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Home My WebLink About2017 Greater Point McIntyre Areabp too e BP Exploration (Alaska) Inc 900 cast Benson Boulevarl PC Box 196612 Anchorage, ,Alaska 99519-6612 (907) 561-51 1 1 June 14, 2018 Hollis French, Chair Alaska Oil and Gas Conservation Commission 333 West 7t' Ave, Suite 100 Anchorage, AK 99501 Re: Prudhoe Bay Unit GPMA Annual Reservoir Reports April 1, 2017 — March 31, 2018 Dear Chair French: 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, 2017 through March 31, 2018. These Annual Reservoir Reports were prepared in accordance with the latest conservation orders for each pool. If you have any questions regarding the reports please contact Bill Bredar at 564-5348 or through email at william.bredar@bp.com. Respectfully, Diane Richmond Alaska Reservoir Development, BPXA 564-4212 cc: Mr. John Schultz, ConocoPhillips Alaska, Inc. Mr. Eric Reinbold, ConocoPhillips Alaska, Inc. Mr. Jeffry Farr, ExxonMobil Alaska, Production Inc. Mr. Hank Jamieson, ExxonMobil Alaska, Production Inc. Mr. Dave White, Chevron USA Ms. Rebecca Kruse, Division of Oil and Gas Mr. Kevin Pike, Division of Oil and Gas Mr. Dave Roby, Alaska Oil and Gas Conservation Commission r 3 Prudhoe Bay Unit Lisburne Oil Pool 2018 Annual Reservoir Surveillance Report This Annual Reservoir Report for the period ending March 31, 2018 is submitted to the Alaska Oil and Gas Conservation Commission for the Lisburne Oil Pool in accordance with commission regulations and Conservation Order 207A. This report covers the period from April 1, 2017 through March 31, 2018. 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 (1-5-15) area. Production and injection volumes for the 12 -month period ending March 31, 2018 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. 3. Results and Analysis of Production Logging Surveys There were three production logs obtained from Lisburne wells during the reporting period. Production logs for April 1, 2017 through March 31, 2018 are shown in Table 3. B. Development and Production Activity 1. Enhanced Recovery Projects a. L5 Gas Cap Water Injection Surveillance (C. O. 207A) 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, 2018, the cumulative Lisburne Oil Pool Page 1 ASR for Apr '17 — Mar' 18 volume of seawater injected in L5-29 was 22,207 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 short time (11 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 5,573 mbbls of seawater as of March 31, 2018. Seawater production has been observed in offset L3-22. 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, 2018 the cumulative volume of seawater injected in both these wells 'was 7,776 mbbls. Confirmed seawater production has occurred in offset L5 -16A. L5-13 developed integrity issues at the beginning of the reporting period and has since been plugged and abandoned. In addition, a pilot water injection project into the Alapah Formation has been initiated from the Niakuk Heald Point pad. Alapah producer NK -25 was converted to seawater injection service in March 2013 and has injected 5,915 mbbls of seawater as of March 31, 2018. Offset producer well pressure response and seawater production have been observed. 2. Well Activity: Drilling Rig New well L3-25 was drilled and completed into the Lisburne Formation during the reporting period. Sidetrack well NK -26A was drilled into the Lisburne Formation during the reporting period and was in the process of being completed at the end of the reporting period. Lisburne Oil Pool ASR for Apr '17 Mar'! 8 3. Well Activity; Nan-Riq Twenty five Lisburne wells had a total of thirty rate -adding non -rig interventions performed during the reporting period. These rate -adding interventions included perforations, hydrate & paraffin removal, acid stimulations, gas -lift work, profile modifications, fill cleanouts, well integrity repairs and surface component repairs. 4. Other Activity Various scheduled minor plant and pipeline repairs and modifications were completed to protect or enhance production from the Lisburne during the reporting period. Support Facilities Lisburne shares North Slope infrastructure with the Point McIntyre and Niakuk Fields. Eight wells from the IPA can produce to the LPC as part of the L2 Re- route Project: L2 -03A, L2 -07A, L2 -08A, 1-2-11, L2 -13A, L2 -18A, L2 -21B and L2 - 29A. 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. 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 78 development wells in the Lisburne Oil Pool. Future development plans are discussed in the 2017 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, 2017. The Commission will be copied when the 2018 update of the Lisburne Plan of Development is filed with the Division. Lisburne Oil Pool ASR for Apr '17 — Mar" 18 Tables & Fiaures Table 2 - Lisburne Pressure data April 1, 2017 to March 31, 2018 Pressure Well Name Survey Date (psi) (Datum = 8900' SS) L1-23 08/12/2017 Table 1 - Lisburne Monthly Production & Injection Volumes 1-2-1413 03/18/2018 2047 Monthly Production Cumulative Production Gas Injection Water Injection 08/18/2017 Oil + NGL Gas Water Oil + NGL Gas Water Monthly Cum Monthly Cum Date mstbo mmscf mbw mstbo mmscf mbw mmscf bscf mbw mbw 4/1/2017 482 8,341 425 188,553 2,041,477 62,356 4,338 2,023,689 223 48,615 5/1/2017 516 8,118 457 189,069 2,049,595 62,814 4,089 2,027,778 215 48,830 6/1/2017 443 6,934 404 189,512 2,056,529 63,218 3,772 2,031,549 79 48,909 7/1/2017 265 4,206 211 189,777 2,060,735 63,428 2,067 2,033,616 118 49,027 8/1/2017 413 6,646 419 190,190 2,067,381 63,847 4,609 2,038,225 24 49,051 9/1/2017 498 7,494 399 190,687 2,074,876 64,246 3,964 2,042,189 0 49,051 10/1/2017 463 7,665 358 191,150 2,082,541 64,604 4,777 2,046,966 102 49,152 11/1/2017 367 6,222 326 191,517 2,088,763 64,930 4,632 2,051,597 285 49,438 12/1/2017 417 6,843 337 191,934 2,095,606 65,267 5,597 2,057,194 155 49,593 1/1/2018 399 7,071 360 192,333 2,102,678 65,628 6,065 2,063,260 155 49,748 2/1/2018 363 5,873 273 192,696 2,108,551 65,901 5,122 2,068,382 275 50,023 3/1/2018 435 7,572 287 193,131 2,116,123 66,188 5,499 2,073,881 304 50,327 Table 2 - Lisburne Pressure data April 1, 2017 to March 31, 2018 Pressure Well Name Survey Date (psi) (Datum = 8900' SS) L1-23 08/12/2017 2186 1-2-1413 03/18/2018 2047 1-3-22 09/27/2017 2768 1-3-25 08/18/2017 2519 1-4-30 02/23/2018 3135 1-5-29 05/31/2017 3648 NK -26 05/02/2017 3814 Table 3 - Lisburne Lo in ' Production logs obtained for the following L1-02 L1-13 L5 -12A Lisburne Oil Pool ASR for Apr ,17 Mar'! 8 co L N J Figure 1 - Lisburne Location and Status Ma �9. Z p o '- JJ c • 3 N HN N � 0 9� m TO J• , m 03 9 W # m• } 190 J t J in J To N� J� 3 q� � J KoM � F m J N 0 9 0 � I N* m � J p r 7-0 .-I m a N J •..I J Lis':_;urne Oii 'Poo; Pale sIIpM Io i,ogt-Fj co V, N LO t0 V CL 7 V >✓ OJ � j V O= W 7 CL Q o E Q C O o N (D Q Y m an o a LL cn a N C (D 0 V1S •.. co V, N LO t0 V CL 7 Z f�i' C Prudhoe Bay Unit Niakuk Oil Pool 2018 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, 2017 through March 31, 2018. 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, 2018 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. 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. 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 Niakuk Oil Pool ASP for Apr '17 — Mar `18 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 are 3 active injectors in the Niakuk Pool with an average total injection rate of approximately 16,000 bwpd for the reporting period. There are two injectors currently down (NK -23 and NK - 28). NK -23 is expected to be back on injection 2-3Q 2018. NK -28 has 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 2016/2017 reservoir pressure surveys. 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. 2. Special Monitoring: NK -43 Well C.Q. 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 3298 on December 7, 2006. Two oil samples were taken from NK -43 during the reporting period (5/17 and 10/17) for geochemical analysis to confirm production allocation splits between the Sag River and Kuparuk reservoirs. The analyses showed that -95% of oil production in NK - 43 is from the Kuparuk. Niakuk Oil Pool Page 2 ASR for Apr ' 17 — Mar `18 I 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 and performed numerous inhibition treatments. NK -27 had a repair job following a leak detect log that allowed for returned production . 4. Future Development Plans (C.O. 329A Rule 9 Future development plans are discussed in the 2016 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, 2017. The commission will be copied when the 2018 update of the Niakuk Plan of Development is filed with the Division. 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 0.86- 1.05. Daily allocation data and daily test data are being retained. Month Year LPC Allocation Factor April 2017 1.01 0.99 May 2017 June 2017 0.99 July 2017 0.96 August 2017 0.86 September 2017 0.90 October 2017 0.94 November 2017 0.89 December 2017 0.97 January 2018 2018 1.05 February 1.02 March 2018 11.00 TAR -21 days of production Niakuk Oil Pool Page 3 ASR for Apr '17 — Mar `18 Tables and Fi ures Note: Monthly Production/I njectionNoidage/Pressure data (Tables 1 & 2) do not include the production results from NK -38B nor NK -14B wells (Raven) or injection from the NK -65A injector. They are subject to a separate Raven Oil Pool Annual Reservoir Report. N;Iakuk 10il Pool Page 4 ASR for Apr '17 -- Mar :i 8 Table 1 - Niakuk Monthly Production & Injection Volumes Table 2 - Niakuk Monthly Voidage Balance Monthly Production Gas Inject Water Inject MI Inject Cumulative MI Inject Oil Gas Water Monthly Monthly Monthly Oil Gas Date mstbo mmscf mbw mmscf mbw mmscf mstb mmscf 4/1/2017 42 60 685 0 568 0 94,998 86,347 5/1/2017 37 59 666 0 550 0 95,036 86,406 6/1/2017 44 59 621 0 367 0 95,080 86.465 7/1/2017 21 36 295 0 611 0 95,100 86,501 8/1/2017 37 72 665 0 250 0 95,138 86,573 9/1/2017 27 49 488 0 236 0 95,165 86,622 10/1/2017 38 71 788 0 383 0 95,202 86,692 11/1/2017 31 53 701 0 566 0 95,233 86,745 12/1/2017 36 65 753 0 627 0 95,269 86,810 1/1/2018 38 69 816 0 658 0 95,307 86,878 2/1/2018 31 50 673 0 603 0 95,338 86,929 3/1/2018 43 44 740 0 650 0 1 95,381 86,973 Note: Monthly Production/I njectionNoidage/Pressure data (Tables 1 & 2) do not include the production results from NK -38B nor NK -14B wells (Raven) or injection from the NK -65A injector. They are subject to a separate Raven Oil Pool Annual Reservoir Report. N;Iakuk 10il Pool Page 4 ASR for Apr '17 -- Mar :i 8 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 4/1/2017 55 21 692 0 573 0 194 5/1/2017 49 23 673 0 556 0 188 6/1/2017 57 19 627 0 371 0 333 7/1/2017 27 15 298 0 617 0 -278 8/1/2017 49 32 672 0 253 0 500 9/1/2017 35 20 493 0 239 0 310 10/1/2017 49 30 796 0 387 0 489 11/1/2017 40 21 708 0 572 0 197 12/1/2017 46 27 761 0 633 0 202 1/1/2018 49 29 824 0 664 0 238 2/1/2018 40 20 680 0 609 0 131 3/1/2018 55 10 747 0 657 0 156 Note: Monthly Production/I njectionNoidage/Pressure data (Tables 1 & 2) do not include the production results from NK -38B nor NK -14B wells (Raven) or injection from the NK -65A injector. They are subject to a separate Raven Oil Pool Annual Reservoir Report. N;Iakuk 10il Pool Page 4 ASR for Apr '17 -- Mar :i 8 Table 3 — 2016 — 2017 Pressure Survey Data Table 3 - Niakuk Pressure data April 1, 2017 to March 31, 2018 Well Name Survey Date Pressure (Psi) (Datum = 8900' SS) NK -42 07/22/2017 4158 NK -09 07/25/2017 4370 NK -21 07/25/2017 4559 NK -22A 07/26/2017 4052 NK -27 08/06/2017 4064 NK -29 06/29/2017 4332 NK -61A 08/05/2017 4345 Niakuk Oil Pool Page 5 ASR for Apr '17 — Mar `18 Prudhoe Bay Unit Pt. McIntyre Oil Pool 2018 Annual Reservoir Surveillance Report This Annual Reservoir Report for the period ending March 31, 2018 is submitted to the Alaska Oil and Gas Conservation Commission for the Pt. McIntyre Oil Pool in accordance with Commission regulations and Conservation Order 31713. This report covers the period between April 1, 2017 and March 31, 2018. A. Reservoir Management 1. Summary Production and injection volumes for the 12 -month period ending March 31, 2018 are summarized in Table 1. Total Pt. McIntyre hydrocarbon liquid production (oil plus NGL) averaged 14.9 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 14 wells on water injection. 2. Progress of Enhanced Recovery Project Implementation and Reservoir Management Summary (Rule 15 a) During the 12 month period from April 2017 — March 2018, a total of 22.4 BCF of MI (miscible injectant) was injected into: P1-16 (5.2 BCF), P2-09 (0.29 BCF), P2 -15A (5.7 BCF), P2-28 (0.5 BCF), P2-29 (0.63 BCF), P2-34 (0.05 BCF), P2-42 (0.59 BCF), P2-46 (6.2 BCF) and P2-47 (3.2 BCF). Thirteen of the fifteen waterflood patterns have had MI injection to date, although P2 -34's is very small due to well operability issues. 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 1 ASR for Apr ' 17 — Mar `18 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. 5. Results and Analysis of Production & Injection Logging Surveys (Rule 15 d) There was one production log and no injection logs obtained from Pt McIntyre wells during the reporting period. Production and injection logs for April 1, 2017 thru March 31, 2018 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. P2-47 began its first MI bulb in September, 2017. 2. Other Activities a. Pipelines Figure 2 shows the existing pipeline configuration together with the miscible injectant distribution pipelines from LPC and CGF to the Pt. McIntyre drill sites. 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 drillsite 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 Point McIntyre Oil Pool Page 2 ASR for Apr ' 17 — Mar `18 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 2018 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 20, 2017. The Commission will be copied when the 2018 update of the Pt. McIntyre Plan of Development is filed with the division. Point McIntyre Oil Pool Page 3 ASR for Apr'17 — Mar `18 Tables and Fiatlres Point McIntyre Oil Pool Page ASR for Apr 'i7 -- Mar `1.8 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 4/1/2017 414 4,392 2,334 5,850 2,772 1729.142 465,274 1,398,876 5/1/2017 413 4,313 2,338 5,465 2,585 1602.1 1 465,687 1,403,189 6/1/2017 428 4,357 2,392 4,842 2,358 1187.579 466,115 1,407,546 7/1/2017 148 1,846 714 3,354 1,598 479.527 466,263 1,409,392 8/1/2017 239 3,011 1,041 5,408 1,241 1253.997 466,502 1,412,403 9/1/2017 417 3,797 3,115 5,658 1,545 1894,435 466,918 1,416,200 10/1/2017 474 4,521 3,346 6,341 2,684 2428.633 467,393 1,420,721 11/1/2017 501 5,722 3,354 6,507 2,727 2824.284 467,894 1,426,443 12/1/2017 530 5,755 3,923 6,625 3,277 3411.102 468,424 1,432,197 1/1/2018 543 6,014 4,105 4,909 3,586 1954.647 468,967 1,438,212 2/1/2018 415 5,354 3,022 4,253 2,696 1603.135 469,382 1,443,566 3/1/2018 497 5,737 3,661 5,014 3,026 2058.163 469,879 1,449,303 Point McIntyre Oil Pool Page ASR for Apr 'i7 -- Mar `1.8 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 4/1/2017 576 2,782 2,369 3,992 2,814 1072 -2,150 5/1/2017 574 2,729 2,373 3,729 2,624 993 -1,670 6/1/2017 595 2,751 1 2,428 3,304 2,394 736 -660 7/1/2017 206 1,183 724 2,289 1,622 297 -2,094 8/1/2017 332 1,931 1,057 3,690 1,260 778 -2,408 9/1/2017 580 2,375 3,161 3,860 1,568 1175 -488 10/1/2017 660 2,839 3,396 4,327 2,724 1506 -1,663 11/1/2017 697 3,644 3,405 4,440 2,768 1751 -1,212 12/1/2017 737 3,652 3,981 4,520 3,326 2115 -1,590 1/1/2018 755 3,822 4,167 3,350 3,639 1212 543 2/1/2018 577 3,438 3,.068 2,902 2,736 994 451 3/1/2018 692 3,657 3,716 3,421 3,071 1276 296 Point McIntyre Oil Pool Page ASR for Apr 'i7 -- Mar `1.8 Table 3 - Pt. McIntyre Pressure data April 1, 2017 to March 31, 2018 Pressure Well (psi) Name Survey Date (Datum = 8900' SS P1-04 07/23/2017 4078 P1-05 08/26/2017 4141 P1 -07A 11/09/2017 3920 P2-17 08/23/2017 4204 P1-13 08/23/2017 4126 P 1-20 11/22/2017 3363 P1-20 02/01/2018 3526 P2-01 11/27/2017 4065 P2-13 12/01/2017 4024 132-22A 08/27/2017 4126 P2-25 08/26/2017 4185 P2 -36A 12/02/2017 4091 P2-40 08/24/2017 3978 P2-4513 08/11/2017 4380 P2-48 08/11/2017 4354 P2-49 08/10/2017 4174 P2 -54A 11/18/2017 4160 P2-60—[05/30/2017 4133 P1-24 01/14/2018 3914 Table 4 — Pt McIntyre Logging Commentslinte rp retatio n Production logs obtained for the following wells: P2-30. No gas cap monitoring logs were obtained Point McIntyre Oil Pool Page 5 ASR for Apr '17 — Mar `18 Figure 1 Pt. McIntyre Well Location Map Point McIntyre Oil Pool Page 6 ASR for Apr'17 – Mar `18 t k - --- - - ---------•---- _------' - - --- - - - j P2 -22A i Unit Boundary___..— — PZ -19A P2 -it _�._.._.._....____ PZ-6,AL, w �CQ a,_il_1-71 yi'Y' .�'I-I3 r1A fit Fra ?1F } 37R 0" a>.i2 ScTf A P2 71 A P,-,1 a �2� P ? �?iti96 Y 1,q _ k pi_� �- P1 -0'7A A f p1-03 1± * dA Pf:25 Y }t A' s s dLA PIy4T -,,WL, Point McIntyre Oil Pool Page 6 ASR for Apr'17 – Mar `18 Figure 2. Drill Site and Pipeline Configuration Point McIntyre Oil Pool Page 7 ASR for Apr '17 — Mar `18 Prudhoe Bay Unit Raven Oil Pool 2018 Annual Reservoir Surveillance Report This Annual Reservoir Report for the period ending March 31, 2018 is submitted to the Alaska Oil and Gas Conservation Commission for the Raven Oil Pool in accordance with Commission regulations and Conservation Order 570. This report covers the period between April 1, 2017 and March 31, 2018. 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, with plans to convert it to a Sag River producer now that NK -15A (injector) has been drilled (1Q 2018). 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, 2018 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. Oil Production from the Raven pool averaged 1.05 mbd for the reporting period. As NK -38B seems to exhibit aquifer support based on pressure and water analysis, NK - Raven Oil Pohl Page 1 ASR for Apr ' 17 — Mar ' 1 8 65A injection has been decreased to a VRR less than 1. NK -15A was recently drilled and completed in March, 2018 in a position in the structure believed to be better situated to support and waterflood the structure for the NK -38B offtake. The long-term depletion plan is to optimize hydrocarbon production in the Raven reservoir through voidage replacement from injection to supplement 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 less than 1.0 due to decreased injection to offset aquifer influx and NK -14B production is included in voidage, however NK -65A is not injecting to make up the voidage for NK -14B due to connectivity uncertainty between the wells. 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 July 2017 and reservoir pressure was 4062 psi (datum). The well shows a -300 psi decline, and thus led to a new injection location with NK -15A for optimized support. 3. Results of Production Logging, Tracer and Well Surveys No production logs were obtained in Raven during the reporting period. 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 at an average rate of 1.7 mbd. Once injection from NK -15A begins, an optimized injection voidage replacement plan will be determined. Raven Oil Pool 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 3298 on December 7, 2006. Two oil samples were taken from NK -43 during the reporting period (5/17 and 10/17) for geochemical analysis to confirm production allocation splits between the Sag River and Kuparuk reservoirs. The analyses showed that -95% of oil production in NK -43 is from the Kuparuk. 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 2018 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, 2017. The Commission will be copied when the 2018 update of the Raven Plan of Development is filed with the division. 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 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 0.86-1.05. Daily allocation data and daily test data are being retained. Month Year LPC Allocation Factor April 2017 1.01 May 2017 0.99 June 2017 0.99 0.96 July 2017 August 2017_ 0.86 0.90 September 2017 October 2017 0.94 November 2017 0.89 December 2017 0.97 January 2018 1.05 February 2018 1.02 March 2018 1.00 TAR -21 days of production Raven Oil Pool Page 4 Tables and Figures Note: Monthly Production/I njectionNoidage for the Ivishak and Sag formation. Raven Oil Fool Page 5 ASIS for Apr 17 e Mar'18 Table 1 - Raven Monthly Production & Injection Volumes Table 2 - Raven Monthly Voidage Balance Monthly Production Gas Inject Gas Inject Water Inject MI Inject Cumulative Oil Oil + NGL Gas Water Monthly Monthly Monthly Oil Gas Date mstbo mmscf mbw mmscf mbw mmscf mstb mmscf 4/1/2017 29 183 129 0 70 0 3,488 18,350 5/1/2017 30 192 130 0 61 0 3,516 18,542 6/1/2017 40 204 92 0 33 0 3,554 18,746 7/1/2017 63 214 60 0 46 0 3,614 18,960 8/1/2017 53 251 112 0 0 0 3,663 19,211 9/1/2017 28 174 108 0 20 0 3,689 19,385 10/1/2017 27 251 136 0 27 0 3,713 19,637 11/1/2017 15 157 119 0 39 0 3,727 19,794 12/1/2017 14 167 113 0 62 0 3,740 19,960 1/1/2018 13 175 122 0 60 0 3,752 20,135 2/1/2018 11 151 114 0 55 0 3,762 20,286 3/1/2018 61 212 144 0 38 0 3,820 20,497 Note: Monthly Production/I njectionNoidage for the Ivishak and Sag formation. Raven Oil Fool Page 5 ASIS for Apr 17 e Mar'18 Table 2 - Raven 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 4/1/2017 41 119 130 0 71 0 219 5/1/2017 43 125 131 0 62 0 237 6/1/2017 59 126 93 0 33 0 244 7/1/2017 92 117 61 0 47 0 224 8/1/2017 76 153 114 0 0 0 343 9/1/2017 40 113 109 0 20 0 241 10/1/2017 38 172 138 0 27 0 321 11/1/2017 21 109 120 0 39 0 211 12/1/2017 20 117 115 0 63 0 188 1/1/2018 19 123 123 0 61 0 205 2/1/2018 15 107 115 0 55 0 183 3/1/2018 89 117 146 0 38 0 313 Note: Monthly Production/I njectionNoidage for the Ivishak and Sag formation. Raven Oil Fool Page 5 ASIS for Apr 17 e Mar'18 Table 3 — Raven Ivishak Pressure Survev Data Since March 2005 Sw Test Date Pres Sury Type Datum Ss Pres Datum Name 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 Raven Oil Pool Page 6 ASR for Apr '17 — Mar `18