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Home My WebLink About2016 Greater Point McIntyre AreaJune 15, 2017 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Re: Prudhoe Bay Unit GPMA Annual Reservoir Reports April 1, 2016 — March 31, 2017 Dear Chair Foerster: BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, AK 99519-6612 USA Main 907 564 5111 RECEIVED JUN 15 2017 AWCC 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, 2016 through March 31, 2017. 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, ` &-2"0Z �� Diane Richmond Alaska Reservoir Development, BPXA 564-4212 cc: Mr. John Schultz, ConocoPhillips Alaska, Inc. Mr. Eric Reinhold, ConocoPhillips Alaska, Inc. Mr. Gerry Smith, 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. Dave Roby, Alaska Oil and Gas Conservation Commission Prudhoe Bay Unit Lisburne Oil Pool 2017 Annual Reservoir Surveillance Report This Annual Reservoir Report for the period ending March 31, 2017 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, 2016 through March 31, 2017. 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 (L5-13 & L5-15) areas. Production and injection volumes for the 12 -month period ending March 31, 2017 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 was one production log obtained from Lisburne wells during the reporting period. Production logs for April 1, 2016 through March 31, 2017 are shown in Table 3. B. Development 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, 2017, the cumulative Lisburne Oil fool Page 1 ASR for Apr "16 — Mar" 17 volume of seawater injected in L5-29 was 22,072 mbbls. The L5-29 pilot injection demonstrated positive results with likely injection water breakthrough occurring in four offset producer wells (1-5-28, 1-5-32, L5-33 & 1-5-36). 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 remained shut in throughout 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 4,291 mbbls of seawater as of March 31, 2017. Seawater production has been observed in offset 1-3-22. 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, 2017 the cumulative volume of seawater injected in both these wells was 7,264 mbbls. Confirmed seawater production has occurred in offset L5 -16A. L5-13 developed integrity issues at the end of the reporting period and has since been secured with plans for abandonment. 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 5,910 mbbls of seawater as of March 31, 2017. Offset producer well pressure response and seawater production have been observed. 2. Well Activity: Drilling Rig Two wells: L1-13 and L5 -12A were drilled and completed into the Lisburne Formation during the reporting period. 3. Well Activity: Non -Rig Lisburne Oil Pool Page 2 ASR for Apr '16 — Mar' l 7 Twenty Lisburne wells had a total of twenty three rate -adding non -rig interventions performed during the reporting period. These rate -adding interventions included perforations, acid stimulations, gas -lift work, profile modifications, casing repairs and surface component repairs. 4. Other Activity L1 crude heater repair work began in 2015 and was completed in 2016. Other various scheduled plant and pipeline repairs and modifications were completed to protect or enhance production. Support Facilities Lisburne shares North Slope infrastructure with the Point McIntyre and Niakuk Fields. Six wells from the IPA can produce to the LPC as part of the L2 Re-route Project: L2 -03A, L2 -07A, L2 -08A, L2 -11A, L2 -13A and L2 -18A. 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 81 development wells in the Lisburne Oil Pool. Future development plans are discussed in the 2016 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 30, 2016. The Commission will be copied when the 2017 update of the Lisburne Plan of Development is filed with the Division. Lisburne Oil Pool_ Page 3 ASR for Apr '16 — Mar'] 7 Fiaures Table 1 - Lisburne Monthly Production & Injection Volumes Monthly Production Cumulative Production Gas Injection Water Injection 10/11/2016 Oil + NGL Gas Water Oil + NGL Gas Water Monthly Cum Monthly Cum Date mstbo mmscf mbw mstbo mmscf mbw mmscf bscf mbw mbw 4/1/2016 234 4075 188 184394 1968547 59034 3896 1981271 20 4173 5/1/2016 233 3855 249 184628 1972402 59283 3344 1984615 22 4195 6/1/2016 277 4949 175 184904 1977351 59459 2689 1987304 18 4213 7/1/2016 240 4224 190 185144 1981575 59648 2501 1989805 22 4235 8/1/2016 176 3315 126 185321 1984890 59775 2151 1991956 19 4211 9/1/2016 98 2190 53 185418 1987079 59828 1230 1993187 6 4217 10/1/2016 344 6589 270 185762 1993668 60098 3993 1997179 21 4238 11/1/2016 421 7688 460 186184 2001356 60558 4608 2001787 21 4217 12/1/2016 518 8077 316 186702 2009433 60874 4698 2006485 21 4238 1/1/2017 439 7485 302 187141 2016917 61176 3760 2010245 22 4260 2/1/2017 434 7586 344 187576 2024504 61520 4036 2014281 19 4279 3/1/2017 495 8632 412 188071 2033136 61931 5070 2019351 22 4301 Table 2 - Lisburne Pressure data April 1, 2016 to March 31, 2017 Well Name Survey Date Pressure (psi) (Datum = 8900' SS) L1-13 10/11/2016 3545 L2 -14B 12/17/2016 2582 L2-25 12/17/2016 3535 1-3-15 6/9/2016 2371 1-4-03 10/21/2016 2910 L5 -12A 10/27/2016 3212 NK -26 5/19/2016 3009 NK -26 2/6/2017 3930 Lisburne 011' fool Takia 4 ASR for :fpr "1 — %lar` 1 1 Table 3 - Lisburne Logging Comments/Inter retation Production logs obtained for the following wells: L3-03 Lisburne Oil Pool Page 5 ASR for Apr " 1 6 — Mar" 17 r-1 CD O O lA I LGI-10 L5-29 L5-36 LGI-12 W A. LG 1 -06 L5-33 NK -2$ L5 -25L5 -2 L5 -28A NK -26 L1 2 is * L5-2§, LGI-O Ll -30 LI -28 3 L5-21 L5-31 CP-- LI -31 -32 LS " 0 " / I L5-24 L5-19 -14 L5-09" Ll -23 Ll 7A 48 K -317B LI -21 L54 _I 0 � -- -111---. -�- LI-10 LGI-a4- too 10 L1 -15A LS 15 Key Planned well Full time producer 0 Cycle producer 0 Shut-in Injector P&A/T&A L3-32 Updated: 4/10117 ,A 04-350i Current Well Status A-36 0 I L2-32 0-01 L5-05 L5 L5-1 * 0 0 L3-02 10 LI -13 LI -09 f" I ) * L -L2-30 L2 I B-05 1/ L5-08 L5-04 L4-12 1 LB -03 0 L4J 10 L2-26 B -12 L2-25 f4 L2-24 20 0 L4-14 L2 j2l�' 4,1 LJ25 i L_`L3-11 L2k48 6 L3-10 0-19 L4-03 L440 L4-18 L,1-08, L4-11 B-15 L3-19 L3-22 L4-30 0 L3-24 L2-10 B-25 L3-23 iL3- n L4-15 0 0 La -28 L4 -§l Key Planned well Full time producer 0 Cycle producer 0 Shut-in Injector P&A/T&A L3-32 Updated: 4/10117 ,A 04-350i Current Well Status A-36 0 I Prudhoe Bay Unit Niakuk Oil Pool 2017 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, 2016 through March 31, 2017. 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, 2017 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 1. Enhanced Recovery Proiects 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 Page 11 ASR for Apr '16 — Mar `17 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 8500 bwpd for the reporting period. There are two injectors currently down (NK -23 and NK - 28) and both are being evaluated for repairs in the near time. The current injection strategy is to maintain balanced voidage replacement in each segment. 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 2015/2016 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.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. Two oil samples were taken from NK -43 during the reporting period (6/16 and 12/16) for geochemical analysis to confirm production allocation splits between the Sag River and Kuparuk reservoirs. The analyses showed that 83-95% of oil production in NK -43 is from the Kuparuk. 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. Niakuk Oil; Pool Page 2 ASR for Apr '16 — Mar `17 During the reporting period, the Niakuk field focused on optimization of producers and scale management and performed numerous inhibition treatments. NK -42 had a fill clean out from barium scale and had a new gas lift design installed for optimized production. 4. Future Development Plans (C.O. 329A Rule 9f) 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 30, 2016. The commission will be copied when the 2017 update of the Niakuk Plan of Development is filed with the Division. Niakuk Oil Pool Page 3 ASR for Apr '16 — Mar"! 7 r-) Tables and Figures Table 2 - Niakuk Monthly Voidage Balance Table I - Niakuk Monthly Production & Injection Volurn0s Gas Inject i Water Inject MI Inject Monthly Production Gas Inject Water Inject MI Inject Cumulative Monthly oil Gas Water Monthly Monthly Mon" Oil Gas Date mstho mmcf rnbw mmscf mtyw nmnscf mm math 411/2016 46 89 748 01 51 01 D! 94,544 84.800 51112016 44 95 660, 0 0 41 16:1 583 0i 94.588 848961 &V2016 271 491 3431 0 0i 0! 94,615 0!1 84,945 7/1,7016 24 381 401, 1 0 0 631 1311 920 1 01 94,639 84.983 &1,12016 32 451 -- 578 ----4- 0 76 01 1 01 94,671, 85.027' 91/2016 10 63 211 0 661 106! 7 49i i 54 0i 94,681 850911 101112016 40 2451 683 0 676 01 ! 01 94J21 85.3351 I I '1 .12 016 i 48 2251 911 0 679 11 94,769 85.5611, 121112016 1 46 218; 720, 0 8811 0i 94,815 85.778; VV2017 52 265 751 01 911 0! 94,867 86,043 ,2017 2;'1;2017 38 1831 541 01 816 oil 94.905 1 86.226 1Vn2 17 51 61 749 0 644 01 94 956 86.288 Table 2 - Niakuk Monthly Voidage Balance Monthly Production Gas Inject i Water Inject MI Inject Not Res, oil Gas Water Monthly Monthly Monthly Voldage Date mrvb mrvb I mrvb mryb mrvb mrvb mvrb 41,f2016 59 39 755! 0 521 0! wa 5111,2016 57 44 667 0 01 7681 61V2016 351 21347 Oi 01 01 403! 7/V2016 32 14 405% 01 0 01 451 80112016 41 16:1 583 01 76 0i 564 9? 13361 2-3 1 1 0! 667 1 0! -402 1 Ot V2016 j 521 148, 689 01 683 -- 0 206 1VV2016 631 1311 920 1 01 2 686 0 428 12,11f2016 1 59, 26! 727 01 i 890 01 23! 111121117 68 59 211,'2017 106! 7 49i i 54 01 1 8241 0 121 3;V2017 67 181 757 1 . .... .... .. 011 6501 01 191 Niakuk Oil Pool Pavia 4 ASIR for Apr 'l 6 — Mar"! 7 Note: Monthly Production/I njectionNoidage/P ressu re data (Tables 1 & 2) do not include the production results from NK -38A well drilled to the Ivishak (Raven) Formation or injection from the NK -65A injector which supports NK -38A. They are subject to a separate Raven Oil Pool Annual Reservoir Report. Table 3 — 2016 — 2017 Pressure Survey Data Table 3 - Niakuk Pressure data April 1, 2016 to March 31, 2017 Well Name Survey Date Pressure (psi) (Datum = 8900' SS) NK -08A 7/12/2016 4321 NK -09 9/8/2016 4444 NK -12C 3/7/2017 4086 NK -21 9/2/2016 3306 NK -22A 9/5/2016 4190 NK -27 9/6/2016 4198 NK -42 9/3/2016 4336 NK -61A 9/8/2016 4297 Niakuk Oil Pool Page 5 ASR for Apr ' 16 — Mar `17 Prudhoe Bay Unit Pt. McIntyre Oil Pool 2017 Annual Reservoir Surveillance Report This Annual Reservoir Report for the period ending March 31, 2017 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, 2016 and March 31, 2017. A. Reservoir Management 1. Summary Production and injection volumes for the 12 -month period ending March 31, 2017 are summarized in Table 1. Total Pt. McIntyre hydrocarbon liquid production (oil plus NGL) averaged 12.4 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 15 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 2016 — March 2017, a total of 11.9 BCF of MI (miscible injectant) was injected into: P1-16 (3.26 BCF), P2 -15A (0.25 BCF), P2-16 (1.8 BCF), P2-34 (0.16 BCF), P2-42 (6.19 BCF) and P2-46 (0.2 BCF). Eleven of the 15 waterflood EOR patterns have had MI injection to date. 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. 4. Analysis of Reservoir Pressure Surveys within the Pool (Rule 15 c) Point McIntyre Oil Pool Page , ASR for Apr '16 — Mar `17 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 log obtained from Pt McIntyre wells during the reporting period. Production and injection logs for April 1, 2016 thru March 31, 2017 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 (Rule 15 f & g) 1. Well Activity_ There currently 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/Ml 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. P2-34 began its first MI bulb. 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 the LPC, and between March of 2004 and November 2011 was also processed at the GC - 1 Gathering Center facilities via a 36" three phase line from PM2 to GC -1. PM1 wells can only flow to the LPC. During this period all wells at drillsite PM2 could be flowed to either the LPC (high pressure system) or to GC -1 (low pressure system). 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 Point McIntyre Oil Pool Page 2 ASR for Apr '16 — Mar `17 was completed October 2016, and all PM2 production now flows to GC -1. 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. L. Support Facilities Pt. McIntyre will continue to share Lisburne Participating Area ("LPA") minimize duplication of facilities. North Slope infrastructure with the and the Initial Participating Areas to 3. Future Development Plans (C.O. 3176) 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 2016 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 30, 2016. The Commission will be copied when the 2017 update of the Pt. McIntyre Plan of Development is filed with the division. Point McIntyre Oil Pool Rage 3 ASR for Apr '16 -- Mar '17 4 i Tables and Figures Table 1 - Pt McIntyre Monthly Production d Injection Volumes Monthly Production Gas Inject Water InjectMI Inject Cumulative Oil Gas iWatcr Monthly Monthly Monthly Ofl Gas Date mstbo mmsct mbw mmsct mbw mmol msYb msib 4'1'2016 4 2 5,2151 3.323 --- 5,866 37 1190 838; 461.0831 t.348,364 '2016 447 5.6331 228 5.464 3.778 318.141 461,530 1,35379971 61112016 370 4,055'; 2.6621 5 784 3238, 1,446` 461 900 1.358,052 7.1!2016 4114 4,523' 3,15? 6498 3 351 1585 276 462,314 1,362576 a? V2016 344 4127 2,638 5,1151 2,651' 943464 462.658 1366.702 �9_V2016 48 11,242 108 1,93()l 438 275.715 462.706 1.367.,944 10,'} 12016 330 4 863' 1,701 5 620 2.6351 909 866, 463 036 1 372 807 1 '20:6 363 4,982 1.959' 5;298 3678 79442 1 463.399 1.477,789 I12.4'2016 1 359 4,572+ 1.807+ 5.235 3.142 872 571 463 758 1 382 361 �1 1.20^017 363 3,946 1,994 5,113 2.804 "43.1611 464,1,21 1.386,307 �2 1:2017 337 3728 759— 5 124 2.517 1276 5161 464458 1 390035 13.1x201 402 4;449 2 283 5.7891 2,501 1710.9CK l 464.860 «,344,484 Table 2 - Pt McIntyre Monthly Voldage Balance r-- Monthly Production Gas inject Water Injectt t I inject j Net Res. Oil Gas Water Monthly Monthly MonthlyVoldage j Date mrvb mrvb mrvb mrvb mrvb mrvb mvrb 41?2016 573. 3.345]-- 3.3731 4,002 3.79211 738,31958] i -1.242 5'1x2016822 3.612 3,2771 3.728] 3835 19724742 ---+ 249' b'1 '20?6 �" 20`6 —� 515, 575L 2 575! -- 21.872 2.702' — 3,198x-- 3 947f —� 4>4a41 3 285,1 —— 3-40?: 546496521 982.871,2 1.987 -2,172] Bi 1, 2016 r� '91;2016 G— 478; 67 2.637 823 2,678! 109 3 4901 1314-- 2,6911 445 564 94708 170.9433 -91-3,1 934 ,10r12016 459,1 3147 ^:.727'' 3835 2,675 %411692 -1;740 111;1;2016 j 505 3.211 1..988 3 615 3.733 492.57254 -2,136 112-,112016 499 2 934 1 834 3 572 3 189�— 540 9934 -20351 0� 21'7 505 2.5041 2.024] -1,4891 2,6461 708.75982 -2,011 2-1,2017 4691 2 369 1.786' 3 496'' 2 5551 791 43992' 212191 ,2017 ( 5591 2.828 2.11 3 g50 2,539 1050.367,2 ',E�Sj Point McIntyre Oil Pool Page 4 ASR for Apr '16 -- Mar ` !, 7 Table 3 - Pt. McIntyre Pressure data April 1, 2016 to March 31, 2017 Well Name Survey Date Pressure (psi) (Datum = 8900' SS) P 1-02A 9/11/2016 4014 P1-12 3/18/2017 4174 P 1-20 9/21/2016 3933 P2-03 9/15/2016 3974 P2-04 9/16/2016 3854 P2-09 3/20/2017 4105 P2-17 9/18/2016 4063 P2-21 3/21/2017 4105 P2-25 9/20/2016 3994 P2 -36A 3/29/2017 4097 P2-44 9/17/2016 3973 P2-49 9/5/2016 4036 P2-52 9/20/2016 4030 Table 4 — Pt McIntyre Logging Point McIntyre Oil Pool Page 5 ASR 4or Apr 16 — Mar `17 Comments/Inter retation Production logs obtained for the following wells: P2-53 No gas cap monitoring logs were obtained Point McIntyre Oil Pool Page 5 ASR 4or Apr 16 — Mar `17 - - - - - - - - - - I r - -------f ---- - - ---------- 2-57 A; P2-66 P2,425 F12 -54A A154 Point McIntyr-- Oil Pool Page 6 ASP, for Apr 16 — Mlar'! 7 ii N P' -72A Unit Bounclar P2 -19A e-14 ---------- 1 :-12-51 -AL I ,P2-23 p_2S =1q 6 ?1 r3Ei-01 pz< ;2-M A 02431 1 D1 -12e. PZ -11A Pz -35 Pl-'17 r--------- i Pl-TA -41 21 t25 P2-3- A P1�38A a 25 ---------- 2-57 A; P2-66 P2,425 F12 -54A A154 Point McIntyr-- Oil Pool Page 6 ASP, for Apr 16 — Mlar'! 7 Figure 2. Drill Site and Pipeline Configuration Point McIntyre Oil Pool Page 7 ASR for Apr '1G — Mar 'l 7 Prudhoe Bay Unit Raven Oil Pool 2017 Annual Reservoir Surveillance Report This Annual Reservoir Report for the period ending March 31, 2017 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, 2016 and March 31, 2017. 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 did not inject for a majority of the reporting period, however it was recently put back on injection once an unsupported NK -38B decline was established. Production from the Raven Field started in March 2001 with the completion of the Sag River in NK -43. The Sag River 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. Oil Production from the Raven pool averaged 0.92 mbd for the reporting period. The reservoir management plan has changed slightly from previous management plan as NK -38B exhibits aquifer support in the new location. NK -65A injection was tapered back to better understand the aquifer support for an optimized reservoir management scheme. However, the long-term plan has remained the same, which is to replace the voidage created by hydrocarbon production and keep reservoir pressure at levels that will optimize oil production. There is a future injector planned at a more optimized location to support NK -38B and enhanced recovery through waterflood sweep. At such time, NK -65A will be converted to a producer and produce from the rich Sag River condensate section. Raven Oil Pool Page 1 ASR for Apr '16 — Mar '17 NK -14B was spudded in March 2017 and is an extension well delineating the outer boundaries of the Raven Oil Pool. 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 -3813, was taken right before being put online in August 2016 and reservoir pressure was 4412 psi. 3. Results of Production Logging, Tracer and Well Surveys No production or casedhole logs were obtained in Raven during the reporting period. B. Development 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 2.5 mbd. With future planned SIBHP for the NK -3813, an optimized injection voidage replacement plan will be determined. Raven Oil Food Page 2 ASR for Apr '16 — Uiar `17 2. Voidage Balance of Produced and Infected 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. Two oil samples were taken from NK -43 during the reporting period (6/16 and 12/16) for geochemical analysis to confirm production allocation splits between the Sag River and Kuparuk reservoirs. The analyses showed that 83-95% 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 2016 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 30, 2016. The Commission will be copied when the 2017 update of the Raven Plan of Development is filed with the division. Raven Oil Pool Rage 3 ASR for Afar '16 — Mar `17 Tables and Figures l Note: Monthly Production/I njectionNoidage for the Ivishak formation. Raven Oil Pool Pape 4 ASP for Apr '16 — Mar `17 Table 1 - Raven Monthly Production S injection Volumes ---------T- Monthly Production Gas inject Water inject MI Inject Cumulative TWater Oil + NGL Gas —Water� Monthly Monthly Monthly Oil Gas Date mstbo mmsct mbw i—mmscf mbw mmscf mstb mstb 4?1,'2016 I 7 821 91. 0{ 0 01 — 3137 17,402 5r1±2016 5� 601 64! 0 0 0� 3.1421 17;462 612016 31 16! 123, OI 0 01 3145 17,478 7;1;2015 0 13 0L _ 0 01 3,145{ f 1 17.47-9) $'1;2016 0' 9 62. 01 0 0 3 1451 174881 91;2016 291 361 13 0 0 0 3.174 17,524 1W 201E 891 fiat 1571 0i 41 0� 3 261 17.654 1 rV2016 47f 83 2141 0{ mm-- 0 CJI 3.306 17,737 1' 1.2016 45{ ' 14T 1281 0 01 0i 3 349 17,851 1 ! 2017 41 861 83; 0 0 0� 3,395 1 ?,937 2 t 2017 43 68 54 0 38 03 437 18005 31,'21717 zl 16`1 '18� 0 73 .0 3x61 18.167' Note: Monthly Production/I njectionNoidage for the Ivishak formation. Raven Oil Pool Pape 4 ASP for Apr '16 — Mar `17 Table 2 - Raven Monthly Voidage Balance Monthly Production Gas Inject TWater Inject ( MI Inject i ` Net Res. oll Gats Water Monthly Monthly —� Monthly Voidage i Date mrvb mrvb I mrvb mrvb L mrvb mrvb mvrb 4+1,2@16 i 0 — 571 _92 01 0! �5iir20?6 42 641 0l 0`.. 13 16,11,`2016 I _ 4' 101i 124 0; 0' 0 7;1,2016 t� 1I 13 t?� a� 0� 14 8112@16 a� 71 62 G 01 01 69; 45 5— 5 13T 0 i --- 0! 0} —63 IO�1�2016 -- 11� 133 -- 33 159'1 @1 0', @ 325' 1I T, 1,2416 70 281 217 01 01 0 315 12f 112016 66 541 130; 0 4! 01 254; i1,�',2@t7 31 441 01 al_ Cl 1451, 21'112017 641 20 5 0 39' 0 00 3r 2C 17 � 1174 0 i 74! --- 1 187 Note: Monthly Production/I njectionNoidage for the Ivishak formation. Raven Oil Pool Pape 4 ASP for Apr '16 — Mar `17 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 Raven Oil P®®I Page 5 ASI' i®r Apr '16 — Alar `17