548 953.141 478,103 1,547,217 11/1/2019 406 3,765 3,430 3,565 4,809 685.011 478,509 1,550,982 12/1/2019 415 4,172 3,596 4,162 4,826 1119.905 478,924 1,555,154 1/1/2020 401 4,998 3,642 4,627 4,782 1398.603 479,326 1,560,152 2/1/2020 440 5,271 3,768 4,014 4,374 1204.885 479,766 1,565,423 3/1/2020 430 4,817 3,671 4,637 4,218 1699.064 480,196 1,570,241 Table 2 - Pt McIntyre Monthly Voidage Balance Monthly Production Gas Inject Water Inject MI Inject Net Res. Oil Gas Water Monthly Monthly Monthly Voidage Date mrvb mrvb mrvb mrvb mrvb mrvb mvrb 4/1/2019 552 3,566 3,020 2,806 4,171 840.96862 -680 5/1/2019 576 3,253 3,586 3,120 4,966 1014.65232 -1,684 6/1/2019 500 2,063 3,148 3,026 4,032 1178.09796 -2,525 7/1/2019 398 1,780 2,570 2,598 4,418 993.92324 -3,262 8/1/2019 532 3,190 3,216 2,533 5,130 586.33214 -1,312 9/1/2019 515 2,543 3,387 2,400 5,282 596.31786 -1,833 10/1/2019 506 2,718 3,249 2,568 4,617 590.94742 -1,303 11/1/2019 565 2,359 3,482 2,433 4,881 424.70682 -1,333 12/1/2019 578 2,631 3,650 2,840 4,898 694.3411 -1,572 1/1/2020 558 3,202 3,697 3,157 4,854 867.13386 -1,421 2/1/2020 612 3,368 3,824 2,739 4,440 747.0287 -121 3/1/2020 598 3,064 3,726 3,164 4,282 1053.41968 -1,110 Point McIntyre Oil Pool Page 5 ASR for Apr ’19 – Mar ‘20 Table 3 - Pt. McIntyre Pressure data April 1, 2019 to March 31, 2020 P1-08A 12/7/2019 3883 P1-09 5/21/2019 3964 P1-17 8/17/2019 3849 P1-20 3/6/2020 3469 P1-21 6/9/2019 3797 P1-24 1/12/2020 3757 P2-08A 12/22/2019 4125 P2-13 1/13/2020 3877 P2-19A 5/11/2019 3965 P2-22A 3/6/2020 3913 P2-24 3/24/2020 3887 P2-25 1/4/2020 4021 P2-36A 1/9/2020 3968 P2-43 7/24/2019 3857 P2-44 7/19/2019 3940 P2-45B 5/22/2019 3596 P2-50B 3/5/2020 3937 P2-51A 2/29/2020 3812 P2-60 3/25/2020 3984 Table 4 – Pt McIntyre Logging Comments/Interpretation No production or injection profile logs were obtained No gas cap monitoring logs were obtained Point McIntyre Oil Pool Page 6 ASR for Apr ’19 – Mar ‘20 Figure 1 Pt. McIntyre Well Location Map Unit Boundary Point McIntyre Oil Pool Page 7 ASR for Apr ’19 – Mar ‘20 PM2 Approximate Scale 0 1Miles Prudhoe Bay Existing Pipelines Pipelines for EOR PM1 LG1 L1 CCP CGF L2 L3 L5 NK L4 LPC Figure 2. Drill Site and Pipeline Configuration GC1* * GC1 location not to scale Figure 3 Raven Oil Pool Page 1 ASR for Apr ’19 – Mar ‘20 Prudhoe Bay Unit Raven Oil Pool and Sag River Undefined Oil Pool 2020 Annual Reservoir Surveillance Report This Annual Reservoir Report for the period ending March 31, 2020 is submitted to the Alaska Oil and Gas Conservation Commission for the Raven O il Pool in accordance with Commission regulations and Conservation Order 570. Data for the Sag River Undefined Oil Pool is included here as the Raven Oil Pool will eventually be expanded to encompass the Sag River Undefined Oil Pool once pool limits are defined. This report covers the period between April 1, 2019 and March 31, 2020. A. Reservoir Management 1. Summary Raven is a small oil and gas field in the Permo -Triassic interval (Ivishak and Sag River) located beneath the Niakuk Field (Kuparuk reservoir). In 2015, there were two oil wells, NK-38A (Ivishak producer) and NK-43 (commingled Kuparuk and Sag River producer), producing from the Raven Oil Pool. In August 2016, NK-38A was sidetracked into an unswept portion of the Raven field to the current NK-38B position. NK-43 has continued on comingled production during this reporting period. NK-65A has been on injection during the reporting period and injector NK-15A remains shut-in due to a tight formation. Production from the Raven Field started in March 2001 with the completion of the Sag River in NK-43. The Sag River in NK-43 was subsequently isolated with a cast iron bridge plug (CIBP), and the well was perforated in the Kuparuk reservoir and produced until 1/2/06 when the CIBP was removed and the Sag River commingled with the Kuparuk. Production from NK-38A began in March 2005 from the Ivishak reservoir. NK-38A was sidetracked and NK-38B began production September 2016 from the optimized location. NK-14B was spudded in March 2017 and is an extension well delineating the outer boundaries of the Raven Oil Pool. It is currently producing under a GOR waiver valid until August 1, 2021 and is a Tract Operation. The well came on production from the Sag River formation in late June, 2017 and by the middle of August had what later was determined to be a production casing leak. The well was shut -in from September, 2017 – March, 2018 to determine failure and repair options. NK -14B has since been restored to production. Raven Oil Pool Page 2 ASR for Apr ’19 – Mar ‘20 NK-15A was drilled and completed in March, 2018 in a position in the structure that was believed to be better situated to support and waterflood the structure for the NK - 38B offtake. Unfortunately, however, the Ivishak reservoir encountered by NK-15A was found to be wet and low permeability. The Sag River formation was flow tested during the reporting period and found to be productive but high WC. Efforts to put NK-15A on water injection have been halted. NK-08B was drilled and completed in April 2019 into an unswept part of Sag River formation within the Raven reservoir. The well came on production in May 2019 has been a full-time producer since that time. Oil Production from the Raven pool averaged 1.44 mbd for the reporting period. As NK-38B seems to exhibit aquifer support based on pressure and water analysis, NK- 65A injection has been decreased to a VRR less than 1. The long-term depletion plan is to optimize hydrocarbon production in the Raven reservoir through voidage replacement from water injection as a supplement to aquifer influx in order to keep reservoir pressure at levels that will optimize oil recovery. The Raven Pool voidage replacement ratio for the reporting period is deliberately less than 1.0 due the known aquifer influx influence. NK-14B production is included in voidage calculations, however due to connectivity uncertainly with NK- 65A injection rates are not managed to directly support NK-14B offtake. NK-14B will continue to be monitored and continued information analysis will allow for optimization of long-term depletion plans for the Sag River. 2. Analysis of Reservoir Pressure Surveys Within the Pool Static pressure surveys have been conducted on the wells in the field. Table 3 shows results of static reservoir pressure surveys conducted on the wells since March 2005. The most recent static reservoir pressure in NK-38B was taken in September 2019 and reservoir pressure was 4257 psi (datum). The proposed number of Raven reservoir pressure surveys to be obtained in the coming plan year April 1, 2020 to March 31, 2021 is two total. BPXA requests flexibility with specifying the two separate wells that will be surveyed while noting that Raven has a low well count. 3. Results of Production Logging, Tracer and Well Surveys No production logs were run during the reporting period. No tracer surveys were performed during the reporting period. Raven Oil Pool Page 3 ASR for Apr ’19 – Mar ‘20 B. Development and Production Activity 1. Progress of Enhanced Recovery Project Implementation and Reservoir Management Summary Waterflood at Raven began in October 2005, using water from the Initial Participating Area Seawater Treatment facilities. NK-65A is currently on injection into the Ivishak reservoir and average a rate of 3.9 mbwpd during the reporting period. 2. Voidage Balance of Produced and Injected Fluids Tables 1 and 2 detail the production, injection and calculated voidage by month for the reporting period. 3. Special Monitoring: NK-43 Well (C.O. 329A Rule 9e) NK-43 is a commingled producer which produces from both the Kuparuk and Sag River reservoirs. The AOGCC approved co-mingled production in NK-43 with production allocated to each reservoir via geochemical analysis in Conservation Order 329B on December 7, 2006. Three oil samples were taken from NK-43 during the reporting period (4/19, 10/19 and 1/20) for geochemical analysis to confirm production allocation splits between the Sag River and Kuparuk reservoirs. The analyses showed that ~96% of oil production in NK-43 is from the Kuparuk during the reporting period. 4. Future Development Plans (C.O. 570) Permanent production facilities that Raven utilizes were commissioned in March 1995. There have been 5 development wells drilled into the Raven Oil Pool through the end of the reporting period. Future development plans are discussed in the 2019 Raven Plan of Development filed with the Division of Oil and Gas of the Alaska Department of Natural Resources, which the Commission received on June 20, 2019. The Commission will be copied when the 2020 update of the Raven Plan of Development is filed with the division. Raven Oil Pool Page 4 ASR for Apr ’19 – Mar ‘20 5. Review of Pool Production Allocation Factors (per Administrative Approval Docket Number: CO-15-013 Done January 7, 2016) LPC monthly oil average allocation factors are supplied below. The N iakuk Oil Pool and Raven Oil Pool will have the same allocation factors as LPC. Any dates with zero allocation factor were excluded. Allocation factors range from 0.87-0.97. Daily allocation data and daily test data are being retained. Month Year LPC Allocation Factor April 2019 0.92 May 2019 0.91 June 2019 0.93 July 2019 0.95 August 2019 0.88 September 2019 0.92 October 2019 0.91 November 2019 0.87 December 2019 0.90 January 2020 0.90 February 2020 0.94 March 2020 0.97 Raven Oil Pool Page 5 ASR for Apr ’19 – Mar ‘20 Tables and Figures Table 1 - Raven & Sag River Undefined Monthly Production & Injection Volumes Monthly Production Gas Inject Water Inject MI Inject Cumulative Oil + NGL Gas Water Monthly Monthly Monthly Oil Gas Date mstbo mmscf mbw mmscf mbw mmscf mstb mmscf 4/1/2019 34 144 91 0 132 0 4,316 23,107 5/1/2019 97 415 103 0 127 0 4,407 23,522 6/1/2019 57 258 99 0 112 0 4,460 23,780 7/1/2019 39 129 56 0 119 0 4,497 23,909 8/1/2019 39 112 64 0 38 0 4,534 24,020 9/1/2019 54 113 52 0 63 0 4,587 24,133 10/1/2019 53 130 96 0 107 0 4,637 24,263 11/1/2019 39 129 53 0 129 0 4,674 24,392 12/1/2019 33 104 3 0 149 0 4,705 24,495 1/1/2020 32 99 3 0 153 0 4,736 24,594 2/1/2020 24 72 3 0 142 0 4,758 24,666 3/1/2020 27 79 59 0 152 0 4,783 24,745 Table 2 - Raven & Sag River Undefined Monthly Voidage Balance Monthly Production Gas Inject Water Inject MI Inject Net Res. Oil Gas Water Monthly Monthly Monthly Voidage Date mrvb mrvb mrvb mrvb mrvb mrvb mvrb 4/1/2019 50 85 92 0 134 0 92 5/1/2019 140 246 105 0 128 0 362 6/1/2019 81 156 100 0 113 0 224 7/1/2019 58 69 57 0 120 0 64 8/1/2019 57 56 65 0 38 0 140 9/1/2019 80 46 53 0 64 0 115 10/1/2019 78 60 97 0 108 0 128 11/1/2019 57 69 53 0 130 0 49 12/1/2019 48 55 3 0 151 0 -45 1/1/2020 47 52 3 0 154 0 -53 2/1/2020 35 38 3 0 144 0 -68 3/1/2020 39 41 60 0 154 0 -14 Note: Monthly Production/Injection/Voidage for the Ivishak and Sag River. Raven Oil Pool Page 6 ASR for Apr ’19 – Mar ‘20 Table 3 – Raven & Sag River Undefined Ivishak & Sag Pressure Survey Data Since March 2005 Raven Oil Pool Page 7 ASR for Apr ’19 – Mar ‘20 Sw Name Test Date Pres Surv Type Datum Ss Pres Datum NK-38A 3/29/2005 SBHP 9850 4973 NK-38A 8/1/2005 SBHP 9850 4237 NK-38A 8/7/2005 SBHP 9850 4273 NK-65A 8/9/2005 SBHP 9850 4463 NK-65A 8/15/2005 SBHP 9850 4295 NK-38A 12/24/2005 SBHP 9850 4210 NK-65A 5/24/2006 SBHP 9850 4414 NK-38A 7/26/2006 SBHP 9850 4155 NK-65A 7/26/2006 SBHP 9850 4400 NK-38A 1/23/2007 SBHP 9850 4104 NK-38A 7/6/2007 SBHP 9850 3758 NK-65A 8/16/2007 SBHP 9850 4827 NK-38A 8/24/2007 SBHP 9850 4370 NK-38A 10/30/2007 SBHP 9850 4379 NK-38A 6/9/2008 SBHP 9850 3543 NK-65A 8/17/2008 SBHP 9850 4379 NK-38A 9/2/2008 SBHP 9850 3507 NK-38A 4/29/2009 SBHP 9850 3537 NK-38A 5/18/2009 SBHP 9850 3928 NK-65A 8/8/2009 SFO 9850 4525 NK-38A 8/31/2009 SBHP 9850 4165 NK-65A 6/5/2010 SFO 9850 4534 NK-38A 7/6/2010 SBHP 9850 4090 NK-65A 6/4/2011 SBHP 9850 4468 NK-38A 6/6/2011 SBHP 9850 4402 NK-65A 6/27/2012 SFO 9850 4497 NK-38A 7/14/2012 SBHP 9850 3976 NK-65A 7/13/2013 SFO 9850 4429 NK-38A 12/26/2013 SBHP 9850 3549 NK-38A 6/26/2014 SBHP 9850 3564 NK-65A 7/13/2014 SFO 9850 4674 NK-43 3/12/2015 SBHP 9850 4057 NK-38A 7/31/2015 SBHP 9850 3386 NK-38A 6/3/2016 SBHP 9850 3061 NK-38B 8/21/2016 SBHP 9850 4412 NK-14B 04/27/2017 MDT -Sag 9850 4608 NK-14B 07/28/2017 SBHP - Sag 9850 3801 NK-14B 11/24/2017 SBHP- Sag 9850 4090 NK-38B 07/21/2017 SBHP 9850 4053 NK-15A 7/2/2018 SBHP 9850 4346 NK-38B 7/17/2018 SBHP 9850 4210 NK-14B NK-65A 3/31/19 10/19/2018 PBU – Sag PBU 9850 9850 2454 4491 NK-08B NK-38B 4/30/19 09/13/2019 SBHP SBHP 9850 9850 4815 4257