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Home My WebLink About2016 Endicott Oil PoolHilcorp Alaska, LLC March 3011, 2017 Cathy Foerster, Chairman Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RECEIVED LIAR 312017 RE: DUCK ISLAND UNIT, ENDICOTT FIELD, ENDICOTT OIL POOL, STATE OF ALASKA, 2016 ANNUAL RESERVOIR REVIEW Dear Commissioner Foerster: Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8377 Fax: 907/777-8580 ckanyer@hilcorp.com In accordance with Conservation Order No. 462, Hilcorp Alaska, LLC ("Hilcorp"), as Operator, hereby submits for your review the following Annual Reservoir Review for the Endicott Field. This is the Annual Reservoir Review and corresponds to events during the 2016 calendar year. The Endicott Field has been on production since October 1987. A. Progress of Enhanced Recovery Project and Reservoir Management Summary During 2016, no new wells were drilled or sidetracked in the Duck Island Unit. Therefore the locations of all the wells in the Duck Island Unit have remained unchanged. Production and injection statistics are summarized in Table 1. Average daily oil production from the Endicott Oil Pool was 6,815 bopd and average daily gas injection was 309.5 mmscfpd. Note this includes downtime associated with the 21 day full - facility turnaround (TAR). During 2016, injected fluid was calculated to be 9,549 thousand -reservoir barrels (MRB) less than reservoir voidage. At year end, the reservoir overall cumulative voidage replacement ratio was 0.93. The average reservoir pressure varies between zones. The average of surveys run in 2016 was 3,695 psia. Hilcorp became the official Operator of the Endicott Field effective November 18, 2014. As a result, the historic reservoir simulation model developed by the previous operator will no longer will be utilized in the enhanced recovery or reservoir management. Hilcorp has elected to optimize the existing waterflood patterns through streamline simulation techniques as opposed to a full field reservoir simulation model. This process will increase waterflood pattern efficiency by allocating existing water injection volumes among existing active injection wells. These streamline simulation models will continue development in 2017. Table 1: ENDICOTT FIELD 2016 OVERVIEW STATISTICAL SUMMARY WELL STATISTICS Produced Fluids As of 12/31/2016 Full year (1) As of Dec -16 (2) Formation Producers 54 50 Gas, MRB Injectors 24 23 6,700,769 NOTES: Voidage, Year Cum since (1) Well count data reflects ONLY those wells which contributed to productionlinjection during the respective year (2) Active w ells as of December 2016 MRB MRB PRODUCTION/INJECTION STATISTICS Jan -2016 332,875 7,249,611 Cumulative Start - 14,705, 504 14, 705, 504 4,102, 422, 922 Up through Production 2016 12/31/16 Oil (BBL) 2,494,394 471,703,031 Gas (MCF) 113,277,733 3,290,333,478 Water (BBL) 71, 622, 620 1, 594, 673, 354 Injection 6,766,586 6,467,830 Water (BBL) 72, 243, 249 1, 937, 549, 905 Gas (MCF) 102,339,032 2,928,038,610 Balance 68, 039, 693 4,155, 757,111 Jun -2016 Cum Production (MRB) 151,099,863 4,238,817,280 Cum Injection (MRB) 141,550,881 3,937,531,226 Over/Under(MRB) -9,548,982 -301,286,054 DAILY AVERAGE RATE DATA 2016 92,192, 987 4,179, 910, 405 Aug -2016 Production 1,982,945 1,836,716 Oil, BOPD 6,815 Sep -2016 Gas, MCF/D 309,502 6,361,433 Water, BWPD 195,690 Oct -2016 Injection 7,023,710 6,974,707 Water, BWPD 197,386 Nov -2016 Gas, MCFPD 279,615 6,736,407 AVERAGE RESERVOIR PRESSURE 137, 548, 067 4, 225, 265, 485 Dec -2016 Average ofsurveys obtained in 2016 3,695 psia B. Voida2e Balance by Month of Produced Fluid and Infected Fluids - 2016 C. Summary and Analysis of reservoir pressure surveys within the pool Page 2 Net Cum sl Injection, Year start MRB Cum, MRB P -884,402 -884,402 -292,751, -806,734 -1,691,136 -293,557, -805,141 -2,496,276 -294,362, -878,371 3,374, 647 -295,241, -863,843 4,258,491 -296.125, -810,473 -5,068,964 -296,935, -616,602 -5,685,566 -297, 552, -306,320 -5,991,886 -297,858, -669,378 -6,661,264 -298.527, -750,701 -7,411,965 -299,278, -773,597 -8,185,562 -300,052, -742,792 -8,928,354 -300, 795, -8,928,354 Produced Fluids Total Formation Water, Total Gas, MRB MRB MRB Cum, MRB start-up, MRB 6,700,769 Water, Voidage, Year Cum since Month Oil, RB Free Gas, RB MRB MRB Cum, MRB start-up, MRB Jan -2016 332,875 7,249,611 7,123, 018 14,705, 504 14, 705, 504 4,102, 422, 922 Feb -2016 302,966 6,846,482 6,365,313 13, 514, 762 28, 220, 266 4,115, 937, 683 Mar -2016 282,650 7,093,875 5,523,064 12, 899, 589 41,119, 855 4,128, 837, 273 Apr -2016 303,768 6,766,586 6,467,830 13, 538,184 54, 658, 038 4,142,375, 456 May -2016 307,856 6,767,998 6,305,801 13, 381, 655 68, 039, 693 4,155, 757,111 Jun -2016 292,745 6,598,145 6,119, 655 13, 010, 545 81, 050, 238 4,168, 767, 656 Jul -2016 241,931 5,522,319 5,378,499 11,142, 749 92,192, 987 4,179, 910, 405 Aug -2016 77,794 1,982,945 1,836,716 3,897,454 96, 090, 441 4,183, 807, 859 Sep -2016 270,914 6,244,656 6,361,433 12, 877, 003 108, 967, 444 4,196, 684, 862 Oct -2016 305,175 7,023,710 6,974,707 14,303,592 123,271,036 4210,988,454 Nov -2016 331,241 7,207,384 6,736,407 14, 277, 031 137, 548, 067 4, 225, 265, 485 Dec -2016 320,013 6,803,603 6,428,180 13, 551, 796 151, 099, 863 4, 238, 817, 281 3,369,927 76,107, 316 71,62Z 620 151, 099, 863 C. Summary and Analysis of reservoir pressure surveys within the pool Page 2 Net Cum sl Injection, Year start MRB Cum, MRB P -884,402 -884,402 -292,751, -806,734 -1,691,136 -293,557, -805,141 -2,496,276 -294,362, -878,371 3,374, 647 -295,241, -863,843 4,258,491 -296.125, -810,473 -5,068,964 -296,935, -616,602 -5,685,566 -297, 552, -306,320 -5,991,886 -297,858, -669,378 -6,661,264 -298.527, -750,701 -7,411,965 -299,278, -773,597 -8,185,562 -300,052, -742,792 -8,928,354 -300, 795, -8,928,354 Injected Fluids Total Formation Water, Injection, Year Cum since Gas, MRB MRB MRB Cum, MRB start-up, MRB 6,700,769 7,120, 313 13, 821,102 13, 821,102 3, 809, 671, 848 6,363,422 6,344,605 12, 708, 028 26, 529,130 3, 822, 379, 876 6,561,914 5,512,535 12, 094, 449 38, 623, 578 3, 834, 474, 324 6,200,193 6,459,620 12, 659, 813 51, 283, 391 3,847,134,137 6,198, 085 6,299,727 12, 497, 811 63, 781, 202 3, 859, 631, 948 6,026,857 6,173, 205 12, 200, 072 75, 981, 275 3, 871, 832, 020 5,021,261 5,504,865 10, 526,147 86, 507, 421 3, 882, 358,167 1,672,432 1,918,702 3,591,134 90, 098, 555 3, 685, 949, 301 5,698,300 6,509,325 12, 207, 624 102,306,179 3,898,156,925 6,470,335 7,082,556 13,552,891 115,859,071 3.911,709,817 6,666,286 6,835,146 13, 503, 434 129, 362, 505 3, 925, 213, 251 6,326,356 6,482,649 12, 809, 004 142,171, 509 3, 938, 022, 255 69,928,260 72,243,249 142,171,509 C. Summary and Analysis of reservoir pressure surveys within the pool Page 2 Net Cum sl Injection, Year start MRB Cum, MRB P -884,402 -884,402 -292,751, -806,734 -1,691,136 -293,557, -805,141 -2,496,276 -294,362, -878,371 3,374, 647 -295,241, -863,843 4,258,491 -296.125, -810,473 -5,068,964 -296,935, -616,602 -5,685,566 -297, 552, -306,320 -5,991,886 -297,858, -669,378 -6,661,264 -298.527, -750,701 -7,411,965 -299,278, -773,597 -8,185,562 -300,052, -742,792 -8,928,354 -300, 795, -8,928,354 The following key wells in the Endicott Pool were proposed in 2016; 2016 Key Well Program 4-46 K3A, K3B 3-31 K1, K2A, K2B 1-39A K3A 1-27 K2A, K2B 1-55 K3C 1-65A K2B 2-64 K3C 2-62 K3A, K3B, K3C 4-20A K3B, K3C 3-09A K213 1-57 K3A, K3B, K3C 1-31 K2A 4-38 K1, K2A, K2B 1-17A K3A 4-06A K3C 3-07A K3A 2-28B K2A 2-58 K3C 1-33B K2A 2-04 K1, K2A 4-28 K3B, K3C Datum: -10,000 ssTVD Static bottomhole pressures collected in 2016 are summarized and submitted quarterly on the form 10-412 form below. Page 3 STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMSSION RESERVOIR PRESSURE REPORT , A..k U � D, S,p,4%. AIT "9�a 2: 3 k8 v1NSe?az'.x'. Ea�,+latm 4. Fe15 en4 Ril(.1'_ Ern+r4a19FAC nMRtd 6Y.m,-P ZC :570 .Us on -Y. 22 r`,*��' 1193&* i 4. YY:tY-�e acd #4x�me• f E Pfv t»rs0e+ {{( 51X7[F000WCOO:K NO B i '3 'YR See b'sMrG- ^.S ROLA-. Rad Cade sZ. Zone 13. ftftN a ;n1evffie 7.0- Batt �TVOSS t4. Fi.W T� 7&84¢9-.:. 9a Pt Ck- Tw* Hous E- Tiy W'e �^3aectlarrt tar Tr BM. Teats. L4 TGci 1kQa5E u" 7732;,223 TWO" IV= 2".. P2ms:±r Pn:swe is Gr s^a.'�ci�t. s+s `.rstlEti5 D 1-11 j M22221070030 O 220160 IVWMk 10,023-10,114 2111P201B 50,101 sax 195 &845 4.041 10.00'0 0.43 4.065 5002922C9?OOW 0 220150 Wishak 5.99.7-10,058 5832048 108.675 SBHP I 2Q9.3 9.,995 4.555 MWD 0.44 4,579 236A 3 50029228 UIOC O 220165 Sag RNW 9,434 -9,545' 512502016 4124 SSHP 165.8 9.377 i ;.264 S,74C 0.11 1,ZT7 4:55 50029219570000 O 220100 I K3A, K38 9.943'-10,228 5WW16 45.3 saw 214 9.945 3,248 10,.000 DA3 3911 i -33B i 50029225770200 O 220103 j K2A 16,01fi-10.0'9' B7,12Ct5 268.9 S64r 15A4 9,2215 3,982 10,000 A10 4,C5: 2104 50029275850CA0 C 220103 K1. K2A 10.167-10.187 &161A116 2426 &BHP 1302 10208 4,189 10.000 0.43 4.099 228 5902921,8150040 C 22010 K3B. K3C 9,834-10,199 8f68018 1S4.T SSW 216,3 &554 1.306 10,0M 0.12 2.68 54029218580000 O 220100 K38,K2C 10.029'-10,147- 87:2016 235.7 S&HP 206 tfk127 3,169 10,00 j 0.40 3,718 1-57 50029218730000 O 220100 K3AK38,K3G 9.875-10.263' S7t2016 236,6 &BHF 213.8 10.312 3.876 10,0'.x: 0.41 3.745 1-= 50329225770200 0 220100 K2A 10.075-1C OtS+ 8f82316 2.x.3 SSHP 1M.2 4,145 3.987 10,000 13.11 4.078 1.31 50029225820000 0 220100 K2A 9.88.5--, UW &'&2016 293.2 SBHP W-3 SAW 3,970 10,= 0.10 4.085 2-308 50029222280200 0 220170 Seg River S.771'-9.633' MW16 276.1 SWP 241.3 5.782 1.853 S'em 0.C5 1,854 4-10A 500292246401Ca O 220100 K28 9.9&1'-9.951 M2016 247.4 SBH? MM §.947 4.065 13.= I 0.43 4,088 331 513029228380000 I O 220100 K1,K2AK25! 9,780-1G,a95 W108G16 2632 ( SSHP 21St 9.950 41099 10,000 027 4,060 4-28 50029218700000 O 220100 138. 13G 9.&68'-'0.152' 8€1012018 303.5 SBHP 2121 S.9% 3.656 1CAM C,43 3,674 238 ? 50029220410000 0 220100 KSC SSM. -10,091' &+108016 296.4 SBHP I IN S,17F 2,421 1000 COS 2,473 2U 60029220840030 O 22Q750 Mshsak 9,92&-t4.013 8ff08018 306.6 SSHP 207,4 9,733 3.331 10.000 0.34 3,423 1-27 50029216930000 O ?20100 K26 We &11.2016 333,5 SSHP 2W-1 9571 4.083 11C,000 CAD 4.092 1-17A 50029221000140 O 220100 K3A 8,958-10 164' 8111!2016 328.3 S8HP 2IS-5 10,129 1.851 10,000 3.37 1.803 1.55 500292;7880000 0 220100 K3C 9,919-10,039 &118016 i 319.2 SSHP 2023 1C.CM 3.592 10.000 0.39 3.552 2-288 50029218470293 O 220100 K?A 13211'-10,118 8112WIS 344.3 SSHP 20&3 10.115. 4,15; 10.000 0.433 4,101 2-62 50029216480003 O 220100 iK30.Kse= 9,9C7-10, 14C 012x2016 3529 MP 201.1 9,463 4.046 I 10,000 0.13 4,10', 4S16A 50029217230100. O 2201CO KX 9SeC'-10.018 8413/X46 3729 S8FEP 247.3 9,.823 2.995 10,000 0.08 3.009 248 50029220320000 i O 220100 KLA, K3B 9.921'-1Q10S 80'13,12016 312.6 SBHP 193.3 40,/350 3.777 16,000 0.10 3.772 4.20A 500292164001001 0 2201CD K3B, K30 9,637-9.925 BIC2016 401.9 SSHP 273.2 9.94T 3.239 101000 0,43 3;317 4.35 50029224620000 O 220100 K1,K2AK2B 5,937-10,174 82'1412016 395.3 SBMP 214.9 9,.940 4,030 10=0 0.10 4,038 139A SCO2929&'rTGtCO O 22010C K3A 9.S9Y-9.583' &.442016 391.4 Saw 20.45 9,910 4,039 10,QQ0 L.44 4,Q78 2-466 W02921021C200 O 220100 M 9.%V-10138 871442016 388.6 SSW 200.1 9.902 2,&% 10,ci0 C.02 2,859 WA 51x29219'.10100 O 220100 K34 9.951'-10,652 8715"1!116 425.5 saw isai 10¢88 4,055 N3,000 C.43 4,016 3.09A 50029217MOC100 O 22010C KEB 9,612-5,984 8±1'SP2016 425.6 S619P i 2159 9,934 4.105 14.0004 0.43 4,133 3-29 54029221960000 O 220100 K3A 9,553 -SAW WISM016 421.6 SSHP 2125 9,897 3,753 10,004 0,43 3,797 327 50C292158600DO O 220100 3 K3A 9,86C-9,971' A15"2Q75 416.7 S614P 217.4 S,S49 4,151 10,0M I- 4.173 3-834 50029216680100 0 220100 { K2A 123 9.913'-9,590' &1602016 441.8 SSHP 204.4 9.944 4.M 10,000 0.44 4,4£5 3-21 53029217143000 0 223100 KSA 901--99K? 8'1501015 44Q2 SBHP 19&2 9,861 4.088 10,000 i 0.43 4.149 3.258 50029221254200 C 223100 K2A 10,157'-10;779' 8/16•201'0 413-3 ( &BHP 214,3 I 1,005 4,065 10,000 0.43 i 4,060 2.L ,4:t lass aG� aeras werege s astatance wY...T.:Re aa{Ccab4 1W. "atiaas .vie Y.s1-,2e&.. a orCm RpSrsp"€ and Gas Ca :aerrstlar: Camm:stiess. t'xTa`aY�"```s�"grsla"avue a-#orse�m is fvesE of k�aneegt 4 S.y:ltme �_Q A 7.s^x4 1:99+2 Cres Kxryrr Tdl- 041 Fkesmra-E: r mbar 9.24x5 Page 3 The following key wells in the Endicott Pool will have static bottomhole pressure measurements captured in 2017; 2017 Key Well Program 1-01 K2A, K2B 2-70 K3B, K3C 4-04A K3B, K3C 1-29 K2B 3-01 K2A 4-08 K2B, K3A 2-14 K2B 3-05 K3B 4-26 K3A 2-22 K3A, K3B, K3C 3-23 K2B, K3A, K3B 4-34 K3A 2-40 K3B, K3C 3-37 K3A 1-11 Ivishak 2-50 K3B, K3C 3-47 K3B, K3C 2-30B Sag River - Minke 2-60 K3C 3-49A K3B, K3C 2-56A Sag River - Eider Endicott Oil Pool Datum: -10,000 ssTVD Minke Tract Datum: -9,800 ssTVD Eider Oil Pool Datum: -9,700 ssTVD D. Summary and Analysis of Gas -Oil Contact or Gas Monitoring Surveillance Plan. The following table summarizes the results of the logs run in 2016 for gas monitoring. END 2016 GOC Mcmitor mg Program ALacs - LogTwe LV8M-crivt�= [ate Results Notes -],SSS !SDI w.„"�R :r .e��'Fei:-ry.?,3gig^�a �,r15,;+�tr16 Gat a_ 13AQ' X33 (A,9&TssV3!' well was logged in fluid 2-t's rrF'i ras satunffen log COUG7 -'-Z Terrp5gma x,114$`ZD15 well was logged in fluid A field wide current GOC is not likely to be identified as the Kekiktuk sands have several subzones that are vertically separated and have different permeability. In addition, faulting in the reservoir may lead to hydraulic isolation or partial pressure communication within a sub zone. Using only the 2016 RST log results and some production observations, the current GOC can be as deep as-10,077'ssTVD. F. The Following Year Gas -Oil Contact or Gas Monitoring Surveillance Plan. In 2017 we will run at least four cased hole pulsed neutron logs. Planned wells include 2-14, 3-23, 3-25B, and 4-50 production wells to monitor GOC. Additional candidates may be identified and logged to continue GOC surveillance of the Endicott Oil Pool. F. Results and Analysis of Production and Injection lot surveys, tracer surveys, observation well survevs and any other special monitoring There were no new production profiles were obtained in 2016. The concentration of surveillance work focused on obtaining static bottomhole pressure measurements during the 21 day full -facility turnaround (TAR). Sampling from the previous waterflood tracer program has been discontinued. No current tracer program is in place. G. Future Development Plans & Review of Annual Plan of Operations and Development In 2016, Hilcorp increased unit production through well intervention projects, and other optimization opportunities, that included the evaluation of shut-in wells for potential return to service. A full field study of the Duck Island Unit is ongoing. The re -mapping of all productive horizons, review of well histories, analyzed production and injection data, and past engineering, geological, and geophysical work will continue to be studied Some additional wellwork was initiated due to data provided by surveillance activities, summarized in above sections C & D. Page 4 Over the past year, the AOGCC has granted three administrative approvals of CO. 462 Rule 3 that regulates well spacing in the Endicott Oil Pool. The approvals for MPI 2-26, SDI 4-46, and SDI 4-10A have resulted in recent successes (documented below) and demonstrate the need for reduced well spacing less than 1,000 feet from existing production wells. Proiects completed during the 2016 calendar year: • MPI 2-26 (Prod) Perf add of UPSZ FV laminated pay, project was successful (+50bopd) (January 2016) • MPI 1-63 (Prod) Perf add of UPSZ FI laminated pay, project was unsuccessful (March 2016) • MPI 1-57 (Prod) Reperf S3A4 & perf add K3A2 near tar pay, project was unsuccessful (April 2016) • SDI 4-14A (Prod) Patch tubing, returned to production (RTP), avoided planned RWO (+60bopd) (April 2016) • Sag Delta North - Ivishak horizon mapped (May 2016) • MPI 2-46B (Prod) Perf add of UPSZ FIV/FV laminated pay, project was unsuccessful (May 2016) • SDI 3-09A (Prod) Gaslift redesign (May 2016) • SDI 3-21(Prod) Gaslift redesign (May 2016) • MPI 2-52 (Prod) RWO, tubing swap, & RTP well (+220bopd) (June 2016) • MPI 2-38 (Prod) RWO, tubing swap, & RTP well (+220bopd) (June 2016) • Performed 21 day full -facility turnaround (TAR) (July -August 2016) • Run several static BHP surveys to identify unhealthy water flood patterns during TAR (August 2016) • SDI 4-42 (Prod) Perf add of UPSZ FII near tar prior to WINJ Conversion, pre -produced (+50bopd) (Oct 2016) • SDI 4-02 (Prod) Perf add of UPSZ FIV traditional pay, project was successful (+65bopd) (October 2016) • S3A2 horizon re -mapped due to gas saturation log data & 4-10A perf results (October 2016) • SDI 4-10A (Prod) Perf add of S3A2 traditional pay, project was successful (+650bopd) (November 2016) • MPI 1-65A (Prod) Fished stuck SSSV with Coil and RTP, success (+150bopd) (December 2016) • SDI 3-41 (WIND) CTCO to improve injectivity into K2A (December 2016) • SDI 4-46 (Prod) Perf add of UPSZ FI laminated pay, project was unsuccessful (December 2016) Projects postponed during the 2016 calendar year: • Rig workovers delayed until 2017 due to rig availability. o MPI 2-50 (PROD) RWO -Endicott PA- Kekiktuk UPSZ o MPI 1-11 (WIND) RWO -Sag Delta North PA- Ivishak • SDI 4-42 (PROD) WINJ conversion delayed due to flow testing the UPSZ FII near tar perfs added in Oct 2016. o Well conversion project to be completed Q1 2017 In 2017, Hilcorp will pursue increased unit production through additional well intervention projects, any necessary infrastructure and facility repairs, and other optimization opportunities as they arise. To accomplish some of the planned projects listed below, a request was submitted in January 2017 to administratively amend CO 462 to allow for unlimited spacing at Endicott. Specifically the MPI 2-14 perf add and likely the 3-23A sidetrack projects will require this approval to proceed. Workover and drilling activities are tentatively planned at Endicott for Q4 2017 calendar year. This schedule is governed by the planned mobilization of a drilling/workover rig to the Endicott field in November 2017 and is subject to change. Projects planned for the 2017 calendar year: • Add Perfs in existing production wells o Add perf in bypassed or laminated pay in Endicott Oil Pool. Page 5 o SDI 3-25B (PROD) Perf K2A &S3A2 o Other opportunities under assessment o Identify additional oil pay with gas saturation logging • Perform WSO/GSO o SDI 3-29 (Prod) dump cement on existing plug to shut off K213 that was originally installed in 2015 o Identify excessive water or gas production with PPROF/RST logging o Perform water/gas shut of using wireline/coil. • Perform water/gas flood maintenance work o Run several static BHP surveys or IPROF logs to identify unhealthy water flood patterns o MPI 1-09A (GINJ) regain well integrity (TxIA communication) through non -rig wellwork. o SDI 4-42 (PROD) convert to injection to improve pattern support. o SDI 4-04A (PROD) convert to injection to improve pattern support to well MPI 4-18 (Prod). o MPI 5-03 (WIND) Coil tubing cleanout to improve injectivity in Ivishak - Sag Delta North Oil Pool o MPI 2-22 (WINJ) Perf UPSZ FV to support existing MPI 2-26 (Prod) o Other production well conversions to injection under assessment. o Reallocate water injection in existing injectors. • MPI 2-60 (PROD) Surface casing repair - Endicott Oil Pool - Kekiktuk UPSZ o Excavate, repair surface casing, and return to production. • MPI 2-14 (PROD) Surface casing repair - Endicott Oil Pool - Kekiktuk o Excavate, repair surface casing, add S3A3/S3A2 perforations, and return to production. • MPI 2-50 (PROD) RWO - Endicott Oil Pool - Kekiktuk UPSZ o Conversion to WINJ to support active MPI 2-58 (PROD) & MPI 2-46B (PROD) o Patch casing, replace tubing, and return to production. • MPI 1-29 (PROD) RWO - Endicott Oil Pool - Kekiktuk o Pull completion, patch liner - GSO, run completion, and return to production. • SDI 3-23A (Prod) Sidetrack -- Endicott Oil Pool - Kekiktuk S3A4/S3A3/S3A2/K2B o Sidetrack LTSI well to bypassed traditional oil pay targets. • MPI & SDI Sidetrack - possible additional sidetrack(s) opportunities will be evaluated, and possibly drilled. Hilcorp will continue to progress the full field study of the Duck Island Unit. This may include re -mapping potentially productive horizons, updating well histories, reviewing all production and injection data, material balance calculations, and reviewing results of recent well intervention projects. Hilcorp will also perform waterflood pattern optimization through streamline simulation techniques. Sincerely, Chris Kanyer Reservoir Engineer - Endicott Page 6