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Home My WebLink About204-228MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-105 KUPARUK RIV U WSAK 1H-105 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/22/2025 1H-105 50-029-20727-01-00 204-228-0 W SPT 3708 2042280 3000 1000 1000 1000 1000 180 200 200 200 REQVAR P Sully Sullivan 8/18/2025 Test to MAIP (3000psi) per AIO 2c.088 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1H-105 Inspection Date: Tubing OA Packer Depth 430 3310 3250 3245IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS251021135400 BBL Pumped:1.5 BBL Returned:1.3 Wednesday, October 22, 2025 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-105 KUPARUK RIV U WSAK 1H-105 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 1H-105 50-029-20727-01-00 204-228-0 W SPT 3708 2042280 3000 820 825 821 821 147 275 240 218 REQVAR P Brian Bixby 8/30/2023 MITIA as per AIO 2C.088 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1H-105 Inspection Date: Tubing OA Packer Depth 160 3310 3230 3220IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230830154556 BBL Pumped:1.7 BBL Returned:1.7 Tuesday, October 17, 2023 Page 1 of 1            CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1H-105 (PTD 204-228) Update 12/28/22 Date:Tuesday, January 10, 2023 9:00:27 AM Attachments:AnnComm Surveillance TIO for 1H-105.pdf MIT KRU 1H-105 diagnostic MITIA 11-30-22.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, December 28, 2022 9:26 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1H-105 (PTD 204-228) Update 12/28/22 Chris, KRU 1H-105 (PTD 204-228) After the previous report a passing MITIA to 3000 psi and passing pack off tests were completed. The IA pressure was charged to ~1500 psi and throughout the monitor period it remained stable and showed no signs of pressure loss. The plan is to manipulate the IA pressure and monitor the well for the previous observed IA pressure fall off for an additional 90 days. Any required paperwork for continued injection or corrective action will be submitted post the monitor period. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. 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VIEW SCHEMATIC wIAlaska ShcematlC9.0 111-105 Casing Strings 3a Deptn,rvDl w,n.en Cag Dea OD(In) IDig Top(nKR) Se, Delos IM1KDI INK gang Grade Top TM1reed WNIWre CONDUCTOR 161 15.06 34.0 108.0 62.50 H40 WELD 1H-105 SURFACEI i u j,41 9.791 33.0 2,443.0 2,223.11 45.50 K-55 BTC 1H-105 PRODUCTION 5.5'.3.5" 5112 4.95 31.1 9,038.0 4,297.3 15.50 L40 BTC 1H-105 coxoucroR'.xo- aRg Tubing Strings sMax Max NIPPLE', 513.5 Nominal SN1310h set.,oh rvog Ds ODIin) ID lin) Top IBKBg (flKBg gNmB) MIN) Mtle Top TM1,utl Wellbx TUBING 3112 2.99 29.1 8,112.5 3,]16.3 9.30 LA0 EUEBMABMO 111-105 SURFACE: MSD .44317 D Completion Details Top nVO) Top Incl Naminal PASLIFT, 21816 Top InKB) (pat (1) nem Des Com IS (in) We11Wre 29.1 HANGER GN GEN IV TUBING HANGER 3,0301H-105 513.5 NIPPLE CAMCO'DS'NIPPLE wMO GO PROFILE 2.875114105 8,107.3 3,688.1 6665 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 114105 8,154.7 3,708.4 63.85 LOCATOR BAKER NO GO LOCATOR 2.950 111-105 8,155.5 3,708.7 63.81 SEAL ASSY BAKER 80-00 GBH SEAL ASSEMBLY- STUNG INTO CASING 2.990 114105 3S5 PRODUCTION CASING SLEEVE, 8.107.3- .tmaOther OtherIn Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (TVD)Top (nlcB) ItMB) Top toN l°g Des Com Run DNe mgn) wenbore 8,565.0 3,935.8 48.38 RBP 2.725"'P ROP IGPP35217)wl Equalizing 82612019 0.0001K105 Valve (CPE035006). DAL T Max OD 2.725" LOCATOR; 8,150.] Liner Details To.Nomura „D Top lfl7' IflKB) Tap lnN l°g Ihm De¢ Com ling Wellbore 33.0 SURFACE 9.194 111-105 5EnLAsav:e,1115 34.0 CONDUCTOR 15.062 111-105 5,162.5 3,111.9 63.54 Seal more Receptacle 4.000 IM -105 Perforations & Slots Shot Dena RPERRa26s.L.A- Top pats) Es.OVD) (.h b Top(nNB) B. (MB)(flKB) IBKB) Un,R Ds a D. ) Types Com Walloons 8,268.0 8,278.0 3,762.4 3,767.6 WS D, 111-105 1/1112018 6.0 RPERF 2"POWERJET NOVA 111-105 CHARGES 8,313.0 8,333.0 3,785.9 3,796.7 WS D, 111-105 7/512017 6.0 WERE 2"POWERJET OMEGA 111-105 CHARGES IPERF; a 3,30-ASS3o 8,313.0 8,338.0 3,785.9 3,799.4 WS D, 111-105 1/1112018 6.0 RPERF 2"POWERJET NOVA 111-105 RPERF;a3ia.'SS.p� CHARGES ,PeRe.5333..URLC 8,333.0 8,358.0 3,796.7 3,810.4 WS D, 111-105 7/512017 6.0 WERE 2"POWERJET OMEGA 111-105 RPERI:5335aa.3u.e1sse; CHARGES 8,338.0 8,358.0 3,799.4 3,810.4 WS D, 111-105 1211012017 6.0 RPERF 2'.POWERJET NOVA 111-105 CHARGES IPERe.53aa.oa3ee.D` 8,368.0 8,398.0 3,815.9 3,832.8 WS D, 111-105 7IW2017 6.0 WERE 2"POWERJET OMEGA 1H-105 RPERF:8SPEon3ae.D- CHARGES 8,378.0 8,398.0 3,821.5 3,832.8 WS D, 111-105 1211012017 6.0 RPERF 2"POWERJET NOVA 111-105 HARGES 8,437.0 8,467.0 3,855.5 3,873.4 WS B. 111-105 7/42017 6.0 IPERF 2"POWERJET OMEGA 111-105 RPERP,5a3ZDSF28� CHARGES PERF;3a37.0-a4678` RPERF;aaPCoa,ffOS�Is- 8,437.0 8,44].0 3,855.5 3,861.4 WS B. 111-105 1/1012018 6.0 RPERF 2"POWERJET NOVA 1H-105 CHARGES ,PERC84770a.402.0 $447.0 8,467.0 3,861.4 3,873.4 WS B. 111-105 1211012017 6.0 RPERF 2"POWERJET NOVA 111-105 RPERF;e47o ,,KDUo CHARGES 8,477.0 8,492.0 3,679.5 3,888.8 WS B. 111-105 7/32017 6.0 WERE 2"POWERJET OMEGA 111-105 CHARGES 8,477.0 8,492.0 3,679.5 3,888.8 WS B. 111-105 12/912017 6.0 RPERF 2"POWERJET NOVA 111-105 RPERF; 85leoa,5ie8 CHARGES IPERF; a 5te00,541S 8,516.0 8,541.0 3,903.9 3,920.0 WS A4, 1H-105 W712017 6.0 WERE 2"POWERJET OMEGA 111-105 CHARGES 8,518.0 8,538.0 3,905.2 3,918.1 WS A4. 1 H-105 1/1012018 6.0 RPERF 2"POWERJET NOVA 111-105 CHARGES RaP, e.Ses.g 8,601.0 81631.0 31960.1 3,980.7 WS A3, 111-105 7/312017 6.0 WERE ERJET OMEGA 111-105 CHARGES RPERF;aact oa,611S� 8,601.0 81611.0 31960.1 3,966.9 WS A3, 1H-105 1/1012018 6.0 RPERF 2"POWERJET NOVA 1H-105 IPERF; 0ap1 Da.W10` CHARGES RPERF,aet,na.wt.p- 8,611.0 8,631.0 3,966.9 3,980.7 WS A3, 1H-105 1/912018 6.0 RPERF 2"POWERJET NOVA 111-105 CHARGES 8,669.5 8,699.5 4,007.8 4,029.3 WS A2, 1H-105 7tW2017 6.0 WERE 2"POWERJET OMEGA 111-105 IPERCVMg aLLvas CHARGES RPERr;8eeaza.WasL 8,669.5 8,699.5 4,007.8 4,029.3 WS A2, 1H-105 5/1312018 6.0 RPERF 2"POWERJET NOVA 111-105 CHARGES PRODUCTION,"1:aatBO 3xxpa 11W ConocoPhillips Alaska, Inc. KUP INJ WELLNAME 1H-105 Mandrel inserts AK All Wellbores Schem 3t Yi Port 1141055,bNJ]➢18256.CB PM Top TYNE LNCM1 Siie i(P Run N^ Top IXKB) IBKB) KB) Make MotlY OD link Sery Type Tyq Iln) (psi) Run Dafe Com Wellbre Vne®I wh—m (—IR 2,491.8 2,251.8 CAMCO KBG2-9 112 INJ MY 479 0.000 0.0 BID2016 1H-105 HANGER: 281 CONDUCTOR:3f.0 j II 0B 0 NIPPLE', 513.5 SURFACE: 33A -2M30 WB LIR; 2.1,N— 101BSLEEVE', SLEEVE 0,10].3 LOCATOR, R1507 SEAL AMY: 0, 1555 RPERF; 8268 8,M.C--- IPERF: 03130$3V 0 RPERF; 831308.330.0 IPERF: 5333.oa.350.0 RPERF: 833BP8,358.9� IPERF: 5303.OS.R0.0` RPERF: 53]3P0.380.D� RPERF:0J3]GB.M].0— IPERF,84PO. 0,48].0` RPERF; B M].08,48]0� IPERF: 5410-8...0 L— RPERF: e an o.e,aez.D RPERF;051008,Si80 IPERF:051908.SM 0� RBP', fl505.0 RPERF: 860108,8110 IPE RF: 080108.010` RPERF; 5811.N II— IPERF;08058.CRS5 "ERF.88058.6.5` PRODUCTION SS S 3t1. WBO Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2042280 Type Inj W Tubing 839 840 840 840 Type Test P Packer TVD 3708 BBL Pump 1.0 IA 195 3000 2965 2959 Interval O Test psi 1500 BBL Return OA 146 249 249 249 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Diagnostic MITIA Notes: 1H-105 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1H Pad Galle 11/30/22 Form 10-426 (Revised 01/2017)MIT KRU 1H-105 diagnostic MITIA 11-30-22 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC)To:AOGCC Records (CED sponsored)Subject:FW: KRU 1H-105 (PTD 204-228) Report of suspect IA pressure fall offDate:Tuesday, December 20, 2022 9:39:08 AMAttachments:AnnComm Surveillance TIO for 1H-105.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, November 29, 2022 8:38 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1H-105 (PTD 204-228) Report of suspect IA pressure fall off Chris, KRU 1H-105 (PTD 204-228) has exhibited an unexplained, slow IA pressure fall off. The IA pressure was charged, but slowly decreased subsequent the charge. DHD will be mobilized to perform initial testing to include an MITIA, pack off tests, and adjusting the IA pressure for a monitor period. Any required paperwork for continued injection or corrective will be submitted post diagnostics and the monitor period. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 1H-105 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASING1H-105 2022-09-23 183 308 125 IA1H-105 2022-09-29 212 350 138 IA1H-105 2022-11-16 238 261 23 IA Last Tag Annotation Depth (ftKB) End Date Last Mod By WellboreLast Tag: SLM 8,447.0 8/17/2016 pproven 1H-105Last Rev Reason Annotation End Date Last Mod By WellboreRev Reason: Set RBP 8/26/2019 famaj 1H-105Notes: General & SafetyEnd Date Annotation Wellbore5/27/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1H-105Casing StringsCsg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB)Set Depth (TVD) (ftKB)Wt/Len (lb/ft) Grade Top Thread WellboreCONDUCTOR 16 15.06 34.0 108.0 62.50 H-40 WELD 1H-105SURFACE 10 3/4 9.79 33.0 2,443.0 2,223.8 45.50 K-55 BTC 1H-105PRODUCTION 5.5"x3.5" 5 1/2 4.95 31.1 9,038.0 4,297.3 15.50 L-80 BTC 1H-105 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 3 1/2 2.99 29.1 8,172.5 3,716.3 9.30 L-80 EUE8rdABMO D 1H-105 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 29.1 HANGER CIW GEN IV TUBING HANGER 3.030 1H-105 513.5 NIPPLE CAMCO 'DS' NIPPLE w/NO GO PROFILE 2.875 1H-105 8,107.3 3,688.1 65.65 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 1H-105 8,154.7 3,708.4 63.85 LOCATOR BAKER NO GO LOCATOR 2.950 1H-105 8,155.5 3,708.7 63.81 SEAL ASSY BAKER 80-40 GBH SEAL ASSEMBLY - STUNG INTO CASING 3.5" PRODUCTION CASING 2.990 1H-105 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 8,565.0 3,935.8 48.38 RBP 2.725" P2P RBP (CPP35217) w/ Equalizing Valve (CPEQ35006). OAL 8' Max OD 2.725" 8/26/2019 0.000 1H-105 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 33.0 SURFACE 9.794 1H-105 34.0 CONDUCTOR 15.062 1H-105 8,162.5 3,711.9 63.54 Seal Bore Receptacle 4.000 1H-105 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 8,268.0 8,278.0 3,762.4 3,767.6 WS D, 1H-105 1/11/2018 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,313.0 8,333.0 3,785.9 3,796.7 WS D, 1H-105 7/5/2017 6.0 IPERF 2" POWERJET OMEGA CHARGES 1H-105 8,313.0 8,338.0 3,785.9 3,799.4 WS D, 1H-105 1/11/2018 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,333.0 8,358.0 3,796.7 3,810.4 WS D, 1H-105 7/5/2017 6.0 IPERF 2" POWERJET OMEGA CHARGES 1H-105 8,338.0 8,358.0 3,799.4 3,810.4 WS D, 1H-105 12/10/2017 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,368.0 8,398.0 3,815.9 3,832.8 WS D, 1H-105 7/4/2017 6.0 IPERF 2" POWERJET OMEGA CHARGES 1H-105 8,378.0 8,398.0 3,821.5 3,832.8 WS D, 1H-105 12/10/2017 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,437.0 8,467.0 3,855.5 3,873.4 WS B, 1H-105 7/4/2017 6.0 IPERF 2" POWERJET OMEGA CHARGES 1H-105 8,437.0 8,447.0 3,855.5 3,861.4 WS B, 1H-105 1/10/2018 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,447.0 8,467.0 3,861.4 3,873.4 WS B, 1H-105 12/10/2017 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,477.0 8,492.0 3,879.5 3,888.8 WS B, 1H-105 7/3/2017 6.0 IPERF 2" POWERJET OMEGA CHARGES 1H-105 8,477.0 8,492.0 3,879.5 3,888.8 WS B, 1H-105 12/9/2017 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,516.0 8,541.0 3,903.9 3,920.0 WS A4, 1H-105 6/27/2017 6.0 IPERF 2" POWERJET OMEGA CHARGES 1H-105 8,518.0 8,538.0 3,905.2 3,918.1 WS A4, 1H-105 1/10/2018 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,601.0 8,631.0 3,960.1 3,980.7 WS A3, 1H-105 7/3/2017 6.0 IPERF 2" POWERJET OMEGA CHARGES 1H-105 8,601.0 8,611.0 3,960.1 3,966.9 WS A3, 1H-105 1/10/2018 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,611.0 8,631.0 3,966.9 3,980.7 WS A3, 1H-105 1/9/2018 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 8,669.5 8,699.5 4,007.8 4,029.3 WS A2, 1H-105 7/2/2017 6.0 IPERF 2" POWERJET OMEGA CHARGES 1H-105 8,669.5 8,699.5 4,007.8 4,029.3 WS A2, 1H-105 5/13/2018 6.0 RPERF 2" POWERJET NOVA CHARGES 1H-105 CommentSSSV: NIPPLE 1H-105, 8/26/2019 2:56:06 PMVertical schematic (actual) PRODUCTION 5.5"x3.5"; 31.1-9,038.0 RPERF; 8,669.5-8,699.5 IPERF; 8,669.5-8,699.5 RPERF; 8,611.0-8,631.0 IPERF; 8,601.0-8,631.0 RPERF; 8,601.0-8,611.0 RBP; 8,565.0 IPERF; 8,516.0-8,541.0 RPERF; 8,518.0-8,538.0 RPERF; 8,477.0-8,492.0 IPERF; 8,477.0-8,492.0 RPERF; 8,447.0-8,467.0 IPERF; 8,437.0-8,467.0 RPERF; 8,437.0-8,447.0 RPERF; 8,378.0-8,398.0 IPERF; 8,368.0-8,398.0 RPERF; 8,338.0-8,358.0 IPERF; 8,333.0-8,358.0 RPERF; 8,313.0-8,338.0 IPERF; 8,313.0-8,333.0 RPERF; 8,268.0-8,278.0 SEAL ASSY; 8,155.5 LOCATOR; 8,154.7 SLEEVE; 8,107.3 GAS LIFT; 2,491.8 SURFACE; 33.0-2,443.0 NIPPLE; 513.5 CONDUCTOR; 34.0-108.0HANGER; 29.1KUP INJ KB-Grd (ft)37.78 Rig Release Date5/18/1982AnnotationLast WO:End DateH2S (ppm) Date...TDAct Btm (ftKB)8,755.0Well AttributesField NameKUPARUK RIVER UNIT Wellbore API/UWI500292072701 Wellbore StatusINJ Max Angle & MDIncl (°)79.21 MD (ftKB)7,595.96WELLNAME 1H-105AK All Wellbores Schem Mandrel InsertsStation No/S Top (ftKB)Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in)TRO Run (psi) Run Date Com Wellbore1 2,491.8 2,251.6 CAMCO KBG-2-9 1 1/2 INJ DMY ??? 0.000 0.0 8/17/2016 1H-105 1H-105, 8/26/2019 2:56:06 PMVertical schematic (actual) PRODUCTION 5.5"x3.5"; 31.1-9,038.0 RPERF; 8,669.5-8,699.5 IPERF; 8,669.5-8,699.5 RPERF; 8,611.0-8,631.0 IPERF; 8,601.0-8,631.0 RPERF; 8,601.0-8,611.0 RBP; 8,565.0 IPERF; 8,516.0-8,541.0 RPERF; 8,518.0-8,538.0 RPERF; 8,477.0-8,492.0 IPERF; 8,477.0-8,492.0 RPERF; 8,447.0-8,467.0 IPERF; 8,437.0-8,467.0 RPERF; 8,437.0-8,447.0 RPERF; 8,378.0-8,398.0 IPERF; 8,368.0-8,398.0 RPERF; 8,338.0-8,358.0 IPERF; 8,333.0-8,358.0 RPERF; 8,313.0-8,338.0 IPERF; 8,313.0-8,333.0 RPERF; 8,268.0-8,278.0 SEAL ASSY; 8,155.5 LOCATOR; 8,154.7 SLEEVE; 8,107.3 GAS LIFT; 2,491.8 SURFACE; 33.0-2,443.0 NIPPLE; 513.5 CONDUCTOR; 34.0-108.0HANGER; 29.1KUP INJ...WELLNAME 1H-105AK All Wellbores Schem MEMORANDUM TO: Jim Regg P.I. Supervisor ��(J�l Z- �L 1 FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 4, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IH -105 KUPARUK RIV U WSAK 1H-105 Sre: Inspector Reviewed By: P.I. Supry Vm- Comm Well Name KUPARUK RIV U WSAK 1H-105 API Well Number 50-029-20727-01-00 Inspector Name: Bob Noble Permit Number: 204-228-0 Inspection Date: 8/1/2021 Insp Num: mitRCN210802092720 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well1H-105 Type Inj W" TVD 3708 Tubing 1050 1050 1050 1050 - PTD2042280 Type Test SPT Test psi — 1500 - IA 345 1820 - - 1770 - 1760- - --E- BBL Pumped: 0.7 BBL Returned: 0.6 OA 380 380 - 380 380 - Interval4vRTST WIT P Notes: Wednesday, August 4, 2021 Page 1 of 1 Schlumberger -Private 20,2' 28 originated: 3 1 1 9 0 Schlumberger Delivered to: � �� 11 -Se 19 PTS - PRINT CENTER�� AOG« 115e 19-JWD1 6411 A Street ro ATTN: Natural Resources Technician II Anchorage, AK 99518 '✓ Alaska Oil & Gas Conservation Commision (907) 273-1700 main (907)273-4760 fax ` y 333 W. 7th Ave, Suite 100 ... Anchorage, AK 99501 Schlumberger -Private Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: y > AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision ! 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 TRANSMITTALDATE TRANSMITTAL& 204228 WELL NAME API 4 ORDERSERVICE # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED Prints CD's 1H-114 1 H•111 1H-105 1H-113 1H-116 3M-19 3G -07A 50-029-23584.00 50.029-23581-00 50-029.20727.01 50-029-23588-00 50-029.23594-00 --iO-0-29-21737-00 50-103-20127.01 EOSH-00071 EA18.00022 El 18.00075 E118-00076 E118-00077 E718-00078 E118-00079 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WL (PROF IPROF-WFL [PROF-WFL ]PROF-WFL IPROF-WFL Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15 -Jul -19 17 -Jul -19 19 -Jul -19 20 -Jul -19 21 -Jul -19 22 -Jul -19 23Ju1•19 1 1 1 1 1 1 1 3G-11 50-103-20133-00 E118-00081 KUPARUK RIVER WL IPROF FINAL FIELD 25 -Jul -19 1 3M-13 1B-16AL1 1A-17 1C-121 3N -14A 3G-08 50-029.21720-00 50.029-22457.60 50-029-22102-00 50-029-23015-00 50-029.21589-01 50-103-20128-00 E118.00084 EDEA -00009 E1'I&00085 E118-00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL WL WL WL Caliper PPROF LDL IPROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 28 -Jul -19 28-JuI-19 29Jul-19 1 -Aug -19 2 -Aug -19 3 -Aug -19 1 1 1 1 1 1 2N-317 50-103-20266-00 EOSH-00076 KUPARUK RIVER WL LDL FINAL FIELD 4 -Aug -19 1 AUG 0-6- 15 A Transmittal Receipt signature confirms that a package (box, X ime Sign toe Date return via courier tsign/scannd email a copyto Sc lu berger and CPAI. 'TSPrintCenter slberkam Conoco hill; envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. ISLB Auditor- ]"Lj SCANNED AUG 0 7 2019 Schlumberger -Private Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: n -� ji/ AOGCC . ATTN: Natural Resources Technician II )-- Alaska Oil & Gas Conservation Commision ' 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 2 4 23 3p 61 TRANSMrTTALDATE16-Apt-19 16Aprt 9 -IW 01 WELL NAME 2B-10 1H-108 API # 50-029.21084-00 50.029-23608-00 ORDERSERVICE # EOSH-00034 E540-00064 FIELD NAME KUPARUK RIVER KUPARUK RIVER DESCRIPTION DELIVERABLE WL WL DESCRIPTION [PROF IPROF DATA TYPE FINAL FIELD FINAL FIELD Color DATELOGGED Prints 26 -Mar -19 27 -Mar -19 CD's 1 1 1H-105 1J-156 1A -04A 50-029.20727-01 50-029-23311-00 50-029-20621.00 E540-00065 EAI8-00008 E540-00068 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL IPROF IPROF Caliper FINAL FIELD FINAL FIELD FINAL FIELD 28- Mar -19 29 -Mar -19 4 -Apr -19 1 1 1 31-1-18 50.103.20095-00 EBLV-00002 KUPARUK RIVER WL (PROF FINAL FIELD 6 -Apr -19 1 2K-26 50-103-20126-00 EBLN-00004 KUPARUK RIVER WL Caliper P FINAL FIELD 8-ppr.19 1 10-06 50-029-21224-00 EBSI-00001 KUPARUK RIVER WL PPROF FINAL FIELD 10 -Apr -19 1 n 8 Name return via courier or sign/scan and email a copy Date and CPA]. 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In c v +�+ N w E Z a.- to n') i.. 2 N N N M r 0 0 0 0 7 r r r a+ _ E a) F- 1'a = a to w N J (2' J Ur (� 2 U U 2 2 2 2 m m E Cu L CI C 4 o W N N N N CO M r r r N -� Z H Y 00 L ial n C a-' CO in O CH a ` R 3 CO a, rts a a a Q Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday,April 6, 2018 12:45 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 1H-105 (PTD 204-228) Update 4-6-18 Attachments: 1H-105 90 day TIO trend 4-6-18.JPG Chris, KRU West Sak water injector 1H-105 (PTD 204-228)was reported March 8, 2018 for suspect IA pressure decrease. Inspection found two surface needle valves with stem packing leaks in addition to a leak under the analog gauge threads. All the leaking equipment was tightened after which the IA maintained pressure throughout the monitor period. CPAI is returning this well to 'normal'status. Attached is a 90 day TIO. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 gills,�lE conocahlaps 5CIkt445) 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, March 8, 2018 4:50 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly on 1H-105S204228) 3-8-18 Attachments: 1H-105 schematic.pdf; 1H-105 90 day TIO 3-8-18.JPG Chris, West Sak water injector 1H-105 (PTD 204-228) is experiencing an unexplained IA pressure anomaly. The IA pressure has slowly bled off over the course of several weeks and is currently nearing the OA pressure around"165psi. The IA appears to be fluid packed based on the very responsive changes to injection rate swings. Therefore this could be a non- obvious thermal response and thus we will initially limit the diagnostics performed. We intend to monitor the well for a "week to observe where the IA pressure will want to naturally fall off,to help narrow down whether or not we are looking for some sort of IAxOA communication. We will then adjust pressures to establish appropriate differential pressures between the annuli and continue the monitor(for a total of 30 days). If during the monitor,communication continues to be suspected we will then perform MITs. A follow-up email will be provided at the conclusion of the monitor. Please let us know if you disagree with the path forward. Attached are the 90 day TIO plot and schematic. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 1 204228 jir WELL LOG 29 1 2 0 RECEIVED �. S TRANSMITTAL MAR 0 2 2010 PROACTIVE DiAgNosTic SERviCES, INC. AOGCC To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED 1) Injection Profile 26-Jan-18 1H-118 Color Log/CD 50-0239-23578-00 2) Injection Profile 27-Jan-18 1111::M. Color Log/CD 50-029-20727-01 Signed : C-----/r\A `13c\--9---- Date : 311 S liB Print Name: Y v \ ( JA '.. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\MastetTemplatenles\Templates\Distribution\TransmittalSheetsTonocoPhillips_Transmit.docx r i 0 rJ 1- C:( ��o CU UP r CC > m h • W v Y O 6 m < m 0 E p U N N > Q I Y 0 N co +- O v1 a) i Qry _ U ti a O O O (i N ? C m y., m •i +.+ 'O co O � a co c U N > 7 Q p Q 03 CO 03 CO 03 CO CO CO 03 N (1.)!I L a) 0 CO E -C -0 O rn JO 4 m 4 4O0 (O0 rs 14 CC ( D L 5- N c 41 - W N (,) e7 I,- O O 00 @ i L Z Q N N N N N M M U -0 r0 O +' Z v > D C) . ll . O OC +Oir. - +' co O I i . W W W W W W W W W (n a) 'O I"' LL LL LL LL LL LL LL LL LL +-' N a) N ') O Q J J J J J J J J J a jj > c (00 Q Q Q Q Q Q Q Q Q a 04- . 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The LPP was defeated on 12/12/2017 when the wellhead pressure had fallen below the LPP setpoint of 500 psig after the well was brought online following well-work. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. David Haakinson on behalf of Marina Krysinski / Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCANNED •26( 11-4 - 10-5 Prb Regg, James B (DOA) X42 zoo From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, December 12,2017 1:07 PM3 (abZ'J1 To: NSK West Sak Prod Engr; Regg,James B (DOA) ( `- � Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt;Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI well 1H-105 on 12/12/2017 Jim, The low pressure pilot (LPP) on well 1H-105 (PTD#204-228)was defeated today, 12/12/2017, after the well was returned to service after an extended shut-in period.The well is currently injecting at a wellhead pressure of 332 psi and a rate of 235 BWPD.The LPP and surface safety valves(SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Evan Reilly on behalf of Marina Krysinski/ Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCS i • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 03,2017 • TO: Jim Regg P.I.Supervisor ?elel 14014(i-i SUBJECT: Mechanical Integrity Tests ll CONOCOPHILLIPS ALASKA,INC. 1H-105 FROM: Brian Bixby KUPARUK RIV U WSAK 1H-105 Petroleum Inspector Src: Inspector Reviewed By: raj P.I.Supry �F-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1H-105 API Well Number 50-029-20727-01-00 Inspector Name: Brian Bixby Permit Number: 204-228-0 Inspection Date: 9/26/2017 Insp Num: mitBDB170926142847 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1H-105 Type Inj W TVD 3708 Tubing 960 960 - 960 ' 960 PTD 2042280 Type Test SPT Test psi 1500 IA 30 1800 1730 - 1730 BBL Pumped: I BBL Returned: 1 OA 200 200 200 - 200 Interval INITAL P/F P ✓ — — Notes: SCW ED 206 Tuesday,October 03,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,September 26,2017 Jim Regg P.I.Supervisor C�L eliz 9 l7 SUBJECT: Mechanical Integrity Tests [ I CONOCOPHILLIPS ALASKA,INC. 1H-105 FROM: Brian Bixby KUPARUK RIV U WSAK 1H-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry cF--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1H-105 API Well Number 50-029-20727-01-00 Inspector Name: Brian Bixby Permit Number: 204-228-0 Inspection Date: 9/26/2017 ." Insp Num: mitBDB170926142847 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1H-105 Type Inj W TVD 3745 - Tubing 960 960 960 _ 960 - PTD 2o422so Type Testl SPT Test psi 1500 ' IA 30 1800 , 1730 _ 1730 - BBL Pumped: I I 1BBL Returned: I - OA 200 - 200 200 - 200 -- - - --------- Interval INITAL / P/F P ✓ Notes: Tuesday,September 26,2017 Page 1 of 1 STATE OF ALASKA ' A KA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Appro��dto qrn Plug for Redrill CI .erforate New Pool CI Repair Well CI Re-enter Susp Well CItCA��4NNOil Sampling ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 204-228 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-20727-01 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1H-105 ADL 25639 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Unit/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,038 feet Plugs measured None feet true vertical 4,297 feet Junk measured None feet Effective Depth measured 8,755 feet Packer measured 0 feet true vertical 4,070 feet true vertical 0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 feet 16 " 108'MD 108 SURFACE 2,410 feet 10 3/4" 2,443'MD 2223S PRODUCTION PRODUCTION 9,007 feet 5 1/2 " 9,038'MD 6048 2 2010, Perforation Depth Measured depth 8313-8338, 8333-8358, 8368-8398,8437-8567, 8477-8492, 8516-8541, 8601-8631, 8669-8699 True Vertical Depth 3786-3799,3796-3810,3816-3832, 3855-3937, 3879-3888, 3904-3920,3960-3980,4007-4029 Tubing(size,grade,measured and true vertical depth) 3.5" L-80 8,172' MD. 3,716'TVD Packers and SSSV(type,measured and true vertical depth) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): JUL 2 5 2017 Treatment descriptions including volumes used and final pressure: N/A IkC)1CC 13. Representative Daily Average Production or Injection Data a✓V Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development El Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-197 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Senior Wells Engineer Authorized Signature: Xi" Phone: (907)265-6471 2. ` ,; '7/ Date: / 251.17 Form 10-404 Revised 4/2017 ��//,// �� if-a- to it 1 G jt RBDMS JUL LContact 7 2011 Submit Original Only • • 1H-105 DTTMSTA JOBTYP SUMMARYOPS 6/11/17 DRILLING MITIA TO 2500 PSI (PASS); MITT TO 2500 PSI (PASS). JOB COMPLETE. SUPPORT- CAPITAL 6/12/17 DRILLING SET 3" F-COLLAR STOP ©990' RKB; RECOVERED 2 SAMPLES OF DIESEL W/ SUPPORT- TWO HYDROSTATIC BAILERS @ 990' RKB; PULLED COLLAR STOP @ 990' CAPITAL RKB. JOB COMPLETE & READY FOR E-LINE (caliper). 6/17/17 DRILLING MIRU. RIH W/24 ARM CALIPER. ENCOUNTER BLOCKAGE AT 8451 FT RKB. SUPPORT- LOG CALIPER TO SURFACE FROM 8451 FT RKB. RDMO CAPITAL 6/21/17 DRILLING RIH WITH DOWN JETTING NOZZLE, DRY TAG AT 8451' RKB, WASH DOWN TO SUPPORT- 8512' RKB, UNABLE TO GET ANY DEEPER, RESTART IN AM WITH MOTOR AND CAPITAL MILL, JOB IN PROGRESS. 6/22/17 DRILLING RIH WITH WEATHERFORD MOTOR &2.75"JUNK MILL, DRY TAG SUPPORT- OBSRTUCTION AT 8508' RKB, MILL DOWN TO HARD STALL AREA AT 8655' CAPITAL RKB, AFTER 11 STALLS PULL BHA TO INSPECT MILL, FOUND METAL TO METAL MARKS ON OUTSIDE OF MILL AND A PIECE OF ALUMINUM STUCK IN THE WATER COURSE OF THE MILL(1.5"X2.5"), RETURN IN AM TO VENTURI, JOB IN PROGRESS. 6/23/17 DRILLING RIH WITH WEATHERFORD MOTOR&2.75"VENTURI, DRY TAG AT 8655' RKB, SUPPORT- VENTURI FOR 15 MINUTES AND POOH, STUCK AT 8294' RKB WHILE POOH, CAPITAL STUCK AT 8294' RKB WHILE POOH, RECOVERED A LARGE CHUNK OF RUBBER, SMALL ALUMINUM PEICES AND CEMENT, VENTURI RUN#2 RECOVERED WHAT APPEARS TO BE A CEMENT WIPER DART RUBBER WITH ALUMINUM STEM AND 1 GALLON OF CEMENT CHUNKS/SAND & DIRT, TAKE CEMNET/DIRT TO LAB FOR ANALYSIS, PERFORM PASSING MITT TO 2000 PSI, RETURN IN AM TO CONTINUE WITH VENTURI, JOB IN PROGRESS. 6/24/17 DRILLING RIH WITH WEATHERFORD MOTOR/VENTURI, RECOVERED SMALL RUBBER SUPPORT- PIECES AND 1/2 GALLON OF CEMENT CHUNKS, RIH WITH MOTOR &2.75" CAPITAL MILL, BEGIN MILLING AT 8655' RKB DOWN TO 8755' RKB, F/P TBG TO 3000' RKB, JOB IN PROGRESS. 6/25/17 DRILLING PERFORM PASSING MIT-T, RIH WITH SIDE JETTING NOZZLE, JET WASH TBG SUPPORT- FROM SURFACE TO 8755' RKB AT 2.5 BPM WITH MI DEEPCLEAN (290 BBLS), CAPITAL CHASE DEEPCLEAN WITH 290 BBLS OF 3% KCL/FRESH WATER 130 DEGREES, CHANGE OUT SIDE JET NOZZLE FOR A LARGE HOLE BALL DROP NOZZLE, RIH WHILE PUMPING N2 DOWN THE COIL AND EVACUATE ALL FLUID FROM 3 1/2"TBG, BEGIN REVERSE CIRCULATING N2 DOWN 3 1/2"TBG WHILE TAKING RETURNS UP THE COIL FROM 8745' RKB TO SURFACE AT 1000 SCFM N2 RATE, AT SURFACE BLED WHP TO ZERO BEFORE SHUTTING THE SWAB,READY FOR ELINE, JOB IN PROGRESS. (TOTAL NITROGEN PUMPED= 5200 GALLONS) 6/26/17 DRILLING PERFORM DUMMY GUN DRIFT RUN WITH WELLTEC TRACTOR ASSIST WITH SUPPORT- 30'X 2.635" DRIFT, TAG AT 6500' RKB AND HAVE TO PULL 2800LBS.SURFACE CAPITAL TENSION (CLOSE TO MSP)TO PULL FREE, POOH PERFORM DUMMY GUN DRIFT RUN WITH WELLTEC TRACTOR ASSIST WITH 30'X 2.15" DRIFT, TAG BTM AT 8751' RKB, LOG CORRELATION PASS UP TO 7900', POOH JOB IN PROGRESS 6/27/17 DRILLING FILL TUBING WITH 1500PSI OF N2, RIH WITH WELLTEC TRACTOR ASSIST SUPPORT- AND PERFORATE 25'X 2" GUN OVER INTERVAL 8516'-8541', CORRELATE TO CAPITAL SLB PERFORATION DEPTH CONTROL LOG DATED 26-JUNE-17, READY FOR FLUID VERIFICATION PRESENCE RUN • • • 6/28/17 DRILLING RIH WITH CCL/GR/PRESS/TEMP/GRADIO/DEFT/FBS WITH WELLTEC SUPPORT- TRACTOR ASSIT TO TD @ 8753' RKB, LOG UP @ 20FPM FROM 8753'-8270' CAPITAL RKB, FLUID LEVEL OBSERVED AT 8400' RKB, WATER FROM TD TO 8660', OIL FROM 8660'TO 8400' RKB, POOH AND LAY DOWN FOR NIGHT FOR HIGH WINDS (33MPH)AND CRANE OPERATOR DOES NOT HAVE ENOUGH HOURS TO MAKE 2ND RUN (NO RELIEF) 6/29/17 DRILLING RIH WITH SINGLE PHASE RESERVOIR SAMPLER X 2 WITH TRACTOR ASSIST SUPPORT- TO 8720' RKB, LOG PASS UP TO 8180' RKB, OIL/WATER INTERFACE FOUND @ CAPITAL 8652' RKB, FLUID LEVEL @ 8212' RKB, TRACTOR BACK DOWN TO 8600' RKB, PULL INTO POSITION FOR SAMPLES, LOWER SAMPLE ©8500' RKB/UPPER SAMPLE @ 8485.5' RKB, TEMP = 76.3 DEGF/PRESS = 1658 PSI @ SAMPLE DEPTH , SURFACE PRESS= 1450 PSI, WAIT FOR SAMPLES TO BE TAKEN AND POOH, BLEED DOWN WELL FROM 1435PSI TO 1010PSI WHILE SAMPLES EXTRACTED FROM SAMPLING TOOLS, LAY DOWN FOR NIGHT, SAMPLES TAKEN TO LAB 6/30/17 DRILLING RIH WITH SINGLE PHASE RESERVOIR SAMPLER X 2 WITH TRACTOR ASSIST SUPPORT- TO 8720' RKB, LOG PASS UP @ 20FPM AND PULL INTO POSITION FOR CAPITAL SAMPLES, LOWER SAMPLE @ 8500' RKB/UPPER SAMPLE @ 8485.5' RKB, TEMP = 76.2 DEGF/PRESS = 1458 PSI @ SAMPLE DEPTH , SURFACE PRESS = 1160 PSI, WAIT FOR SAMPLES TO BE TAKEN AND POOH, OIL/WATER INTERFACE OBSERVED @ 8638' RKB, FLUID LEVEL @ 6900' RKB, BLEED DOWN WELL FROM 1130 PSI TO 800 PSI WHILE SAMPLES EXTRACTED FROM SAMPLING TOOLS, LAY DOWN FOR NIGHT, SAMPLES TAKEN TO LAB, WELL READY FOR LRS TO PUMP DIESEL 7/1/17 DRILLING RIH WITH CBL WITH WELLTEC TRACTOR ASSIST TO 8720' RKB, LOG REPEAT SUPPORT- PASS FROM 8720'-8050' RKB, TRACTOR BACK TO 8720'AND LOG MAIN PASS CAPITAL FROM 8720'-7900' RKB, BLED N2 FROM TUBING UNTIL AT 0 PSI, FLUID LEVEL OBSERVED @ 2570' RKB, ESTIMATED TOP OF CEMENT= 8178' RKB 7/2/17 DRILLING RIH WITH 2"X 30' GUN WITH WELLTEC TRACTOR ASSIST, SHOOT GUN OVER SUPPORT- A2 INTERVAL 8669.5'-8699.5' RKB, CCL TO TS =6.1', CCL STOP DEPTH = CAPITAL 8663.4' RKB, GUN INFO: 2"x 30'/6 SPF/176 TOTAL/60 DEG/POWERJET OMEGA 2006/ENTRANCE HOLE = 0.22"/PENTRATION =21.8" 7/3/17 DRILLING RIH WITH 2"X 30' GUN WITH WELLTEC TRACTOR ASSIST, SHOOT GUN OVER SUPPORT- A3 INTERVAL 8601'-8631' RKB, CCL TO TS =6.1', CCL STOP DEPTH = 8594.9' CAPITAL RKB, GUN INFO: 2"x 30'/6 SPF/176 TOTAL/60 DEG/POWERJET OMEGA 2006/ENTRANCE HOLE = 0.22"/PENTRATION =21.8" RIH WITH 2"X 15' GUN WITH WELLTEC TRACTOR ASSIST, SHOOT GUN OVER B INTERVAL 8477'-8492' RKB, CCL TO TS= 10.0', CCL STOP DEPTH = 8467' RKB, GUN INFO: 2"x 15'/6 SPF/91 TOTAL/60 DEG/POWERJET OMEGA 2006/ENTRANCE HOLE= 0.22"/PENTRATION =21.8" 7/4/17 DRILLING JOB CONTINUED FROM 7/3/17. RIH W/2"X 30' POWERJET OMEGA. SHOOT SUPPORT- GUN OVER INTERVAL 8437'-8467' RKB, CCL TO TS =6.0', CCL STOP DEPTH = CAPITAL 8431' RKB, LOG CORRELATED TO SLB PERFORATION DPETH CONTROL LOG DATED 26-JUNE-2017. POOH. RIH W/2"X 30' POWERJET OMEGA. SHOOT GUN OVER INTERVAL 8368'-8398' RKB, CCL TO TS =6.0', CCL STOP DEPTH = 8362' RKB, LOG CORRELATED TO SLB PERFORATION DPETH CONTROL LOG DATED 26-JUNE-2017. POOH. RIG DOWN. ***JOB IN PROGRESS*** • . • 7/5/17 DRILLING JOB CONTINUED FROM 4-JULY-2017. GUN 7: RIH W/2"X25' POWERJET SUPPORT- OMEGA. PERFORATE INTERVAL 8333' -8358', CCL TO TOP SHOT=6', CCL CAPITAL STOP DEPTH = 8327'. LOG CORRELATED TO SLB PERFORATION DEPTH CONTROL LOG DATED 26-JUNE-2017. GUN 8: PERFORATE INTERVAL 8313' - 8338', CCL TO TOP SHOT= 5', CCL STOP DEPTH = 8308'. LOG CORRELATED TO SLB PERFORATION DEPTH CONTROL LOG DATED 26-JUNE-2017. RDMO. ***JOB COMPLETE*** KUP e 1H-105 `ConocoPhillips -. .#"`+` g Well Attrib Max An Ii.. _ D TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl I') MD(ftKB) Act Bye(ftKB) ' • Lono ,phdhps 500292072701 KUPARUK RIVER UNIT INJ 79.21 7,595.96 8,755.0 ..- Comment H25(ppm) Date Annotation End Date KB-Grd(B) -Rig Release Date 1H-105,7/25/20179.08.42AM__. SSSV:NIPPLE Last WO: 37.78 5/18/1982 Vernal cchemabc(ectuafl 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,447.0 8/17/2016 Rev Reason:PERFS,UPDATED PBTD(PLUG pproven 7/24/2017 HANGER,29.1 1a,)11 BACK TOTAL DEPTH) I!JI Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ", ''i CONDUCTOR 16 15.062 34.0 108.0 108.0 62.50 H-40 WELD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade 'Top Thread 'i SURFACE 103/4 9.794 33.0 2,443.0 2223.5 45.50 K-55 BTC f Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 7 -um PRODUCTION 5.5"x3.5" 51/2 4.950 31.1 9,038.0 15.50 L-80 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 29.1 8,172.5 3,716.0 9.30 L-80 EUE8rdABMOD Completion Details r-, Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) CONDUCTOR;34.x1080 ';': ) 29.1 29.1 0.00 HANGER CIW GEN IV TUBING HANGER 3.030 513.5 513.5 0.33 NIPPLE CAMCO'DS'NIPPLE w/NO GO PROFILE 2.875 I!'' 8,107.3 3,687.8 65.65 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 NIPPLE;513.5 t 8,154.7 3,708.1 63.85 LOCATOR BAKER NO GO LOCATOR 2.950 • 8,155.5 3,708.4 63.81 SEAL ASSY BAKER 80-40 GBH SEAL ASSEMBLY-STUNG INTO 2.990 SURFACE;33.0-2,443.0 CASING 3.5"PRODUCTION CASING Perforations&Slots Shot Dens GAS LIFT,2,491.8 Top(ND) etm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (like) Zone Date ft) Type Com 8,313.0 8,338.0 3,785.6 3,799.1 WS D,1H- 7/5/2017 APERF 105 8,333.0 8,358.0 3,796.4 3,810.1 WS D,1H- 7/5/2017 APERF • 105 A° 8,368.0 8,398.0 3,815.6 3,832.5 WS D,1H- 7/4/2017 APERF 105 8,437.0 8,567.0 3,855.2 3,936.9 WS B,1H- 7/4/2017 APERF 105 SLEEVE;8,107.3 6,477.0 8,492.0 3,879.2 3,888.5 WS B,1H- 7/3/2017 APERF 105 8,516.0 8,541.0 3,903.6 3,919.7 WS A4,1H- 6/27/2017 APERF • 105 8,601.0 8,631.0 3,959.8 3,980.4 WS A3,1H- 7/3/2017 APERF 105 8,669.5 8,699.5 4,007.5 4,029.0 WS A2,1H- 7/2/2017 APERF 105 LOCATOR;8,154.71111 Mandrel Inserts jS St ad ar' on Top(ND) Valve Latch Port Size TRO Run is NTop(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Corn SEAL ASSY;8,155.5 + ,1 2,491.8 2,251.3 CAMCO KBG-2- 11/2 INJ DMY '??? 0.000' 0.0 8/17/2016 ' 11 9 1 lit Notes:General&Safety End Date Annotation 12/18/2004 NOTE:1982 WELL SUSPENDED,RE-ENTERED 2004;1H-05 RENAMED"1H-105" 5/27/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 --44111 APERF;8,313.0-8,338.0--.1 --sal APERF;8,333.0-8,358.0-+71 i APERF;8,368.0-8,398.0 -ems • APERF;8,477.0-8,492.0-. so -,�, APERF;8,437.0-8,587.0-.. ... APERF;8,516.0-8,541.0-mss-es• -.II APERF;8,601.0-8,631.0 APERF,8,669.5-8,699.5-- PRODUCTION 5.513.5';31.1- 9,038.0 N • 0 N T • w° ¢/ CI _c a C� 0o01111 v s o O Y 07 U' NZ v L + Q y O C a u e-. > c co + O v L 0o Qprg ua: ac c +� o NIII a y ra •c _ m o a w„ r N- N- N- N- N- N- r- r- N- N- N- N- r- v a 5 m OU J 7 7 7 7 7 O O 7 3 7 7 7 -o +-' N c „N., H LO c.._ O 0) O Lf) co O O ,- N to C Ip U a) PO (./1 Z ...4- Q N N N N M u C .1-, O u a -o a) M Q \ c0 o0 115 ONN N vteN 00000000000000 c ,_ U.' -1 J J J J J J J J J J J OD — oOaW W W W W W W W W W W W W W U a>I- LL LL Y. U. U. U. LL U. IL U. 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AUG 4 7 2.017, SCAHNE® Tyson Wiese Get Outlook for iOS From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent:Saturday,July 1,2017 7:43 PM Subject: Re: [EXTERNAL] 1H-105 Cement Bond Log To:Wiese,Tyson M<tvson.m.wiese@conocophillips.com> Tyson, Approval is granted to proceed with perforating based on CBL provided. Thanx, Victoria Sent from my iPhone On Jul 1,2017,at 7:17 PM,Wiese,Tyson M<Tyson.M.Wiese@conocophiliips.com>wrote: Victoria, Attached is the 1H-105 CBL Field Print,showing good cement across the Liner Top/Seal Assembly area, as well as cement coverage across the zones of interest. Top of Cement is estimated to be at 8,178' RKB. The attached email contains additional CBL interpretation comments from Schlumberger. We are setup to continue perforating tomorrow, pending AOGCC review and approval to proceed. Thanks, Tyson Wiese Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)-659-7199 Cell Phone (907)-943-0301 1 • S 41WELLS TEAM From: NSK E-line and DSL Field Supv Sent:Saturday,July 01,2017 7:07 PM To:Wiese,Tyson M<Tyson.M.Wiese@conocophillips.com> Subject: FW: [EXTERNAL] 1H-105 Cement Bond Log From:Stephen Miles [mailto:SMiles2@slb.com] Sent:Saturday,July 01,2017 6:14 PM To: NSK E-line and DSL Field Supv<n2540@conocophillips.com> Subject: [EXTERNAL] 1H-105 Cement Bond Log Tyson, Please see the attached CBL for 1H-105. Estimated top of cement is 8178' RKB. Stephen Miles General Field Specialist Prudhoe Bay,Alaska (832) 580-3952 <CPAI_1H-105_SCMT_1July17_FieldPrint.Pdf> <mime-attachment> <1H-105.pdf> 2 S Loepp, Victoria T (DOA) From: Peirce,John W <John.W.Peirce@conocophillips.com> Sent: Thursday,June 29,2017 8:58 AM To: Loepp,Victoria T(DOA) Cc: NSK E-line and DSL Field Supv;Wiese,Tyson M Subject: 1H-105 Update regarding the 1H-105 CBL Follow Up Flag: Follow up Flag Status: Flagged Victoria, Yesterday we logged 1H-105 after perfing 25'of A4 sand. We verified presence of -260'of inflowed oil column per the density log. A4 oil sampling was put on hold due to high winds that developed late in the day,so we plan to gather oil samples today if weather permits. We may log a 1H-105 CBL tomorrow if can we complete sampling today. At the earliest,a CBL may become available late Friday. Thus, I passed your contact info to our E-line Well Supervisor,Tyson Wiese,who is currently supervising E- line work at 1H-105. Tyson will be forwarding a CBL log to you as soon as it becomes available. Tyson is cc'd on this email at his functional and personal emails. Tyson can also be reached at(907)-943-0301 cell,or(907)-659-7199 office. Tyson will contact you by phone(242-9156 cell)to notify you that he will be sending you the CBL with COP's initial interpretation of the CBL data. I'll be out of office during 6/30-7/4, but I am always available to assist at any time if needed. You and Tyson can reach me at(907)-240-5533 cell. Thanks, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From:Peirce,John W Sent:Wednesday,June 28,2017 11:03 AM To:'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL] KRU 1H-105(PTD 204-228,Sundry 317-197)CBL Victoria, Thanks for the clarification that AOGCC must review the 1H-105 CBL before we perforate additional zones. We will plan remaining work on 1H-105 as you have requested. Regards, John Peirce Sr Wells Engr 1 • • CPAI Drilling&Wells (907)-265-6471 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,June 28,2017 9:31 AM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL] KRU 1H-105(PTD 204-228,Sundry 317-197)CBL John, The AOGCC will be available to review the CBL as soon as it is available. Review of the CBL by the AOGCC is necessary before additional perforating takes place. Please provide the CBL as well as CPAI's interpretation as soon as it becomes available. The CBL and interpretation may be emailed to me after hours if necessary and I will take the time to review. Just give me a heads up when it is coming. My cell phone is 242-9156. Please provide a wellbore schematic showing the current status as well as the various sand depths. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp analaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Peirce,John W[mailto:John.W.Peirce@conocophillips.com] Sent:Wednesday,June 28,2017 9:17 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:Question Re: 1H-105 Sundry Approval 317-197 Victoria, On 1H-105 we shot 25'of A4 sand yesterday as planned. Today we will be logging to identify presence of inflowed fluid column in the well to sample A4 fluid. If we don't have a fluid column yet in the well,we will bleeding off the 1460 psi Nitrogen pressure currently on the well in 100 psi increments to try to initiate inflow. Hopefully we get a fluid column to sample A4 oil today. CBL logging will be performed after we get A4 oil samples,so a CBL could start as early as tomorrow. Our plan is to evaluate the CBL soon as we have the data,then decide to perf other West Sak zones(or not)depending on assessed quality of the primary cement job behind 3.5" liner. If we verify that the cement job looks good,then we will proceed to perf the other zones. If the cement job looks questionable,we will take a time out to have AOGCC assess the CBL to determine if it looks good enough to enable putting the well on injection service. 2 • Does AOGCC need to review the CBL before we can perf the other zones that we plan to perforate? We would like to proceed ASAP perfing the other zones provided ConocoPhillips staff are comfortable that we have a good primary cement job which would ultimately be acceptable to AOGCC to place 1H-105 on injection. This way we don't have lots of crew and equipment on Standby waiting for an AOGCC verdict on the CBL in order to continue perforating other zones. In proceeding this way,we would be perfing zones before a final verdict by AOGCC regarding the CBL,so we realize that permission to put the well on injection service would still be at stake pending AOGCC review of the CBL. Is this plan forward acceptable to AOGCC? Regards, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,June 26,2017 6:52 PM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL] Re:Question Re: 1H-105 Sundry Approval 317-197 John, Approval is granted to proceed as outlined below. Thanx, Victoria Sent from my iPhone On Jun 26,2017,at 5:35 PM, Peirce,John W<John.W.Peirce@conocophillips.com>wrote: Victoria, Thanks for calling me to discuss work in progress on 1H-105. As per our conversation,we have agreed that CPAI can proceed to perforate the West Sak A4 sand and inflow A4 oil into the 3.5" liner. CPAI will then proceed to obtain A4 oil samples for Geochemical analysis. After this sampling work is complete, we will again have fluid present in 3.5" liner which then enables us to perform a CBL. We will proceed to execute the CBL of the 3.5" liner from current PBTD at'"8755' RKB up to the Seal Assembly at 8155' RKB to verify quality of the cement job behind pipe before shooting any other perforation intervals in the liner as proposed per Sundry Approval#317-197. Would you concur that this is an accurate summary of what we have agreed to regarding our plan forward for 1H-105 well work? John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Peirce,John W 3 • Sent: Monday,June 26,2017 3:01 PM To: Loepp,Victoria T(DOA)(victoria.loepp@alaska.gov)<victoria.loepp@alaska.gov> Subject:Question Re: 1H-105 Sundry Approval 317-197 Victoria, We are about to start executing perforating in 1H-105 but noticed that we do not have a CBL yet in the well. This well is scheduled for future injection into West Sak D B and A sand perfs per the approval# 317-197. We have milled out cement from 3.5" liner to 8755' RKB completed day before yesterday, and yesterday we blew down the well with Nitrogen. We have a seal assembly at 8155' RKB(3708'ND),so we can log a CBL from"`8755' RKB up to this depth, but then the Liner crosses over to 5.5"OD liner above 8155' RKB,so we would have 3.5"tubing inside 5.5" Liner above 8155' RKB and we can't log a CBL through 2 strings of pipe. My question is can we perforate the West Sak D sand as planned that would be our uppermost perf interval with a upper perf depth of 8313' RKB? That pert depth is only 158'from the seal assembly. How much total footage of good cement do we have to have per regulations above the uppermost perf zone? We do not want to perforate zones that may not have enough verifiable cement footage above that may negate the well from being put into service as a WINJ well. Our current plan was to start perforating beginning with the West Sak A4 at 8518—8538' RKB as early as tomorrow. Regards, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office (907)-240-5533 cell 4 • Loepp, Victoria T (DOA) From: Peirce,John W <John.W.Peirce@conocophillips.com> Sent: Wednesday,June 28, 2017 11:03 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL] KRU 1H-105 (PTD 204-228, Sundry 317-197)CBL Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the clarification that AOGCC must review the 1H-105 CBL before we perforate additional zones. We will plan remaining work on 1H-105 as you have requested. Regards, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,June 28,2017 9:31 AM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL] KRU 1H-105 (PTD 204-228,Sundry 317-197)CBL John, The AOGCC will be available to review the CBL as soon as it is available. Review of the CBL by the AOGCC is necessary before additional perforating takes place. Please provide the CBL as well as CPAI's interpretation as soon as it becomes available. The CBL and interpretation may be emailed to me after hours if necessary and I will take the time to review. Just give me a heads up when it is coming. My cell phone is 242-9156. Please provide a wellbore schematic showing the current status as well as the various sand depths. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a�alaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loer>p@alaska.gov 1 • • From: Peirce,John W [mailto:John.W.Peirce@conocophillips.com] Sent:Wednesday,June 28,2017 9:17 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:Question Re: 1H-105 Sundry Approval 317-197 Victoria, On 1H-105 we shot 25'of A4 sand yesterday as planned. Today we will be logging to identify presence of inflowed fluid column in the well to sample A4 fluid. If we don't have a fluid column yet in the well,we will bleeding off the 1460 psi Nitrogen pressure currently on the well in 100 psi increments to try to initiate inflow. Hopefully we get a fluid column to sample A4 oil today. CBL logging will be performed after we get A4 oil samples,so a CBL could start as early as tomorrow. Our plan is to evaluate the CBL soon as we have the data,then decide to perf other West Sak zones(or not)depending on assessed quality of the primary cement job behind 3.5" liner. If we verify that the cement job looks good,then we will proceed to perf the other zones. If the cement job looks questionable,we will take a time out to have AOGCC assess the CBL to determine if it looks good enough to enable putting the well on injection service. Does AOGCC need to review the CBL before we can perf the other zones that we plan to perforate? We would like to proceed ASAP perfing the other zones provided ConocoPhillips staff are comfortable that we have a good primary cement job which would ultimately be acceptable to AOGCC to place 1H-105 on injection. This way we don't have lots of crew and equipment on Standby waiting for an AOGCC verdict on the CBL in order to continue perforating other zones. In proceeding this way,we would be perfing zones before a final verdict by AOGCC regarding the CBL, so we realize that permission to put the well on injection service would still be at stake pending AOGCC review of the CBL. Is this plan forward acceptable to AOGCC? Regards, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,June 26,2017 6:52 PM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL] Re:Question Re: 1H-105 Sundry Approval 317-197 John, Approval is granted to proceed as outlined below. Thanx, Victoria Sent from my iPhone On Jun 26,2017,at 5:35 PM, Peirce,John W<John.W.Peirce@conocophillips.com>wrote: 2 • Victoria, Thanks for calling me to discuss work in progress on 1H-105. As per our conversation,we have agreed that CPAI can proceed to perforate the West Sak A4 sand and inflow A4 oil into the 3.5" liner. CPAI will then proceed to obtain A4 oil samples for Geochemical analysis. After this sampling work is complete, we will again have fluid present in 3.5" liner which then enables us to perform a CBL. We will proceed to execute the CBL of the 3.5" liner from current PBTD at 8755' RKB up to the Seal Assembly at 8155' RKB to verify quality of the cement job behind pipe before shooting any other perforation intervals in the liner as proposed per Sundry Approval#317-197. Would you concur that this is an accurate summary of what we have agreed to regarding our plan forward for 1H-105 well work? John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Peirce,John W Sent: Monday,June 26,2017 3:01 PM To: Loepp,Victoria T(DOA)(victoria.loepp@alaska.gov)<victoria.loepp@alaska.gov> Subject:Question Re: 1H-105 Sundry Approval 317-197 Victoria, We are about to start executing perforating in 1H-105 but noticed that we do not have a CBL yet in the well. This well is scheduled for future injection into West Sak D B and A sand perfs per the approval# 317-197. We have milled out cement from 3.5" liner to 8755' RKB completed day before yesterday, and yesterday we blew down the well with Nitrogen. We have a seal assembly at 8155' RKB(3708'ND),so we can log a CBL from "8755' RKB up to this depth, but then the Liner crosses over to 5.5"OD liner above 8155' RKB,so we would have 3.5"tubing inside 5.5" Liner above 8155' RKB and we can't log a CBL through 2 strings of pipe. My question is can we perforate the West Sak D sand as planned that would be our uppermost perf interval with a upper perf depth of 8313' RKB? That perf depth is only 158'from the seal assembly. How much total footage of good cement do we have to have per regulations above the uppermost perf zone? We do not want to perforate zones that may not have enough verifiable cement footage above that may negate the well from being put into service as a WINJ well. Our current plan was to start perforating beginning with the West Sak A4 at 8518—8538' RKB as early as tomorrow. Regards, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office (907)-240-5533 cell 3 • • Loepp, Victoria T (DOA) From: Peirce,John W <John.W.Peirce@conocophillips.com> Sent: Wednesday,June 28, 2017 9:17 AM To: Loepp,Victoria T(DOA) Subject: Question Re: 1H-105 Sundry Approval 317-197 Follow Up Flag: Follow up Flag Status: Flagged Victoria, On 1H-105 we shot 25'of A4 sand yesterday as planned. Today we will be logging to identify presence of inflowed fluid column in the well to sample A4 fluid. If we don't have a fluid column yet in the well,we will bleeding off the 1460 psi Nitrogen pressure currently on the well in 100 psi increments to try to initiate inflow. Hopefully we get a fluid column to sample A4 oil today. CBL logging will be performed after we get A4 oil samples,so a CBL could start as early as tomorrow. Our plan is to evaluate the CBL soon as we have the data,then decide to perf other West Sak zones(or not)depending on assessed quality of the primary cement job behind 3.5" liner. If we verify that the cement job looks good,then we will proceed to perf the other zones. If the cement job looks questionable,we will take a time out to have AOGCC assess the CBL to determine if it looks good enough to enable putting the well on injection service. Does AOGCC need to review the CBL before we can perf the other zones that we plan to perforate? We would like to proceed ASAP perfing the other zones provided ConocoPhillips staff are comfortable that we have a good primary cement job which would ultimately be acceptable to AOGCC to place 1H-105 on injection. This way we don't have lots of crew and equipment on Standby waiting for an AOGCC verdict on the CBL in order to continue perforating other zones. In proceeding this way,we would be perfing zones before a final verdict by AOGCC regarding the CBL,so we realize that permission to put the well on injection service would still be at stake pending AOGCC review of the CBL. Is this plan forward acceptable to AOGCC? Regards, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,June 26,2017 6:52 PM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL] Re:Question Re: 1H-105 Sundry Approval 317-197 John, Approval is granted to proceed as outlined below. Thanx, 1 • • Victoria Sent from my iPhone On Jun 26,2017,at 5:35 PM, Peirce,John W<John.W.Peirce@conocophillips.com>wrote: Victoria, Thanks for calling me to discuss work in progress on 1H-105. As per our conversation,we have agreed that CPAI can proceed to perforate the West Sak A4 sand and inflow A4 oil into the 3.5" liner. CPAI will then proceed to obtain A4 oil samples for Geochemical analysis. After this sampling work is complete, we will again have fluid present in 3.5" liner which then enables us to perform a CBL. We will proceed to execute the CBL of the 3.5" liner from current PBTD at—8755'RKB up to the Seal Assembly at 8155' RKB to verify quality of the cement job behind pipe before shooting any other perforation intervals in the liner as proposed per Sundry Approval#317-197. Would you concur that this is an accurate summary of what we have agreed to regarding our plan forward for 1H-105 well work? John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Peirce,John W Sent: Monday,June 26,2017 3:01 PM To:Loepp,Victoria T(DOA)(victoria.loepp@alaska.gov)<victoria.loepp@alaska.gov> Subject:Question Re: 1H-105 Sundry Approval 317-197 Victoria, We are about to start executing perforating in 1H-105 but noticed that we do not have a CBL yet in the well. This well is scheduled for future injection into West Sak D B and A sand perfs per the approval# 317-197. We have milled out cement from 3.5" liner to 8755' RKB completed day before yesterday, and yesterday we blew down the well with Nitrogen. We have a seal assembly at 8155' RKB(3708'ND),so we can log a CBL from 8755' RKB up to this depth, but then the Liner crosses over to 5.5"OD liner above 8155' RKB, so we would have 3.5"tubing inside 5.5" Liner above 8155' RKB and we can't log a CBL through 2 strings of pipe. My question is can we perforate the West Sak D sand as planned that would be our uppermost perf interval with a upper perf depth of 8313' RKB? That perf depth is only 158'from the seal assembly. How much total footage of good cement do we have to have per regulations above the uppermost perf zone? We do not want to perforate zones that may not have enough verifiable cement footage above that may negate the well from being put into service as a WINJ well. Our current plan was to start perforating beginning with the West Sak A4 at 8518—8538' RKB as early as tomorrow. 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O 0 O O 0 O O O O O VIC lD O O O O O O O O O O O a0 ri CO N In 'Cr N Q ,- 0 r0 M N ▪ 0 0 M Yt 7 , N N N N CO N �' (0 0 0O U M 0 0 0 M N N 0 N N d N N N N N N N N N N N n < O T M M O) O) O) O) M O O a) ON N 0 0 N N N N 0 N ( Q1 O 0e- ' 999999 O O O N (� O • i O O O O O O O O O O OF' O a) c c N I) In If) In N LC) In In 10 N Q u w co C IO a) ▪ W rov > Y L".. w Y c c co , c w 3 O_ yE Z +:, m nt Z O e-- M M r I- 1- N N C a+ E a) F- = CE ° ^ -' LL O Y = W 0 N 14- re F Z d ro C arm D. 4 O N w M N N I`') M N h .G V in '�-I c n rca d raa OCI3 a3Q !' H a aQ • )'�V OF T1t� • • yam\11/7,��A THE STATE Alaska Oil and Gas ti -s • of Conservation Commission _ • ___= ALASKA 5 }� __ 333 West Seventh Avenue 415:1- — Anchorage, Alaska 99501-3572 � GOVERNOR BILL WALKER g Q '" P Main: 907.279.1433 F ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce ni Senior Wells Engineer s(oto � ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-105 Permit to Drill Number: 204-228 Sundry Number: 317-197 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster ,t,� Chair DATED this �7'day of May, 2017. RBDMS VV MAY 1 9 2017 RECEIVE® • • MAY 1 1 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONAOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate I] Other Stimulate ❑ Pull Tubing ❑ Chane Approved Program uvti V-71/42 W� Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ ther: A4 Oil Samplin0 r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 204-228 3.Address: Stratigraphic ❑ Service D . 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-20727-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A " KRU 1H-105 Will planned perforations require a spacing exception? Yes ❑ No CI 7 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25639 Kuparuk River Unit/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TV,D: MPSP(psi): Plugs(MD): Junk(MD): 9,038' 4,297' vy l g 44,0 I �^rl none none Casing Length Size MD ND Burst Collapse Structural Conductor 74' 16" 108' 108' Surface 2,410' 11" 2,443' 2,223' Intermediate Production 9,007' 6" 9,038' 6,048' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None 3.500" L-80 8,155' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 12.Attachments: Proposal Summary U Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 r 14.Estimated Date for 6/5/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ U' WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Senior Wells Engineer Contact Email: John.W.Peirce@cop.com rte' � ,/ iAuthorized Signature: !v • -- Date: —J �.f.1I COMMISSION USE ONLY Contact Phone: (907)265-6471 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311- \ `1 I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test I Location Clearance ❑ IAS S ((Z L Other: Post Initial Injection MIT Req'd? Yes /No ❑ !r Y 1 9 2017 Spacing Exception Required? Yes o No Subsequent Form Required: /0 — 4O1— RBDMS i/ APPROVED BY Approved by: /0 n% COMMISSIONER THE COMMISSION Date: 5_ r 7 _ / 7 ��a sl -. sib RJrQ1LI � 1G�i�6,4i Form 10-403 Revised 4/2017I 1 lIId for 12 months from the date of approval. Attachments in Duplicate • • West Sak 1H-105 Non-Rig Wellwork Proposal to Perforate A4 Sand to obtain Fluid Samples, and to Perforate D, B, and A Sands, and to Change Well Status following the Completion of this Proposed Wellwork 1H-05 was drilled in 1982 to evaluate Kuparuk sands, but the Kuparuk sands were wet. This resulted in a P&A to 2400' MD with cement. In Dec 2004, a 1H-05 Rig-ST created 1H-05A, which was drilled to TD of 9038' RKB (4297' TVD) to evaluate West Sak D, B, and A sands. MDT logging and fluid sampling was done from Doyon 14 Rig, and then a 5.5" x 3.5" L-80 tapered production 'long string' was run in 8.5" OH to 9038' MD and cemented with 250 bbls 12.5# DeepCrete Cement. The plug bumped at 199 bbls. 3.5", L-80, 9.3# tubing string was set in a Seal Assembly at 8155' RKB. 1H-05A was left unperforated when D14 moved off the well. In 2005, 1 H-05A was renamed to 1H-105 to name the well as a West Sak well. Per this proposed procedure, non-rig well work will obtain West Sak A4 Sand oil samples for Geochem analysis. 1 H-05A zonal fluid sampling during Dec 2004 failed to attain the A4 sample due to a concretion encountered which prevented gathering this sample. There are risks associated with gathering a good A4 sand oil sample in 1H-105, but most risks identified can be mitigated. With mitigations, there is a good chance of getting good quality A4 oil samples. This could make A4 sampling efforts on rig unnecessary during drilling of a future 1H NEWS development well. This work will be executed mid-late June 2017 before 1H NEWS development drilling begins. This procedure attains A4 oil samples and then perforates West Sak D, B, and A Sands to leave 1H-105 ready for future injection service as a 1H NEWS `WIND' well. This proposal requests that current `Suspended' status of 1H-105 be converted to Current Well Status of `Service' (box 4 of 10-403). 1H-105 will be used as a future water injector as part of the 1H NEWS Development starting in Q3 2017. 1H-105 will not be pre-produced, and there are no plans for a gas injection line to the well. Thus, a requested Well Status after the completion of the proposed procedure is WINJ' (box 15 of 10-403) for a water injector. Objectives: Perf A4 to inflow A4 to gather A4 fluid for Geochem analysis, and then perf D, B, and A sands. Well Status: 1H-105 was drilled as a West Sak well (aka: 1H-05A) in December 2004. 1H-105 is currently a suspended well. 1H-105 was completed in West Sak D, B, and A sands, but was never perforated or put in service. 1H-105 has no flowline. 1H-05A West Sak Reservoir Data: Expected A4 Zonal Pressure: 12/13/04 MDT = 1749 psi at 8617' MD; 3971' TVD; 8.5# EMW. Reservoir Temp & Fluid API: 79°F at W Sak A Sd; —21 API, per 12/13/04 MDT in 1H-05A. 1 • • Procedure: 1) SL or DSL: a) Perform MITIA to 2500 psi. Bleed IA pressure to 0 psi. Perform MITT to 2500 psi. Bleed tubing to 0 psi. ---- b) RIH with 2.80" Gauge Ring to deep as possible to verify no obstructions exist in well. Survey data shows inclination is 73 to 80 degrees through the tubing at 3745 - 7879' MD. Since no perforations exist in the well, it is not possible to pump a tool string down tubing. c) RIH with a cleaned Collar Stop and set it at 1000' MD. This provides a platform to beat on with a Hydrostatic Bailer (part d), to shear the Bailer open and collect a Diesel FP sample for Geochem finger printing. d) RIH with a cleaned 2.5" OD Hydrostatic Bailer to collect a `Diesel FP Control' sample. The Bailer will be disassembled before job to clear it of all hydrocarbons, then reassembled. This ensures Diesel collected will be free of other hydrocarbons. RIH with Hydrostatic Bailer. Beat down on Collar Stop and open Bailer to draw in `Diesel FP Control' sample for Geochem analysis. Geochem data of Diesel sample may be used to back out Diesel contamination detected in West Sak A4 oil sample collected later in this procedure, if Diesel contamination still exists while collecting A4 oil samples. POOH with Bailer. Transfer Diesel sample to clean sample container and send for Geochem. e) RIH & pull Collar Stop from tubing at —1000' MD. 2) E-line: An 8/22/16 SL Caliper log was not able to get deeper than 4200' SLM, so we will not reattempt a Caliper on SL. We will run the Caliper log on E-line Tractor. This log will verify tubing and liner are in proper condition for remaining well work proposed in this procedure. a) RIH with E-line Tractor with Caliper and 2.5" OD x 25' OAL Dummy Perf Gun Drift. A Tractor deployed Caliper is needed due to 73 - 80 degree incline between 3745 - 7879' MD. Activate the Tractor when needed to tractor to PBTD at 8946' RKB. Obtain Caliper data from as deep as possible to surface. b) If needed, make Tractor run #2 with just the 2.5" OD x 25' OAL Dummy Perf Gun Drift BHA alone to PBTD at 8946' RKB. This verifies 2.5" x 25' guns to be run later will drift OK. POOH with Tractor BHA. RD. 2 • . 3) Coil Tubing - Jet Wash Tubing & Liner Clean and then perform N2 Blowdown: 1H-105 has never been perforated. Fluid in 3.5" tubing / liner is Diesel FP to 2491' MD and then 9.3# Corrosion Inhibited Brine to PBTD at 8946' MD. TD is 9038' MD. By the end of CT N2 blowdown operations, almost no hydrocarbon should remain in the tubing or liner. This condition will then be retained to maximum extent possible until A4 fluid samples are attained. Spot 2 ultra-clean fluid Transports on location. Transport 1 will contain 290 bbls of 3% KCL Water mixed with 5% DeepClean solution. This cleaning solution will be pumped as lead wash fluid, to remove hydrocarbon from all surface lines, CT, pump, and tubing / liner. Transport 2 will contain 290 bbls of 3% KCL Water without additives. This fluid will be pumped as rinse fluid to displace all Deepclean solution from well to tanks. Rinse fluid will then be removed by subsequent CT N2 blowdown of the well. Spot 3 x 400 bbl return tanks. Fluids expected circulated from well to tanks = 1 wellbore volume of fluid currently in the well (78 bbls) + (2 x 290 bbl Transports) = 658 bbls max. Spot Nitrogen Transport. N2 will be used to blow down 1H-105 to tanks immediately after jetting all rinse fluid into 1H-105. We plan to leave 1H-105 with N2 gas filled tubing with final target tubing pressure of —1400 psi trapped on wellhead. N2 will freeze protect the tubing. Residual fluid in well will be minimal and much deeper than permafrost after N2 blowdown. E-line Ops will commence immediately after completing CT Ops. Coil Tubing -Job Execution: MIRU CTU with 2" OD CT. 1H-105 is cased, cemented, unperforated, and will have passed an MITT & MITIA (per step 1) before executing this work step. Stab 2" CT on well with Jet Swirl Nozzle BHA. Open Swab and CT x Tbg annulus to tanks. RIH to 2750' MD to get nozzle below Diesel FP while performing a cleaning operation of all in-line surface equipment. The cleaning operation will remove hydrocarbon from all in-line hardline, flex hoses, choke skid, pump, to CT, by drawing 5% DeepClean solution in 3% KCL from ultra-clean Transport. Also route DeepClean through surface lines not yet actively in-line, that we will put in-line later during CT operations (ie fluid line from Transport #2). Verify all surface lines, including dead legs get decontaminated. Circulate DeepClean down CT to displace the 2491' MD Diesel FP from tubing. Jet wash Diesel FP section between 2500' to surface with DeepClean to clean this tubing of Diesel, then RIH to 8946' PBTD jetting and displacing all 9.3# Brine from 3.5" tubing & liner to tanks. Make passes up and down well jetting all DeepClean solution from Transport #1, then swap to ultra-clean Transport #2 containing 3% KCL Water rinse fluid jetted from nozzle between PBTD to surface. 3 • • When rinse fluid reaches nozzle, POOH from PBTD to surface chasing DeepClean from tubing to tanks. Make passes between PBTD and surface circulating tubing & liner clean. Prepare to swap to N2 for Blowdown of the well as Transport#2 becomes empty. RIH with CT to PBTD and park nozzle. Start pumping N2 to displace all wellbore fluid from well to return tanks. N2 blowdown objective is to vacate as much fluid as possible from the 3.5" tubing and liner to tanks. When the fluid returns to tanks diminish and become all N2 gas, POOH with CT and trap 1400 psi on tubing. This will result in —200 psi underbalance at the A4 sand for E-line perforating. A4 pressure from 12/13/04 MDT = 1749 psi at 8617' MD; 3971' TVD (8.5# EMW). Per Nitrogen Handbook, 1400 psi on tubing leaves —1550 psi at —3900' TVD assuming no remaining fluid leg exists in the well above 3900' TVD. If we find fluid leg (step 4), we may bleed down tubing to lower hydrostatic at A4 depth due to some fluid leg length that may exist above this depth. Take final tank straps and calculate the estimated fluid volume returned to tanks during N2 blowdown operation. Estimate remaining fluid volume in 3.5" tubing / liner based on starting and ending tank straps. RD CTU. MOL to let E-line RU on well for tractoring operations. 4) E-line -Tractor Log to Verify Remnant Fluid Column Consider 24 hr Ops to achieve E-line work steps 4 - 8 below. Arrange 24 hr Ops if viable. Stage E-line Tractor (and a backup Tractor) to execute remaining work steps in this procedure. Stage 2.5" &/or 2" OD Perforating Guns to execute steps 6 & 8 of this procedure. Gun size used will be 2" OD if we shoot in gas (N2) at A4 perf interval. Use 2.5" guns if we verify the gun will be in fluid. The 2.5" guns may swell too large in gas to safely drift the well min ID. Stage two 1.75" run OD Samplers to sample inflowed A4 sand fluid, if needed. Stage big Crane needed to complete all remaining work steps. We will need to PU a long Lubricator for E-line Tractor Ops. Review risks identified to be mitigated to get good A4 fluid samples. It will be critical to mitigate hydrocarbon entry to the well during E-line Ops. Diesel, greases, and lubes are contaminant sources. The Lubricator will require Diesel decontamination. 1H-105 will have already been cleaned by CT Ops, so E-line will prevent new hydrocarbon contamination from entering the well that can contaminate A4 fluid samples to be collected. MIRU E-line & Crane. Maintain —1400 psi pressure on tubing to provide —200 psi underbalance for perfing A4 (step 6) to assist A4 oil inflow for sampling, and to have freeze protect. PU long Lubricator for Tractor Ops. E-line Lubricator will be clean of all Diesel. Load BHA & PT Lubricator. Open Swab & RIH with Tractor BHA with GR/CCL/Temp/Pressure/Gradio/DEFT to identify any remnant fluid column left in wellbore after CT N2 blowdown. 4 • • The objective is verifying interface depth between N2 and remaining fluid leg in the well, and to identify remaining length of any hydrocarbon, if any hydrocarbon leg still exists in the well. If hydrocarbon leg still exists, a decision will be made to either do another N2 blowdown (unlikely), or if excessive contamination still exists we may opt to forego attempting to get A4 fluid samples (unlikely). If the hydrocarbon leg is short, we may opt to attain a sample of the remnant hydrocarbon leg. If we choose to sample remnant hydrocarbon leg (step 5), the intent would be to perform a GeoChem analysis on the sample to fingerprint the hydrocarbon contaminant in the well to attempt to back out the contaminant from an A4 fluid sample Geochem analysis. The Gradio measures fluid density and DEFT differentiates between water and hydrocarbons, so we can identify gas/fluid and hydrocarbon/water interfaces. The Gradio does not work in over 70 degree inclines, so it may be of limited value at < 8000' MD, where inclines are > 70. BHP data will be used to verify we have -200 psi BHP at the A4 Sand. We can then adjust pressure on wellhead to get -200 psi underbalance at the A4 sand. Tractor down tubing and log remnant fluid column. Slow tractor RIH rate immediately after detecting remnant fluid column in well. Slow RIH mitigates mixing fluid column. Incline > 8000' continually drops from 69 to 32 degree at PBTD (8946' MD). Record gas/fluid interface and hydrocarbon/water interface depths detected, then POOH with tractor to surface while preventing mixing. Maintain -1400 psi of trapped N2 pressure on tubing. Download log data. If hydrocarbon leg MD length is < 10' MD OAL, we will likely skip step 5. If hydrocarbon leg MD length is 10' - 115' MD OAL (< 1 bbl), we will likely sample the hydrocarbon leg for fingerprinting (in step 5). If hydrocarbon leg is > 115' MD OAL (> 1 bbl), we will likely skip sampling hydrocarbon leg (skip step 5). We may perform another CT blowdown (unlikely), or do we may decide to perf and inflow A4 for sampling anyway (step 6), or we may skip sampling (step 7) due to expected contamination of any collected A4 samples. 1H NEWS Team will finalize make decisions to sample A4 or not based on results of this log. 5) E-line, only if needed- Gather Fluid Sample of Remnant Hydrocarbon Leg: If this step is to be executed, stage Fluid Samplers to obtain a minimum of 2 samples of the remaining hydrocarbon contamination in the well. Follow the Lubricator decontamination & PT protocol. RIH with Tractor BHA with GR/CCL/Temp/Pressure/Gradio/DEFT and Samplers on bottom with timers set to open at time that Samplers will be in position to take hydrocarbon samples. POOH with samples. Maintain -1400 psi trapped on tubing. Bleed off pressure at surface from Samplers. Transfer fluid samples from Samplers to shipping containers and send `Remnant Hydrocarbon Contaminant' for Geochem fingerprinting. 5 • • 6) E-line -Tractor Perforate A4 Sand: Follow Lubricator decontamination & PT protocol. RU & RIH with Tractor BHA with GR/CCL and 25' OAL perforating gun to perf the A4 perforation target at 8516 - 8541' MD. a) If gas (N2) is in wellbore at A4 target, use a 2" OD gun x 25' OAL, 60 deg ph, 6 spf. If A4 target has gas across it, a 2"OD gun ensures no issues drifting the swollen gun OOH. b) If fluid is in wellbore at the A4 target, use a 2.5" OD gun x 25' OAL, 60 deg ph, 6 spf. Reference SBHP from previous logging runs (steps 4 or 5) to determine if 25' A4 perforation target at 8516 - 8541' MD is —200 psi underbalanced. A4 SBHP is expected = 1749 psi. If less than —200 psi underbalanced at A4, bleed pressure off tubing as needed to get —200 psi underbalance at A4 before firing gun. Log into position across the A4 perf target at 8516 - 8541' MD referencing 1H-105 OH GR log. Fire the gun to perforate the A4 sand at 8516 - 8541' MD. POOH with the Tractor BHA. Bleed down trapped pressure on tubing to 1000 psi to help assist A4 inflow and create sufficient oil leg length for sampling. 7) E-line -Tractor Log A4 Fluid Leg in Wellbore: Follow Lubricator decontamination & PT protocol. RU logging BHA. Hoist & PT Lubricator. Open the Swab & RIH with Tractor and GR/CCL/Temp/Pressure/Gradio/DEFT to verify presence of an A4 fluid column. Log N2 to hydrocarbon interface depth, then slowly tractor down to identify hydrocarbon to water interface depth. If insufficient fluid length exists in the tubing to sample, park logging tools 100' above N2 to hydrocarbon interface and bleed 100 psi pressure on wellhead, and then tractor to note if N2 to hydrocarbon interface changed. If not, POOH 100' above N2 to hydrocarbon interface and bleed another 100 psi pressure. Repeat this process until enough A4 fluid has inflowed into well for sampling. We prefer at least a couple hundred feet of A4 fluid column for sampling. If needed, we can bleed WHP down to 0 psi, provided the top of inflowed fluid level is kept deeper than 2500' TVD (-3900' MD), to maintain freeze protection. POOH with logging BHA. Proceed to step 8, if sufficient A4 fluid column exists for sampling. 8) E-line -Tractor Collect A4 Sand Oil Samples: Follow Lubricator decontamination & PT protocol. RU & RIH with Tractor BHA and GR/CCL/Temp/Pressure/Gradio/DEFT, and tandem Samplers on timers to gather A4 oil samples. Tractor to N2/hydrocarbon interface depth. As tractor BHA approaches anticipated fluid top interface depth, slow tractor RIH rate to mitigate fluid mixing in hydrocarbon leg. 6 • • Log through hydrocarbon to hydrocarbon/water leg interface and then halt RIH. Slowly POOH with samplers back into A4 oil leg so that lower sampler is at least 20' up into the A4 oil leg. Park the BHA and wait for timers to expire to gather the A4 oil samples. Record the SBHP at the A4 sand at 8520' MD. POOH with the A4 oil samples. Since PVT analysis is not an objective, bleed pressure off the Samplers on surface, and then transfer the A4 fluid samples from the Samplers to shipping containers. Send samples for A4 oil Geochemical analysis. Bleed the remaining trapped N2 WHP to 0 psi, or until fluid reaches surface. Fullbore pump 22 bbls of Diesel FP down tubing to A4 perf interval at matrix injection rates. Limit pump rate to stay below 1100 psi WHP. 9) E-line -Tractor Perforate Other West Sak Zones Call out 2.5" OD guns to shoot perforation intervals listed below at 60 deg phasing, 6 spf. RU to make multiple perforating runs, as needed on 2-1/8" OD Tractor with GR/CCL. Shoot the following additional perforation intervals (total = 180' of perforations): Zone MD TVD SS Footage D Top Perfs 8313.0 -3698.8 45.0 D Base Perfs 8358.0 -3723.0 D Top Perfs 8368.0 -3728.7 30.0 D Base Perfs 8398.0 -3745.7 B Top Perfs 8437.0 -3768.0 30.0 B Base Perfs 8467.0 -3786.4 B Top Perfs 8477.0 -3792.6 15.0 B Base Perfs 8492.0 -3801.9 A3 Top Perfs 8601.0 -3872.9 30.0 A3 Base Perfs 8631.0 -3893.2 A2 Top Perfs 8669.5 -3920.6 30.0 A2 Base Perfs 8699.5 -3942.1 RD E-line & MOL. Flowline installation still needs to be completed. 1H-105 will then become a 1H NEWS Service well in the near future as a WINJ Injector. 7 t^ • a KUP 1H-105 ConocoPhillips a Well Attribut Max Angle TD Alaska<Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Garw,aSNdllipn , 500292072701 KUPARUK RIVER UNIT INJ 79.21 7595.96 9,038.0 Ate, Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date ... 10-105,5/11/2017157:40 PM SSSV:NIPPLE Last WO: 37.78 5/18/1982 Vertical schematic.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 8,447.0 8/17/2016 Rev Reason:GLV 0/0,TAG pproven 9/5/2016 .......................................... HANGER;29.1 I1.10FCasing Strings !-Al1. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 34.0 108.0 108.0 62.50 H-40 WELD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WSLen(I...Grade Top Thread SURFACE 10 3/4 9.794 33.0 2,443.0 2,223.5 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 5.5"x3.5" 51/2 4.950 31.1 9,038.0 15.50 L-80 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)1..Wt(Ibtk) Grade Top Connection ,,,,,,,,,,,,,,„,,,,,,,r,.,.,,,,,..,,rana...., , TUBING 31/2 2.992 29.1 8,172.51 3,716.0 9.30 LOU EUE8rdABMOD i I Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 29.1 29.1 0.00 HANGER CIW GEN IV TUBING HANGER 3.030 , 513.5 513.5 0.33 NIPPLE CAMCO'DS'NIPPLE w/NO GO PROFILE 2.875 8,107.3 3,687.8 65.65 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 - 8,154.7 3,708.1 63.85 LOCATOR BAKER NO GO LOCATOR 2.950 CONDUCTOR 34.0-105.0 �,..:. a 8,155.5 3,708.4 63.81 SEAL ASSY BAKER 80-40 GBH SEAL ASSEMBLY-STUNG INTO 2.990 CASING 3.5"PRODUCTION CASING ' I- Mandrel Inserts St eh on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com NIPPLE;513.5 1 2,491.8 2,251.3 CAMCO KBG-2- 11,2 INJ DMY Tr 0.000 0.0 8/17/2016 9 Notes:General&Safety SURFACE;33 S-2,443.0- 4 4. End Date Annotation 12/18/2004 NOTE:1982 WELL SUSPENDED,RE-ENTERED 2004;1H-05 RENAMED"1H-105" II5/27/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT;2,491.8 C�' i) , E • SLEEVE,8,107.3 I I. 10.1 LOCATOR;8,154.7 Mt tib 1119. SEAL ASSY;8,155.5 . Ilk r ° I i PRODUCTION 5.553.5";31.1- 9,038.0 • • 0 0 -0 Z ' 4 V)I 0 0 a r•7 1 a 2 o O 41 4 N O u_ Q i1s i ` n N > - 6 N i ix .41 Cl IL. o N viiIt +' o v CD d can r 4 C I n S 2 I V A o = , / T7Z..._„..............„..,.m f N y I/ 6�0 / ////:// a y o _ \\ \ _ 47.\\. , © z , /7/ 17/7 ;5 l / '`,.„. ',..,..., W ( / N f CC d Ii y Z _ _, - 1 i 6 �A� G Q O 1°1t N R Iv v \ - 0 I \ i Ii • • C H in r r r r .- r r co w a) O 4 > tuv°w oUn a a -c V • i— <6- U . u v > Y Ci — a O O 0 a C T3 o co C a Q ro It 0. C `^ m ,W,^^ fD CO f0 CD tD f0 t0 _c u 41 L J • Q V • a) O Y l/) 1- a Q a cn cn 0 fn " n3 'LC ‘112 F- O N N N C co a) Q N z Q � Q Q. O Ou a�� K a) a 10000000 W J J J J J J J C a-' a W W W W W W W op c co.-C F- LL LL LL LL LL LL LL Y E D N O Q J J J J J J J a o C v, cc F- Z z z z z z z v co v o o) LL LL LL LL LL LL LL [Y 47" U O > Y O CG7 a v O m Z C O -0 C v N «-- V 0.a. � a) a) _ O i. —ccal Q C s co OO > c-> ti 73,� )z. W u. LL W LL LL LL LL �. r� OOa000O p y CI c WcG Q• Q j a. a s a. .. z PI V % w• =,i z W 111.6 � > ft 0 4C fif a01 ,at .c. do No 0t Ecke oto CO K. W 0' ] zR Wt) t,w o recccecccccc cc W W W W W W W • LU > > > > > > > z Y Y Y Y Y Y Y c:1 = > > > > > > CL w < < < < < < •4 LLaa. a. a. a. a. a ! on Y Y Y Y Y Y Y ff 8 X in a. 'W N c•-,r ? to 0 o III K 0 0 0 0 0 0 0 _ _� 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W 3t ro N4; U ac0 W coo H F coo coo a) `> I (9 0 0 0 O O _� Lli c-1 .9„ tW 0 Q 0 0 ••7 N V Q J !LIC a 0 00 0 0 0 U 6 0 0 — 0 0 0 0 o CO41 N N M CO T Y 0 0 0) N N 0 COtro Q M M VI VI 0 N 0 a ate+ : 'n 1 N a N N N N N N N -..E- _ '2 N. C) 0) 0) 0) M O) 0) y� L o N N N N O N N , -O 0- 8 0, o O o O O o ea u O O o 0 0 0 0 o w •a O 00 to Ln in to in N Um 00 C _G O CO CID cc tR 1 GE O) °D a. 8 2 z '^ E E �� 6! 1 .,,,a N O O O O N Mco ate.+ c w a) a) Li, g0 M = 2 Q m ro ti E Q L N .6. L ?LU C.1 N M •, E z (II O O y _ it in.. a 1-° STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CON,. .3SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations E Fracture Stimulate r Pull Tubing r Operations shutdow n r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Suspend Well Inspect J 2.Operator Name: 4 Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204-228 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-20727-01 _ 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25639 KRU West Sak 1H-105 9.Logs(List logs and submit electronic and printed data per 20AAC25.071) 10.Field/Pool(s). NA Kuparuk River Unit/West Sak Oil 11.Present Well Condition Summary: Total Depth measured 9038 feet Plugs(measured) None true vertical 4297 feet Junk(measured) none Effective Depth measured 8946 feet Packer(measured) 8156 true vertical 4220 feet (true vertical) 3708 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 108 108 1640 630 SURFACE 2410 10 3/4 2443 2223 3580 2090 PRODUCTION 8151 51/2 8182 3721 7000 4990 PROD LINER 856 3 1/2 9038 4297 10160 10540 Perforation depth: Measured depth None SCANNED .1 u, 1 r7 ;,D j`, RECEIVED True Vertical Depth. None JUN 3 U 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80, 8155 MD, 3708 TVD AOGCC Packers&SSSV(type,MD,and TVD) BAKER 80-40 GBH SEAL ASSY-STUNG INTO 3.5"PROD CASING @ 8156 MD and 3708 TVD No SSSV 12 Stimulation or cement squeeze summary NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25 071,825 283) 15.Well Class after work: Daily Report of Well Operations rExploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work. Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt NA Contact MJ Loveland/Martin Walters Email n1878@conocophillips.com Printed Name 77n..._ MJ Loveland Title WI Project Supervisor Signature 6.....,_____,.......-- Phone:659-7043 Datei - /?/q/15 RBDMS\ JUL - 1 2015 //,5----- Form 10-404 Revised 5/2015 Submit Original Only Iry ConocoPhillips RECEWED Alaska JUN 3 0 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC June 29, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit West Sak 1H-105 (PTD 204-228) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit West Sak well 1H-105 (PTD 204-228). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs The well is being held for future West Sak development. Please call Martin Walters or me at 659-7043 if you have any questions. Sincerely, . /Z7/,-- --e-j:t..— MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT WSAK 1H-105 Field/Pool: KUPARUK RIVER/WEST SAK Permit#(PTD): 204-228 Sundry 304-389 API Number: 50-029-20727-01-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 12/18/2004 Surface Location: 528' FNL, 803' FEL Section: 23 Township: 12N Range: 10E Nearest active pad or road: KRU DS1 H Meridian: UMIAT Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: none Pits condition: backfilled Surrounding area condition: good Water/fluids on pad: none Discoloration, Sheens on pad, pits or water: none Samples taken: none Access road condition: Good Photographs taken (#and description): 3 of well and surrounding area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good Cellar description, condition, fluids: Clean Rat Hole: NA Wellhouse or protective barriers: NA Well identification sign: Yes Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: IA=100, OA= 160 Wellhead Photos taken (#and description): 3 photos of well and area Work Required: None Operator Rep (name and signature): Perry Greenwood AOGCC Inspector: Johnnie Hill Other Observers: Cody Warfield Inspection Date: 6/27/2015 AOGCC Notice Date: 6//25/15 Time of arrival: 1415 Time of Departure: 1420 Site access method: Truck • `, KUP 1H-105 CQnocoPhiUi Well Attributes Max Angle&MD TD -I� Wellbore APWWI Field Name Well Status Incl(°) MD MB) Act Btm(MB) Aiaska. i�xi,,u,,il,r, , 500292072701 KUPARUK RIVER UNIT INJ 79.21 7,595.96 9,038.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date Well Confp:•1H-105,4/dW20138:33:28 AM SSSV:NIPPLE Last WO: 37.78 5/18/1982 Schematic-ActualAnnotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW _ ___ osborl 4/30/2013 Cas in g Strings Casing Description String 0... String ID..Top(RKB) 'Set Depth(f...Set Depth(TVD)..String Wt...String...String Top Thrd HANGER,z9— CONDUCTOR 16 15.062 34.0 108.0 108.0 62.50 H-40 WELD LIfr Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd SURFACE 10 3/4 9.794 33.0 2,443.0 2,222.7 45.50 K-55BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...'String Top Thrd PRODUCTION 51/2 4.950 31.1 9,038.0 15.50 L-80 BTC 5.5"x3.5" Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 31/2 2.992 29.2 8,172.5 3,717.0 9.30 L-80 EUE8rdABMOD Completion Details Top Depth (TVD) Top Incl Nom... Top(RKB) (RKB) (°) Item Description Comment ID(In) 29.2 29.2 -13.84 HANGER CIW GEN IV TUBING HANGER 3.030 _ 513.7 513.7 0.33'NIPPLE CAMCO DS'NIPPLE w/NO GO PROFILE 2.875 8,107.3 3,688.3 65.65 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 8,154.7 3,708.1 63.85 LOCATOR BAKER NO GO LOCATOR 2.950 8,155.5, 3,708.4 63.81 SEAL ASSY BAKER 80-40 GBH SEAL ASSEMBLY-STUNG INTO CASING 3.5" 2.990 PRODUCTION CASING Notes:General&Safety CONDUCTOR. End Date Annotation 34-108 12/18/2004 NOTE:1982 WELL SUSPENDED,RE-ENTERED 2004;1H-05 RENAMED"1H-105' 5/27/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 NIPPLE,514 SURFACE, tt 33-2,443 I GAS LIFT, 2,492 SLEEVE,8,107 — }' I 1 U - LOCATOR, 8,155 SEAL ASSY, , 8.156 Mandrel Details Top Depth Top Port ' (TVD) Incl OD Valve Latch Size TRO Run N...Top(RKB) (RKB) (°) Make Model (in) Sery Type Type lin) (psi) Run Date Com... 1 2,491.8 2,251.355.32 CAMCO KBG-2-9 1 GAS LIFT SOV DKC-3 0.000 0.0 12/18/2004 PRODUCTION 5.513.5-. 31-9,038 TO NH-105), Ad . 9,038 csl li 1r,�_ Z tx s g 1. 8 u, IJ`=a m O o W + + + _ s♦♦ ^ \ Z y W J i c I ...N\ . a tAJ CY o Q J d F Vl CL— CL— II m 101— -- •� 1 ....y____ -__._---•----0~ W W (Il U Z W 1.11 co 2 V Y i O 11 ZO + I j O 0] O 181 C w * _ V ^ A Y — p -•-__-r •III �h _. {31 m O Z III p ...._--f-- . ._._. . ..__. y tsi fz to 14 n I81 j L. 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W ' Yin C 1 =.13 •' ' ^` • co Iiiik 1: 4 ' . vit co 4 u�. tf CC ' •ter � 0 • Q N �_ •^� O CO "- IF Ci.. / (27 J C77 CV Ohl 'Z U N M Ay.CV, •' dk c � S0ill ' 1 e .zg '. a #]'� s +� d 6 d H w t,;•..1.1:',.: , ti e r t ' � � F a r � r � � + i _ , "- {a C. . w tF 1 t .' t ,4,.015 ;03. _ .sI ••"A" � .r " 4 i' j * +M l •S err -k� 1 'rO ) 1``m Y ,,,,,n 4k N„AA. '4! Z4h ., *,fes 4 .� ` ''1 a k. 1 H-105 PTD 204-228 ©ConocoPhillips Alaska, Inc l", This photo is copyrighted by Ego • nocoPhillips Alaska, Inc. and r. nnot be released or published I without express written consent ,` •t ,,ConocoPhillips Alaska * `z.p"' v jY 61-4 Allii NW 144 OP , 4 14 iw` t. . i. �` ra..w.l � RIia 4 al, m �3iimi,k+ 5d v. WNW 440 4i a ? � y. ..„.„,,,..1,,,,,,,,,..... , k w. • OA ' <j rw i rt, • '....,:, •,..0 � �,: u s gi' '°g, r° m r �'"` ... - /.7,,_ ', i7-%•';. Yr.jr �. #` j „ f,'.�'v .-�z`,`'4�Mt, r ya ..4— 'y`"S"-J!...; * za'z++' < " 1,01e4..;t",4'.!". ...'4-I',..'Lvr. .,�.c u r'l 4 °";: ConocoPhillips 7 5. �'= , .a afera�.,«°' r.,, x 4,1,,,,,,,.......-"*" x 7�, • $`f V F y .. 4 .. -= - Well Name: 1H-105 ;,., *0.11.4.;44,, 4 : € x API Number: 50-029-2072701 !0 • � -,.,,, , _ •, PTD: 204-228f" ��.* • . ,,, Sur.location: 529' FNL, 803' FEL, _� Y. -.*Ir'''=. Sec. 33, T12N, B1OE, UM i 10 • ,:°. ,s. - „ " Via, . 3 I, RIP-Irlitiii. -0 CO I, O O CO C 1,_ _ - U. �, . Q Q N E U N (,) .'"', — Q i..m." .ae Wror d' OQ L., c OU CN (/) , O a Q ,0 ca O C - --- .= 1111111. i LOQ - O O 0 O r = O Q Q i A A A • 0 v - U s . , , . R A * di• a-Ile , 4 1 '' om ,I) r tF A p � Y4 � RR f {r I ‘ ' . 'li g . * '„ ' .g: .• • , i. g. , g ) iW. li 1 rtft•;:it4;45:*;i1 l'i';'''%*. 1:%'''•',%i't,iit,,n6,:4,t 4\ ix, • 1 . } STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 06/27/15 Inspector: Johnnie Hill Operator: ConocoPhillips Alaska Inc Well Name: 1H-105 Oper.Rep: Perry Greenwood PTD No.: 204-228 Oper.Phone: Location Verified? Yes Oper.Email: If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 12/18/04 Date AOGCC Notified: 06/25/15 Sundry No.: Well Completion Report Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 ' Photos Taken? Yes IA 100 OA 160 Condition of SCANNED AO �1 1 9 2`15 Wellhead: good and clean-no well house Condition of Surrounding Surface Location: good clean gravel/celler little water Follow Up Actions Needed: none Comments: none Attachments: Photos(3) REVIEWED BY: �� Insp.Supry Si( /) Comm PLB 06/2014 2015-0627_Suspend_KRU_1H-105jh.xlsx Suspended Well Inspection—KRU 1H-105 PTD 2042280 Photos by AOGCC Inspector J. Hill 6/27/2015 • • . C. mew• wMr I IC *•"'""'"" --- reImo SI awn 7/1 Mt Kern Ur Imam in ILMI Ift au it MIL W0.IN • 2015-0627_Suspend_KRU_1H-105_photos jh.docx 1 Page 1 of 2 iii t' _.. ..moi' i.'-4i, _•� . 17.4 WIPP 01.0" I If*4011141C— 6 n A , ;1;4114.'em-eisa; •1":a. cr, .0 OWORliip� ntOwt 2015-0627_Suspend_KRU_1H-105 photos jh.docx 2 Page 2 of 2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/29/10 Inspector: Bob Noble Operator: CPA Well Name: KRU 1H-105 Oper. Rep: Ian Ives PTD No.: 204 -228 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: If Verified, How? ier (specify in commei Onshore / Offshore: Onshore Suspension Date: 12/18/04 - Date AOGCC Notified: 08/28/10 Sundry No.: Well Completion Rpt ' Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 1075 - Photos Taken? Yes IA 0 OA 175 " Condition of Wellhead: Verified with plot plan. Guard around tree. No Flowline. All lines blinded with gauges. Cellar was dry. OA valve has stem valve packing leak.Wellhead has a guard around it. Condition of Surrounding Surface The area around looked good with no signs of spills or leaks. Location: Follow Up Actions Valve crew was going to address the stem packing leak. Needed: Attachments: Photos (4) REVIEWED BY: Insp. Suprv. - Comm PLB 08/2010 2010- 0829_Suspend_KRU_1H- 105_bn.xls Suspended Well Inspection — KRU 1H -105 PTD 2042280 Photos by AOGCC Inspector B. Noble 8 -29 -2010 lir rill"' .,.; , Hrof. :I v 1 1 , �.. .. '� • mss _... i ' 1 1110 ..--- a ........... . IJ • t .A ,.ate '.!. _. • ur 105 _ '. eNtr y . . . i a r ► • 1 • • KRU 1H -105 Suspended Well Inspection 8 -29 -10 bn 1 • • 0 ,F :!.1#':::1":1':ri''''.1';'''':.'4,./ -,,,„:;:": ,.:.;: ' ' } '' r ' „ -..,.., too W� w a .+ , 4'1 f t` 4A` r k 4 lit y h a 'aS ipt r ..-4,, ! l .gs + 7 t ` 0 'c # wf f 4 # r , 1..1! , d ...-tr- I - - s w .., _, „ • , wig I „. twi iii III. iiiiii , . , .. « Ft M . „_. 1. . � � T ` I. .',7,` ; -,z,:,.,.. ' F.4 l 'i s :. 2 KRU 1H-105 Suspended Well Inspection 8 -29 -10 bn • • • sirwil SEAN PARNELL, GOVERNOR c�t� ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1H-105 Sundry Number: 310 -415 ,}fi�1�� Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 9 Daniel T. Seamount, Jr. Chair DATED this day of January, 2011. Encl. • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 DEC 1 4, 2010 Masks pis & as Cons. Commission pnchorogS December 11, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Renewal of Suspended Well 10 -403 Status Kuparuk River West Sak 1H -105 (PTD 204 -228) Dear Commissioner Seamount: ConocoPhillips Alaska Inc. (CPAI) hereby submits a request for renewal of the suspension status of Kuparuk River Unit well 1H -105 (PTD 204 -228) per 20 AAC 25.110. The well was visually inspected September 29, 2010 and the results submitted on a 10 -404. The condition of the well is noted on an attached schematic and 10 -403 form. Please note the following: - The well bore is not perforated - The well is on an active pad. CPAI request the renewal of the suspension because the well is being held for future West Sak development. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, //77,./ r ' MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures r l ` STATE OF ALASKA �� ALASK.1L AND GAS CONSERVATION COMMISSO 1 �`�� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 lt. 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r tr\• Suspend ( • Rug Perforations r Perforate r Rill Tubing r Time Extension Operational Shutdown r Re - enter Susp. Well r Stimulate r Alter casing r i ~/ Other: ��.uw Sk �s�oea," ly 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Explorator r 204 - 228 3. Address: Stratgraphic r Service r • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20727 - 01 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r' s 1H -105 • 9. Property Designation: 10. Field / Pool(s): ADL 25639 ALK 464 Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9038 • 4297 • 8946' 4220' NONE NONE Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 108' 108' SURFACE 2410 10.75 2443' 2223' PRODUCTION 8149 5.5 8182' 3721' PRODUCTION 856 3.5 9038' 4297' Perforation Depth MD ft : Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): MD NONE 3.5 L -80 8155 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) SEAL ASSY - BAKER 80 -40 GBH SEAL ASSEMBLY MD= 8156 ND= 3708 Camco DS Landing Nipple MD =514 TVD =514 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service ' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: NA Oil r Gas r WDSPL r Suspended P • 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Perry Klein Printed Name MJ Loveland /Perry Kin Title: WELL INTEGRITY SUPERVISOR Signature /°�� •�° Z C / Phone: 659 -7043 Date / // /� Commission Us my Sundry Number: 310-14 15 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RECEIVED DEC i 4 2010 Subsequent Form Required: N bAG . /./c 7 hc.L • A1000 Oil & G $ Cons. 'ommis$ien p APPROVED BY Approved by: oF4 n r A �, g01 i COMMISSIONER THE COMMISSION Date: L.� H v(°� R I o./ I N '/l j e > i y � 2S Form 10 -403 Revised 1/201 L A f /� Submit inpupli to L. /y/ • KUP 1 H -105 Conoc ° Well Attributes ax Angle & MD TD Ai Iska. II II:. Wellborn API/UWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) Lc...0PNbps 500292072701 KUPARUK RIVER UNIT PROD 79.21 7,595.96 9,038.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (N) Rig Release Date Well Conk - 114705, 5,27@0101:0903 PM SSSV: NIPPLE Last WO: 37.78 5/18/1982 Schematic - Acton/ Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: UPDATE TO 9.0, QC Imosbor 5/27 /2010 Casing Strings , 17 Casing Description String 0... String 10 ... Top (ftKB) Sat Depth (4... Sat Depth (TVD( ... String Wt... String ... String Top Thrd HANGER. za R CONDUCTOR 16 15.062 34.0 108.0 108.0 62.50 H WELD - Casing Description String 0... String ID ... Top (K103) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 33.0 2,443.0 2,222.7 45.50 K - 55 BTC Casing Description String 0... String ID ... Top (48(8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 31.1 9,038.0 15.50 L -80 BTC 5.5 "x3.5" Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 29.2 8,172.5 3,717.0 9.30 L -80 EUE8rdABMOD Completion Details Top Depth (TVD) Top Inc! Nornl... ' Top (fd(8) (ftKB) ( °) item Descrption Comment ID (In) 29.2 29.2 -13.84 HANGER CIW GEN IV TUBING HANGER 3.030 513.7 513.7 0.33 NIPPLE CAMCO 'DS' NIPPLE w /NO GO PROFILE 2.875 8,107.3 3, 688.3 65.65 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 8,154.7 3,708.1 63.85 LOCATOR BAKER NO GO LOCATOR 2.950 8,155.5 3,708.4 63.81 SEAL ASSY BAKER 80-40 GBH SEAL ASSEMBLY - STUNG INTO CASING 3.5" 2.990 PRODUCTION CASING DoNDUC7oR, Notes: General & Safety LOA End Date Annotation 12/18/2004 NOTE: SIDETRACKED WELL 1H-05 RENAMED "1 H -105" 5/27/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NIPPLE, 514 !I SUACE, _ 33 - - -° GAS LT, 2,4 _ SLEEVE, 8,107 ' LOCATOR, 8,155 SEAL ASSY, 8,156 1 fi Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top (411(8) (RKB) (°) Make Model (in) Sate TYpe Type (In) (psi) Run Date Com... 1 2,491.8 2,251.3 55.32 CAMCO KBG - 2 - 9 1 GAS LIFT SOV DKC 0.000 0.0'12/18/2004 PRODUCTION 5.5Y3.5 31 -9,038 TD (1H-105), ° 9,038 • • Page 1 of � Schwartz, Guy L (DOA) From: NSK Well Integrity Proj [N 1 878@conocophillips.com] Sent: Monday, November 15, 2010 9:06 AM To: Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj Subject: RE: AOGCC Suspended well Inspection minor Follow up. _l 05 Guy, Here is what DHD found with 1 H -105. Trouble shoot T pressure T /I/O/00= SI - 0/50/170/0. Rep laced gauge on tree can verified T on vac. ..Charged with lift gas ( 5 min ) T /I /O /O= SI 525/50/170/0. Torqued and cleaned leaking GN on OC -PO. There are no records of a bleed, however the ambient temperature is significantly cooler now. DHD did add a —500 psi gas cap to the well. Let me know if you have any additional questions MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. NOV 3 0 2010 Office (907) 659 -7043 Cell (907) 943 -1687 From: NSK Well Integrity Proj Sent: Wednesday, November 10, 2010 10:06 AM To: 'Schwartz, Guy L (DOA)' Subject: RE: AOGCC Suspended well Inspection minor Follow up. Guy, I've requested the Problem Wells Supervisor schedule DHD to bleed 1 H-1 05's tubing to zero and perform a documented 1 hr build up test. The problem Wells Supervisor will forward you the data in the next few days. Perry Klein Well Integrity Projects 907.659.7043 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, October 28, 2010 3:07 PM To: NSK Well Integrity Proj Subject: RE: AOGCC Suspended well Inspection minor Follow up. mi, 11/15/2010 Page 2 of * `l.- I am still plugging through some 404's for Suspended wells. 11-1-105 has 1075 psi on the tubing. Has it been bled and documented ?? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Thursday, October 21, 2010 10:47 AM To: Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj Subject: RE: AOGCC Suspended well Inspection minor Follow up. Guy, Attached are TIO plots to follow up with the Suspended well 10 -404's for 2T -04 ( D 186-143),2T-11(186-097), and 2A -07 (PTD 184 -064). 2T -04 and 2A -07 bled to +0 and stayed there. 2T -11 has a small amount of c mmunication. Please let me know if you would like more information to close the 10 -40 Thank you MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 From: Schwartz, Guy L (DOA) [ma ilto:guy.schwa @alaska.gov] Sent: Wednesday, September 29, 2010 4:14 P To: NSK Well Integrity Proj Subject: RE: AOGCC Suspended well Insp ion minor Follow up. MJ, Thanks ... it appears a couple of the w s below have pressure communication .... 2T -04 and 2T -11. Would like to have more data on these two wells' order to determine how severe the leaks are and the source( flowline or downhole). I realize these are on th subsidence workover /watchlist already and more work is planned to further suspend these wells. Additionally, could you perform bleed off of 2A -07. It had 200psi tubing and 600 psi IA pressure. Thanks, Guy Schwartz Senior Petroleum Engine AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Monday, September 27, 2010 5:58 PM 11/15/2010 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 18, 2010 Commissioner Dan Seamount 2 3 ��1 C r Alaska Oil and Gas Conservation Commission `, 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 "IND Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River West Sak 1H -105 (PTD 204 -228) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River West Sak well 1H -105 (PTD 204 -228). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, r i Mj4:oveland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair well r Plug Perforations r Stimulate r OtherF Suspended well inspection Alter Casing r Pull Tubing ( Perforate New Pool r Waiver r Time Extension r Change Approved Program 1 Operat. Shutdown F_ Perforate r Re - enter Suspended r 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen r Exploratory r � 204 -228 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphi r Service 50- 029 - 20727 -01 7. Property Designation: 8. Well Name and Number: ADL 25639 ALK 464 ` 1 H -105 9. Field /Pool(s): .� Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 9038 feet Plugs (measured) NONE true vertical 4297 feet Junk (measured) NONE Effective Depth measured 8946 feet Packer (measured) 8156 true vertical 4220 feet (true vertucal) 3708 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 108 108 SURFACE 2410 10.75 2443 2223 PRODUCTION 8149 5.5 8182' 3721 PRODUCTION 856 3.5 9038' 4297 u r Perforation depth: Measured depth: NONE NUJ` ` {jf�} True Vertical Depth: NONE Tubing (size, grade, MD, and TVD) 3.5, L - 80, 8155 MD, 3708 TVD Packers & SSSV (type, MD, and TVD) SEAL ASSY - BAKER 80 - 40 GBH SEAL ASSEMBLY @ 8156 MD and 3708 TVD No SSSV 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after proposed work: 1 Copies of Logs and Surveys run Exploratory r Development r Service F 15. Well Status after work: SuSPGr-Ytcl , CV' Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WAG r GASINJ r WINJ r SPLUG r 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Contact MJ Loveland /Perry Klein Printed Name MJ Loveland/Perry Klein Title WELL INTEGRITY SUPERVISOR Signature Phone: 659 -7043 Date s l' /ate/ RM'Mb SEP 2 3 20 Form 10 -404 Revised 7/2009 Submit Original Only Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk Riv U WSak 1 H -105 1 Field /Pool: KRU /West Sak Oil Pool Permit # (PTD): 204 -228 Sundry 304 -389 API Number: 50029207270100 Operator: ConocoPhillips Date Suspended: 12/18/2004 Surface Location: Section: Twsp: T12N Range: R10E UM Nearest active pad or road: KRU DS1 H Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: 670di? Pad or location surface: e-&,yyU tSA? L&rz, Location cleanup needed: 1W Pits condition: 1//4- Surrounding area condition: 6ck Water /fluids on pad: /1/0 Discoloration, Sheens on pad, pits or water: / Samples taken: /1/0 Access road condition: Photographs taken (# and description): Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: ,,V xvew AW- �GO3,i� Bf X '/'r 70 a"A M 'K Cellar description, condition, fluids: Rat Hole: Wellhouse or protective barriers: tA1X( -r4; Al#. Well identification sign: ll/T fin/ 7XIr I L Tubing Pressure (or casing if no tubing): J A Annulus pressures: Wellhead Photos taken (# and description): Work Required: 1 Y1 old 0"o Operator Rep (name and signature): ' AOGCC Inspector: PD9 AZQV Other Observers: Inspection Date: ZzQlb AOGCC Notice Date: Time of arrival: Time of Departure: Site access method: Il KUP 1H-105 ConocoPFuihps S ! 'SSV: bo� APIIUValtes FIeldName WBIISbtU6 I MaxAnglle BMD TD 002 ' 00292072701 KUPARUK RIVER UNIT PROD 79.21 7,595.96 9,038.0 ment H2S (pp-) Date Annotation End Data KB-Grd (ft) Rig Release Date ••• Well C-onfl : - iFF105 5/27Y20101:09:03PM NIPPLE Last WO: 37.78 5/18/1982 Schematic - AcNel Annotation Depth (ftKB) End Date Annotation Last Motl ... End Date Last Tag: Rev Reason: UPDATE TO 9.0, QC Imosbor 5/27/2010 Casing Strings ,. Casing Description Strang 0... String I tTop(ftKB) ) Set Depth (f... Set Depth (ND) ... String WL.. String ... String Top Thrd HANGER, 29 CONDUCTOR 16 15.0 108.0 108.0 62.50 H-40 WELD Casing Description String 0... String I) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Third SURFACE 103/4 9.79 2,443.0 2,222.7 45.50 K - BTC Casing Description String 0... String I) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Third PRODUCTION 51/2 4.95 9,038.0 15.50 L - BTC 5.5 "x3.5" Tubing Strings Tubing Description String 0... String ID ITop (ftKB) Set Depth (f... Set Depth (TVD) ... string Wt... string ... String Top Thrd TUBING 31/2 2.992 29.2 8,172.5 3,717.0 9.30 L -80 EUE8rdABMOD Com ietion Details Top Depth (TVD) Top Incl Nomi... Top (ftKB) (ftKB) 0 Item Description Comment ID (in) 29.2 29.2 -13.84 HANGER CIW GEN IV TUBING HANGER 3.030 513.7 513.7 0.33 NIPPLE CAMCO'DS' NIPPLE w /NO GO PROFILE 2.875 8,107.3 3,688.3 65.65 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 8,154.7 3,708.1 63.85 LOCATOR BAKER NO GO LOCATOR 2.950 8,155.5 3,708.4 63.81 SEAL ASSY BAKER 80-40 GBH SEAL ASSEMBLY - STUNG INTO CASING 3.5" 2.990 PRODUCTION CASING Notes: General & Safe CONDUCTOR, End Data Annotation 34 -108 12/18/2004 NOTE: SIDETRACKED WELL 1H -05 RENAMED "1H -105'• 5/27/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NIPPLE, 514 SURFACE, 33 -2,443 GAS LI FT, 2,492 SLEEVE, 8,107 LOCATOR, 8,155 SEAL ASSY, 8,156 Mandrel Details Top Depth Top Port (T De ) Incl OD Valve Latch Sim TRO Run Stn Top (fti(B) (ftKB) ( ") Make Model (in) sary Type Type (in) (psi) Run Deb Corr... 11 2,491.81 2,251.3 55.32 CAMCO KBG -2 -9 I 1 GAS LIFT ISOV DKG3 0.000 0.0112118/2004 v PRODUCTION 5.5'X3.5', 31 -9,038 TD (1 H -105); 9,038 ALAWM �^ "��,•,• D5••• "-ter- o 1- ur ,1aElA RpW Q El2W0+ i DRILL SITE 1H I i e v 1a SCALE a 12 n so a rt 1s a 100 0 50 100 + E roap z 1 "= 100' �) o �� 1 f 7 RESERV PIT �I I LEGEND p THERM051PNON5 ff 0 WELLS + F + RESER4 PIT + E «m 20 19 22 V 10 15 1 2 3 d SM OILY W ASTE PIT + + + + + + E s«o➢ i x x x LOVNBEURY + + + + + + E INq ! IDC. FORM: SSIZE w.a�. DRAWN: DESIGN: ECM N0: Y AREA: 1H MODULE: )= UNIT: DI 2 4/10/10 Add thamlos ons 1 k 14 M Ai NRB piEGCEO MEH APPROVAL — CC NO COIIOCQPhilli IS PLOT PLAN Alaska, Inc" 1 1/30/10 U tad Therm on and Well Asbu ➢t locations NRB FC SCALE DATE: CARD nUDIAME: 48 NO: SUB JOB N0: DRAWING N0 PART: REt REV DATE REVISION BY cw �B PROJ 1" = 100' 3/11/09 SEH PLT PLN 3/11/09 NS`DK 0000 DS1H PLOT PLAN 1 OF 1 2 ,ate AO ( _ f •< aar. r: ; yam r {`} er 1 ..k� lJp • y t 1 H -105 PTE) 204228 ConocoPhillips Alaska, Inc is photo is copyrighted by Conoco Phillips Alaska. Inc. and ' annot be released or published ithout express written consent f Conoco Phillips Alaska C- C i i 1 H -105 PTD 204228 c ConocoPhillips Alaska, Inc his photo is copyrighted by ConocoPhillips Alaska, Inc. and annot be released or published ithout express written consent f ConocoPhillips Alaska I D -126 PTD 198-108 w ConocoPhillips Alaska, Inc his photo is copyrighted by ConocoPhillips Alaska, Inc. and annot be released or published ithout express written consent Conoco Philli s Alaska y . fill e � N M HU H at are a . • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 12, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: • RECEIVED FED 1 6 2010 Alaska Q~ & 6a~ Ceps. Comrmssion Anchera w , V Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped February 9~' &10`", 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off ..~ Report of Sundry Operations (10-404) Kuparuk Field Date Pad 1 H 1.1 R 1 R Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ff bbls ft al 1 H-15 50029223280000 1930030 23" n/a 23" n/a 4.2 2/9/2010 1 H-16 50029223150000 1921310 25" n/a 25" n/a 4.8 2/9/2010 1 H-19 50029223120000 1921280 22" n/a 22" n/a 4 2/10/2010 1 H-20 50029223130000 1921290 25" n/a 25" n/a 4.6 2/10/2010 1 H-22 50029223640000 1930600 22" n/a 22" n/a 4.2 2/9/2010 1 H-105 50029207270100 2042280 3" n/a 3" n/a 3.4 2/9/2010 1J-180 50029233290000 2061500 18" n/a 18" n/a 3.8 2/9/2010 1J-182 50029233210Q00 2061320 17.5" n/a 17.5" n/a 3.6 2/9/2010 1 R-21 50029222110000 1911130 24" n/a 24" n/a 4.6 2/9/2010 • • ~~~ ._ _~ -~.. MICR{3FILMED 03/01 /2008 DD Nt~T PLACE 4' _tlk ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Viicrofilm M~rker.doc gJ~~7 DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2042280 Well Name/No. KUPARUK RIV U WSAK 1H-105 Operator CONOCOPHILLlPS ALASKA INC 5 YlcJ. Co D,,-c- ^~ 6 '1 API No. 50-029-20727-01-00 MD 9038 /' TVD 4297./ Completion Date 12/18/2004 __ Completion Status SUSP Current Status SUSP UIC Y ----_.-._------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GRlRes, Neutron/Density/Porosity (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr . Data Digital Dataset Log Log Run Interval OH/ :z Med/Frmt Number Name Scale Media No Start Stop CH Received Comments -_...~._.._--_.- C Pds 12843 Formation Tester 1 7695 8753 12/31/2004 MODULAR FORMATION DYNAMICS ~g f TESTER/TLC/ACTS/GR Formation Tester Col 7695 8753 12/31/2004 MODULAR FORMATION DYNAMICS TESTER/TLC/ACTS/GR/D ~ SN 12843 D Asc Directional Survey 2366 9038 1/27/2005 IIFR ED C Pdf 12948 Rate of Penetration 2438 9038 Open 1/27/2005 MWD/ROP/DGRlEWR dD D Pds 12949 Gamma Ray 2350 9000 1/27/2005 MWD/GRlEWR4/CNP/SLD/ ROP/ACALNRI Rpt 12949 Gamma Ray vt". l~~H_~ 2350 9000 1/27/2005 MWD/GRlEWR4/CNP/SLD/ ROP/ACALNRI Well Cores/Samples Information: Sample . Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y 0 Chips Received? ~ Daily History Received? ~/N Œ!YN Formation Tops Analysis Received? ~ -~._~-~--~----_._- Comments: DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2042280 Well Name/No. KUPARUK RIV U WSAK 1H-105 Operator CONOCOPHILLlPS ALASKA INC MD 9038 TVD 4297 Completion Date 12/18/2004 Completion Status SUSP Current Status SUSP UIC Y Compllan" Rov:we:BY' -__~~= ......... . Date: API No. 50-029-20727-01-00 -rv--- 1 ------- /0 ~~~7 . . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 H-05A pear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 2,366.29' MD 2,434.16' MD 9,038.00' MD . (if applicable) o 1-Jan-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~7 J \~)t~ ~'_. Signed v -. /~71 Î '¡ J, ~~i. fill f U//J'^-/ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Atlachment(s) ) 6 vI - tÀ tÀ6 . ConocóÃ,illips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 January 17, 2005 RECEI\/E. JAN 2 1 Z005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oi! f}¡, Subject: Well Completion Reports for 1 H-1 05 (APD 204-228 I 304-389) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached revised Well Completion Report for the recent drilling operations of the West Sak wells 1 H-1 05. We have changed the status of the well to suspended. This well is completed as a water injector but will not be placed in service for a couple of years. The cement bond log and perforations will be done prior to being place in service. We request all data from 1H-105 and 1H-05A to be held confidential as required by law. Digital and paper copies of logs will be forthcoming from the vendor under separate cover. This data and any other data provided by the LWD vendor should be considered confidential. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. \ ·'C~-~"·--ì·-\.;:::.:~~_ \. .-" ...--.. .~,._--- 5¡j~&L1 .IrfJŠ;b~. .. ...~~~"." j, ~,;¡...~- r;::lll I}/' ()~Io ¡h NUø.f~" ..J~~ R...e.'^~ ~ /II~Ç~ /iI-Ie£; p£ J1 (J YKb¿,y- A tJ,A ..... ?t'~ S'vf!l¡.,e <::;;>" jJl) /./Z,·-r, Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT Iskad AtKA OIL AND ~:~T~g~S~':;:;:ON COISSION R~~;l Z005 WELL COMPLETION OR RECOMPLETION REPQ~li~hº,Giinrm;¡Si:\n Oil 0 Gas U Plugged 0 Abandoned 0 Suspended 0 WAG 0 1b. Well clasf~¡;d'íJragH 20AAC 25.105 20AAC 25.110 Development 0 . Exploratory 0 No. of Completions _ Other Service 0 Stratigraphic TeU 12. Permit to Drill Number: 1 a. Well Status: GINJ 0 WINJ 0 WDSPL 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 5. Date Comp., Susp., or Aband.: December 18, 2004 6. Date Spudded: December 6, 2004 7. Date TD Reached: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 528' FNL, 803' FEL, Sec. 33, T12N, R10E, UM At Top Productive Horizon: 1734' FNL, 510' FEL, Sec. 27, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549543 y- TPI: x- 554773 y- Total Depth: x- 555080 y- 18. Directional Survey: Yes 0 NoU Zone- 4 Zone-4 Zone-4 December 11, 2004 8. KB Elevation (ft): 34' RKB 9. Plug Back Depth (MD + lVD): 8946' MD /4220' TVD 10. Total Depth (MD + lVD): 9038' MD / 4297' TVD Total Depth: 1994' FNL, 820' FEL, Sec. 27, T12N, R10E, UM 21. Logs Run: GRlRes, NeutronlDensity/Porosity (2425'-9038') 22. CASING SIZE WT. PER FT. GRADE 16" 62.5# H-40 10.75" 45.5# K-55 5.5" 15.5# L-80 3.5" 9.3# L-80 5980175 5984025 5984287 11. Depth where SSSV set: Landing Nipple @ 514' 19. Water Depth, if Offshore: N/A feet MSL '-r/vJ~ CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD TOP BOTTOM TOP BOTTOM Surface 108' Surface 108' Surface 2425' Surface 2259' Surface 8182' Surface 3721' 8182' 9038' 3721' 4297' HOLE SIZE 24" 13.5" 8.5" 8.5" 23. Perforations open to Production (MD + lVD of Top and Bottom Interval, Size and Number; if none, state "none"): none 26. Date First Production Date otTest Hours Tested Flow Tubing press. psi 27. Casing Pressure 24. SIZE 3.5" 204-228 / 304-389 13. API Number: 50-029-20727-01 14. Well Na~nd Number: I ¡J.-t O~ 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool ~ 16. Property Designation: ADL 25639 17. Land Use Permit: ALK 464 20. Thickness of Permafrost: z. <13'1- / ß1b 2Z/"'j l¡V'þ .-61:> I . z..l ~£'.;:::.s CEMENTING RECORD AMOUNT PULLED 250 sx AS II 1000 sx ASIII, 250 sx AS II 596 sx LiteCrete (included in above) TUBING RECORD DEPTH SET (MD) 8172' PACKER SET none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) shut-in Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL WATER-BBL GAS-MCF WATER-BBL 24-Hour Rate -> CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Form 10-407 Revised 12/2003 NONE CONTINUED ON REVERSE CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - API (corr) f-êë;;¡;:r~iõN-1 i - I~;,I£';>~ ! \lø,>·r"c;., ¡ j . , ~ ! -- . ._,.:: 1 Gç~ RB£JMS tsf-L ,IAN ~ 1 2005 28. GEOLOGIC MARKER. 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 H-1 05 West Sak B 8435' 3854' n/a Note: refer to MDT and cuttings descriptions for oil and gas shows 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Nal'fle Randv Thomas Title: Signature ~~~Phone Kuparuk DrillinQ Team Leader MS (,-if S7.) Date I. ( ,. ~. . ¿I:} . ~1-5 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 8ÝevtL-- ~ ~P/~~~~~~ ae- k. tv.Ld ~ ~ 4c?7 ÆÞó ~/-/~o/ . 4Dtf ~1.'Vl'ÓÝ 201- 2. 2. <¿ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West ih Avenue, Suite 100 Anchorage, Alaska January 19, 2005 RE: MWD Formation Evaluation Logs IH-05A, AK-MW-3424644 LDWG LWD DataJ)igital Log Images API#: 50-029-20727-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: /-- 2-7 - O~ Sig~d~ ... ,;{ t) '-I ~ ;JJ..3 . . '~~!Æ~E lID} !Æ~!Æ~'ß!Æ II ~1/ASIiA. OIL AND GAS CONSERVATION COMMISSION / I FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Scott Rennie West Sak Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk IH~105 Sundry Number: 305-005 Dear Rennie: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superio 0 unless rehearing has been requested. DATED thisÆ day of January, 2005 Enc!. )29W . . c:!t)~ 22? WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corum. Attn.: Helen Wannan 333 West ih Avenue, Suite 100 Anchorage, Alaska January 13, 2005 RE: MWD Formation Evaluation Logs IH-05A, AK-MW-3424644 I LDWG formatted Disc with verification listing. API#: 50-029-20727-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: · t<4-- .. . Scott Rennie GKA Satellites Engineer GKA Reservoir Planning 41 ' . ~ ConocoPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4929 January 10, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 RE.CE JAN 1 2 l005 Ala3k~¡ ()i! & l~n!il1on¡UU Subject: Application for Sundry for 1 H-1 05 (APD 204-228) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry to change the name of the West Sak well 1 H-05A to 1 H-1 05. If you have any questions regarding this maUer, please contact me at 263-4929. Sincerely, ~,/->4 ....."'~~ ~. ..,,'" ~ /~~" '.'~~) , S. Rénnie GKA Engineer GKA Reservoir Planning SR/skad '" 1. Type of Request: ~~ RECr\'~3 . STATE OF ALASKA . //~ . ..... 15 ALASKA Oil AND GAS CONSERVATION COMMISSION ;(6- JAN I :2 2005 APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown 0 o o o Alter casing 0 o o Repair well 0 o Abandon Suspend Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 34' RKB 8. Property Designation: ADl 25639 I ALK 464 11. Total Depth MD (ft): 9038' Casing Structural Conductor Surface Intermediate Production Total Depth TVD (ft): Effective Depth MD (ft): 4297' 8946' Length Size Plug Perforations Perforate 0 o Alaska Oil & Commissiol Variance c5lìt.l~~~JïIa~ DiSPOsC] Time Extension 0 Other o Stimulate Perforate New Pool Re-enter Suspended Well 0 Name Change 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: Exploratory 0 Service 0 204-228 1 304-389 6. API Number: 50-029-207?7 -01 9. Well Name and Number: 1 H-1 05 10. Field/Pools(s): Kuparuk River Field 1 West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 4220' MD rvD Burst Collapse 78' 16" 108' 2425' 10.75" 2425' 5.5" / 3.5" 8182' 1 9038' Plug Integrity 0 BOP Test 0 108' 2259' 3721' /4297' Perforation Depth TVD (ft): None Packers and SSSV MD (ft): 1/14/2005 Date: Mechanical Integrity Test 0 \'~ \ l-\C) l Form 10-403 Revised 12/2003 Tubing Size: 3.5" Tubing Grade: l-80 Liner Perforation Depth MD (ft): None Packers and SSSV Type: no packer, Camco 'DS' Landing Nipple 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Scott Rennie Title West Sak Engineer Signature ~~ " Phone 263-4929 COMMISSION USE ONLY Tubing MD (ft): 8172' landing nipple @ 514' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Service 0 Plugged 0 WINJ 0 Abandoned C WDSPL 0 Contact Scott Rennie @. 263-4929 Date J;"", L t ) 2..00 :s- Conditions of approval: Notify Commission so that a representative may witness Other: Sundry Number: ..3oS-ù06- Location Clearance 0 RBDMS 8Ft ~~ 8 Z005 COMMISSIONER BY ORDER OF THE COMMISSION D're Ik/~ II t~< I L INSTRUCTIONS ON REVERSE Submit in Duplicate . . . Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Phone: (907) 279-1433 Fax: (907) 276-7542 Fax Transmission The information contained in this fax is confidential and/or privileged. This fax is intended to be reviewed initially by only the individual named below. If the reader of this transmittal page is not the intended recipient or a representative of the intended recipient, you are hereby notified that any review, dissemination or copying of this fax or the information contained herein is prohibited. If you have received this fax in error, please immediately notify the sender by telephone and return this fax to the sender at the above address. Thank you. To: s¥~~, Fax#: From: ~ d-&...- *~ Phone #: Date: I~Y:/OS- Subject: Pages (including cover sheet): d-- Message: If you do not receive all the pages or have any problems with this fax, please call for assistance at (907) 793-1223. . Conoc6Phillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 January 11, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECE\VED JAN 1 'L 2005 , f' "mm¡~~¡º\I I,. .. Q.." Q. Î'a¡¡ Cmu;, \../.. A\~$...a 1\ \)!. '" Þ-nchorage Subject: Well Completion Reports for 1 H-1 05 (APD 204-228 I 304-389) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the West Sak wells 1H-105. ,/ If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, ~~\~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT Iskad RE~ C~E,~'VED .. STATE OF ALASKA A···· L-J . A~ OIL AND GAS CONSERVATION COrB'SSION JAN 1 '2 'l005 WELL COMPLETION OR RECOMPLETION REPOR! A~P1i~:g:q"mm¡ss¡a!i 011 [2] Gas U Plugged 0 Abandoned 0 Suspended 0 WAG DA a¡¡1We~1áS$:'"' 20AAC 25.105 20AAC 25.110 Development ~Iwrí!ge Exploratory 0 WINJ 0 WDSPL 0 No. of Completions _ Other _XXX Pre-Produced Injector 0 Stratigraphic TeU ber: 1a. Well Status: GINJ 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 528' FNL, 803' FEL, Sec. 33, T12N, R10E, UM At Top Productive Horizon: Total Depth: 1994' FNL, 820' FEL, Sec. 27, T12N, R10E, UM 1734' FNL, 510' FEL, Sec. 27, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549543 I y- TPI: x- 554773 y- Total Depth: x- 555080 y- 18. Directional Survey: Yes [2] NoU 21. Logs Run: GRlRes 22. CASING SIZE WT. PER FT. 62.5# 45.5# 15.5# 9.3# GRADE H-40 K-55 L-80 L-80 16" 10.75" 5.5" 3.5" 5980175 ' 5984025 5984287 Zone- 4 Zone- 4 Zone- 4 5. Date Comp., Susp., or Aband.: December 18, 2004 6. Date Spudded: December 6, 2004 -' 7. Date TD Reached: December 11, 2004 8. KB Elevation (ft): 34' RKB 9. Plug Back Depth (MD + TVD): 8946' MD /4220' TVD 10. Total Depth (MD + TVD): , 9038' MD /4297' CASING, LINER AND CEMENT G RECORD SETTING DEPTH MD SETTIN DEPTH TVD TOP BOTTOM TOP BOTTOM Surface 108' Surf ce 108' Surface 2425' S 2259' Surface 8182' 3721' 8182' 9038' 4297' 23 Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): none 26. 'Date First Production 24. SIZE 3.5" / -' 204-228 / 3 -389 13. API Nu 50-029-20727-01 14. W I Name and Number: .viJ 1 H-J.DB' ø-t): 5. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25639 17. Land Use Permit: ALK 464 20. Thickness of Permafrost: feet MSL 7' t.I~ Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WA TER-BBL press. psi 24-Hour Rate -> 27. CORE DATA Brief description of lithology, porosity, actures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "n e". NONE HOLE SIZE 13.5" 243&/" H1þ 2. Z-I "t" -rv'-ð 11>~ I""Z.~''" CEMENTING RECORD AMOUNT PULLED 24" 250 sx AS II 1000 sx ASIII, 250 sx AS II 596 sx LiteCrete (included in above) 8.5" 8.5" TUBING RECORD DEPTH SET (MD) 8172' PACKER SET none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a PRODUCTION TEST thod of Operation (Flowing, gas lift, etc.) shut-in Production for OIL-BBL GAS-MCF 'Date ofTest Hours Tested Form 10-407 Revised 12/2003 WATER-BBL CONTINUED ON REVERSE CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - API (corr) 28. GEOLOGIC MARKE. 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 H-1 05 West Sak B 8435' 3854' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed ~. Ra,ndv Thqm-S§. Title: Signature ( ~ \ ~hone Kuparuk DrillinQ Team Leader L. ,,"5- 6-8 ~ (;) Date \ ((r/or Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 H-05 1 H-05 ROT - SIDETRACK Doyon 14 Start: Rig Release: Rig Number: 12/1/2004 12/18/2004 Spud Date: 4/26/1982 End: 12/18/2004 Group: 12/1/2004 14:00 - 15:00 From - To Hours Sub Code Code Date 12/2/2004 15:00 - 19:00 19:00 - 20:30 20:30 - 22:00 22:00 - 00:00 00:00 - 12:00 12:00 - 00:00 12/3/2004 00:00 - 03:30 03:30 - 08:00 08:00 - 12:00 12:00 - 17:00 17:00 - 21 :00 21 :00 - 22:30 22:30 - 00:00 12/4/2004 00:00 - 03:00 03:00 - 16:30 16:30 - 17:00 17:00 - 20:00 20:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 12/5/2004 00:00 - 01 :30 01 :30 - 02:00 02:00 - 07:30 07:30 - 09:00 09:00 - 10:30 10:30 - 13:00 13:00 - 14:00 14:00 - 20:00 20:00 - 21:00 21 :00 - 23:00 23:00 - 00:00 12/6/2004 00:00 - 03:00 1.00 MOVE DMOB MOVE 4.00 MOVE DMOB MOVE 1.50 MOVE OTHR MOVE 1.50 RIGMNT RGRP MOVE 2.00 MOVE OTHR MOVE 12.00 RIGMNT RGRP MOVE 12.00 RIGMNT RGRP MOVE 3.50 RIGMNT RGRP MOVE 4.50 RIGMNT RGRP MOVE 4.00 RIGMNT RGRP MOVE 5.00 RIGMNT RGRP MOVE 4.00 RIGMNT RGRP MOVE 1.50 RIGMNT RGRP MOVE 1.50 MOVE DMOB DE MOB 3.00 MOVE DMOB DEMOB 13.50 MOVE MOVE MOVE 0.50 MOVE MOVE MOVE 3.00 MOVE MOVE MOVE 1.50 MOVE RURD MOVE 1.50 MOVE POSN MOVE 1.00 MOVE POSN MOVE 1.50 MOVE RURD RIGUP 0.50 WELCTL NUND RIGUP 5.50 WELCTL NUND RIGUP 1.50 DRILL OTHR RIGUP 1.50 WELCTL EQRP RIGUP 2.50 DRILL PULD RIGUP 1.00 DRILL SFTY RIGUP 6.00 DRILL PULD RIGUP 1.00 DRILL RIRD RIGUP 2.00 WELCTL BOPE RIGUP 1.00 WELCTL BOPE RIGUP 3.00 WELCTL BOPE RIGUP 03:00 - 05:00 2.00 DRILL PULD RIGUP 05:00 - 06:30 1.50 DRILL OTHR RIGUP 06:30 - 08:30 2.00 WELCTL BOPE RIGUP 08:30 - 09:00 0.50 WELCTL BOPE RIGUP 09:00 - 10:00 1.00 CASE DEQT RIGUP 10:00 - 10:30 0.50 DRILL PULD INTRM1 PJSM - Skid rig floor from drlg position to move position - Clear cellarof all equipment PJSM - with pad operator - move off well - turn and position on pad Place BOP stack on stand - Remove from cellar Remove cellar spreader beam - Install space heaters and weatherize PJSM - Skid rig floor from move position to drlg position for repair work Change out Left rear jacking cylinder for moving system Remove left / Right tires from sub base - take out jack cylinder from Frame assy - Clean frame and cellar area - Prep for new cylinder Con't prep new jack assembly for installation Install jack assembly Position tires and axel in wheel well Bolt axel and jack assembly together Reinstall hydraulic hoses and manifolds Test jacking and moving system - check for leaks Move rig off double matts - move substructure spreader beam into position Install BOP in cellar - Install boosters Move rig from Milne pt B Pad to KOC Turn rig around @ KOC Move rig from KOC to 1 H Pad Remove rear booster wheels - Install substructure doors - heaters Move rig over 1 H-05A well - Shim substructure PJSM - Skid rig floor from move position to drlg position - Spot rock washer Rig up rig floor - Rig up rock washer and tiger tank - Accept rig @ 01 :30 hrs on 12/5/2004 Nipple down dry hole tree Nipple up BOP's Change out 4" savor sub to 5" savor sub -JAWS - Bell guide on top drive Switch top rams 27/8" x 5" to the bottom with 3 1/2" x 6" bottom rams to the top Pick up 5" drill pipe from pipe shed and stand back in derrick Pre-Spud meeting with Conoco Phillips personnel and rig / service personnel Con't picking up 5" drill pipe from pipe shed and stand back in derrick Re-berm rockwasher with handy-berms Rig up to test BOP's Test BOP's - Test annular to 250 low 5 mins - pressure to 2300 psi - choke hose failed blew hole in side of hose - Con't pressure test top rams to 250 I;ow 5 mins 3000 high 5 mins Test BOP's - Test lower rams to 250 low 3000 high 5 mins each - Test upper /Iower IBOP - Kill manual - Kill HCR - Floor safety valves - 250 low 3000 high for 5 mins each Con't Pick up 5" drill pipe from pipe shed and stand back in derrick Change out choke hose Con't test BOP equipment - Choke manifold - Choke manual valve - Choke HCR - 250 low 3000 high 5 mins each test - BOP tested sucessful - Chuck Scheve with AOGCC waived witness of BOP test Rig down test equipment - Pull test plug - Install wear ring - Close annulus valve Test 10 3/4" surface casing to 1500 psi for 30 mins - Recorded on chart Moblize BHA Printed: 1/10/2005 1:32:30 PM · Make up BHA Single in 5" dp from 270' to 740' Displace freeze protection from well bore - Surface test MWD - Good test RIH from 740' to 1212' PJSM - on stripping drill - Conduct Stripping drill PJSM - On well kill drill - Conduct Well kill drill D-5 Blow down Choke manifold - Choke line - Kill lines Con't RIH from 1212' to 1900' Wash from 1900' to 2200' Tag hard cement @ 2200' - Drill cement with 466 GPM - 15 to 20k WOB - 60 RPM - TO 4K - PP 1100 psi - Drlg Rap 80 fph - to 2425' Directional Drill from 2425' to 2435' - ROP 80 fph with WOB 10K - From 2435' to 2475' - Rap 400 fph with WOB 10K - RPM 60 - TO on 4K - off 4K - GPM 400 - PP on 1100 - OFF 1040 - PU 105K - SO 95K - ROT 100K 1.50 DRILL CIRC INTRM1 PJSM - Displace we II bore with 9 ppg FIe-Pro drilling fluid - Pump Hi-Vis spacer - Follow with 9 ppg Flo-Pro RPM 60 - GPM 400 - pp 1000 psi - TQ 4 - Flush kill and choke lines - flush surface equipment - Pull up into casing Rig up lines for FIT Preform FIT - MW 9 ppg - Surface pressure 340 psi - MD 2425 - TVD 2224' - EMW = 11.94 Directional Drill from 2475' to 2894' - WOB 12 - GPM 450 - PP on 1230 - off 1060 - RPM 60 - TO on 4.5K - off 3.5K - PU 1 05K - SO 90K - ROT 100K CBU 1.5 X for BHA change - GPM 450 - PP 1150 - RPM 60 - TO 4.5K Pump out to shoe from 2894' to 2425' - Pump at drlg rate - Monitor well, pump dy job, POOH to BHA. Stand back flex collars, down-load MWD, laydown kick off BHA. M/U BHA, up-load and test MWD, down-link manifold 105 SPM@800 psi, load source into MWD. TIH to 2,365', perform A-Cal calibration @ 2,495', cont. RIH to 2,738'. Wash/ream from 2,738' to 2,894', warm bearings on GEO-pilot. Directional drill from 2894' to 3681'MD 2673'TVD - WOB 15 - GPM 450- PP on 1250 - off 1100 - RPM 140 - TO on 7K - off 4.5K - P/U 120K- S/O 90K - ROT 105K, ADT= 5.83 hrs. Drilling from 3681 '-4180' MD. Drilling from 4030' to 4180' very slow. Varied WOB from 5K - 30k. RPM 160 with 5K - 1 OK ftlbs of torque. PU 120K Slack Off 90K Rot 105K. ADT= 9.97 Pump out of hole to 10-3/4" shoe at drilling rate. Hole ratty dragging 15 to 20K over from 3800' to 3200'. Monitor well at 10-3/4" shoe. Pulled out of hole to BHA. Stand back BHA and remove sources from MWD. Download MWD. Pulled bit to floor and broke out bit. Bit damaged. UD Gee-Pilot. P/U new Gee-Pilot, M/U bit, M/U TM sub. Perform continuity test on MWD, up-load MWD, surface test Geo-Pilot, downlink MWD, test good, PJSM on nuke source and load same. RIH to 2,365' and fill DP. Slip and cut drill line, inspect brake bands and linkages, service rig, top-drive and crown section. Cont. RIH from 2,365' to 4,059', wash and ream from 4,059' to 4,180' and warm Geo-Pilot bearings. Trip in went well. Legal Well Name: 1 14-05 Common Well Name: 1 14-05 Event Name: ROT - SIDETRACK Contractor Name: Rig Name: Doyon 14 Hot..lrs Code Sub Phase Codé 12/6/2004 10:30 - 12:30 2.00 DRILL PULD INTRM1 12:30 -13:00 0.50 DRILL PULD INTRM1 13:00 - 13:30 0.50 DRILL CIRC INTRM1 13:30 - 14:00 0.50 DRILL TRIP INTRM1 14:00 - 15:00 1.00 DRILL SFTY INTRM1 15:00 - 16:00 1.00 DRILL SFTY INTRM1 16:00 - 16:30 0.50 DRILL OTHR INTRM1 16:30 - 17:00 0.50 DRILL TRIP INTRM1 17:00 - 18:00 1.00 DRILL REAM INTRM1 18:00 - 21 :00 3.00 DRILL DRLG INTRM1 21 :00 - 21 :30 0.50 DRILL DRLG INTRM1 21 :30 - 23:00 23:00 - 23:30 0.50 DRILL RIRD INTRM1 23:30 - 00:00 0.50 DRILL FIT INTRM1 12/7/2004 00:00 - 04:00 4.00 DRILL DRLG PROD 04:00 - 05:00 1.00 DRILL CIRC PROD 05:00 - 05:30 0.50 DRILL TRIP PROD 05:30 - 06:30 1.00 DRILL TRIP PROD 06:30 - 08:00 1.50 DRILL PULD PROD 08:00 - 11:30 3.50 DRILL PULD PROD 11 :30 - 13:00 1.50 DRILL TRIP PROD 13:00 - 14:00 1.00 DRILL REAM PROD 14:00 - 00:00 10.00 DRILL DRLG PROD 12/8/2004 00:00 - 07:30 7.50 DRILL DRLG INTRM1 07:30 - 09:30 2.00 DRILL TRIP INTRM1 09:30 - 10:30 1.00 DRILL OBSV INTRM1 10:30 - 13:30 3.00 DRILL PULD INTRM1 13:30 - 14:30 1.00 DRILL PULD INTRM1 14:30 - 16:30 2.00 DRILL DEOT INTRM1 16:30 - 17:30 1.00 DRILL TRIP INTRM1 17:30 -19:30 2.00 DRILL OTHR INTRM1 19:30 - 21 :00 1.50 DRILL TRIP INTRM1 Start: Rig Release: Rig Number: 12/1/2004 12/18/2004 Spud Date: 4/26/1982 End: 12/18/2004 Group: Printed: 1110/2005 1:32:30 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 H-05 1 H-05 ROT - SIDETRACK Doyon 14 Start: Rig Release: Rig Number: 12/1/2004 12/18/2004 Spud Date: 4/26/1982 End: 12/18/2004 Group: Sub Code 3.00 DRILL DRLG INTRM1 Cont. drilling from 4,180' to 4,406' MD-2,829' TVD, WOB - 4K, GPM- 550, PP - 1610 on & 1570 off, RPM -150, TO - 5-11 K on & 6K off, P/U- 135K, S/O - 80K, ROT - 105K, ADT= 2 hrs. Drilling rate sporadic-hitting hard stringers. 12.00 DRILL DRLG INTRM1 Drilled 8 1/2" hole per directional plan from 4,406' to 5,565' MD/3,100' TVD, ADT 9.73 hrs, 14K WOB, 150 RPM's, 125 SPM, 566 GPM, off btm pressure 1820 psi, on btm pressure 1840 psi, off btm torque 7-9K, on btm torque 8-11 K, up wt 150K, dn wt 75K, rot wt 105K, ECD at 11.4. 12.00 DRILL DRLG INTRM1 Drilled 81/2" hole per directional plan from 5,565' to 6,847' MD/3,372' TVD, ADT 17.35 hrs, 15K WOB, 150 RPM's, 125 SPM, 566 GPM, off btm pressure 2000 psi, on btm pressure 2100 psi, off btm torque 11 K, on btm torque 12K, up wt 175K, dn wt 75K, rot wt 11 OK, ECD at 10.8. 12.00 DRILL DRLG INTRM1 Drilled 81/2" hole per directional plan from 6,847' to 7,840' MD/3,590' TVD, ADT 25.51 hrs, 23K WOB, 140 RPM's, 130 SPM, 550 GPM, off btm pressure 1850 psi, on btm pressure 2000 psi, off btm torque 11 K, on btm torque 15.5K, up wt 180K, dn wt 70K, rot wt 115K, ECD at 10.85. 12.00 DRILL DRLG INTRM1 Drilled 8 1/2" hole per directional plan from 7,840' to 8,660' MD/3,980' TVD, ADT 34.02 hrs, 15K WOB, 120 RPM's, 120 SPM, 508 GPM, off btm pressure 2000 psi, on btm pressure 2100 psi, off btm torque 12K, on btm torque 15K, up wt 220K, dn wt 90K, rot wt 120K, ECD at 11.1. 6.50 DRILL DRLG INTRM1 Drill from 8660' to 9036' MD 4297' TVD. ADT 38.89 hrs. 20-25K WOB, 140 Rotary, 550 GPM at 2100psi off bottom pressure and 2500 psi on bottom pressure. Off bottom torque 11,000 fUbs and on bottom torque 15,000 ftlbs torque. Up weight 220K Down weight 90 K. 2.00 DRILL CIRC INTRM1 Circulated bottoms up 3 times and shakers were clean. 550 GPM at 2500 psi. Reciprocate and rotate pipe 125 rpm. 8.00 DRILL TRIP INTRM1 Pumped out of the hole at 450 gpm from 9038' to 3683'. Had packing off problems at 6200'-6040', 5550'-5480' and 4625'-4590'. Had to pull through packoff at 4620'-4590'. Packed off at 3683' Stopped pumping and pulled into shoe at 2425' with no problems. Monitor well - hole static, CBU 1 x, rot and recip at 450 GPM at 1,000 psi, 50 RPM with 4K torque. Service top drive and rig. RIH from 2,372' to 8,931' filling DP at 4,250', 6,130' and 8,000'. Wash to btm from 8,931' to 9,038' with no problems. CBU 2x, rot and recip staging pumps to 525 GPM. 125 RPM's with 14K torque. Displace hole with new 9.3 ppg FLO-PRO mud to a 60% dilution, for logging program, at 525 GPM. Cont displacing with new 9.3 ppg FLO-PRO for a 60% dilution. Flow check - negative. Pump out of hole from 9038' to 2400' with 150 gpm. Recorded PU and SO weights every 5 stands. Flow check well - negative. Circulated 1. 5 bottoms up at 450 gpm. Casing clean. Drop 2 3/8" rabbit down drill string. Pulled out of hole with 5" drill pipe to BHA. Stand back HWT and Jars. PJSM. Remove sources, lay down drill collars, download MWD and lay down Geo-Pilot and bit. Service Geo-Pilot Tool. Clear floor of excess tools and equipment. Spot Schlumberger wire line unit and mobilize tools. Held PJSM and singled in MDT tools. Checked tool continuity. Trouble shooting tools. All tools not powering up. 1218/2004 21 :00 - 00:00 12/9/2004 00:00 - 12:00 12:00 - 00:00 12/10/2004 00:00 - 12:00 12:00 - 00:00 12/11/2004 00:00 - 06:30 06:30 - 08:30 08:30 - 16:30 16:30 - 17:00 0.50 DRILL CIRC INTRM1 17:00 - 17:30 0.50 DRILL OTHR INTRM1 17:30 - 22:00 4.50 DRILL TRIP INTRM1 22:00 - 23:30 1.50 DRILL CIRC INTRM1 23:30 - 00:00 0.50 DRILL CIRC INTRM1 12/12/2004 00:00 - 00:30 0.50 DRILL DRLG INTRM1 00:30 - 05:00 4.50 DRILL TRIP INTRM1 05:00 - 06:00 1.00 DRILL CIRC INTRM1 06:00 - 06:30 0.50 DRILL TRIP INTRM1 06:30 - 08:30 2.00 DRILL PULD INTRM1 08:30 - 09:00 0.50 DRILL PULD INTRM1 09:00 - 11:00 2.00 LOG RURD INTRM1 11 :00 -13:00 2.00 LOG RURD INTRM1 13:00 - 13:30 0.50 LOG DEOT INTRM1 Printed: 1/10/2005 1:32:30PM - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 H-05 1 H-05 ROT - SIDETRACK Doyon 14 Sub Code Code Phase 12/12/2004 13:30 - 16:00 2.50 LOG RURD INTRM1 16:00 - 16:30 0.50 LOG RURD INTRM1 16:30 - 17:00 0.50 LOG RURD INTRM1 17:00-18:30 1.50 LOG DLOG INTRM1 18:30 - 19:00 0.50 LOG CIRC INTRM1 19:00 - 00:00 5.00 LOG DLOG INTRM1 12/1 3/2004 00:00 - 01 :00 1.00 LOG DLOG INTRM1 01 :00 - 01 :30 0.50 LOG CIRC INTRM1 01 :30 - 04:00 2.50 LOG ELOG INTRM1 04:00 - 09:00 5.00 LOG OTHR INTRM1 09:00 - 10:00 1.00 LOG OTHR INTRM1 10:00 - 12:00 2.00 LOG OTHR INTRM1 12:00 - 13:30 1.50 LOG DLOG INTRM1 13:30 - 15:00 1.50 LOG ELOG INTRM1 15:00 - 17:30 2.50 LOG OTHR INTRM1 17:30 - 21 :30 4.00 LOG OTHR INTRM1 21 :30 - 23:00 1.50 LOG DLOG INTRM1 23:00 - 00:00 1.00 LOG OTHR INTRM1 12/14/2004 00:00 - 08:30 8.50 LOG OTHR INTRM1 08:30 - 10:00 1.50 LOG DLOG INTRM1 10:00 - 16:00 6.00 LOG OTHR INTRM1 16:00 - 18:00 2.00 LOG DLOG INTRM1 18:00 - 00:00 6.00 LOG DLOG INTRM1 12/15/2004 00:00 - 00:30 0.50 LOG DLOG INTRM1 00:30 - 05:00 4.50 LOG PULD INTRM1 05:00 - 06:00 1.00 DRILL PULD INTRM1 06:00 - 06:30 0.50 DRILL TRIP INTRM1 06:30 - 07:00 0.50 DRILL CIRC INTRM1 07:00 - 08:00 1.00 DRILL OTHR INTRM1 08:00 - 10:30 2.50 DRILL TRIP INTRM1 Start: Rig Release: Rig Number: Spud Date: 4/26/1982 End: 12/18/2004 Group: 12/1/2004 12/18/2004 Checked power head-good. Pulled tools out of hole tested each individual tool. All tools check out good. Found software problem in e-line unit. Checked tool continuity - Good test. RlU and hang SLB sheave in derrick. RIH from 136' to 2,390' at slow controlled rate. Fill 5" DP and pump 1x DP volume. Cont RIH from 2,390' to 6,900' at slow controlled rate, filling 5" DP every 5 stnds. Cont. RIH from 6,900' to 7,549' at a slow controlled rate, filling 5" DP every 5 stnds. Circ 1x DP volume. M/U SDE sub and pump down PDWC. Latch on to DHWC and test tool continuity. Test OK. M/U wire clamp on SDE sub and pull test. Cont. RIH slow, start collecting gama data at 7,552' and 1st pressure test at 8,331 '. Cont. obtaining MDT pressure logs from 8,331' through 8,759'. POOH from 8,759' to 8,200' slowly, resume logging from 8,200' to 8,344'. P/U wt at 8,759' = 150K - S/O wt = 102K. Attempt to take fluid sample at 8,344' and had packer inflation failure. K/U and stage pump to 8bpm to ensure DHW connection. Pump OOH from 8,334' to SDE sub at 7,520' at 126GPM. Remove wire clamp at SDE sub, pull wet head to surface. Trouble shoot power head and found short in wire. Cut off 200' e-line and re-connect head to wire while circ at 125 GPM/300 psi, recip while circ P/U 130K - 5/0 105K. M/U SDE sub, K/U and pump down the power head at 60 SPM/410psi, latch up and test. Test good. Install wire clamp. Perform pull test on clamp and had tool failure. Re-clamp wire and pull test. Test good. RIH from 7,520' to 8,344' at slow controlled rate. Inflate packers and start MDT log at 8,344'. P/U wt 140K - S/O wt 104K. Continue obtaining MDT oilphase samples at 8,344' - 8,456' - 8,616 - 8,690. Pump OOH from 8,690' to 7,776' at 3 bpm. Resume MDT pressure logging at 7,776' - 7,733' - 7,701', and had a seal loss at 7,770'. POOH from 7,770' to 7,745' and attempt oilphase sample with a resulting seal loss. POOH from 7,745' to 7,695' with a good seal test, for a total of 14 MRPS Pressures, 7 MPRA inflations and 15 oil samples. POOH from 7,695' to the SDE sub at 7,520'. Remove wire clamp. POOH with power head and wire. R/D sheave, wire and SDE sub. Remove excess SLB hardware from floor. Pump OOH with 5" DP at 127 GPM, from 7,520' to 2,394'. Total fluid loss at 6 bbls while circ across top of hole, for last 12 hrs. Service rig and top drive while monitor well at 2,395'. Cont. POOH to SLB MDT tool. Break dwn and UD SLB tools and samples. Clear rig floor. M/U 8 1/2" hole opener, 8 3/8" stab, float sub, 7 7/8" stab, HWDP, and jars. RIH to 2,400'. CBU 1x at 450 GPM while rot and recìp DP at 80 RPM. Cut and slip drill line. Cont RIH from 2,400' to 9,038' filling every 25 stnds, wash and ream last Printed: 1/10/2005 1 :32:30 PM Legal Well Name: 1 H-05 Common Well Name: 1 H-05 Event Name: ROT - SIDETRACK Contractor Name: Rig Name: Doyon 14 Hours CQde Sub Code 12/15/2004 08:00 - 10:30 2.50 DRILL TRIP INTRM1 10:30 - 12:30 2.00 DRILL CIRC INTRM1 12:30 - 18:30 6.00 DRILL TRIP INTRM1 18:30 - 20:00 1.50 DRILL CIRC INTRM1 20:00 - 23:30 3.50 DRILL TRIP INTRM1 23:30 - 00:00 0.50 DRILL TRIP INTRM1 12/1 6/2004 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 01 :30 - 04:00 2.50 DRILL PULD INTRM1 04:00 - 05:00 1.00 CASE RURD CMPL TN 05:00 - 07:00 2.00 CASE RUNC CMPL TN 07:00 - 08:30 1.50 CASE RUNC CMPL TN 08:30 - 09:30 1.00 CASE RUNC CMPL TN 09:30 - 10:00 0.50 CASE CIRC CMPL TN 10:00 - 16:30 6.50 CASE RUNC CMPL TN 16:30 - 17:00 0.50 CASE RURD CMPL TN 17:00 - 19:00 2.00 CEMENT CIRC CMPL TN Start: Rig Release: Rig Number: 12/1/2004 12/18/2004 Spud Date: 4/26/1982 End: 12/18/2004 Group: stnd to btm. CBU 2x at 500 GPM, 1,500 psi, while rot and recip at 120 RPM. Flow check - hole static, Backream OOH from 9,038' to 4,340' at 500 GPM, 900 - 1,400 psi, torque 5 - 11 K at 120 RPM, flow check - hole static. CBU 2x at 500 GPM - 920 psi, while rot and recip at 120 RPM with 5K torque. Flow check - hole static, pump dry job. POOH from 4,340' LID 5" DP, HWDP, string stabs, and hole opener. Clear rig floor. M/U M/S and RIH to 566' with 5" DP from derrick. Service rig and top drive. Cont. LID 5" DP, pull wear ring. Close blind rams. PJSM, cont break dwn and LID 5" DP from mouse hole. PJSM, inspect handling equip, R/U to run 3 1/2" casing. M/U shoe jnt, install plug catcher top of jnt #3, fill and check float equip, P/U and RIH with 3 1/2" 9.3# L-80 EUE casing. C/O elevators to 51/2", M/U seal bore assembly, cont RIH with 5 1/2" 15.5# L-80 BTC casing to 2,400'. C/O bails and elevators to 175 ton and install Frank's fillup tool. Break circ to 6.5 bpm at 650 psi surface to surface. Cont P/U RIH with 5 1/2" casing, breaking circ every 35 jnts, from 2,400 to 9,038' with no problems. RID Frank fill up tool, blow dwn top drive and M/U cement head. Stage pumps to 380 GPM at 900 psi, circ and cond 8,800 strokes dropping mud wt from 9.3ppg to 9.2ppg with H20 and SAPP, while recip 15' stroke. P/U wt 140K, S/O wt 80K and held PJSM with rig, Dowell crew and truck drivers. CPF 1 area now in phase 3 weather condo 2.00 CEMENT PUMP CMPL TN Line up on Dowell, pump 5 bbl H20, test lines to 3,500 psi, pump 50 bbl CW 100 at 6 bpm at 830 psi, 50 bbl Mudpush II at 10.5ppg at 5 bpm at 500 psi, followed by 250 bbl Class WS Deepcrete Slurry at 12.5 ppg with 0.6% D046 + 0.22 gallsx D185 + 0.050 gallsx D186 + 0.35% D167 at 5 bpm and 500 psi, flush surface lines with 5 bbl H20, drop dual wiper plug. 1.00 CEMENT DISP CMPL TN Line up on Dowell and displace with 200 bbl 9.3 brine. Full returns, casing trying to float so landed and finish displacement. Bumped plug at 199.7 bbl away, up to 2,000 psi. and held for 5 min. Bled off to check float equip, float holding. CIP at 21 :45. Final up wt 185K, S/O wt 55K. Block wt 50K. Blow dwn Dowell equip, hold safety meeting with all personnel on phase 3 weather condo Rig cleaning on hold to conserve H20. Crew up-dating procedures. Phase 3 waiting on weather. RlU on outer ann and flush up through stack, blow dwn landing jnt, kill and choke lines. NID 13 5/8" BOP and lift for casing cut. P/U to 230K on 5 1/2" casing, assemble and set slips, cut and dress casing stub, install Cameron tubing spool, install and test pack-off at 250 and 3,200 psi. Cut off jnt = 38.79'. Install adaptor flange, N/U 135/8" BOP, install test plug and shell test BOP at 250 and 3,000 psi. Test OK. RID 5 1/2" casing equip, C/O bails, clear rig floor, R/U to run 3 1/2" completion. PJSM, P/U and RIH with Baker 80/40 GBH-22 seal assembly, locator 19:00 - 21:00 21 :00 - 22:00 22:00 - 00:00 2.00 WAlTON WOW CMPLTN 12/17/2004 00:00 - 13:00 13.00 WAlTON WOW CMPL TN 13:00 - 14:00 1.00 CMPLTN OTHR CMPL TN 14:00 - 15:00 1.00 CMPL TN NUND CMPL TN 15:00 - 19:00 4.00 CMPL TN OTHR CMPLTN 19:00 - 21 :30 2.50 CMPL TN NUND CMPL TN 21 :30 - 23:00 1.50 CMPL TN RURD CMPLTN 23:00 - 00:00 1.00 CMPL TN RUNT CMPL TN Printed: 1/10/2005 1 :32:30 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/17/2004 12/18/2004 1 H-05 1 H-05 ROT - SIDETRACK Doyon 14 Start: Rig Release: Rig Number: 12/1/2004 12/18/2004 Spud Date: 4/26/1982 End: 12/18/2004 Group: 23:00 - 00:00 00:00 - 00:30 00:30 - 06:30 06:30 - 08:30 1.00 CMPL TN RUNT 0.50 CMPL TN OTHR 6.00 CMPL TN RUNT 2.00 CMPL TN SOHO CMPL TN CMPL TN CMPL TN CMPL TN 08:30 - 09:00 0.50 CMPL TN CIRC CMPL TN 09:00 - 09:30 0.50 CMPL TN OTHR CMPL TN 09:30 - 10:00 0.50 CMPL TN RURD CMPL TN 10:00 - 13:00 3.00 CMPL TN NUND CMPL TN 13:00 - 15:30 2.50 CMPL TN NUND CMPL TN 15:30 - 16:30 1.00 CMPL TN SEQT CMPL TN 16:30 - 17:30 1.00 CMPL TN DEQT CMPL TN 17:30 - 20:30 3.00 CMPL TN FRZP CMPL TN 20:30 - 21 :00 0.50 CMPL TN RURD CMPL TN sub, CMU sliding sleeve and 15 jnts 31/2" tubing. Service rig and top drive. Cont P/U and RIH with 258 jnts 3 1/2" completion string and jewelry. Space out for seal assembly and hanger, M/U hanger, landing jnt and circ lines. Break cir dwn tubing and displace inner ann with 9.3 ppg brine, mixed with corrosion inhibitor for a total of 77 bbls, then chased with 59 bbls 9.3 ppg brine, at 4.5 bpm at 1,300 psi. Verified sting into seal assem with pump press. Drained BOP stack and landed hanger. RILD's. RID circ equip, UD landing jnt and install TWC. N/D and stnd back 13 5/8" BOP while flushing mud and pump lines. Rig off high line at 11 :00 hrs. Orient tree valves, N/U FMC 3 1/2" x 10 3/4" tubing head adaptor and test pack-off to 5,000. N/U tree and RlU for tree test and freeze protection. Test tree against TWC at 250 and 5,000 psi on chart, pull TWC. Test OK. RlU and press test tubing to 2,000 psi on chart for 5 min, RlU HOT OIL on I/A. Test circ lines, press up to 3,500 psi on I/A and chart for 30 min. Bleed off tubing and sheared DCK-3. Freeze protect fA with 51 bbls diesel at 2 bpm with 1,750 psi. RID HOT OIL from fA, install BPV, RlU HOT OIL on O/A and pump 167 bbls diesel at 2 bpm with 1,150 psi. SITP and SICP at 100 psi. O/A shuUn press at 700 psi. RID HOT OIL, install blind flanges, needle valves and gauges, clean and secure well. Rig released at 21 :00 hrs. Printed: 1/10/2005 1 :32:30 PM Halliburton Sperry-Sun Western North Slope ConocoPhillips 1 H-05A . Job No. AKMW3424644, Surveyed: 11 December, 2004 Survey Report 29 December, 2004 Your Ref: API 500292072701 Surface Coordinates: 5980174.54 N, 549543.27 E (70021' 23.8320" N, 149035' 51.5167" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 87.29ft above Mean Sea Level !5peI'""1I'""1Y-!5u,,-, DFUL..L.ING seRVices A Halliburton Company Survey Ref: svy2096 Halliburton Sperry-Sun Survey Report for 1H-05A Your Ref: API 500292072701 Job No. AKMW3424644, Surveyed: 11 December, 2004 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 2366.29 49.500 44.500 2090.18 2177.47 545.22 N 476.31 E 5980722.90 N 550015.97 E 705.42 Tie On Point MWD+SAG - 2434.16 55.950 48.590 2131.27 2218.56 582.27 N 515.54 E 5980760.21 N 550054.95 E 10.641 758.92 Window Point 2481.24 54.980 49.490 2157.96 2245.25 607.70 N 544.83 E 5980785.83 N 550084.07 E 2.593 797.55 . 2526.08 56.400 48.660 2183.24 2270.53 631.96 N 572.81 E 5980810.28 N 550111.89 E 3.517 834.44 2572.14 57.590 50.620 2208.33 2295.62 656.97 N 602.24 E 5980835.48 N 550141.15 E 4.406 872.95 2619.62 59.570 52.220 2233.08 2320.37 682.23 N 633.92 E 5980860.95 N 550172.66 E 5.065 913.41 2665.40 61.290 52.120 2255.67 2342.96 706.65 N 665.37 E 5980885.58 N 550203.95 E 3.762 953.21 2712.66 63.300 53.230 2277.64 2364.93 732.02 N 698.64 E 5980911.16 N 550237.05 E 4.734 995.03 2760.04 65.710 54.630 2298.04 2385.33 757.19 N 733.21 E 5980936.56 N 550271.45 E 5.743 1037.79 2807.50 68.630 54.640 2316.45 2403.74 782.50 N 768.87 E 5980962.11 N 550306.95 E 6.153 1081.53 2853.95 72.380 56.640 2331.95 2419.24 807.20 N 805.01 E 5980987.05 N 550342.93 E 9.036 1125.29 2893.00 72.130 56.290 2343.85 2431.14 827.75 N 836.02 E 5981007.80 N 550373.79 E 1.067 1162.45 2988.28 70.980 56.380 2374.00 2461.29 877.85 N 911.24 E 5981058.40 N 550448.69 E 1.210 1252.77 3087.69 71.230 57.410 2406.19 2493.48 929.22 N 990.03 E 5981110.29 N 550527.13 E 1.012 1346.71 3183.83 72.790 58.180 2435.88 2523.17 977.95 N 1067.40 E 5981159.53 N 550604.18 E 1.793 1437.96 3276.36 72. 700 58.680 2463.33 2550.62 1024.21 N 1142.68 E 5981206.29 N 550679.15 E 0.525 1526.08 3371.60 72.370 58.350 2491.91 2579.20 1071.66 N 1220.16E 5981254.25 N 550756.31 E 0.479 1616.66 3466.22 72.260 57.850 2520.66 2607.95 1119.30 N 1296.69 E 5981302.39 N 550832.53 E 0.517 1706.60 3558.44 71.760 57.640 2549.14 2636.43 1166.11 N 1370.87 E 5981349.69 N 550906.39 E 0.584 1794.13 3652.20 73.160 57.500 2577.39 2664.68 1214.05 N 1446.32 E 5981398.13 N 550981.53 E 1.500 1883.37 3745.48 73.540 56.730 2604.12 2691.41 1262.57 N 1521.37 E 5981447.15 N 551056.26 E 0.890 1972.62 . 3838.63 74.010 55.500 2630.15 2717.44 1312.44 N 1595.62 E 5981497.50 N 551130.17 E 1.365 2062.00 3933.68 74.370 55.580 2656.05 2743.34 1364.19N 1671.02 E 5981549.75 N 551205.23 E 0.387 2153.43 4026.36 75.620 55.140 2680.04 2767.33 1415.07 N 1744.67 E 5981601.12 N 551278.55 E 1.425 2242.93 4121.65 77.650 54.880 2702.07 2789.36 1468.23 N 1820.62 E 5981654.78 N 551354.14 E 2.147 2335.62 4216.86 77.940 56.360 2722.20 2809.49 1520.78 N 1897.42 E 5981707.83 N 551430.59 E 1.550 2428.65 4311.60 78.160 56.840 2741.81 2829.10 1571.80 N 1974.80 E 5981759.36 N 551507.63 E 0.547 2521.25 4406.42 78.830 57.550 2760.72 2848.01 1622.14 N 2052.90 E 5981810.22 N 551585.39 E 1.019 2614.03 4500.21 78.020 54.600 2779.55 2866.84 1673.41 N 2129.13 E 5981861.99 N 551661.29 E 3.200 2705.85 4592.80 77. 700 55.950 2799.02 2886.31 1724.97 N 2203.52 E 5981914.05 N 551735.34 E 1.467 2796.35 4686.06 78.020 56.880 2818.63 2905.92 1775.40 N 2279.48 E 5981964.98 N 551810.96 E 1.034 2887.45 4781.90 78.580 56.580 2838.07 2925.36 1826.89 N 2357.94 E 5982016.98 N 551889.08 E 0.660 2981.20 4874.37 78.460 56.090 2856.47 2943.76 1877.12 N 2433.37 E 5982067.71 N 551964.17 E 0.535 3071.75 4969.22 78.260 54.370 2875.61 2962.90 1930.10 N 2509.67 E 5982121.19 N 552040.12 E 1.789 3164.63 5063.45 77.250 54.030 2895.60 2982.89 1983.96 N 2584.36 E 5982175.55 N 552114.45 E 1.128 3256.72 29 December, 2004 - 16:32 Page 2 of5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for 1H-05A Your Ref: API 500292072701 Job No. AKMW3424644, Surveyed: 11 December, 2004 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 5158.53 77.510 54.570 2916.37 3003.66 2038.11 N 2659.71 E 5982230.19 N 552189.44 E 0.618 3349.50 5251.88 77.270 55.230 2936.75 3024.04 2090.49 N 2734.24 E 5982283.07 N 552263.62 E 0.736 3440.59 5347.97 77.390 55.720 2957.83 3045.12 2143.62 N 2811.48 E 5982336.71 N 552340.51 E 0.513 3534.31 5439.52 77.700 55.910 2977.57 3064.86 2193.85 N 2885.43 E 5982387.43 N 552414.13 E 0.395 3623.67 5534.32 77.640 55.150 2997.81 3085.10 2246.27 N 2961.78 E 5982440.35 N 552490.13 E 0.786 3716.26 . 5630.28 77.190 54.360 3018.72 3106.01 2300.31 N 3038.27 E 5982494.89 N 552566.26 E 0.930 3809.90 5727.18 76.490 54.110 3040.78 3128.07 2355.46 N 3114.83 E 5982550.55 N 552642.45 E 0.765 3904.26 5820.71 76.120 54.090 3062.93 3150.22 2408.74 N 3188.44 E 5982604.32 N 552715.71 E 0.396 3995.13 5915.31 77.130 54.600 3084.81 3172.10 2462.39 N 3263.22 E 5982658.45 N 552790.13 E 1.190 4087.16 6008.19 77.450 55.390 3105.25 3192.54 2514.36 N 3337.43 E 5982710.92 N 552864.00 E 0.898 4177.75 6099.21 77.440 55.260 3125.03 3212.32 2564.91 N 3410.50 E 5982761.95 N 552936.73 E 0.140 4266.58 6191.77 78.140 55.150 3144.61 3231.90 2616.53 N 3484.79 E 5982814.06 N 553010.68 E 0.765 4357.03 6286.49 78.080 55.120 3164.12 3251.41 2669.51 N 3560.84 E 5982867.55 N 553086.37 E 0.071 4449.70 6380.77 78.390 55.910 3183.35 3270.64 2721.77 N 3636.92 E 5982920.31 N 553162.11 E 0.884 4541.97 6471.02 78.520 56.570 3201.41 3288.70 2770.91 N 3710.43 E 5982969.93 N 553235.29 E 0.731 4630.34 6564.39 77.880 56.690 3220.50 3307.79 2821.18 N 3786.76 E 5983020.70 N 553311.29 E 0.697 4721.65 6659.57 77.390 56.950 3240.88 3328.17 2872.06 N 3864.57 E 5983072.10 N 553388.76 E 0.580 4814.52 6752.78 77.300 56.640 3261.31 3348.60 2921.87 N 3940.67 E 5983122.41 N 553464.53 E 0.339 4905.37 6847.13 74.530 56.100 3284.26 3371.55 2972.54 N 4016.86 E 5983173.58 N 553540.38 E 2.988 4996.80 6940.64 73.570 56.650 3309.96 3397.25 3022.33 N 4091.72 E 5983223.87 N 553614.91 E 1.172 5086.64 7033.89 74.420 56.980 3335.67 3422.96 3071.39 N 4166.74 E 5983273.42 N 553689.60 E 0.973 5176.18 7128.41 76.870 58.170 3359.10 3446.39 3120.48 N 4244.03 E 5983323.02 N 553766.57 E 2.865 5267.57 . 7221.80 77.450 57.420 3379.86 3467.15 3169.01 N 4321.07 E 5983372.06 N 553843.29 E 0.999 5358.44 7316.07 76.890 56.210 3400.79 3488.08 3219.32 N 4397.99 E 5983422.87 N 553919.88 E 1.385 5450.26 7409.77 78.340 56.470 3420.89 3508.18 3270.04 N 4474.17 E 5983474.10 N 553995.71 E 1.571 5541.71 7499.47 79.150 56.160 3438.40 3525.69 3318.83 N 4547.37 E 5983523.38 N 554068.59 E 0.965 5629.62 7595.95 79.210 56.680 3456.51 3543.80 3371.25 N 4626.32 E 5983576.31 N 554147.19 E 0.533 5724.31 7689.71 79.130 56.790 3474.13 3561.42 3421.76 N 4703.32 E 5983627.33 N 554223.86 E 0.143 5816.30 7784.46 76.420 57.550 3494.19 3581.48 3471.96 N 4781.12 E 5983678.05 N 554301.33 E 2.966 5908.76 7879.50 73.140 56.120 3519.14 3606.43 3522.11 N 4857.88 E 5983728.71 N 554377.75 E 3.744 6000.35 7974.15 69.040 54.760 3549.80 3637.09 3572.89 N 4931.61 E 5983779.96 N 554451.14 E 4.540 6089.85 8069.04 67.110 53.840 3585.23 3672.52 3624.25 N 5003.10 E 5983831.80 N 554522.29 E 2.224 6177.87 8162.18 63.560 53.250 3624.10 3711.39 3674.53 N 5071.17 E 5983882.53 N 554590.03 E 3.855 6262.49 8253.85 59.680 52.480 3667.66 3754.95 3723.20 N 5135.46 E 5983931.62 N 554653.99 E 4.297 6343.11 8346.39 56.790 52.190 3716.37 3803.66 3771.27 N 5197.74 E 5983980.10 N 554715.95 E 3.134 6421.74 29 December, 2004 - 16:32 Page 3 of5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for 1H-05A Your Ref: API 500292072701 Job No. AKMW3424644, Surveyed: 11 December, 2004 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8440.60 53.820 51.530 3769.99 3857.28 3819.09 N 5258.66 E 5984028.33 N 554776.55 E 3.205 6499.13 8536.13 49.460 50.400 3829.27 3916.56 3866.24 N 5316.84 E 5984075.86 N 554834.42 E 4.657 6573.90 8629.60 45.960 50.630 3892.15 3979.44 3910.20 N 5370.19 E 5984120.17 N 554887.48 E 3.749 6642.90 8722.34 42.860 50.270 3958.39 4045.68 3951.52 N 5420.23 E 5984161.82 N 554937.25 E 3.354 6707.66 . 8813.08 39.480 49.650 4026.69 4113.98 3989.93 N 5465.96 E 5984200.53 N 554982.73 E 3.752 6767.22 8905.71 35.990 49.330 4099.93 4187.22 4026.74 N 5509.06 E 5984237.63 N 555025.58 E 3.714 6823.72 8998.59 33.010 47.350 4176.47 4263.76 4061.68 N 5548.38 E 5984272.83 N 555064.67 E 3.428 6876.05 9007.53 32.570 47.440 4183.99 4271.28 4064.96 N 5551.94 E 5984276.13 N 555068.21 E 4.952 6880.86 " 9038.00 32.570 47.440 4209.66 4296.95 4076.05 N 5564.02 E 5984287.30 N 555080.22 E 0.000 6897.15 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 54.140° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9038.00ft., The Bottom Hole Displacement is 6897.29ft., in the Direction of 53.715° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment . 2366.29 2434.16 9038.00 2177.47 2218.56 4296.95 545.22 N 582.27 N 4076.05 N 476.31 E 515.54 E 5564.02 E Tie On Point Window Point Projected Survey 29 December, 2004· 16:32 Page 4 of 5 DrillQuest 3.03.06.006 Western North Slope Survey tool program for 1 H-05A From Measured Vertical Depth Depth (ft) (ft) 0.00 2366.29 0.00 2177.47 29 December, 2004· 16:32 To Measured Vertical Depth Depth (ft) (ft) 2366.29 9038.00 2177.47 4296.95 Halliburton Sperry-Sun Survey Report for 1H-05A Your Ref: API 500292072701 Job No. AKMW3424644, Surveyed: 11 December, 2004 ConocoPhillips Survey Tool Description Tolerable Gyro - SEEKER MS (1 H-05) MWD+SAG (1 H-05A) Page 5 of5 DrillQuest 3.03.06.006 . . Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . Well 1 bY ¡5~2P-447 (J\. " 2P-447 ,8H/b 1A-06 P ~..29} 3F-21 ';pt- W 1 H-05A Job# 10709677 10696820 10942812 10942813 10687716 . Log Description Date USIT USIT INJECTION PROFILE INJECTION PROFILE MDT 12/24/03 01/07/04 12/21/04 01/07/04 12/13/04 12/30104 NO. 3297 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 1 1 1 ../ 1 1 DATE: If3f~ Please sign and retur one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . ~~!Æ~E mJF !Æ~!Æ~~~1 . AI,A.SIiA OILAlO) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk IH-05A ConocoPhillips Alaska, Inc. Permit No: 204-228 Surface Location: 528' FNL, 803' FEL, SEC. 33, TI2N, RlOE, UM Bottomhole Location: 1838' FNL, 579' FEL, SEC. 27, TI2N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to ness any required test. Contact the Commission's petroleum field inspector at (907) 659- 07 ager). / BY ORDER OF THE COMMISSION DATED this.lf)day of November, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . ¡ \l) \0 PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: RedrillU 1b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 528' FNL, 8031 FEL, Sec. 33, T12N, R10E, UM ,/ Top of Productive Horizon: 2049' FNL, 893' FEL, Sec. 27, T12N, R10E, UM Total Depth: 1838' FNL, 579' FEL, Sec. 27, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549543 y- 5980175 Zone- 4 16. Deviated wells: Kickoff depth: 2438 ft. Maximum Hole Angle: 76° 18. Casing Program Size Specifications Hole Casing Weight Grade Coupling Length 8.5" 5.5 x 3.5" ExploratoryU Development Oil U Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket [J Single Well 11. Well Name and Number: Bond No. 59-52-180 1 H-05A 6. Proposed Depth: 12. Field/Pool(s): MD: 8999' TVD: 4374' Kuparuk River Field 7. Property Designation: ·vVt2.fS1- ~~J:. Þ. ALK 25639 - ~Oil Pool I/·c;ð« 8. Land Use Permit: 13. Approximate Spud Date: 11/27/2004 ADL 464 9. Acres in Property: 2560 14. Distance to Nearest Property: 1838' 15. Distance to Nearest 10. KB Elevation Well within Pool: none, (Height above GL): 30 feet 17. Anticipated Pressure (see 20 Me 25.035) Max. Downhole Pressure: 1852 psig I Max. Surface Pressure: 1399 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) Top MD TVD MD 15.5x9.3# L-80 BTCM x 8999' 30' 30' 8999' 4374' 590 sx DeepCrete EUE 8rd Mod I I PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (It): Plugs (measured) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) 7152' 5 cement plugs 2230' 2077' Length Size Cement Volume MD TVD 19 Total Depth MD (It): 10840' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 78' 2425' 16" 10-3/4" 250 sx AS II 1000 sxAS III, 250 sx AS II 78' 2259' 78' 2425' none 20. Attachments: Filing Fee 0 Property Plat 0 I Perforation Depth TVD (ft): none Drilling Program0 Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: Commission Use Only Permit to Dri~1 í / I API Number: I Permit Approval I / -t) ¡ J Isee cover letter Number: .2..D yo .- .2-ZB 50- 02- cr- 2-0 72 "7 .~ 0 I Date: ///1 ¿J.1j 7 for other requirements Conditions of approval: Samples ired 0 Yes ~ No Mud log required 0 Yes IRf No Hy gen sui de measures 0 Yes ro No Directional survey required ~ Yes 0 No , ",~~\ ~V>~">~_ \--\ \~ c:...~~Q:ß\..-\cy'H\\\\-.....( \~. . CJ.. ~'-.~ \-0 """ t ~ \ C) ~ ~ <. I '/ "-- ORIGINAL BOP Sketch 0 Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randy Thomas ,...,.......'...~:".""'''-''';:> Signature ~ "-......o;..~ - \ 'v-..> Form 1 0-401 R~003' Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 Contact Mike Greener @ 263-4820 Title Kuparuk Drilling Team Leader Phone 2-i- 5- b230 Date It ( 'f I () 't PreDared bv Sharon AllsuD-Drake COMMISSIONER BY ORDER OF THE COMMISSION D~ Ittfte . . Application for Permit to Drill, Well 1 H-05A Revision No.O Saved: 2-Nov-04 Permit It - West Sak Well #1 H-05A Application for Permit to Drill Document M~J:O:il'l'1izli: W ~ II IIgh,J e Table of Contents 1. Well Name ..................................................................................................................... 2 Requirements of 20 AAC 25.005 (f) ...... ...... ....... ...... ........ ....... ...... ................... ........ ..... ............... ....... 2 2. Location Su m mary ....................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ... ....... ........ ..... ......... ............ ........ ...... ..... .............. ............... .... 2 Requirements of 20 AAC 25.050(b) . ..... .................... ............... ............ ........ ............. ...... ...... ......... ..... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(c)(3) .... ........ ...... ........ ...... ....... ...... ....... ....... ...... ...... ...... ...... ............. 3 4. Ori II i ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)( 4) ....... ..... ........ ....... ........ ..... ...... .................... ........ .............. ....... 3 5. Procedure for Conducting Formation Integrity Tests.............................................4 Requirements of 20 AAC 25.005 (c)(5) .. ...... ........ ...... ...... ......... .... ........ ........ .... ....... ....... ............... ..... 4 6. Casing and Cementing Program................................................................................4 Requirements of 20 AAC 25.005(c)(6) ..... ...... ....... ............... ............. ....... ...... ....... ............ ..... ............. 4 7. Oiverter System Information ......................................................................................4 Requirements of 20 AAC 25.005(c)(7) .. ...... ...... .............. ........ ...... ...... ............. ....... ...... ....... ........ ....... 4 8. Ori II i ng Flu id Prog ram................................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) .......... ....... ..... ........ ............. ........ ...... ...... ....... ....... .............. ..... 4 Intermediate Hole Mud Program (extended bentonite) ........................................................................ 4 9. Abnormally Pressured Formation Information ........................................................5 Requirements of 20 AAC 25.005 (c)(9) ............................................................................................... 5 10. Seismic Analysis ...... ............ ............. ....... ............. ............. ............. ............................. 5 Requirements of 20 AAC 25.005 (c)(10) .... ........ ............. ....... ............. ................... ....... ............... ....... 5 11. Seabed Condition Analysis ....................... ........... ...................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...... ....... ..... .......... ....... ............. ........ .... ....... ....... ................... 5 12. Evidence of Bonding ............. ......................................... ............................................. 5 Requirements of 20 AAC 25.005 (c)(12) ... ...... ...... ......... ....... ....... ..... ........ ............ .......... ......... .... ....... 5 ORIGINAL 1H-05A PERM/T /T.doc Page 10f6 Printed: 2-Nov-04 . . Application for Permit to Drill, Well 1 H-05A Revision No.O Saved: 2-Nov-04 13. Proposed Drilling Program ................. .............................................. .................. ........ 5 Requirements of 20 AAC 25.005 (c)(13) .............................................................................................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6 Requirements of 20 AAC 25.005 (c)(14) ........ ........ ....... ........ ......... ........... .......... ................... ............. 6 15. Attach ments.................................................................................................................. 6 Attachment 1 Doyon 14 West Sak 2004 3ksi BOP Configuration .......................................................6 Attachment 2 Directional Plan ............. ...... ....... ....... ....... ....... ............. ....... ...... ....... ...... ....... ....... ........ 6 Attachment 3 Drilling Hazards Summary... ....... ....... ....... ......... .... ....... ............. ...... ....... .............. ........ 6 Attachment 4 Cement Data .... ............. ...... ....... .......... ............. .... ....... ........ ......................... ........ ....... 6 Attachment 5 Well Schematic. ....... ..... ........ ...... ...... .................... ....... ............. ........ ..... ....... ........ ....... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branche~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1H-05A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUlvey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface I 528' FNL, 803' FEL, Section 33, T12N, RlOE ./ ASP Zone 4 NAD 27 Coordinates I RKB Elevation I 88.0' AMSL Northings: 5,980f174.54 Eastings: 549,543.24 / Pad Elevation 54.4' AMSL Location at Top of Productive Interval (West Sak "B" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,983,970 Eastings: 554,700 2,049' FNL, 893' FEL, Section 27, T12N, RlOE Measured Depth RKB: Total Vertical Depth RKB: Total Vertical Depth 55: 8,359 3,861 3,773 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,984,182 Eastings: 555,012 1,838' FNL, 579' FEL, Section 27, T12N, R10E Measured Depthf RKB: Total Vertical Depth RKB: Total Vertical Depth 55: 8,999 4,374 4,286 / and (D) other information required by 20 MC 25.050(b); ORIGINAL 1H-05A PERMIT IT.doc Page 2 of 6 Printed: 2-Nov-04 . . Application for Permit to Drill, Well 1 H-05A Revision No.O Saved: 2-Nov-04 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviate~ the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well,' Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet ofthe proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public record~ and show that each named operator has been furnished a copy of the application by certified mail,' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 AAC 25.03~ or 20 MC 25.03/; as applicable/ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well or all operations the stack will be equipped with 3-1/2" to 6" variable bore ra uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in th~Joweffi'TOšfêavity. See attached diagram entitled "Doyon 14 BOP Configuration" for clarifiçgtion;-tJpõ'ñTnitial nipple up, and at intervals of no more than 14 days thereafter, a test plug will..be-sëfbelow the lowermost rams, the annular preventer will be tested to 1,500 psi and the bliod·rams·ánd upper rams will be tested to 3,000 psi. (This test will test the shell and end connec:tiORS"6fthe lowermost ram). Immediately prior to running the production string of 5-1/2" x 3-1/~~síng, a test plug will be set below the lowermost rams, and the variable rams will be closed and .teSted to 3,000 psi on a 5-1/2" 00. S~ <t. ({ M.6:\ \~'\R~\<>\<JV\ 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drdl must be accompanied by each of the following items, except for an item already on file wIth the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountere~ criteria used to determine it and maximum potential surface pressure based on a methane gradient," The expected reservoir pressures in the West Sak sands in the 1H-05A area vary from 0.43 to 0.45 psi/ft, ./ or 8.3 to 8.6 ppg EMW (equivalent mud weight). " The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak A2 sand formation is 4,116 feet giving a MPSP of 1,399 psi, calculated thusly: MPSP = (4,116 ft)*(0.45 - 0.11 psi/ft) = 1,399 psi / (B) data on potential gas zones/ The well bore is not expected to penetrate any gas lones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strat0 lost circulation zone~ and zones that have a propensity for differential sticking/ Please see Attachment 2: 1H-05A Drilling Hazards Summary. ORIGINAL 1H-05A PERMIT IT.doc Page 3 of 6 Printed: 2-Nov-04 . . Application for Permit to Drill, Well 1 H-05A Revision No.O Saved: 2-Nov-04 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25. 030(f),' 1H-05A will be completed with 5-1/2" x 3-1/2" tapered casing string landed below the base of the West Sak A1 sand. The 10-3/4" casing plug will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installe~- Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/fl) Grade Connection (fl) (fl) (fl) Cement Program 16" 24 65 H-40 Welded 78 32 / 32 110/ 110 Cemented to surface with 200 sxs P.F. 10-3/4 13-112 45.5 K-55 BTC 2,594 31/ 31 2,425 /2,217 Cemented to Surface wi 1,000 sxs Fondu & 250 sxs AS II 5-1/2 X 8-1/2 15.5 X L-80 BTCM X 8,999 30 / 30 8,999/ 4,374 Cement Top 3-1/2 9.3 EUE 8rd planned @ 5300' MD I 2989' TVD. MOD Cemented wi 590 sx DeepCRETE 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description ofthe diverter system as required by 20 MC 25.03-" unless this requirement is waived by the commission under 20 MC 25.035(h)(2); No diverter will be required in the drilling of this well as the 10-3/4" surface casing has already been set. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system as required by 20 MC 25.033,' Drilling will be done with muds having the following properties over the listed intervals: Production Hole Mud Program (LSND) 10-3/4" Casing Shoe to 5-1/2" x 3-1/2" Casing Point Initial Value Density (ppg) 9.1- 9.2 ,/ ORIGINAL 1H-05A PERMIT IT. doc Page 4 0'6 Printed: 2-Nov-04 . . Application for Permit to Drill, Well 1 H-05A Revision No.O Saved: 2-Nov-04 Funnel Viscosity (seconds) Plastic Viscostiy (/b1100 sf) Yield Point (cP) API Filtrate (cc 130 min)) Chlorides (mgll) pH MBT 45-60 10 28 - 30 4-6 15,000 - 17,000 9.0 - 9.5 <20.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 14. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. 1. Prepare cellar and circulate out plug fluid (brine and diesel) out of well using coil. Test 10-3/4" casing string and replace old wellhead with new Gen 5 wellhead. ORIGINAL 1 H-05A PERMIT IT.doc Page 50f6 Printed: 2-Nov-04 . . Application for Permit to Drill, Well 1 H-05A Revision No.O Saved: 2-Nov-04 2. Move in / rig up Doyon Rig 14. NU and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 3. PU 8-1/2" bit and 6-3/4" Rotary Steerable assembly, with MWD, LWD & PWD. RIH, clean out cement to surface casing shoe depth of 2,425' MD. 4. Drill below casing shoe to KOP of 2,438' MD / 2,224'lVD. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 5. Directionally drill to 5-1/2" x 3-1/2" casing point at 9,000' MD / 4,374'lVD, the TD of the well. 6. POOH and PU drill pipe conveyed logs. RIH and log Ugnu and West Sak sands. v 7. POOH and lay down logging tools. 8. RIH and circulate at TD in preparation of running 5-1/2" x 3-1/2" casing. 9. POOH laying down DP. Run casing. Ensure that seal bore assembly is not run higher than 8,100' MD (159' above top of West Sak) Cement string in place. ./ 10. Run 3-1/2" completion string and sting into seal bore assembly. 11. Install BPV and nipple down stack. Nipple up tree. Install tree test plug. Test tree to 250 and 5000 psi. Test packoff to 5000 psi. Pull tree test plug, remove BPV. Pressure up on annulus and test seal. 12. Freeze protect well with diesel down the annulus with maximum flowrates, RU slickline and RIH and close sliding sleeve, POOH with wireline 13. Pressure test annulus to 3000 psi for 30 minutes. Close in well. 14. Set BPV. Rig down and move off drilling rig. Prepare an accurate ~andover form and .send to pad eng~neer'~ (.«.s"~~~~~'-J~ \ \.-\--( \~ ~ ~<;., ~\ ~CJ lIt ~ 14. Discussion of Mud and Cuttings Disposal and Annular Disposal \\ J'lC Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. 080 for an annular disposal operation in the well./ Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 15.Attachments Attachment 1 Doyon 14 West Sak 2004 3ksi BOP Configuration Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Cement Data Attachment 5 Well Schematic ORIGINAL 1H-05A PERMIT IT.doc Page 6 of 6 Printed: 2-Nov-04 o ::::0 -T------------ qJ .. \ ! ) , ~------------------ .. ~r ~ 3/8"L:~~:-::- I ," CHOK' UN' - " 5-3/,' /1 Z 1 J 1/8~ 5000 PSt HCR VALVEJ J 1/8- 5000 PSI GATE VAL -. -------------------- G; - Z )::> r- BOP STACK WEI.I.HEAD 16" 150 PSI HYDR. OPERATED KNIFE GATE VALVE 18" FLO'D VENT UNE SURFACE DIVERTER CONFIGURATION 13 5/8", 5000 PSI, HYORIL ANNULAR BOP, STUDDED TOP/fLANGED BOTTOM FlANGED TOP/STUDDED BOTTOM ex 160 -135/8", 5000 PSI, 10M MPl OPERATORS, HYDRIL PIPE RAM _ 13 5/8", 500D PSI, 10" MPL OPERATORS, HYDRll BUND RAM sruDOEO TOP/fLANGED BOTTOM ax 160 J 1/8" 5000 PSI HCR VALVE 2" Kill UNE J 1/8" 5000 PSI GATE V/JJ...VE ~- SINGLE 13 5/8", 5000 PSI, 10· MPL OPEARTORS. ~ HYDRIL PIPE RAM STUDDED BOITOM/FlANGED TOP ex 160 ADAPTER SPOOL FlANGE/FlANGE ELEVATION I i ~ I) ~ 3/'.'~ != " 3-F--- @) -------- 3"3" I I FlANGE i 21 1/4·, 2000 PSI, MSP HYDRll BOP /DlVERTER STUDDED TOP/FLANGED BOTTOM Fi..ANGE/FLANGE RX 7 J '\ ACCUMUw\TOR: TRIPLEX PUMP: AIR PUMP: NL SHAFFER, 180 GAL, 575 VAC, 30 HP 1, NL SHAFFER [~ '- , , r'-. F'- /'- fi'o. ./".. -I, F'- /'- /'- -I II II II II II II II 11 JJ I I ACCUMULATOR MANIFOLD 18 BOTTLES, 10 GALLONS EACH AAAA yyyy I I NITROGEN BACKUP BOTTLES 4 BOTTLES, 220 CU. FT. /' STATION VALVE LEGEND 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7 ANNULAR . 0· 0· 0· " ,. .. -/. ./ - ./- .. .. .. IMANIFOLD PRESSURfJlACCUMULATOR PRESSURElIANNULAR PRESSURE I ~ . IANN~I,N( HI:.G~IO' INCREASE DFCRFASE ~ I PUSH &: HOLD I ~O OPE:?rr PANFI ~ REMOTE PANEL IN DOGHOUSE AND UTILl1Y MODULE ~è~m.~~~~Of' ~on -"" RIG 14 03/05/01 4 ow. l£A UPMlE SOP STACK . 01/31/00 3 owe l£A liteM: CHOICE{ICIU. UNŒ SOP SYSTEM 12-20-00 2 ow. l£A UPMTE SOP STACI( AND CONTROL "-28-98 1 oIT11 l£A DIlAWNTOALJTOC:AD Mtt ~u~~ ~: ~28/98 RPR LEA Mtt 'W: rwr· N',tR' DESCRIPTION NTS J~ . k14BOPSYS&:CONTROl ¢: <.0 N 1350 N " E ü <J) 1800 ã'i ü (f) - 2250 .... (,) ~ - .t:: 2700 .... Q. (,) CI 3150 CI:I U t: 3600 (,) > (,) 4050 ::::s II.. l- I V 4500 4950 5400 Ref wellpath is 5A Ver#2. Coordînates are in feet reference slot #5. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum Rig Datum: Planned Datum(Doyon 14) Rig Datum to mean sea level: 88.00 ft. Plot North is aligned to TRUE North. ConocoPhiUips Alaska., Inc.. North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1H Scale 1 em = 300 ft slot #5 Well: 5 Well bore: 5A East (feet) -> -0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 -0 450 900 1350 Scale 1 em =: 225 ft SURFACE LOCATION: 528' FNL, 803' FEL SEC. 33, T12N, R10E 6000 5 5400 TO LOCATION: I 4800 1838' FNL, 579' FEL I ~ SEC. 27, T12N, R10EI ~ - 4200 Ugnu C C 8 Target - EOC Drop TARGETLOCATION: 2049' FNL, 893' FEL SEC. 27, T12N, R10E Az.imuth 3150 3600 4050 4500 4950 5400 5850 Vertical Section (feet) -> to.OO E from slot #5 1800 2250 2700 6300 6750 3600 (\ 3000 2400 1800 1200 (J) (') ill ¡¡¡ 600 (') 3 It (¡,) o o ;::¡, o SakD 7200 7650 Created by Planner Date plotted 26-00t-2004 ~~P¡otreference is 5A Ref well path is SA Ver#!2. Coordinates are in feet reference slot #5 True Vertical Depths are reference Rig Datum. Measured Depths are reference Datum. Datum: Planned Datum(Doyon Datum to mean sea level: 88.00 It Plot North is aligned to TRUE North. ConocoPhiHips Alaska, Inc.. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1H Seale 1 em == 150 ft o 300 600 900 Slot: slot #5 Well: 5 Well bore: 5A ¡II ips East (feet) -> 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700 6000 5800 5500 5800 5200 4000 5500 3700 3400 2800 4600 4300 (y~ . "---~-~700 5500 5200 4900 3400 4600 / 4300 3100 6400 5800 5500 4900 5200 4200 3900 e 3600 3300 3000 2700 ^ 2400 ~ 0 ;+ 2100 .=: ;' C'I) - 1800 - 1500 1200 900 (f) " 600 ID (j) " 300 3 II 0 ;::!> .e Conoc6Phillips ConocoPhillips Alaska, Inc.,slot #5 Pad 1 H, Kuparuk River Unit, North Slope, Alaska Well bore Name 5A Well Name 5 Slot Name slot #5 Installation Name Pad 1 H Field _Name KUDaruk River Unit -e PROPOSAL LISTING Page 1 Wellbore: 5A Wellpath: 5A Ver#2 Date Printed: 25-0ct-2004 I Created 29-Sep-2004 I Last Revised 25-0ct-2004 Ba. BAKER HUGHU INTEQ East 802.07W North Alianment True North Alianment True Government 10 Last Revised Grid Northinq I 5980174.5400 . ~~~5~~~~~0 ·1 Latitude N70 21 23.8320 Lonqitude W149 35 51.5176 North 528.30S Eastína I 550341.6600 - Northina 5980708.1700 Coord SYStem Name AK-4 on NORTH AMERICAN DATUM 1927 datum Eastina 487754.6208 Coord SYStem Name AK-4 on NORTH AMERICAN DATUM 1927 datum Northin.a 5948985.8206 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum(Doyon 14) 88.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 54.03 degrees Bottom hole distance is 6780.88 Feet on azimuth 54.14 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORiGiNAL .e Conocc>Pt,illips ConocoPhillips Alaska, Inc.,slot #5 Pad 1 H, Kuparuk River Unit,North Slope, Alaska ee PROPOSAL LISTING Page 2 Wellbore: 5A Well path: 5A Ver#2 Date Printed: 25-0ct-2004 _i. BAKER HUGHES INTEQ WellpathRe :>ort MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogie Vertical Station Comment Depth SS Position(Grid Position(Grid g Section[f North) East) [deg/1 t] OOftl 3.00 0.00 0.00 3.00 -85.00 O.OON O.OOE 5980174.54 549543.24 0.00 0.00 503.00 0.00 0.00 503.00 415.00 O.OON O.OOE 5980174.54 549543.24 0.00 0.00 597.00 2.75 32.50 596.96 508.96 1.90N 1.21E 5980176.45 549544.44 2.93 2.10 688.00 5.25 34.50 687.74 599.74 7.17N 4.74E 5980181.75 549547.94 2.75 8.05 809.00 9.50 32.50 807.71 719.71 20.16N 13.25E 5980194.79 549556.35 3.52 22.57 931.00 14.00 37.50 927.12 839.12 40.38N 27.65E 5980215.09 549570.62 3.78 46.09 1053.00 18.00 33.50 1044.38 956.38 67.81N 47.05E 5980242.66 549589.83 3.40 77.91 1144.00 21.00 36.50 1130.15 1042.15 92.65N 64.51 E 5980267.61 549607.13 3.47 106.63 1235.00 23.75 40.00 1214.29 1126.29 119.80N 85.99E 5980294.90 549628.43 3.36 139.97 1326.00 26.25 40.00 1296.76 1208.76 149.26N 110.71E 5980324.52 549652.95 2.75 177.28 1387.00 27.75 28.50 135U 1 1263.11 170.71 N 128.22E 5980346.08 549670.32 2.70 204.05 1644.00 23.50 41.50 1582.79 1494.79 255.95N 199.46E 5980431.78 549740.98 1.73 311.77 2148.00 36.50 44.50 2018.36 1930.36 438.92N 371.85E 5980615.87 549912.15 2.60 558.77 2367.00 49.50 44.50 2178.18 2090.18 545.22N 476.32E 5980722.85 550015.89 5.94 705.75 2428.00 50.72 44.68 2217.30 2129.30 578.55N 509.17E 5980756.39 550048.52 2.01 751.92 10 3/4in Casino I 2438.00 50.92 44.71 2223.62 2135.62 584.06N 514.62E 5980761.93 550053.94 2.01 759.57 KOP, Tie on 2468.00 52.22 45.66 2242.26 2154.26 600.62N 531.30E 5980778.60 550070.50 5.00 782.79 Build 6°/100. 3DS Kick off Point 2500.00 53.98 46.62 2261.48 2173.48 618.35N 549.75E 5980796.45 550088.83 6.00 808.14 2600.00 59.53 49.35 2316.28 2228.28 674.25N 611.89E 5980852.76 550150.60 6.00 891.27 2700.00 65.13 51.79 2362.71 2274.71 730.43N 680.30E 5980909.38 550218.62 6.00 979.63 2800.00 70.76 54.02 2400.25 2312.25 786.28N 754.21 E 5980965.71 550292.16 6.00 1072.25 2900.00 76.42 56.10 2428.49 2340.49 841.17N 832.82E 5981021.12 550370.40 6.00 1168.11 2901.17 76.49 56.12 2428.77 2340.77 841.81N 833.77E 5981021.76 550371.34 6.00 1169.25 End of Build/Tum 3000.00 76.49 56.12 2451.86 2363.86 895.38N 913.54E 5981075.85 550450.75 0.00 1265.28 3100.00 76.49 56.12 2475.22 2387.22 949.58N 994.27E 5981130.58 550531.11 0.00 1362.45 3200.00 76.49 56.12 2498.59 2410.59 1002.78N 1074.99E 5981185.31 550611 .46 0.00 1459.61 3300.00 76.49 56.12 2521.96 2433.96 1057.98N 1155.71E 5981240.04 550691.82 0.00 1556.78 3400.00 76.49 56.12 2545.32 2457.32 1112.19N 1236.43E 5981294.77 550772 .17 0.00 1653.95 3500.00 76.49 56.12 2568.69 2480.69 1166.39N 1317.16E 5981349.50 550852.53 0.00 1751.11 3600.00 76.49 56.12 2592.05 2504.05 1220.59N 1397.88E 5981404.23 550932.88 0.00 1848.28 3700.00 76.49 56.12 2615.42 2527.42 1274.79N 1478.60E 5981458.96 551013.24 0.00 1 945.45 3800.00 76.49 56.12 2638.78 2550.79 1328.99N 1559.33E 5981513.69 551093.59 0.00 2042.62 3900.00 76.49 56.12 2662.15 2574.15 1383.20N 1640.05E 5981568.42 551173.94 0.00 2139.78 4000.00 76.49 56.12 2685.52 2597.52 1437.40N 1720.77E 5981623.15 551254.30 0.00 2236.95 4100.00 76.49 56.12 2708.88 2620.88 1491.60N 1801.50E 5981677.88 551334.65 0.00 2334.12 4200.00 76.49 56.12 2732.25 2644.25 1545.81 N 1882.22E 5981732.60 551415.01 0.00 2431.28 4300.00 76.49 56.12 2755.61 2667.61 1600.01N 1962.94E 5981787.33 551495.36 0.00 2528.45 4400.00 76.49 56.12 2778.98 ~690.98 1654.21 N 2043.67E 5981842.06 551575.72 0.00 2625.62 4500.00 76.49 56.12 2802.35 2714.35 1708.41N 2124.39E 5981896.79 551656.07 0.00 2722.79 4600.00 76.49 56.12 2825.71 2737.71 1762.61N 2205.11 E 5981951.52 551736.43 0.00 2819.95 4700.00 76.49 56.12 2849.08 2761.08 1816.82N 2285.84E 5982006.25 551816.78 0.00 2917.12 4800.00 76.49 56.12 2872.44 2784.44 1871.02N 2366.56E 5982060.98 551897.14 0.00 3014.29 4900.00 76.49 56.12 2895.81 2807.81 1925.22N 2447.28E 5982115.71 551977.49 0.00 3111.46 5000.00 76.49 56.12 2919.17 2831.17 1979.42N 2528.00E 5982170.44 552057.85 0.00 3208.62 5100.00 76.49 56.12 2942.54 2854.54 2033.63N 2608.73E 5982225.17 552138.20 0.00 3305.79 5200.00 76.49 56.12 2965.91 2877.91 2087.83N 2689.45E 5982279.90 552218.56 0.00 3402.96 5300.00 76.49 56.12 2989.27 2901.27 2142.03N 2770.17E 5982334.63 552298.91 0.00 3500.12 5400.00 76.49 56.12 3012.64 2924.64 2196.23N 2850.90E 5982389.36 552379.27 0.00 3597.29 5500.00 76.49 56.12 3036.00 2948.00 2250.43N 2931.62E 5982444.09 552459.62 0.00 3694.46 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum(Doyon 14) 88.0ft above mean sea level) , Vertical Section is from O.OON O.OOE on azimuth 54.03 degrees Bottom hole distance is 6780.88 Feet on azimuth 54.14 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL .e -e 'r-/ ConocoPhillips ConocoPhillips Alaska, Inc.,slot #5 Pad 1 H, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Well bore: 5A Wellpath: 5A Ver#2 Date Printed: 25-0ct-2004 R¡. BAKER HUGHES INTEQ We II path Re :)ort MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North(ft] East[ft] Station Station Dogie Vertical Station Comment Depth SS Position(Grid Position(Grid g Section[f North) East) [deg/1 t] OOftl 5600.00 76.49 56.12 3059.37 2971.37 2304.64N 3012.34E 5982498.82 552539.98 0.00 3791.63 5700.00 76.49 56.12 3082.74 2994.73 2358.84N 3093.07E 5982553.55 552620.33 0.00 3888.79 5800.00 76.49 56.12 3106.10 3018.10 2413.04N 3173.79E 5982608.28 552700.69 0.00 3985.96 5816.69 76.49 56.12 3110.00 3022.00 2422.09N 3187.26E 5982617.41 552714.10 0.00 4002.18 UQnu C 5900.00 76.49 56.12 3129.47 3041.47 2467.24N 3254.51 E 5982663.01 552781.04 0.00 4083.13 6000.00 76.49 56.12 3152.83 3064.83 2521.45N 3335.23E 5982717.74 552861.40 0.00 4180.29 6100.00 76.49 56.12 3176.20 3088.20 2575.65N 3415.96E 5982772.47 552941.75 0.00 4277.46 6200.00 76.49 56.12 3199.56 3111.56 2629.85N 3496.68E 5982827.20 553022.11 0.00 4374.63 6300.00 76.49 56.12 3222.93 3134.93 2684.05N 3577.40E 5982881.93 553102.46 0.00 4471.80 6400.00 76.49 56.12 3246.30 3158.30 2738.26N 3658.13E 5982936.66 553182.81 0.00 4568.96 6500.00 76.49 56.12 3269.66 3181.66 2792.46N 3738.85E 5982991.38 553263.17 0.00 4666.n 6600.00 76.49 56.12 3293.03 3205.03 2846.66N 3819.57E 5983046.11 553343.52 0.00 4763.30 6700.00 76.49 56.12 3316.39 3228.39 2900.86N 3900.30E 5983100.84 553423.88 0.00 4860.46 6800.00 76.49 56.12 3339.76 3251.76 2955.07N 3981.02E 5983155.57 553504.23 0.00 4957.63 6900.00 76.49 56,12 3363.12 3275.12 3009.27N 4061.74E 5983210.30 553584.59 0.00 5054.80 6937.99 76.49 56.12 3372.00 3284.00 3029.86N 4092.41 E 5983231.09 553615.11 0.00 5091.71 UQnu B 7000.00 76.49 56.12 3386.49 3298.49 3063.47N 4142.46E 5983265.03 553664.94 0.00 5151.97 7100.00 76.49 56.12 3409.86 3321.86 3117.67N 4223.19E 5983319.76 553745.30 0.00 5249.13 7200.00 76.49 56.12 3433.22 3345.22 3171.87N 4303.91 E 5983374.49 553825.65 0.00 5346.30 7300.00 76.49 56.12 3456.59 3368.59 3226.08N 4384.63E 5983429.22 553906.01 0.00 5443.4 7 7314.61 76.49 56.12 3460.00 3372.00 3233,99N 4396.42E 5983437.22 553917.75 0.00 5457.66 Uonu A 7400.00 76.49 56,12 3479.95 3391.95 3280.28N 4465.36E 5983483.95 553986.36 0.00 5540.64 7500.00 76.49 56.12 3503.32 3415.32 3334.48N 4546.08E 5983538.68 554066.72 0.00 5637.80 7600.00 76.49 56.12 3526.68 3438.68 3388.68N 4626.80E 5983593.41 554147.07 0.00 5734.97 7700.00 76.49 56.12 3550.05 3462.05 3442.89N 4707.52E 5983648.14 554227.43 0.00 5832.14 7730.13 76.49 56.12 3557.09 3469.09 3459.22N 4731.84E 5983664.63 554251.64 0.00 5ß61.41 End of Hold 7800.00 72.99 56.12 3575.48 3487.48 3496.79N 4787.80E 5983702.57 554307.34 5.00 5928.76 7900.00 67.99 56.12 3608.86 3520.86 3549.32N 4866.03E 5983755.61 554385.21 5.00 6022.93 8000.00 62.99 56.12 3650.32 3562.32 3600.02N 4941.55E 5983806.81 554460.38 5.00 6113.83 8095.16 58.24 56.12 3697.00 3609.00 3646.23N 5010.37E 5983853.46 554528.89 5.00 6196.67 K-13 8100.00 57.99 56.12 3699.56 3611.56 3648.52N 5013.78E 5983855.78 554532.29 5.00 6200.78 8200.00 52.99 56.12 3756.19 3668.19 3694.44N 5082.18E 5983902.14 554600.37 5.00 6283.10 8259.16 50.04 56.12 3793.00 3705.00 3720.25N 5120.61E 5983928.20 554638.63 5.00 6329.37 Top West Sak 0 8300.00 47.99 56.12 3819.79 3731.79 3737.44N 5146.21E 5983945.56 554664.11 5.00 6360.18 8329.78 46.50 56.12 3840.00 3752.00 3749.63N 5164.36E 5983957.87 554682.18 5.00 6382.03 C 8359.88 45.00 56.12 3861.00 3773.00 3761.65N 5182.26E 5983970.00 554700.00 5.00 6403.58 B Target, 1H-05A Top B TGT RVSD102104, End of Drop/Tum 8400.00 43.80 56.12 3889.67 3801.67 3777.29N 5205.57E 5983985.80 554723.20 3.00 6431.63 8405.99 43.62 56.12 3894.00 3806.00 3779.60N 5209.01 E 5983988.13 554726.62 3.00 6435.77 A4 8468.57 41.74 56.12 3940.00 3852.00 3803.24N 5244.22E 5984012.00 554761.67 3.00 6478.16 A3 8500.00 40.80 56.12 3963.63 3875.63 3814.80N 5261.43E 5984023.67 554778.81 3.00 6498.88 8571.99 38.64 56.12 4019.00 3931.00 3840.44N 5299.62E 59ß4049.57 554816.82 3.00 6544.84 A2 8600.00 37.80 56.12 4041.01 3953.01 3850.1 ON 5314.01 E 5984059.32 554831.14 3.00 6562.16 8698.06 34.85 56.12 4120.00 4032,00 3882.48N 5362.23E 5984092.01 554879.14 3.00 6620.20 A 1 8700.00 34.80 56.12 4121.59 4033.59 3883.1 ON 5363.15E 5984092.64 554880.06 3.00 6621.31 8798.62 31.84 56.12 4204.00 4116.00 3913.29N 5408.11E 5984123.12 554924.82 3.00 6675.44 Base, End of DroplTum 8800.00 31.84 56.12 4205.17 4117.17 3913.70N 5408.72E 5984123.53 554925.42 0.00 6676.16 8900.00 31.84 56.12 4290.12 4202.12 3943,11 N 5452.51 E 5984153.23 554969.01 0.00 6728.88 8998.62 31.84 56.12 4373.90 4285.91 3972.11 N 5495.70E 5984182.51 555012.01 0.00 6780.87 TD, End of Hold All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 54.03 degrees Bottom hole distance is 6780.88 Feet on azimuth 54.14 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL .e Conoc6'Phillips ConocoPhillips Alaska, Inc.,slot #5 Pad 1 H, Kuparuk River Unit, North Slope, Alaska Comments MOrftl TVDrftl 2438.00 2223.62 2468.00 224226 5816.69 3110.00 6937.99 3372.00 7314.61 3460.00 8095.16 3697.00 8259.16 3793.00 8329.78 3840.00 8359.88 3861.00 8405.99 3894.00 8468.57 3940.00 8571.99 4019.00 8698.06 4120.00 8798.62 4204.00 8998.62 4373.90 Hole Sections Diameter I Start finl MDrftl 81/2 2438.00 Northrftl 584.06N 600.62N 2422.09N 3029.86N 3233.99N 3ß46.23N 3720.25N 3749.63N 3761.65N 3779.60N 3803.24N 3840.44N 3882.48N 3913.29N 3972.11N Start TVDrftl 2223.62 Eastrft 1 514.62E 531.30E 3187.26E 4092.41 E 4396.42E 5010.37E 5120.61E 5164.36E 5182.26E 5209.01 E 5244.22E 5299.62E 5362.23E 5408.11 E 5495.70E Start Northrftl 584.06N ee PROPOSAL LISTING Page 4 Wellbore: 5A Wellpath: 5A Ver#2 Date Printed: 25-0ct-2004 BI. BAKER HUGHES INTEQ Comment KOF Build 6°/100 Uanu C Uç¡nu B Uanu A K-13 Top West Sak D C B Taraet A4 A3 A2 A1 Base TO I Start I Eastrftl 514.62E End Northlftl 3972.11N Endwellbore Eastrftl 5495.70E 5A End TVDrftl 4373.90 End MDlftl 8998.62 Casinas Name Top Top Top Top ShOe Shoe Shoe Shoe I:ellbore MDrftl TVDrftl Northrftl Eastrftl MDrftl TVDrftl Northrftl Eastrftl 10 3/4in Casina 3.00 3.00 O.OON O.OOE 2428.00 2217.30 578.55N 509.17E Taraets Name 1H-05A TOD B TGT RVS01021 04 I Northrftl I Eastrftl I TVOfftl 3761.65N 5182.26E 3861.00 Survey ToolProaram Reference I Survev Name 96024 MSS <0-10840'> 710918 Planned MDrftl 2438.00 8998.62 Latitude N70 22 0.8096 Lonqitude I W149 33 19.9455 Eastinq 554700.00 Northinq 5983970.00 TVDrftl 2223.62 4373.90 I Survev TOOI Error Model Photomechanical Maç¡netic Standard ISCWSA MWC . MWD+SAG - ISCWSA - 28 Jan 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum(Doyon 14) 88.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 54.03 degrees Bottom hole distance is 6780.88 Feet on azimuth 54.14 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR'Gf~LA; ·e ee -..:' ConocòPhillips ConocoPhillips Alaska, Inc. SA Ver#2, SA slot #5, Pad 1 H CLEARANCE LISTING Page 1 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and Maqnetic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of ft/100Oft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/Casinqs are NOT included Hole size/Casinqs are NOT subtracted from Centre-Centre distance Ellipses scaled to 258standard deviations. Closinq Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (3.00) Report uses Revised: (D-C)/E Factor Calculation Well bore Name 5A Wen l'J.ame 5 Slot· Name slot #5 I Grid NorthinQ _~~_~80174.5400 J LonQitude ~21 23.8320. ~---.W149 3!L.51.5176 Installation Namª-----~_ Pad 1 H J NorthinQ I Coord System Name 550341.660 5980708.170~ AK-4 on NORTH AMERICAN DATUM 1927 Field lJame Kuparuk River ~l)nit jcoord Systeì'nName 5948985.820· AK-4 on NORTH AMERICAN DATUM 1927 - . True ranee Summary Offset Offset Offset WellName WeUbore Slot ~-~~---~ 5 5 _----.§lQt #5 Pad 1 H ---ºJ)j-----------.-.2A44.72 ..1~~_.12........ slot #12 Pad 1ti~___.. 511.59 2438.0C 401 (old 4001 (old slot #Ugnu-01 Pad 1 H 625.50 2438.0C UQnu-01) UQnu-01 ) JA...._--..1L slot #14 'pad 1.H 757.72 2438.0C_ . 2438.0(:__ 7 7 slot #7 Pad 1H 772.83 2438.0C 2438.0C 21 21 slot #21 Pad 1 H 790.96 2438.0C 2438.0C -~- 10 slot #1 0__.......£.<&1 H 846.25 2438.0C 2438.0C ~----- 20 20 slot #20 _------"'-ª-º..1l:L___ 851.66 2438.0(: 2438.0C 17 17 slot #17 Pad~__ 862.16 2438.0C 2438.0(:__ -- 6 6 slot #6 Pad 1H 884.19 2438.0C 2438.0C ~- 13 slot #JQ.__ Pad 1 H_ 951.74 2438.0C 2438.QC 15 iL..._ slot #..lli....._~j H 978.20 2438.0C 2438.0C 22 22 slot #22 Pad 1H 1048.51 2438.0C 2438.0C Jß_~ 18 _......§!ot#18 Pad 1 H.____ 1073. ~ 2438.0L___2438.0C~_ 11 11 slot #11 Pad 1H 1 099.2:< 2438.0C 2438.0C 16 16 slot #1§..__ Pad 1 H 1138.46 2438.0C 2438.0C All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) prel~yrtj r1\t:l\t.orated .e ee ..,' ConocòPhillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 2 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska Il'iTEQ 9 9 slot #9 Pad 1 H 1143.77 2438.0C 2438.0C 19 19 slot #19 Pad 1H 1214.6E 2438.0C 2438.0C 2_ 2 §lot #!2.___ Pad 1 H 121911 2438.0C 2438.0C 8 8 slot #8 Pad 1H 1229.6L 2438.0C 2438.0C 4 4 slot #4 Pad 1 H 1303.72 2438.0C 2438.0C 3 3 slot #3 Pad 1H 1397.5E 2438.0C 2438.0C 1 1 slot #1 Pad 1 H 1425.5E 2438.0C 2438.0C Planned All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORfGINAl~ .e -e .' ConocòPhillips ConocoPhillips Alaska, Inc. SA Ver#2, SA slot #5, Pad 1 H CLEARANCE LISTING Page 3 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... ..,. INTEQ 2438.0C 2223.62 584.06N 514.62E 20 2269.38 2003.77 820.27N 273.54,^ -95.8 851.66 2468.0C 2242.2€ 600.Q2J:L 531.30E20 2294.87 2019.99 839.90N 272.18,^ -95.8 867.31 2503.0C 2263.2L 620.02N 551.51 E 20 2323.76 2038.37 862.13N 270.66,^ -95.5 886.09 2603.0C 2317.8C 675.94N 613.86E 20 2409.63 2093.01 928.20N 265.88,^ -94.5 942.40 2703.0C 23§3.97 732.12N 682.44E 20 248~45 2138.67 986.00N 261.12,^ -92.9 1002.7E 2803.0C _2~01.2L 7!IT.94N 756.50E 20 2550.0C 2178.35 1039.221\ 256.40,^ -90.7 1067.1L 2901.17 2428.77 841.81N ~833.77E 20 2609.12~2:L1j~ 1086.8~1\ 252.29,^ -87.8 1134.05 2903.0C 2429.1 S 842.80N 835.24E 20 2610.27 2213.81 1087.771\ 252.22,^ -87.8 1135.32 ~003.0C 2452.5€ 897.00N 915.97E20 26651~ 2245.85 1132.1L1\ 248.67,^ -89.6 1205.9S 3103.0C 2475.92 951,21 N 996.69.1: 20 2724.66 2280.47 1180.461\ 245.12,^ -91.4 127I.82 3203.0C 2499.2£ 1005.411\ 1077.41 E 20 2789.96 2318.50 1233.401\ 241.24,^ -93.1 1350.37 ~03.0C 2522.6€ 1059.611\ --Î158.13E 20 2849.43 _-2~º-3.27 _~2...8J.l131\ 237.79,^ -94.6 1423.5€ 3403.0C 2546.02 1113.811\ 1238.86E 20 2900.00 2382.91 1322.411\ 235.19,^ -95.8 1497.6L ~Q3.0C 2569.3£ _.-1168.021\ 131~58E20 2950.00 2412.32 1362J~~~2,^ -96.8 1572.52 3603.0C 2592.75 1222.221\ 1400.30E 20 3005.42 2445.15 1407.401\ 230.70,^ -98.0 1648.1C 3703.0C 2616.12 1276.421\ 1481.03E 20 3065.41 2481.25 1455.231\ 228.54,^ -99.1 1724.17 3803.0C 2§39.4S 1330.621\ 1561.75E 20 3125.3€ 2518.25 1502.37N 226.53,^ -100.3 1800.5S 3903.0C 2662.85 1384.821\ 1642.47E 20 3186.92 2556.55 1550.521\ 224.46,^ -101.4 1877.2ê __1003.0C 2686.22 1439031\ 1723.19E 20 325-L2L__ 2598.65 1603.051\ 222.10,^ -102.5 1954.16 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) prJ~rGr r~eAc[Orated .e ee ~llips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 4 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska .... 'WI. INTEQ 2438.0C 2223.62 584.06N 514.62E 17 2453.86 2272.89 543.42N 345.17V1 -126.9 862.16 24680~ 2242.26 600.62N 531.30-'= 17 2472.82 2287.70 555.26N 344.92V1 -127.1 878.57 2503.0C 2263.2L 620.02N 551.51E 17 2500.00 2308.91 572.25N 344.70Vl -127.1 898.65 2603.0C 2317.8C 675.94N 613.86E 17 2575.9C 2368.14 619.72N 344.37V1 -126.5 961.20 2703.0C 2363.97 732.12N 682.44E 17 2647.47 2424.01 664.45N 344.06V1 -125.2 1030.47 ~803.0C 2401.2L 787.94N 756.50E 17 2707.8C 247112 702.13J',[_~:L82V1 -123.0 1105.87 2901.17 2:428.77 841.~1N 833.77E 17 2753.91 2507.13 730.93N 343.93V1 -119.5 1185.5C 2903.0C 2429.1S 842.80N 835.24E 17 2754.85 2507.87 731.52N 343.94V1 -119.5 1187.0:: ~003.0C 2452.56 897.00N ~15.97E 17 2796.76 2540.61 757.68N 344.45V1 -120.7 1271.1:: ~103.0C 2475.9:: 951.21 N 996.69E 17 2840.65 _ 257A~~8504N.__~5.29V1 -121.8 1355.8:: 3203.0C 2499.2S 1005.411\ 1077.41 E 17 2887.55 261159 814.25N 346.30Vl -122.9 1440.87 3303.0C __2.522.66 1059.611\ 1158.13E 17 ~~2934. 35 2648.25 843.33N 347.39V1 -123.8 1526.16 3403.0C 2546.02 1113.811\ 1238.86E 17 2981.40 2685.2C 872.43N 348.55V1 -124.7 161167 3503.0C 2569.3S 1168.021\ 1319.58E 17 3029.13 2722.7S_ 901.82N _~~~~16V1 -12~~.37 3603.0C 2592.7:: 1222.221\ 1400.30E 17 3078.15 2761.47 931.89N 351.01V1 -126.4 1783.21 3703.0C 2616.12 1276.421\ 1481.03E 17 3127.11 2800.2C 961.83N 352.25V1 -127.1 1869.16 3803.0C __~39.4S 1330~621\ 1561.75E 17 3176.4S 2839.31 991.95N 353.49V1 -127.8 1955.1S All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORIGJNAL .e ee """ ConocòPhillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 5 Date Printed: 26-Oct-2004 Kuparuk River Unit, North Slope, Alaska .... ".JJi INTEQ 2438.0C 2223.62 584.06N 514.62E 16 2245.75 2237.59 138.655 364.91\1\ -170.9 1138.46 2468.0C 2242.26 600.62N 531.30E 16 22./37.4Z_-..2259.:i1_13&.235 36486\1\_ -172.3 1161.59 2503.0C 2263.2L 620.02N 551.51 E 16 2288.87 2280.71 137.815 364.80\1\ -173.8 1189.22 2603.0C 2317.8C 675.94N 613.86E 16 2354.32 2346.15 136.365 364.50\1\ -178.3 1271.92 2703.0C 2363.97 73212N 682.44E 16 2410.0<1__ 2401.84 _134 ,ª05__ 364.10\1\ 176.6 1359.5C 2803.0C 2401.2L 787.94N 756.50E 16 2459.82 2451.58 132.9;>5 363.60\1\ 170.3 1450.92 2901.17 2428.77 841.81N 833. 7IDº-. 251QQL 2502.36 130.425 362.91\1\ 162.0 1543.6C 2903.0C 2429.19 842.80N 835.24E 16 2511.17 2502.86 130.405 362.90\1\ 162.0 1545.3L - 3003.0C 2452.56 897 j)ON 915.97E 16 2547.89 2539.51 128.155 362.37\1\ 163.4 1640.93 3103.0C 2475.92 951.21 N 996.69E 16 2585.5<1 2577. DE 125.475 361.83\1\ 164.8 _ 1736.38 3203.0C 2499.29 1005.411\, 1077.41E 16 2622.4C 2613.79 122.505 361.32\1\ 1660 1831.72 3303.0C 2Q22..66 1059.611\ 1158.13E 16 2658.2Q__2649.5C 119.365 360.82\1\ 167.0 1926.99 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Ooyon 14) 88.0ft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated ORIGINAL .- e_ CLEARANCE LISTING Page 6 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska Conoa;'Â'1illips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H INTEQ 2438.0C 2223.62 584.06N 514.62E 18 2002.55 1951.1C 415.185 233.68E 125.6 1073.1E ~68.0C 2242.2E 600.62N 531.30E 18 201.~33 1965.41 420.945 240.29E 123.3 1097.6~_ 2503.0C 2263.2¿ 620.02N 551.51E 18 2030.8E 1975.18 424.955 244.91E 119.9 1126.47 2603.0C 2317.8C 675.94N 613.86E 18 2074.67 2011.88 440.565 263.01E 110.9 1209.6e 2703.0C 2363~-Z32.12N 6B2.44E 18 --- 2103.89 2035.92 421355 275.64E 101.7 1293.71 2803.0C 2401.2L 787.94N 756.50E 18 2133.89 2060~.28 462.765 288.94E 93.2 1378.09 ~901.17 2428.77 841.81N 8~~J7E 18 2157.75 2079.42 472.985__ 299.70E 85.3 1.460.67 2903.0C 2429.19 842.80N 835.24E 18 2158.3E 2079.91 472.325 299.99E 85.3 1462.21 3003.0C 2452.5E 897.00N 91597E 18 2180.0~ -..2.Q~7. 11 480.985 3Q9.92E 86.5 1546.7E 3103.0(; 2475.9; 95121N 996.69.!;; 18 2203.77_ 2115.7~ 490.675 32Q97E 87.8 1632.59 3203.0C 2499.29 1005.411\ 1077.41E 18 2229.86 2135.99 501.555 333.33E 89.1 1719.47 _3303.0C 2.52~ 1059611\ 1158.13E 18 2256.06 215609 ~,§;>5 345.94E 90.4 180722 3403.0C 2546.02 1113811\ 1238.86E 18 2282.36 2176.03 523.985 358.81E 91.6 1895.72 3503.0L 2569.39 1168.Q2t. 1319.58E 18 2310.90 2197.4C 536.485 373JL1E 92.8 1984.8E All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORIGINAL .- -_ CLEARANCE LISTING Page 7 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska .... ..". INTEQ ~illips ConocoPhillips Alaska, Inc. SA Ver#2, SA slot #5, Pad 1 H 2438.0C 2223.6:< 584.06N 514.62E 2 2196.99 2189.57 268.125 356.50,^ -1785 1219.11 2468.0L 2242.26 600.62_N 531.30E2 2215.90 2208.46 268.585 356.77,^ 179.9 1243.11 2503.0C 2263.2< 620.02N 551.51E2 2236.1 C 2228.66 269.075 357.06,^ 178.1 1271.69 2603.0C 2317.8C 675.94N 613.86E 2 2288.40 2280.94 270.355 357.80,^ 172.4 1356.81 2703.0C-----2363.97 732J~ 682.44E 2 2330~8~2323.35 271.455 ~:iL\,II, 165.4 1446A1-_ 2803.0C 2401.2< 787.94N 756.50EL-.__~23º~_2~;;3.99 272.335 358 76,^ :155.7 1539.56 -~-- 2901.17 2428.77 841.81N_ 833.77E 2 2:i86.35 2378.84 273.125 359.07,^. 141.5 1633.52 2903.0C 2429.19 842.80N 835.24E 2 2386.73 2379.22 273.135 359.07,^ 141.6 1635.3C 3003.0C 2452.56 897.00N 915.97~__ 2400.03 ~2.52 21:3.565 359.23,^ 142.6 1732.01 3103.0~~75.92 951.21.N 996.69E 2 2420.39 _2412.85 274.385 359.44,^. 144.1 1828.96 -- 3203.0C 2499.29 1005.411\ 1077.41 E 2 2433.33 2425.79 274.905 359.57,^ 145.0 1926.01 All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Planned oatum(Ooyon 14) 88.Oft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated ORI G1NAL .e ee ~/ . ConocóPhillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 8 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ThïEQ 2438.0C 2223.62 584.06N 514.62E 21 2363.41 2307.18 177.278 317.10E 141.3 790.96 2468.0C 2242.2e 600.62N 531.30E 21 2388.~2329.28 177..8.l8 328.88E 139.8 809.07 2503.0C 2263.2L 620.02N 55151E21 2416.37 2353.81 178.578 342.17E 137.8 830.53 2603.0C 2317.8C 675.94N 613.86E21 2491.69 2419.5~ 180.808 378.88E 1327 894.18 2703.0C 2363.97 732.12N 682.44E 21 2574.89 2491.28 183.428 420.92E 128.1 960.63 2803.0C 2401.~ 787.941'1_ 756.50E 21~_~~_~_265º,"~. 2559.6e 185.538 463.12E 123.9 1028.99 2901.17 2428.77 841.81N _~~.77E 21 .2728.65 2621.35 186.978 502.82E 119.9 1097.7~. 2903.0C 2429.19 842.80N 835.24E 21 2729.80 2622.31 186.998 503.45E 120.0 1099.02 -----ªQ03. DC 2452.5e 897001',!_ 915.97E21 2792.75 2674.73 188.398 538.28E 122.0 ---.1j70.51 3103.0C 2475.92 951.21 N 996.69E 21 2851.85 2723.66 189.968 571.39E 123.6 1242.7E 3203.0C 2499.29 1005.411\ 1077.41E21 2914.99 2775.77 191.928 607.00E 125.2 1315.8C 3303.0C 2522.6e 1059.611\ 1158.13E 21 2984.87 ~....2832 94------.194.308 64710~.J2P7 1389.1: 3403.0C 2546.02 1113.811\ 1238.86E 21 3063.41 2896.09 197.288 69371E 128.2 1462.42 3503.0C 25.99.39 11ºª.02!', 1319.58E 21 3137..5.1.....__29;;4.29 _ 200.468 739.51E _ 129.3 1535.37 3603.0C 2592.75 1222.221\ 1400.30E 21 3204.26 3006.35 203.428 781.12E 130.2 1608.38 3703.0C 2616.12 1276.421\ 1481.03E 21 3268.88 3056.65 206.428 821. 58E 131.0 1681.59 3803.0C 2639.49 _ 133Q.621\ 156175E 21 3336.20 3108..8.8 209.748 ~863.~1 E 13~ 1754.99 3903.0C 2662.85 1384.821\ 1642.47E 21 3405.13 3161.80 213.528 907.93E 132.3 1828.4L 4003.0C 2686.22 1439.031\ 1723.19E 21 _ _3472,~ 3213.20 217.428 ~J.36E 132.9 1901.91 4103.0C 2709.58 1493.231\ 1803.92E 21 3537.37 3262.59 221.248 993.19E 133.4 1975.47 All data is in Feet unless otherwise stated Coordinates are from 810t and TVO's are from Rig ( Planned Datum(Doyon 14) 88.Oft above mean sea level) Reference MO's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) PÕR ", BG' fÑAr"oo .e ·e ConocÓPhillips ConocoPhillips Alaska, Inc. SA Ver#2, SA slot #5, Pad 1 H CLEARANCE LISTING Page 9 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... -øt.-!L;. INtEQ 2438.0C 2223.62 584.06N 51462E 10 2218.77 2210.67 90.89S 4.32E 167.8 846.25 2468.0C 2242.26 .. 600.62i'11 531.30E 10 2241. 66 ~....--...2233 5-º-------_ 91.23S 4.26E 166.3 ß69.77 2503.0C 2263.2L 620.02N 551.51E 10 2262.40 2254.30 91.538 432E 164.4 897.67 2603.0C 2317.8C 675.94N 61386E 10 2328.03 2319.91 92.408 5.21E 158.9 980.20 2703.0C 236397 732.12N 682.44EJO 2391.37 ------.....£383.23 92.848 7.01E 152.9 1066.36 2803.0C 2401.2L 787.94N 756.50E 10 2444.71 2436.53 .9293S 9.20E 145.5 1155.7C 2901.17 2428.77 841.81N 833.77E 10 2482.64 2474.41 -~~ 11.09E 135.7 _ 1246.0;'; 2903.0C 2429.18 842.80N 835.24E 10 2483.15 2474.91 92.91S 11.12E 135.8 1247.72 3003.0C 2452.56 897.00N 915.97E 10 2518.32 2510.03 92.838 1313E 138.5 1340.9E 3103.0C 2475.92 951.21 N 996.69E 10 2554]~ 2546.38 92.72S 15.36E 141.0 1434.48 3203.0C 2499.28 1005.41t\, 1077.41E 10 2583.70 2575.27 92.59S 17.31E 142.8 1528.1L 3303.0C 2522.6E 1059.61 t\, 1158.13E 10 2620..96 2612.43 92.42S 19.94E 144.9 1621.95 3403.0C 2546.02 1113.81t\, 1238.86E 10 2658.30 2649.68 92.248 22.75E 146.8 1715.87 3503.0C ~ 2569.38 1168.02t\, 1319.58E 10 2688.33 2679.60 92, 108 25.16E 148.2 1809.85 3603.0C 2592.75 1222.22t\, 1400.30E 10 2740.69 2731.76 91.858 29.73E 150.3 1903.83 3703.0C 2616.12 1276.42t\, 1481.03E 10 2784.6C 2775.45 91.64S 34.12E 151.8 1997.62 All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Planned Oatum(Ooyon 14) 88.0ft above mean sea level) Reference MO's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated OR! G1NAL .e .e ConocÒPhillips ConocoPhillips Alaska, Inc. SA Ver#2, SA slot #5, Pad 1 H CLEARANCE LISTING Page 10 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska INTEQ 2438.0C 2223.62 584.06N 514.62E 401 (old 2248.81 1943.07 999.28N 140.27E -66.9 625.50 Uqnu-O...1.J 2468.0C 2242.2€ 600.62N 531.30E401 (old 2278.34 1966.33 1017.281\ 142.90E -68.3 632.92 Uqnu-01 ) 2503.0C 2263.2L 620.02N 551.51 E 401 (old 2311.6C 1992 71 1037.321\ 145.77E -69.8 641.84 ~- Uqnu-01 ) ~~--~- 2603.0C 2317.8C 675.94N 613.86E 401 (old 2395.30 2059.63 1087.141\ 152.66E -73.5 669.66 Uqnu-01 ) 2703.0C 2363.97 732.12N 682.44E 401 (old 2485.7€ 2132.54 1140.111\ 160.35E -77.4 701.85 Uqnu::.01 ) --- 2803.0C 2401.2L 78794N 756.50E 401 (old 2562.44 2196.73 1181.69N 165.41E -80.4 739.09 Uqnu-O 1 ) 2901.17 2428.77 841.81N 833.77E 401 (old 2609.86 223792 1205.151\ 166.68E -81.3 783.22 - Uqnu-01 ) 2903.0C 2429.1 S 842.80N 835.24E 401 (old 2610.72 2238.68 1205.561\ 166.69E -81.3 784.12 Uqnu-01 ) 3003.0C 24525€ 897.00N 915.97E401 (old 2641.4C 2265.74 1220.001\ 166.54E -83.5 837.18 Uqnu-01 ) 3103.0C 2475.93 951.21 N 996.69E 401 (old 2673.17 2294 06 1234.351\ 165.43E -85.7 896.79 Uqnu-01 ) 3203.0C 2499.2S 1005.411\ 1077.41 E 401 (old 2702.6C 2320.64 1246.861\ 163.76E -878 961.76 Uqnu-01 ) 3303.0C 2522.6€ 1059.611\ 1158.13E 401 (old 2733.48 2349.05 1258.731\ 161.27E -89.9 1031.27 Uqnu-O 1 ) ~-~--_.~ 3403.0C 2546.02 1113.811\ 1238.86E 401 (old 2754.96 2369.08 1266.171\ 159.17E -91.4 1104.65 Uqnu-01 ) 3503.0C 2569.38 1168.021\ 1319.58E 401 (old 2772. 57 2385.63 1271.821\ 157.14E -92.6 1181.45 Uqnu-01 ) 3603.0C 2592.75 1222.221\ 1400.30E401 (old 2786.28 2398.58 1275.981\ 155.37E -93.5 1261.12 Uqnu-O 1 ) 3703.0C 2616.12 1276.421\ 1481.03E 401 (old 2796.73 2408.47 1279.001\ 153.88E -94.3 1343.28 Uqnu-01 ) 3803.0C 2639.4S 1330.621\ 1561.75E 401 (old 2807.18 2418.38 1281.891\ 152.28E -95.0 1427.5L _~_~__Uqnu-01) ._~~-~--~ 3903.0C 2662.85 1384.821\ 1642.47E 401 (old 2817.92 2428.58 1284.75N 150.50E -95.7 1513.5€ Uqnu-O 1 ) ~- 4003.0C 2686.22 1439.031\ 1723.19E 401 (old 2824.00 2434.36 1286.311\ 149.43E -96.1 1601.08 Uqnu-01 ) 4103.0C 2709.58 1493.231\ 1803.92E401 (old 2828.6€ 2438.78 1287. 501\ 148.60E -96.4 1689.88 Uqnu-01 ) 4203.0C 2732.95 1547.431\ 1884.64E401 (old 2839.40 244899 1290.15N 146.58E -97.1 1779.8C Uqnu-O 1 ) 4303.0C 2756.32 1601.631\ 1965. 36E 401 (old 2839.40 2448.99 1290.151\ 146.58E -97.1 1870.68 Uqn.u-01 ) 4403.0C 2779.68 1655.841\ 2046.09E 401 (old 2855.47 2464.28 1293.881\ 143.33E -98.2 1962.38 Uqnu-OtL~~ -- All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated ORIGIN.At~ ee ee ~' . ConocOPhillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 11 Date Printed: 26-Oct-2004 Kuparuk River Unit, North Slope, Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Planned Datum(Ooyon 14) aa.Oft above mean sea level) Reference MO's are from Rig, Offset MD's are from Rig Calculation method uses Minimum CUNature method Confidence Limit of 99.01 (1 D) PoaR bl tje} rJÃnrorated ... IIfItI:...¡ INTEQ ·e -e ~/ - ConocòPhillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 12 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... IIMIftIL: INTEQ 2438.0C 2223.62 584.06N 514.62E 19 2032.77 1851.71 506.61N 639.091/\ -108.6 1214.65 2468.0C _ 2242.26 600.62N 531.30E 19 2051.04 __1865.04 518.03N 644.151/\ -108.3 1237.25 2503.0C 2263.21 620.02N 55151E19 2072.84 1880.94 531.66N 650.211/\ -107.4 1264.16 2603.0C 2317.8C 675.94N 613.86E 19 2125.92 1919.63 56484N 665.051/\ -103.8 1344.05 2703.0C 2363.97 __732.12N_º.82.44E 19 2166.67 1949.27 59Q26N 676.671/\ -98.3 1428.01 2803.0C 2401.21 787.94N 756.50E 19 2200.Qº- 1973.47 611.03N 686. 391/\ -90.9 1515.33 --- 2901.17 2428.77 841.81 ~_-ª-33.77E_~.____... 2228.12 ~,--ª-L_º-28.51N 694.641/\ -81.7 1603.32 2903.0C 2429.19 842.80N 835.24E 19 2228.61 1994.24 628.82N 694.781/\ -81.7 1604.9E 3003.0C . 2452.56 897.00N 91597E 19 ._____.~258.6.L_...2016j)8 647.50N 703.591/\ -83.6 1695.79 3103.0C 2475.93 951.21 N .J9§j¡9EJlJ~__ 2285.77 2035.8C .J364.33N 711.491/\ -85.3 1787.15 3203.0C 2499.29 1005.41t\, 1077.41E 19 2315.69 2057.58 682.91 N 720.201/\ -87.0 1878.97 3303.0C 2522.66 1 0§9. 6 L"'----1:!-º8. 13 E 19 2342.93 2077.41 6~.82N 728.111/\ -88.5 1~Zl.19 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated ORiGiNAL .e ee )00:' ~ ConocóPhillips ConocoPhillips Alaska, Inc. SA Ver#2, SA slot #5, Pad 1 H CLEARANCE LISTING Page 13 Date Printed: 26-Oct-2004 Kuparuk River Unit, North Slope, Alaska ... .'IIIS INtEQ 2438.0C 2223.62 584.06N 514.62E 4 2213.83 2216.62 387.788 354.39'11 175.4 1303.73 2468.0C 2242.26 600.62N 531.30E4 223233 2235.11 387.648 __~~54.69V\ _~ 173.8 1327.29 2503.0C 2263.2L 620.02N 551.51E4 2252.91 225569 387.498 355.03'11 171.9 1355 3E 2603.0C 2317.8C 675.94N 613.86E4 2307.12 2309.9C 387.158 355.86'11 166.1 1438.9E 2703.0C 2363.97 732.12N. 682.44E 4 2353.4E 2356.22 386.908 356.51'11 159.1 1526.9€ 2803.0C 2401.2L 78794N l.56.50E 4 2390.07 2392.82 386.758 356.94'11 149.8 1618.56 2901.11 2428.77 841.81N 833.77]; 4 2409..J E 2411.91 386.698 357.21'11 136.5 ._1711.~__ 2903.0C 2429.19 842.80N 835.24E 4 2409.5E 2412.31 386.698 357.21'11 136.5 1712.86 3003.OC ~2452.56 89'Z.00N 915.97E4 2425.0C 242776 ____386.668 357.46'11 137.6 1808.32 3103.0C 2475.92 951.21 N 996.69E 4 2435.27 2438.03 386.678 357.74'11 138.4 1904.16 All data is in Feet unless otherwise stated Coordinates are from 810t and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORIGINAL .e -e Conocò'Phillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 14 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska INTEQ 2438.0C 2223.6:2 584.06N 514.62E 7 2574.99 2537. 98 9.13S 131.78E 167.9 772.83 2468.0C 2242.26 600.62N 531.30E7 2608.3~ 2568.36 :U~. 137.48E ___167.5 786.20 2503.0C 2263.2L 620.02N 551.51E7 2644. 9~ 2601.5~ 17.46N 143.81E 167.0 802.34 2603.0C 2317.8C 675.94N 613.86E7 2751.80 2697.53 60.37N 162.84E 166.1 852.37 2703.0C 2363.97 732.12N 682.44E 7 2855. 5~ 2789.15 104.8QN 182.53E___ 165.5 907.81 2803.0C 2~01.2L 787.94N 756.50E 7 2947.77 2869.42 146.56N 200..QJ E 164.8 969.38 ~2.901.17 2428.77 841.81!'L_ 833.77E 7 3037.50 2946.5~ 188.93N 218.10E 1643 103~~___ 2903.0C 2429.19 842.80N 835.24E 7 3038.6<1 2947.50 189.48N 218.33E 164.3 1037.33 3003.0C 2452.56 897.00N 91597E7_ 3149.4«1 3040.2~ 245.62N_~~_ 168.2 1106.7e 3103.0C 2475.93 951.21 N 996.69E 7 32489~_ 3121.30 299.14N 262.68E 171.2 1174.93 3203.0C 2499.29 1005.411\ 1077.41 E 7 3344.12 3197.29 352.38N 283.95E 173.8 1242.27 3303.0C 25£2.6(3 1059.611\ 1158. 13E 7 344178 327385 408.71 N 306.37E 176.2 1309.0C 3403.0C 2546.0:2 1113.811\ 1238.86E 7 3531.21 3342.75 461.46N 327.96E 1781 1374.79 3503.0C 2569.39 Up8.021\ 131958E7 3615.30 3407.12 _----º11.231\!_ 349.18E __..1Z~J~ 1440.43 3603.0C 259275 1222.221\ 1400.30E 7 3707.07 3476.85 565.68N 373.56E -178.6 1505.61 3703.0C 2616.1:2 1276.421\ 1481.03E 7 3775.4~ 3528.64 606.29N 392.11E -177.6 1570.83 3803.0C 2639.49 1330.Q2L_ 1561.75E7 3845.69 3581.97___-º17~86N 411.15E -176.5 1636.55 3903.0C 2662.85 1384.821\ 1642.47E 7 3919.7C 3638.25 691.42N 431.47E -175.5 1702.57 4003.0C 2686.2:2 1439.031\ 1723.19E] 3994.04 3694.82 734.g8t'J__--.-A.Q2Jß~ -174.6 1768.7L 4103.0C 2709.5e 1493.231\ 1803.92E 7 4063.47 3747.7C 775.54N 471.63E -173.8 1835.1L 4203.0C 2732.95 1547.431\ 1884.64E 7 4130.8~ 3799.09 814. 8QJ':L_~0 .40E -173.1 1901.9C 4303.0C 2756.3:2 1601.631\ 1965.361;: 7 4195.9~ 3848.91 852.70N 508~ -172.5 1969.1:2 -- All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) P'01< fš mæxr" ·e -e .,< . ConocóPhillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 15 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska .... W\J..; INTEQ 2438.0C 2223.6:< 584.06N 514.62E 6 2183. 5~ 2192.13 129.818 6.14W 165.9 884.19 2468.0C 2242.26 600.62N 531.30E6 2202.79 2211.36 130.558 6.28W 164.3 908.05 2503.0C 2263.2L 62002N 551.51E6 2222.9C 2231.45 131.338 6.38W 162.3 936.36 2603.0C 2317.8C 675.94N 61386E6 2279.11 2287.62 133.598 6.34W 1561 1020.2L 2703.0C 2363.97 ~.12N 682.44E 6 2325.91 23~.4.37 _ 135.578 5.94W 148.7 1107.9E 2803.0C 2401.2~ 787.94N 756.50E 6 2364.8C 2373.23 137.298 5.31W 139.4 1198.82 2901.17 2428.77 841.81N 833.77E6 2394.86 2403.2~ 138.6.§..~~.62W 1275 1290.3C 2903.0C 2429.19 842.80N 83524E 6 2395.27 2403.66 138.688 4.61W 1275 12920:< 3003.0C 2452.56 897.00N 915.97E6 2424 09 2432.42 .-140038 3.76W 130.2 1386.26 __.......9103 OC 2475.93 951.21 N 996.69E 6 .2...456 25 2464.53 141.548 2.55W 132.9 . 1480.7E 3203.0C 2499.29 1005.41t\, 1077.41 E 6 248987 2498.07 143.158 0.97W 135.4 1575.46 3303.0C 2522.66 1059.61 t\, 1158.13E-º-_____._2522.J>1_ 2530.79 144.718 0.81E 137.7 1670.2E 3403.0C 2546.02 1113.81t\, 1238.86E 6 2554.1C 2562.13 146.198 2.59E 139.6 1765.2E 3503.0C~69.39 1168.02t\, 1319.58E 6 2579.74 2587.7C 147.378__ 4.13E 14t.L..........1ß60.37 3603.0C 2592.75 1222.22t\, 1400.30E 6 2607.84 2615.72 148.678 583E 1426 1955.61 6 GMS <0-6750'> All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated OR1GINAL .e -e ~iIlips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 16 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska INTEQ 2438.0C 2223.62 584.06N 51462E 8 1838.01 1828.57 442.938 34.25\fv 140.1 1229.6L 2468.0C 2242.26 600.62N 531.30E 8 1847.97 1837.98 445.438 36.3~ 137.0 1256.93 2503.0C 2263.2L 620.02N 551.51E8 1858.67 1848.1C 448128 38.58\fv 132.7 1288.98 2603.0C 2317.8C 675.94N 613.86E 8 1874.27 1862.81 452.048 41.94\fv 118.0 1381.82 ~103.0C_ 2363.97 732.12N 682.44E 8 1888.44 1876.17 455.608 45.09\fv 101.9 1475.77 ~803.0C_ 2401.2L 787.94N 756.50E 8 1893.11 1880.56 456.778 46.12\fv 8Q.&~_1569.91 2901.17 2428.77 _1M.1.81N_ 833. 77J;-ª----~~._ 1888.38 1876.1C_ 455.588 45.07\fv ._~ 1661.63 2903.0C 2429.19 842.80N 835.24E 8 1888.20 1875.94 455.548 45.03\fv 71.4 1663.33 3003.0C 2452.56 -ª97.00N__ 915.97E 8 1878.69 1866.98 453.158 42.9_2\lIJ~ 70.5 1756.5C 3103.0C 2475.9£.~ 951.21N 996.69E 8 1869.19 1858.03 _1~Q 778 40.81\fv 69.7 1850.32 3203.0C 2499.29 1005.411\ 1077.41 E 8 1866.67 1855.65 450.138 40.25\fv 69.5 1944.75 All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Planned Oatum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) P'lJ'~ fG ÏÑ~Ãr"d .e -e eonoOOPhillips ConocoPhillips Alaska, Inc. SA Ver#2, SA slot #5, Pad 1 H CLEARANCE LISTING Page 17 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... W~ INTEQ 2438.0C 2223.62 584.06N 514.62E 3 2050.2~ 1983.0~ 30.90S 717.11V\ -145.1 1397.5E 2468.0C 2242.2~0.62N _5~30E 3 2066.~__1998.11 27. 58S__---...Z21.71 V\ -145.7 1422.77 2503.0C 2263.2L 620.02N 551.51E3 2078.28 2009.2~ 25.06S 725.20V\ -145.8 1452.8C 2603.0C 2317.8C 675.94N 613.86E 3 2117.1C 2045.39 16.75S 736.66V\ -145.4 1542.0e 2703.0C 2363.97 732.12N 682.44E 3 2146.59 2072. 73 1 0.24~ 745.56V\ -143.1 1635.57 2803.0C 2401.2L 787.94N 756.50E 3 2166.67 2091.31 5.7~51.70V\ -136.9 1732.22 2901.17 2428.77 841.81N 833.77E 3 2179.4e 2103.1C 2.77S 755.68V\ -118.8 1829.12 2903.0C 2429.19 842.80N 835.24E 3 217962 2103.25 2.74S 755.73V\ -118.8 1830.ge 3003.0C 2452.56 897.00N 915.97E 3 2188.52 ..2111.45 0.688 7~8.51V\ -120.3 1930.3C All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) prDR fB rrzr;trr:rated .e -e c:onoa*mllips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 18 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... ~ INTEQ 2438.0C 2223.62 584.06N 514.62E 15 2395.98 2184.42 374.838 325.27E 131.8 978.20 ~4680C_ 2242.26 600.62N !5~1.30E 15 2416.49 ~-2197.40 378.448 ~4075E 129.5 998.44 2503.0C 2263.2L 620.02N 551.51E 15 2438.21 2210.9<1 382.325 357.27E 126.6 1022.32 2603.0C 2317.8C 675.94N 613.86E 15 2500.00 224833 393.795 405.11E 118.7 1092.12 ~03.0C_~363.97 732.12N 682.44E 15 2564.20 2285.67. 406.338 455.80E~ 111.5 ~.4~___ 2803.0C 2401.2L 787.94N 756.50E 15 2626.0G 2320.7L 418.848 505.08J;;.~ 105.0 1235.32 2901.17 2428.77 ª41.¡;tlli~~,ll.çJ..~___ 2681i.~!L 2356.45 431.6~S_ 554.63E 99.4 1305.7C 2903.0C 2429.1S 842.80N 835.24E 15 2689.59 2357.15 431.90S 555.59E 99.5 1307.01 3003.0C 2452.56 897.00N 915.97E 15 2753.25 2393.90 _445.078 605.88E 100.7 1378.6e 3103.0C 2475.92 951.21 N 996.69E 15 ____2817.17__ 2430.92 458.3.!5.s...~ 656.26E 101.9 1450.7E 3203.0C 2499.2S 1005.411\ 1077.41E 15 2876.53 2465.06 470.898 703.17E 102.8 1523.3E 3303.0C 2522.66 1Q59.6~ 151i.13E 15 __._ 2933.37 2497.26 483.1ß..8 748.37E 103.7 1596.4E 3403.0C 2546.02 1113.811\ 1238.86E 15 2993.89 2530.41 496.778 797.14E 104.4 1670.13 3503.0C 2569.3S 1168.021\ 1319.58E 15 3056.17 2563.87 511.068 847.70E 105.1 1744.13 3603.0C 2592.75 1222.221\ 1400.30E 15 3120.8<1 2598.63 525.928 900.16E 105.7 1818.2S 3703.0C 2616.12 1276.421\ 1481.03E 15 3186.4C 2633.87 541.028 953.35E 106.3 1892.5E 3803.0C 2639.4S ....1330.Q2~_1561.75E 15________3252.6C. 2669.46 556.278 _.....1007.04E 106.9 1966.96 15 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ORIGINAL ee -e ,.,' ~ ConocòPhillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 19 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... ... LNTEQ 2438.0C 2223.62 584~06N 514~62E 12 2402~ 52 2294.4C 77.52N 526.06E 127.2 511.59 ___246!LQÇ~42.26 600.62N 531.30E 12 2429.18 2316.51 80.94N _540.55E 126.2 _525.05 2503.0C 2263.2L 620.02N 551.51E 12 2462.63 2344.07 85.34N 558.99E 125.1 540.81 2603.0C 2317.8C 675.94N 613.86E 12 2558.05 242154 98.64N 613.08E 122.5 586.55 2703.0C 2363.97 732.12N 682.44E 12 2648.48 2493.71 112.11N 665.86E 120.7 633.65 2803.0C 2401.2L ___~~~~_}5650E~_~_____~_ 273~J3. 2561 09 125.18N 716.44E 119.4 682.94 2901.17 2428.77 841.81N 833.77E 12 2813.59 2623~11 137.53N 7j)4.44E 118.4 734~05 2903.0C 2429.1 S 842.80N 835~24E 12 2814~98 2624.79 137.74N 765.28E 118.4 735.02 3003.0C 2452~ 56 897.00N 915.97E 12 2901.65 2691.66 1'§'1.51 N 818.66E 121.7 788.9£ ~103.0C 2475.92 951.21 N ..ß.96.69E 12 __~8.U.<L.. 2753.71 164.8QtL__ 870.68E 124.3 843.49 3203.0C 2499.2S 1005.411\ 1077.41 E 12 3065.09 2814.45 178. DON 923.22E 126.5 898.72 3303.0C 2522.66 1 059~611\, 1158.13E 12 3159~32 2883.9L 193.49N 98~93ç_ 128.6 954.30 3403.0C 2546.02 1113.811\, 1238.86E 12 3264.68 2958.62 211.64N 1056.99E 130.5 1008.57 3503.0C 2569.3~ 1168.02~_..1~19.58E 12 3358.Q!L 3022.66 228.~ 1123.75E 131.9 1061.5L 3603.0C 2592.7!: 1222.221\ 1400.30E 12 3441.7~ 3078.82 243. DON 1183.16E 132.9 1114.57 3703.0C 2616.12 1276.421\, 1481.03E 12 3523~ 32 3133.97 25732N 1241.54E 133.8 1167.9L 3803~OC 2639.4S 133~_ 1561.75E 12 ~~1§___ 3191.59 272.~14N 1303.42E 134.6 1221.4L 3903~OC 2662 8!: 1384.821\, 1642.47E 12 3693.9C 324785 286.48N 1365.14E 135.3 1274.9!: 4003.0C 2686.22 1439.031\, 1723.19E 12 3764~03 3294.29 29792N 1416.43E 135.8 1328.9C 4103.0C 2709.5E 1493.231\, 1803.92E 12 3841.43 3345.75 309.94N 1472.98E 136.4 1383.62 4203.0C 2732.9!: 1547.431\, 1884~64E 12 3923.28 3400.2iL._~ 322.46N 1532.74E--.136.9 1438.6!: 4303.0C 2756.32 _16~01.631\, 1965.36E 12 4007.8!: 3456.88 335.78N__ 1594.14E 137.4 1493.6!: -- 4403.0C 2779.6E 1655.841\, 2046.09E 12 4085.86 3509~53 348.32N 1650.32E 137.9 1548.8L 4503.0C 2803.0!: 1710041\, 2126.81E 12 4160.1!: ~560.08_. 360.24N 1703.44E 138.3 1604.47 4603.0C 2826.41 1764.241\, 2207.53E 12 _4257.9C 3626.91 376.13N 1772.97E 138.9 1660.27 4703.0C 2849.78 1818A~~__228~26E 1~_~_~~_~2L 3712.67 398.54N 1864.40E 139.6 1714.7L 4803.0C 2873.1L 1872.651\, 2368.98E 12 4478.08 3774 08 416.21N 1931.74E 140.0 1767.5C 4903.0C 2896.51 1926.851\, 2449.70E 12 4562.52 3829.7S 432.25N 1993.14E 140.4 1820.2!: 5003.0C 2919.88 1981.051\, 2530.43E 12 _19-º2.45 3889.01 _<H9.28N 2058.65E ..140 7 1873.0C --- 5103.0C 2943.2L 2035.251\, 2611.15E 12 4733.33 3942.1~ 464.66N 2117.65E 141.0 1925.6L 5203.0C 2966.61 2089.451\, 2691.87E 12 4799.05 3985.4!: 476.57N 2165,62E.. 141.3 1978.98 12 12 PGMS <0-10172'> All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Oatum(Ooyon 14) 88.Oft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated ORIGINAL ee ee Conocd»t,illips ConocoPhillips Alaska, Inc. SA Ver#2, SA slot #5, Pad 1H CLEARANCE LISTING Page 20 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... .~u.;. INTEQ 2438.0C 2223.62 584.06N 514.62E 14 2235.93 2228.86 33.31N 5.75W 177.9 757.72 2468.0C 2242.2§ 600.62N 531.30E 14 2255.17 2248.1 C 3341N 5.65W 1764 781.07 2503.0C 2263.2L 620.02N 551.51E 14 2276.36 2269.29 33.51N 5.53W 174.6 808.90 2603.0C 2317.8C 675.94N 613.86E 14 23334~ 2326.37 33.84N 5.15W 1694 891.93 2703.0C 23~~7 732.12N 682.44E 14 2384.06 2376.98 _~27N 4.71W 1634 97946 2803.0C 2401.2L 78794N 756.50E 14 2441.0~ 2433.95 35..31N_._ 4.05W 156.5 __1QZQ,5C ~01.17_-2±28.77 841.81N 833.77E 14 2507.73 2500.55 38.45N 2.86W 149.2 1162.1C 2903.0C 2429.19 842.80N 835.24E 14 2508.25 2501.07 3848N 2.84W 1493 1163.82 3003.0C 2452.56 897.00N 915.97E 14 25-º-647 _ 2559.08 43.07N__.-1..32W 153.3 1257.76 3103.0C 2475.93 951.21 N 996.69E 14 2641.7~ 2633.82 51.54N 143E 157.5 1350.8!: 3203.0C 2499.29 1005411\ 107741 E 14 2737.62 272846 66.06N 6.19E 161.7 1443.05 3303.0C ~522.66 1059.611\ 1158.13E 14 2862 33 2850.12 ..92.17N 14.19E 166.1 1533.55 ~~.~ 3403.0C 2546.02 1113811\ 1238.86E 14 2990.98 297347 127.05N 24.83E 1697 1621.81 3503.0C 2569.39 1168.02-""--....1.3.1~.58E 14 3214.6C ....31.ª-LQ;j 20444N 50.54E 174.5 1706.95 3603.0C 2592.75 1222.221\ 1400.30E 14 348746 34204~ 327.71N 95.90E 179.2 1785.12 3703.0C 2616.12 1276421\ 148103E 14 357549 3493.82 373.60N 11193E -1794 1860.07 3803.0C 263949 1330.62[\ _.J2Q1.75E 14 .~~~- 3659.51 ..3562.77 419.31N 126.63E -178.1 1934.56 3903.0C 2662.85 1384.821\ 164247E 14 4170.56 393686 744.95N 24243E -171.1 1998.16 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Ooyon 14) 88.Oft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Põl~ 1 BG'¡"ÑÃr- ee ee ,.---.....'.!"~·II· UJlJUUI"'"nllpS ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 21 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska INTEQ 2438.0C 2223.62 584.06N 514.62E 9 1906.28 1745.39 454.355 549.33E 95.9 1143.77 2468.0C 2242.2€ 600.62N 531.30E9 1920.00 1I55.25 458.605__557.88E 9~_~ 1166.1:: 2503.0C 2263.2L 620.02N 551.51E9 1940.00 1769.4C 464.805 570.57E 92.0 1192.09 2603.0C 2317.8C 675.94N 613.86E 9 198631 1801.30 479.135 600.92E 85.9 1265.3€ 2703.0C 2363.97 732.12N _~--ºª244E3___~___~35.52_ 1834.00 494.355 634.41 E 80.9 1336.93 2803.0C 2401.2L 787.94N 756.50E 9 2083.6C 1864.98 509.245 _668.02E 76.8 1406.4L 2901.17 2428.77 841.81N 833.77E 9 2130.55 1894.36 _523.805 701.61 E 73.4 1472.4C 2903.0C 2429.19 842.80N 835.24E 9 2131.57 1894.99 524.125 702.36E 73.4 1473.6C 3003.0C 2452.5€ 897.00N 915.97E 9 2180.0C 1924.47 ~539.J 85 737.6~._ 75.0 1540.55 3103.0C 2475.92 951.21 N 996.69E 9 2234.8C 19.5707 556.265 _....l78.30E 76'ª---.. 160915 3203.0C 2499.29 1005.411\ 1 077.41 E 9 2291.68 1990.81 573.995 820.52E 78.4 1679.0C 3303.0C 2522.6€ 1059.611\ 1158.13E 9 2351.19 2026.12 592.525 86A&~__80.1 _ 1749.91 3403.0C 2546.02 1113.811\ 1238.86E 9 2408.77 2060.31 610.395 907.45E 81.6 1821.71 3503.0C .2569.3~ 1168.02~_ 1319.58£9____ 2465.4.L. 2093.29 627,ª85 950.02E 83.0 1894.32 3603.0C 2592.75 1222.221\ 1400.30E 9 2522.8€ 2125.77 645.565 994.01E 84.3 1967.67 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated ORJG~NAL ee ee ~illips ConocoPhillips Alaska, Inc. SA Ver#2, SA slot #5, Pad 1 H CLEARANCE LISTING Page 22 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... rw.'u.;. INTEQ 2438.0C 2223.62 584.06N 514.62E 22 2226.35 2214.19 127.965 254.9811I -176.0 1048.51 2468.0C 224226 600.62N 531.30E22 2244.58 2232.3.C 129.565 253.7311I -177.7 1072.16 2503.0C 2263.2L 620.02N 551.51E 22 2261.63 2249.23 131.185 252.4911I -179.6 1100.42 2603.0C 2317.8C 675.94N 613.86E 22 2308.11 2295.28 136.225 248.7511I 174.5 118499 2703.0C 2363.97 732.12N 682.44E 22 2350.66 2~:rr3~ 141.5~~491111 167.3 1274.33 2803.0C 2401.2L 787.94N 756.50E 22 23846º--£:r70.85 . 146.135 241.5711I 1576 1367.32 .~_2901.17 2428.TL_~ 84j.81N 833.77E 22 2410.79 2396.56 149.885 238. 85'lL_ 143.6 146J...17 2903.0C 2429.19 842.80N 835.24E 22 2411.22 2396.98 149.955 238.8111I 143.7 1462.93 3003.0C 2452.56 897.00N 915.97E22 2434.~_. 2420.21 153.468 236.2611I 145.1 1559.53 3103.0C 2475.93 ~21N 996.69E 22 2458.5~ 2443.47 157.108 233.5911I 146.3 1656.19 3203.0C 2499.29 1005.411\ 1077.41E 22 2482.36 2466.83 160.858 230.8211I 147.4 175291 3303.0C 2522.66 1059.611\ 1158. 13E 22 2505.51 2489.51 164.5JJL_.....228.08111 148.4 1849.67 3403.0C 2546.02 1113.811\ 1238.86E 22 2529.3C 2512.80 168.488 225.1811I 149.3 1946.4E PGMS <0-7440'> All data is in Feet unless otherwise stated Coordinates are from 510t and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated OR!G!NAL~ ee ee eonoa*hillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 23 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska .... 'III. INtEQ 2438.0C 2223.62 584.06N 514.62E 13 2087.12 1866.28 275.608 712.38E 91.5 951.74 2468.0C 2242.2E 600.62N 531.30E 13 2104.38 1877.35 277.218 ~25.51E 90.2 970.29 2503.0C 2263.2- 620.02N 551.51E 13 2126.3<1 1891.27 279.278 742.38E 88.4 991.72 2603.0C 2317.8C 675.94N 613.86E 13 2193.41 1932.47 285.518 794.93E 84.2 1051.49 2703.0C 2363.97 732.12N 682.44E 13 2262.41 j973.37 291.898 _ 850.13E 80.9 1108.72 _~03.0C 2401.2- 787.94N 756.50E 13 2334.2L. 2015.09 2~57S_ 908.18E 78.5 1163.02 2901.17 2428.77 JL41.81 N 833.77E 13 2411.17 2059.78 _~05.648 970.44E 77.1 1213.0: 2903.0C 2429.19 842.80N 835.24E 13 2412.52 2060.56 305.778 971.53E 77.1 1213.9: 3003.0C 2452.5E 897.00N 915.97E 13 2487.57 21042fL 312.568 1032~17E 79.2~ 1264.0E 3103.0C 2475.92 951.21 N 996.69E 13 2573.5<1 2153.82 319.818 1102.m.L......--.ßi..~1315.42 3203.0C 2499.29 1005.411\ 1077.41E 13 2655.38 2200.15 325.818 1169.22E 83.3 1367.5C 3303.0C . 2522.6ç_ 1059.611\ 1158. 13E.J..L............~_ 2731.77_ 2243.72 331,278 1231.74E 85.0 1420.48 3403.0C 2546.02 1113.811\ 1238.86E 13 2804.31 2285.21 336.498 1291.02E 86.5 1474.49 3503.0C 2569.39 1168.021\ 1319.58E 13 287336 2324.28 ---ª41588 1347.72E 87.9 1529.62 3603.0C 2592.7: 1222.221\ 1400.30E 13 2946.37 2364 97 347.148 1408.08E 89.2 1585.82 3703.0C 2616.12 1276.421\ 1481.03E 13 3017.9C 2405.02 352.778 1467.09E 90.4 1642.87 3803.0C 2639.49 1330.~__. 1561.75E 13 ~092.01__ 2446.69 358.728 1528.08E 91.6 1700.6- 3903.0C 2662.8: 1384.821\ 1642.47E 13 31883: 2500.9: 365.938 1607.36E 93.1 1758.57 4003.0C 2686.22 1439.031\ 1723.19E 13 3291.86 2559.1<1 372. 13s...~ 1692.73E 94.5 1815.87 4103.0C 2709.58 1493231\ 1803.92E 13 3372.15 2604.32 376.268 1758.98E 95.6 1872.99 4203.0C 2732.9: 1547.431\ 1884.64E 13 3449.02 2647.73 ~...J80228 1822.30E 96.6 1930.51 4303.0C _2756.32 1601.631\ 1965.36E 13 3527.01 2691.97 384.218~ 1886.40E 97.5 1988.46 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Oatum(Ooyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1D) prfjeN ra.l;. 5. rj.' UihE1:.. S.lncorporated ""i\) ",11\11\' \.A" \ \1",,1 '1 "~to 'I'M ¡ . '~'" ~ ~ ee ee C~II¡ps ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 24 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... ... INtEQ 2438.DC 2223.62 584.D6N 514.62E 5 2435.0.0. 2223.58 584.D8N 514.65E 6.5 0..0.5 2444.72 2227 ~8L 587.77N 518.32E 5 2441.7_3__ 2227.84 587.78N 51]d~_ -71.2 0..01 2468.0C 2242.26 6DD.62N 531.30E 5 2465.0.0. 2242.35 6DD.69N 531.13E -124.0. 0..20. 25D3.DC 2263.2L 62D.D2N 551.51E 5 2499.99 2263.96 620..21 N 55D.53E -139.1 1.23 260.3. DC 2317.8C 675.94N 613.86E 5 2599 76 2323.73 676.651\[.__ 6D7.D5E -146.4 ___9.0.6 27D3.DC _~363.97 732.12N 682.44E 5 _~6992D 2380..46 734.D9t:-L......_665.10E -148.7 24.01 2803J2C..-.24D1.2L 787.94N 756.50E 5 2797.36 2433.91 791.66N 72~1JAE -150..3 46.28 --- 290.1.17 2428.77 84181N 833.77E 5 2892.79 2483.95 848.0.1 N 782.49E -151.8 75.58 290.3. DC 2429.19 842.8DN 835.24E 5 289451 2484.82 849.D-3N _783.56E -151.8 76.19 3DD3.DC 2452.56 897.DDN 915.97E 5 2989.97 2;13.3AL 9D5.44N 843.31E -152.6 109.03 31D3.DC 2475.92 951.21 N 996.69E 5 30.85.13 2581.71 96D.9DN 9D3.69E -153.4 141.18 32D3.DC 2499.29 10.05.411\ 10.77.41 E 5 3181.47 2630..55 1016.291\ 965.53E -154.2 172.84 33D3.DC 2522.66 1059.611\ 1158.13E5 32780.2 2679.15 10.71.311\ 1D28.28E -155.0. 20.3.69 34D3.DC 2546.02 1113.811\ 123886E 5 3375.0.2_._ 2727.27 1126.431\ 1091.95E -155.5 233.64 3503.0C 2569.39 1168.0.21\ 1319.58E 5 3474.4<1 2775.75 1182.731\ 1157.98E -156.0. 262.56 360.3. DC 2592.75 1222.221\ 14DD.3DE 5 357252 2822.92 1238.101\ 1223.8DE -156.4 290.49 3703.0C 2616.12 1276.421\ 1481.D3E.§..__ 3672 58 ...2.870..29_ 1294.391\ 1291.63E -156.8 317.48 3803.0C 2639.49 1330..621\ 1561.75E 5 3769.8<1 2915.82 1348.871\ 1358.D9E -157.2 343.77 39D3.DC 2662.85 1384.a2!'-..._J242._47E 5 3867.58 2961.44 ..1'1.0.3.371\ 1425.2DE -15li_ 369.73 4DD3.DC 2686.22 1439.031\ 1723.19E 5 3963.98 30.0.6.51 1456.70.1\ 1491.66E -157.9 395.61 41D3.0C 2709.58 1493.231\ 18D3.92E 5 __'H252.-ª-º----__ 3049.16 150.4.531\ 1553.22E ::.1 58.4 422.24 4203.0C 2732.95 1547 ~_jß84.64E 5 4139.89 3093.2C 1549.0.0."'-- 1613.69E -159.3 450..78 43D3.DC 2756.32 1601.631\ 1965.36E 5 4221.26 3136.12 1589.271\ 1669.89E -160.2 481.36 4403.o.L...........2779.68 1655.841\ 2D46.09E..5_____ 4296.31 3178.1s... 1624.90.1\ 172D.8DE -161.1 515.35 4503.0C 280.3.0.5 ..:1110..041\ 2126.81 E 5 4384.65 3230..1<1 1665. OO!'...._ 1779.89E -162.3 552.0.7 46D3.DC 2826.41 1764.24L.......22D7.53E 5 4475.40. 3284.0.2 170.5.101\ 184D.95E -163.5 589.31 47D3.DC 2849.78 1818.441\ 2288.26E 5 4566.40. 3338.52 1743.891\ 19D2.65E -164.7 627.0.0. 48D3.0C 2873.1L 1872651\ 2368.98E 5 4667.19 3398.6C 1786.221\ 1971.62E -166.0. 664.43 490.3. DC 2896.51 1926.85"'-------2449.7DE 5 4772.94 3460..25 1831.1~._ 2D44.87E -167.1 ---.LOD.61 50.0.3. DC 291988 1981.0.51\ 253D.43E 5 4880.13 352117 1877.20.1\ 2120.D7E -168.1 735.35 5103.0C 2943.2L 2035.25""-------.2.611.15E 5 4981.2<1 3577. 16 1921.~ 2191.86E -169.0 768.54 520.3. DC 2969.61 20.89.451\ 2691.87E 5 5087.0.5 36~.4c.32 _ 1967.671\ 2267.80E -169.7 80.0.33 53D3.QC 2989.97 2143.661\ 2772.59E 5 --- 5181.81 3Qß.5.2<1_ 20.0.9.321\ 2336.DDE -170..4 831.90. 54D3.0C 3013.3L 219786L_~853.32E 5 5276.28 3736. DC 2D~ 24D4.12E -171 JL... 863.53 55D3.DC 3D36.7C 2252.0.61\ 2934.D4E 5 5371.0.1 3786.9C 20.91.971\ 247249E -171.6 895.23 5603.0C ...3.0.60..0.7 230.6.261\ 3D14.76~._.___ 5460..0.4 3834. 8C__.213D. 781\ 2536.73E -172.1 927.10. 5703.0C 3D83.4L __43.60.471\ 3D95.49E 5 5528.12 . 3872.42 2161.20.1\ 2584.62E_ -172.4 960..82 580.3. DC 3106.~C 2414.671\ 3176.21 E 5 5589.6s..............3907.75 2189.791\ 2626.15E_ -1725 997.32 5903.0C 3130..17 2468~___3256.93E 5 5657.62 3948.0.5 2222.411\ 267D.D4E -172.6 10.36.39 6DD3.DC 3153.52 2523.0.71\ 3337.66E 5 5723.12 3987.89 2255.331\ 271D.26E -172.5 1077.71 61D3.DC 31JlL9C 2577.281\ 3418.38E 5 5795. DC .AQ322Ç 2293.741\ 2751.82E -172.2 1120..82 620.3. DC 320.0..26 2631.481\ 3499.1DE 5 5858.2C 40.71.58 2329.671\ 2785.73E -171.8 1165.8L 630.3. DC 3223.62 2685.681\ 3579.82E 5 5914.0.0. 410.6.62 2363.691\ 281271E -171.3 1213.19 ~ 6403_JK__ 3247.DC 2739.881\ 3660.55E 5 ~~-~ 5990..45 4154.6~ 2412.381\ 2846.88E -170..5 1262.2C 6503. DC 3270..36 2794~_3741.27E 5 60.66.21 420.2.0.<1 2.461.821\ 2879.26E -169'"º-............1312.D5 660.3. DC 3293.73 2848.291\ 3821.99E 5 S>JAD.29_.424816 2511.30.1\ 29D9~.45E.__ -168.7 1362.8C 670.3. DC 3317.0.5 290.2.491\ 39D2.72E 5 6212.1C 4292.72 2560..151\ 2937.46E -167.9 1414.48 ~.6803.0J;_334D.46 2956.691\ 3983.44E5______ _..___6288.DL__~3..9.9L 2611.911\ 2966.75E -167.0. 1466.79 6903.0C 3363.82 30.10..891\ 4D64.16E 5 6370..48 4391.48 2667.911\ 2998.43E -166.1 .1519.7C 70.0.3. DC 3387.19 3065.0.91\ 4144.89E 5 6445.84 4438.9C 2718.891\ 3D27.27E -165.4 1573.22 7103.DC 3419.56 3119.30.1\ 4225.61 E 5 6520..82_ 4486.31 2769.451\ 30.55. 88E_ -164.7 1627.2L 720.3. DC 3433.92 3173.50.1\ 43D6.33E 5 6595.41 4533.7C 2819.591\ 3D84.24E -164.0. 1681.75 73D3.0C .~457.29 3227.701\ 4387.061;..5.........____ 6671.27 ...4582..1 1 2870..40.1\ 3113.D1E -163.4 1736.69 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.Dft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.0.1 (1 D) Prepared by Baker Hughes Incorporated OR~G!~\! ee ee ~11¡ps ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 25 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... ... INTEQ 7403.0C 3480.61: 3281.91 t\ 4467. 78E 5 6748.56 4631.71 2921.95t\ 3142.30E -1628 179202 -----------.l503.0C 3504.0:2 3336.11 t\ 4548.50E 5 6825.72 4681.4<1 297316t\ 3171.58E -162.3 1847.7C 7603.0C 3527.3£ 3390.311\ 4629.22E 5 6906.00 4733.45 302617t\ 3202.07E -161.8 1903.67 7703.0C 3550.71: 3444.51 t\ 4709.95E 5 6984.2~ 4784.40 3077.56t\ 323184E -161.3 1959.92 7730.12 3557.0£ 3459.22t\ 3?31.8~ 7001.67 4795.78 30..88.97t\ 3238.47E -161.2 1975.21: All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum(Doyon 14) 88.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ()R'C~J~J,,^ I ."""", -.,. ,; ~\.",l J ;; ,~l-\ t'..~ ee ee .,' . ConocóPhillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 26 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... ... INTEQ 2438.0C 2223.62 58406N 514.62E 11 1897.58 1749.33 402.768 417.03E 100.6 1099.22 2468.0C ~42.2s 600.62N 531.30E 11 1913.12 1L60.47 409.008 425.89E 98.6 ~.6l 2503.0C 2263.2l 620.02N 551.51E 11 1922.76 1767.35 412.888 431.42E 95.5 1152.0!: 2603.0C 2317.8C 675.94N 613.86E 11 1965.49 1797.08 430.298 456.68E 88.0 1232.72 2703.0C 239397 _ 732.12N ---º-ª2.4<4E 11 1996.89 ~818.42 443.278 475.69E 81 .1-------.n.12. 21 2803.0C 2401.2l 787.94N 756.50E 11 2033.18 _--.1842~2_ 458.528 498.1§.E_ 75.6 1390.17 2901.17 2428.77 841.81N 833Z7Ejj 2067.17 186459 472.98~L~ 519.58E 710 1464.82 2903.0C 2429.19 842.80N 835.24E 11 2067.96 186510 473.328 52008E 71.0 1466.19 3003.0C 2452.56 897.00N 915.97E 11 2101.69 1886.50 ~868 541.72E 72.5 1542. H~ 3103.0C 2475.92 951.21 N 996.69E 11 _.2130.33 1904.26 500..348 560.40E 73.7 1619.92 3203.0C 2499.29 1005.411\ 1077.41E 11 2173.52 1930.74 519.318 588.76E 75.4 1699.0e 3303.0C 2522.66 1059.611\ 1158. 13E 11 .22.1706_ 1957.43 538.428 617.35E 77.0 1779.22 --~ 3403.0C 2546.02 1113.811\ 1238.86E 11 2257.53 1982.25 556.248 643.89E 78.5 1860.3e 3503.0C ....2999.39 1168.021\ 1319.58E 11 2300.89 200Mº_ 575.358 672c~.E~_ 80.0 1942,2e All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Planned Datum(Ooyon 14) 88.Oft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated OR!GINAL ee ee ConocriPhillips ConocoPhillips Alaska, Inc. 5A Ver#2, 5A slot #5, Pad 1 H CLEARANCE LISTING Page 27 Date Printed: 26-0ct-2004 Kuparuk River Unit, North Slope, Alaska ... ÞfM'fw INTEQ 2438.0C 2223.6:2 584.06N 514.62E 1 1895.55 1775.46 634.398 74.21V\i 136.3 1425.55 ~68.0~_2242.26 600.62N 531.3010 1 1906.71 1784.87 639.428 70.98V\i 132.9 1452.47 --~-~- 2503.0C 2263.2i 620.02N 551.51E1 1921.5C 1797.3~ 646.118 66.69V\i 128.4 1484.0:2 2603.0C 2317.8C 675.94N 613.86E 1 1957.9~ 1828.08 662.608 56.11V\i 115.2 1574.9:2 2703.0C 2363.97 7~2.12N -----ºª2.44E 1 19-ª-128 .~~ 1856.16 677.728 46.42V\i 102.2 1666.36 2803.0C 2401.2i 787.94N 756.50E 1 2016.97 _.JßZ7..J!-º_-º-89.398 38.96V\i 89.9 1757.62 2901.17 2428.77 841.81N 83377E 1 2038.1 C _1895.5ß_ 699.008 32.82V\i 79.4 1 ª-.46.4i 2903.0C 2429.1 S 842.80N 835.24E 1 2038.43 1895.87 699.158 32.72V\i 79.4 1848.0S 3003.0C 2452.56 897.00N_~97E 1 2055.2~ 1910.01 706.808 27.85V\i 80.5 1938.38 All data is in Feet unless otherwise stated Coordinates are from 810t and TVO's are from Rig ( Planned Oatum(Ooyon 14) 88.0ft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated O· R ,G' J 1\.1' ',4" ~ <oJ" ~ ~¡IAL. lH-O. Drillina Haza"s Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 8-1/2" Open Hole / 5-1/2" x 3-1/2" Casina Interval Hazard Running Sands and Gravels Risk Level Low Gas Hydrates Low / Stuck Pipe Low Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Low ¡' Low Moderate Mitigation Strategy Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight BOP training and drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, proper hole filling (use of trip sheets), pumping out OR Irq . , ., ,', . I <~ ~ i\ t } ,," ¡ ') ", L/' .,,¡¡- t " t "a¡,,:-' ¿ ~ '!i;. 1H-05 Drilling Hazards Summary. doc prepared by Steve McKeever 10/26/2004 1:11 PM Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 14 Location: West Sak Client: CPAI Revision Date: 10/26/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com SeIIl..'I8' Volume Calculations and Cement Systems (Volumes are based on 9.5" Hole size). Top of tail slurry is designed to at 5300' (500' above top of Ugnu). Tail Slurry (minimum thickening time 156 min.) DeepCRETE @ 12.5 ppg with a yield of 2.26 ft3/sk 0.2291 ft3/ft x 2802' x 1.45 (45% excess) = 3 0.4320 ft 1ft x (9022' - 8102') x 1.32 (32% excess) = 0.0488 1elft x 60' (Shoe Joint) = 930.8 ft3 + 397.4 ft3 + 2.9 ft3 = 1331.1 ft31 2.26 ft3/sk = Round up to 590 sks Previous Csg. @ 2425' < 103/4",45.5#, L-80 grade BTC, AB Modified KOP at 2,550 ft. MD 930.8 ft3 397.4 ft3 2.9 ft3 1331.1 ft3 589.0 sks BHST = 93°F, Estimated BHCT = 82°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time < 51/2",15.5#, L-80 grade (bbl) (min) BTC, AB Modified CW100 5.0 10.0 2.0 2.0 in 81/2" OH Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 MUDPUSH II 6.0 50.0 8.3 28.3 DeepCRETE 6.0 237.3 39.5 67.8 Drop combo plug 0.0 0.0 5.0 72.8 Mud 7.0 185.2 26.5 99.3 < Top of Tail at Slow & bump plug 3.0 15.0 5.0 104.3 5,300 ft. MD < X-over at 8,102 ft. MD MUD REMOVAL < Top of West Sak Fm. at 8,258 ft. MD Recommended Mud Properties: 9.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. < 31/2",9.3#, L-80 grade EUE, 8rd Modified in 8 1/2" OH Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 21-23, Ty = 24-28 Centralizers: Minimum 1 per joint below 5700 to avoid most low side channel. TO at 9,022 ft. MD (4,395 ft. rvD) Mark of Schlumberger ORJG ~\lð. West Sak IH-O Injector Proposed Completion Schematic 3-1/2" Completion String 30" X 16" 62.6# @ +/- 78' MD (Installed 1982) Depths are based on Doyon 14 RKB Surface csg. lO-3/4" 45.5# K-55 BTC c 2,425' MD / 2,224' TYD (Installed 1982) 5 Yz" 15.5# L-80 STCM x 3 Yz" 9.3# L-80 EUE8RD Mod crossover at +/- 8,100' MD / 3,700' TYD 3 '12" 9.3# L-80 EUE8RD Mod 3 '12" 9.3# L~80 Mod Tubing to Surface 3 Yz" nipple w/ 2.875" No-Go pups installed above and below, 8RD 3 Yz" x 1" Cameo installed above and below, 3 Yz" xl" Cameo 'KBG-2-9' mandrel shear (casing to tubing differential),3 Yz" x 6' L-80 installed above and below, EUE8RD Mod 3'12" Baker 'CMU' sliding sleeve w/2.813" profile, EUE 8RD Mod box x pin. 3Yz" x 6' Mod handling pup installed above 3 Yz" Baker 80~40 casing seal L-80 EUE8RD Mod box up, 3 '12" X 6' pup installed on top Baker Seal Bore Extension, 5 llz" SBE set at +/- 200' MD above the top of Future Perforations Production csg 5 W' ¡ 55# L-80 BTCM x 9.3# L-80 EUE8RD Mod Well Name: 1 HoGS API 41 : 5002920727 Surface Casina Date set 4/30/1982 Size 10-314" in Set at 2425 It Wt. 45.5 ppf Grade ~ Hole Size 13-1/2" in Wash Out % Est. T.O.C. 0 It fEND OF WELL SCHEMA TIC Spud Date: 26-Apr-82 DNew DUsed Hole angle @ shoe 49-1/2 Degrees Csg Shoe @ ~ ft Cement Piua #5 Date cmt'd: 5/17/1982 Plug: 240 sxs Arctic Set I @ 15.7 ppg Top @ 2,200', Btlm @ 2,545' Note: Tagged @ 2,200' Cement PIIIQ #4 Date cmt'd: 5/17/1982 Plug: 240 sxs Arctic Set II @ 15.7 ppg Top @ 2,550', Bttm @ 2,715' Note: Tagged @ 2,550' Cement PluCl #3 Date cmt'd: 5/16/1982 Plug: . 260 sxs "G" @ 15.8 ppg, 2% CaCl2 + .2% 0-46 Top @ 4,160', Bttm @ 4,590' Note: Tagged @ 3,979' Cement PluC! #2 Date cmt'd: 5/16/1982 Plug: 290 sxs "G" @ 15.8 ppg, 2% CaCl2 + .2% 0-46 Top @ 5,100', Bttm @ 5,700' Note: not tagged Cement PluC! #1 Date cmt'd: 5/16/1982 Plug: 225 sxs "G" @ 15.8 ppg, 1% 0-60 + .1% 0-13 + .2% 0-46 Top @ 9,825', Btlm @ 10,890' Note: not tagged Hole Angle @ TD 52-34 degrees TD @ 10,840 ft .- \ Rig Release Date: Rig RKB (ft): 18-May-82 NA Diesel Top @ Surface Bttm @ 620' ~ 10.5 ppg Brine from 2,200' to 620' ~ SCANNED OCT 2 7 2004 RE: lH-05A . . Subject: RE: IH-05A From: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> Date: Wed, 10 Nov 200408:29:28 -0900 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> You are correct. The corrected statement should read: An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1H-05A. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 5-1/2" rams in the lowermost cavity for running casing. See attached diagram entitled "Doyon 14 BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram) . Immediately prior to running the production string of 5-1/2" x 3-1/2" casing, a test plug will be set below the lowermost rams, and the variable rams will be closed and tested to 3,000 psi on a 5-1/2" OD. Mike Greener Senior Drilling Engineer ConocoPhillips Alaska, Inc. 907-263-4820 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admìn.state.ak.us] Sent: Wednesday, November 10, 2004 8:09 AM To: Greener, Mike R. Subject: 1H-05A Mike, Please have a look at the BOP equipment information statement in your permit application. I don't think that the ram sizing agrees with your casing plan. Tom Maunder, PE AOGCC 1 of 1 11/10/20048:36 AM · o Feet I 4,000 lH-05A Subject: 1H-05A From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 10 Nov 200408:08:48 -0900 To: Mike.R.Greener@conocophillips.com Mike, Please have a look at the BOP equipment information statement in your permit application. I don't think that the ram sizing agrees with your casing plan. Tom Maunder, PE AOGCC . . 1 of 1 11/10/20048: 12 AM • Page 1 of 3 • Maunder, Thomas E {DOA) From: Thomas Maunder [tom_maunderQadmin.state.ak.us] Sent: Friday, October 29, 2004 7:29 AM To: Rennie, Scott B Cc: Werner, Michael; Paul, Jerome; Greener, Mike R. Subject: Re: Proposed 7 H-05 Re-entry Thanks Scott, My question was just to be sure that it had been asked. As you are aware, there can be concerns when a new shallower formation (WS) well is drilled amongst much older Kuparuk wells. The original drilling practice in Kuparuk was not to drill through the WS before setting the surface casing. In the "older" areas of the field (generally earlier than 1983/1984) this results in the WS and sometimes the Ugnu not being covered by cement. The study recently shared in the September meeting indicated that for water injection the likelihood of crossflow was very low and probably not of consequence. MI injection is another issue due to its greater mobility and that it is an energized fluid. I think the ultimate area/location for the FOR pilot was influenced by how the older Kuparuk wells in the area were constructed. Something to keep in mind. Gall or message with any questions. Tom Maunder, PE AOGCC Rennie, Scott B wrote: Tom, Regarding injection fluids for the 1 H-05A, there is not currently an MI line to drillsite 1 H. However, there is a possibility that one will be installed in the future and that 1 H-05A could be a WAG injector. It is also worth noting that this is an appraisal well in an undeveloped area of the West Sak. No injection wilt occur until offset development wells are drilled, likely a year or more in the future. Scott -----Original Message----- From: Paul, Jerome Sent: Thursday, October 28, 2004 5:13 PM To: Greener, Mike R.; Rennie, Scott B Subject: RE: Proposed iH-05 Re-entry Scott, Can you respond to Mike? Thanks. -----Original Message----- From: Greener, Mike R. Sent: Thursday, October 28, 2004 5:10 PM To: Paul, Jerome Subject: FW: Proposed 1H-05 Re-entry DO YOU HAVE AN ANSWER ON THIS QUESTION? ~~~~- ~~ .~~, 10123/2007 Page 2 of 3 • -----Original Message----- From:Thomas Maunder [mailtoaom_maunder~admnatate.ak._us] Sent: Wednesday, October 27, 2004 1:14 PM To: Greener, Mike R. Subject: Re: Proposed iH-05 Re-entry Mike, One other question. Is this well to be just a water injector or are the reservoir/production people planning to also inject MI?? Thanks, Tom Greener, Mike R. wrote: Thanks, will do. Mike Greener Senior Drilling Engineer ConocoPhillips Alaska, Inc. 907-263-4820 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.usJ _ - - --- _ - Sent: Monday, October 25, 2004 7.42 AM To: Greener, Mike R. Subject: Re: Proposed 1H-05 Re-entry Thanks Mike. Since this is proposed to be an injector, remember at any well that penetrates the West Sak within 1/4 mile of 1H-0 entry into the West Sak and along the well path. Call with any questions. Tom Maunder, PE AOGCC Greener, Mike R. wrote: Yes there is a permit to drill application coming. The wel West Sak well. It will also be an injector. Still accumulating information for the permit to drill appl Mike Greener Senior Drilling Engineer ConocoPhillips Alaska, Inc. 907-263-4820 -----Original Message----- From: Thomas Maunder [maiito:tom maunder@admin.state.ak.us] Sent: Friday, October 22, 2004 11:07 AM To: Greener, Mike R. Cc: Thomas, Randy L Subject: Proposed 1H-05 Re-entry 10/23/2007 c: Mike, This is We have 1H-05. also • Page 3 of 3 a followup to my voice mail message. received your sundry proposing to re-enter suspende Applying with a 403 is the appropriate first step. preparing a permit to drill application?? All the steps you propose on the procedure cannot be author sundry. Also, will this well be drilled to the Kuparuk or will it b well?? It is not clear. I also note that your are plannin completion. Will the well be a producer or an injector?? I look forward to your reply. Tom Maunder, PE AOGCC 10/23/2007 ·.../ . . ConocoPhllhps Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com November 1st, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1H-05A Dear Commissioners: '. .. ~D 1l1ö'f Il'j 6'-t,.,ht.7~ ' ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore ~n well, a vertical injector well in the West Sak "A2", "6" and "D" sands. The main bore of the well will be designated 1H- 05A. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. The expected spud date of 1H-05A is November 27th, 2004. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, .~~~ ) Randy Thomas Greater Kuparuk Area Drilling Team Leader 1081 DATE (1oJte/~4/311 ~~;\,'" 7fÌ'f1e Or 1tLA5~/~CC I $/00. oò __ /k I Jd Jd 11 ~ 4ø_ - A ,,,"~,.,,".. {J/¿ ~ t:...-...,( l/ð DOLLARS W =:':._ ...~ C HASE Chase Manhaltan Bank USA, N.A. Valid Up To 5QOO Dollars .., 2DOWhltec~y C,nte, D'., ""',,', DE 19111 d r ...0 /6- rof ~-_~~_.JIÄ"F~~ I: 0 :i . .00 . l. l.1: 2 .8 l. 7 . Ii 0 7 Ii 2 7 b II- .08 . ( I ~ b .£ SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ATO 1530 700 G ST. ANCHORAGE AK 99501 .- ¡., . . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER /<í2K /)/-6S- A WELL NAME PTD# '2-D tj ". 2 Z S" Development v" Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API Dum ber last two. (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new wellboresegment of existing well,. . Permit No, .' API No. Production.sbould continue to be reponed as a function' of tbe original API number. stated above. HOLE )n accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance witb 20 AAC 25..0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to the spacing .exception tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample inter:vals tbrougb target zones. ~~I~!:ifJt~JJ!1; Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 H-05A PTD#: 2042280 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType SER I PEND GeoArea 890 Unit 11160 1 Pj'!rmitfee attache~:L ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 2 ~Leasj'!~number ~apprORriate~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ Entire well located in ADL 025639. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 3 ~U~nique wel'-na!T1j'!~aod Ol!mb~er ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ . ~ . ~ . ~ ~ . . . . . . ~ . . . . . . . . ~ . ~ . ~Yj'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ . ~ ~ . ~ ~ . ~ . . . . ~ . ~ . . ~ ~ . ~ . . ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ . . ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ . . . ~ . ~ ~ ~ 4 WellJoC<ltj'!d [n~a~d~efined~pool~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~Yj'!$ ~ ~ ~ ~ ~ ~ ~ KRU WestSakOjIPool.goYeroed~byCooseJ\lationOrder~No, 4Q6B~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 5 WellJOC<lted proper ~distance~ from driJIing unitb~ound~ary~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ WelJ is more than 500 feet fJom an exteJnaJ prope~rty Jine~. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 6 WelUoC<ltj'!d proper ~distance from otber welJs~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ NO restrictioos asJo well spaciog io COA~06B ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 7 ~S~utficienLacreage~aYailable [n~dJilIiog unjL ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ No restrictioos asJo well spaciog io COA~06B ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 8 Kdj'!viated, js~ weJlbore platJocJuded ~ ~ ~ ~ ~ ~ ~ Xes ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 9 ~Operator onl~ affected party ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Y j'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 1 0 ~Oper~ator bas~appropriate~ bond inJorce ~ ~ ~ . ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~Yj'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . ~ . . ~ ~ ~ . . . ~ . . . . ~ . ~ ~ ~ . . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . . . . . . . . . . . . . . . . ~ ~ ~ ~ ~ ~ 11 pj'!rmit c~ao be iS$l!ed witbout ço~nservaJion order ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ Appr Date 12 Pj'!rmitc~ao be iS$l!edwitbout administratille~approvaJ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ SFD 11/9/2004 13 Can permit be approved before 15-day wait Yes 14 WelUocatj'!d within area and~strata~author[zed by.lojectioo Ordj'!r# (putlO# ¡n~cO!T1!T1j'!otsUFor~ Yj'!$ ~ ~ ~ ~ Aœa InjectioRQrder No.~26 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 15 AJlwel!s~withinJl4J'1Jite~area~ofreyiewidj'!ot[fied(Forservjq:!.we!lonl~>' ~ ~. ~ ~ ~. ~ ~ ~ ~. ~ ~ Yj'!$~. ~ ~ ~ ~ ~Non~e, 1H-05willbe~&A'd.~.. ~. ~. ~ ~ ~ ~. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~.... ~... ~ ~....... ~ ~ ~ ~ ~ ~ 16 PJe-produced iojector; duraUon~of pre-production j'!$S. than 3 montbs~ (For~se(Vice well only) ~ ~ No~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 17 ACMPFjndjng~ofCon~si$teocyha$ beenissued~forJbi$ project ~ ~ ~NA ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Administration 18 19 20 21 22 23 24 25 26 27 Appr Date 28 TEM 11/10/2004 29 B.. ¥( 30 31 32 33 34 Engineering Geology Appr SFD Date 11/912004 Geologic Commissioner: Dr~ Program SER On/Off Shore On D D Well bore seg Annular Disposal - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e Cooductor stringpJov[ded ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~NA ~ ~ Conductor ~setio orjginal well J H-05(182-038) ~S~uúacecasing~PJotects alLknown USDWs ~ ~ ~NA ~ ~ ~ ~ ~ ~ ~ Surface ca~si.ng seLin orgioal well. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~CMT v~ol adequ~ateJo circu'-ate~o~ncond~uctor~ & SUJtcsg ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~NA ~ ~ ~ ~ Surface casing cemented in orgioal welL ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ CMT vol adequ~ateJo tie-i.nJongstriog to surf çsg~ ~ ~ No~ ~ ~ ~ ~ ~ ~ ~ All hydrocarbons are~pJa~noedJo be coverj'!d. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~CMT will coYer~aU known~pro~ductiYe borilons~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~C~a$iog desigos ad~eCluate for C.~T" B ~&~ Rermafr~o$t ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~AdequateJan~kage~oJ re~serye pit ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ Rig isequippe~d~with steel~pjts. ~ No reseJVe~pitplaooed, AU wç¡ste to~approve.dannuJl!SOr Cla$S II well, ~ ~ ~ ~ ~ Jfare-drill" bas a 10-403 for abandonment bej'!O ç¡PPJoved ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ 30A~3~89,~approvedJO/~26/04. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~Adequate.we!lbofe sepªration~Pfoposed ~ ~ . . . . . . . ~ ~ ~ ~ ~ ~ ~ ~ . . . . . . . . . . .Yj'!$ . ~ ~ ~ . ~ ~ ~rOJ5imity- analysis pertorme~d, OJigioal wel!boreJs closj'!$!, WeJI pªths divergeJrom kjckoff poinL ~ ~ . ~ . . . ~ ~ ~ Jf diverter JeCl-uiJed, does iLmeet reguJations ~ ~ NA ~ ~ ~ BO~ will ~already be in place. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ DJilliog f]uidRrogram $chemat[c& eCl-uipJi$tadequate ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ BHE' expected be1we~eo 8.~3-8.6EMW.~ Plaoned MW 9.:1 ~- 9.2ppg. ~ ~ ~ ~ ~ ~ ~ ~ ~BQPEs,~do ~they meetreguJation ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ BOPEpres$ ratiog appropriate;testto(put psig ¡ncomments) Yj'!L ~ ~ ~ ~ ~ ~ MASE' çalculated~at 1399 p$i, 30QO~p$itest proposj'!d.~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~CMkemanjfold compJies w/API RP-53 (May 84)~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Work wiU oçc~ur withoutoperç¡tion ~sbutdown~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yj'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Js preseoce~of H2S 9ªs~Rrobable ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ No~ ~ ~ ~ ~ ~ ~ ~ 1:12S is notkoownio WeslSak.~ Ri.gis eCl-uipped~withsensors~and ç¡larms. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Mecban[cç¡LcondjUoo o{well$ within AOR yerified (for~s~erv[ce wel! only) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~Yj'!$ ~ ~ ~ ~ ~ ~ ~ 1H-05 was~drilledJo the ~Kuparuk, Jndjvjd~ual~cement plugs were set over al! Kup" WSand ~UgOl!. AO%~XS on WS.~ 35 pj'!lJT)it cao be iS$l!ed w/o hydrogen~ s.ulfide measures ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~Yj'!$ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 36 ~D~ata~PJeseoted on~ Rote~ntial oveJ:)ressure ~zones ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~Yj'!$ ~ ~ ~ ~ ~ ~ Expected œ$ervoir pre~s$uJe is ~8,3~- ~8,6~p-P9 EMW; wj\Lbj'!~drilled witb 9."- 9.2ppg mud. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 37 ~Sj'!is!T1icanªlysjs of sbaJlow gaszooes~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~NA ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 38Sj'!abed ~condjtipo $l!rvey -<if off-shore) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~NA ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 39 ~ Conta~ct namelphonefor~weekly progressreport$ [e¡cplorç¡tolY ~onlYl ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~NA ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ e - - - - - - - - - - - - - - Date: ì / I/(]) /1- Engineering Commissioner: ~ ~' 'Ý'YðjC Date Date . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . lot{., 2,Z~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 11 16:28:28 2005 I ) J-1t1/9 :/ Reel Header Service name...... .......LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments... .... ........ ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name. ..... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA IH - 0 SA 50029207270100 ConocoPhillips Alaska Inc Sperry Sun 11-JAN-OS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003424644 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0003424644 T. MCGUIRE E. VAUGHN MWD RUN 3 MW0003424644 T. MCGUIRE E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 99 MW0003424644 R KALISH # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 33 12N 10E 538 803 .00 87.29 . . GROUND LEVEL: 53.20 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 8.500 8.500 CASING SIZE (IN) 10.750 10.750 10.750 DRILLERS DEPTH (FT) 2425.0 2425.0 2425.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD RUNS 2&3 ARE DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON POROSITY (CTN) WITH INTEGRAL ACOUSTIC CALIPER (ACAL), AND STABILIZED LITHO-DENSITY (SLD). 4. THIS WELL BORE SIDETRACKS FROM THE PARENT WELL 1H-05 AT 2425'MD, 2214'TVD. 5. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM M WERNER OF CPAI GKA GEOSCIENCE GROUP-DATED 12/16/05. 6. MWD RUNS 1-3 REPRESENT WELL 1H-05A WITH API#: 50-029-20727-01-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9038'MD, 4297'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . " SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX, DYNAMIC HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . ACAL = ACOUSTIC CALIPER. VEXP = INVERSION-DERIVED (ENHANCED) EXTRA SHALLOW RESISTIVITY VESP = INVERSION-DERIVED (ENHANCED) SHALLOW RESISTIVITY VEMP VEDP MEXP MESP MEMP MEDP . . INVERSION-DERIVED (ENHANCED) MEDIUM RESISTIVITY INVERSION-DERIVED (ENHANCED) DEEP RESISTIVITY FORWARD-MODELED EXTRA SHALLOW RESISTIVITY FORWARD-MODELED SHALLOW RESISTIVITY FORWARD-MODELED MEDIUM RESISTIVITY FORWARD-MODELED DEEP RESISTIVITY PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACOUSTIC CALIPER CORRECTED MUD WEIGHT: 9.0-9.2 PPG MUD SALINITY: 15000-17500 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.OOl Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/11 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name.... ...STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPX RPM RPS ROP NCNT NPHI FCNT CALA RHOB PEF DRHO RDVR $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2350.0 2415.0 2415.0 2415.0 2415.0 2415.0 2425.5 2744.0 2744.0 2744.0 2748.0 2757.0 2757.0 2757.0 7800.5 STOP DEPTH 9000.0 8992.5 8992.5 8992.5 8992.5 8992.5 9038.0 8948.0 8948.0 8948.0 8951. 5 8961. 5 8961. 0 8961. 5 8990.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO 1 2 3 MERGE TOP 2350.0 2894.5 4180.5 MERGE BASE 2894.5 4180.5 9038.0 . MWD $ 99 7800.5 8990.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..... . . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction...... ...........Down Optical log depth units..... ......Feet Data Reference Point... ...........Undefined Frame Spacing.......... ......... ..60 .1IN Max frames per record..... ...... ..Undefined Absent value............. ....... ..-999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 FET MWD HRS 4 1 68 24 7 NPHI MWD PU-S 4 1 68 28 8 FCNT MWD CTS/ 4 1 68 32 9 NCNT MWD CTS/ 4 1 68 36 10 RHOB MWD G/CM 4 1 68 40 11 DRHO MWD G/CM 4 1 68 44 12 PEF MWD B/E 4 1 68 48 13 CALA MWD IN 4 1 68 52 14 RDVR MWD OHMM 4 1 68 56 15 RPD MWD OHMM 4 1 68 60 16 . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2350 9038 5694 13377 2350 9038 ROP MWD FT/H 0 1096.82 216.803 13226 2425.5 9038 GR MWD API 18.44 401.15 75.2525 13301 2350 9000 RPX MWD OHMM 0.25 2000 10.1307 13156 2415 8992.5 RPS MWD OHMM 0.3 2000 12.7549 13156 2415 8992.5 RPM MWD OHMM 0.21 2000 14.7092 13156 2415 8992.5 FET MWD HRS 0.09 15.5 0.741811 13156 2415 8992.5 NPHI MWD PU-S 11. 44 78.75 39.1627 12409 2744 8948 FCNT MWD CTS/ 572 3897 1004.29 12409 2744 8948 NCNT MWD CTS/ 123886 227006 152101 12409 2744 8948 RHOB MWD G/CM 1. 442 2.68 2.15432 12410 2757 8961. 5 DRHO MWD G/CM -0.082 0.278 0.0373479 12410 2757 8961.5 PEF MWD B/E 0.47 3.12 1.70894 12409 2757 8961 CALA MWD IN 8.13 11.43 8.69654 12383 2748 8951.5 RDVR MWD OHMM 0.854 87.716 8.67701 2381 7800.5 8990.5 RPD MWD OHMM 0.07 2000 15.4356 13156 2415 8992.5 First Reading For Entire File...... ... .2350 Last Reading For Entire File.......... .9038 File Trailer Service name............ .STSLIB.001 . Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation..... ..05/01/11 Maximum Physical Record..65535 File Type... ........... ..LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name......... ... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/11 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPX RPS RPM FET ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 2350.0 2415.0 2415.0 2415.0 2415.0 2415.0 2425.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 2849.0 2841. 5 2841. 5 2841. 5 2841.5 2841. 5 2894.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS 07-DEC-04 Insite 6.02 Memory 2350.0 2894.5 49.5 72 .4 TOOL NUMBER 124724 56933 8.500 2425.0 . MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction. ............. ...Down Optical log depth units...........Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. ... ...... ..... ...... .-999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Water 9.00 54.0 9.5 16000 6.8 Based .240 .262 .300 .200 63.0 57.2 63.0 63.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 FET MWD010 HRS 4 1 68 24 7 RPD MWD010 OHMM 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2350 2894.5 2622.25 1090 2350 2894.5 ROP MWD010 FT/H 10.68 450.77 270.7 939 2425.5 2894.5 GR MWD010 API 18.44 123.5 64.2616 999 2350 2849 RPX MWD010 OHMM 0.25 20.02 10.4662 854 2415 2841. 5 RPS MWD010 OHMM 0.3 2000 21.0531 854 2415 2841.5 RPM MWD010 OHMM 0.21 2000 21. 848 854 2415 2841. 5 FET MWD010 HRS 0.27 3.86 0.818876 854 2415 2841. 5 RPD MWD010 OHMM 0.07 2000 29.3892 854 2415 2841. 5 First Reading For Entire File........ ..2350 Last Reading For Entire File....... ....2894.5 File Trailer . Service name... ........ ..STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/11 Maximum Physical Record. .65535 File Type.. .... ......... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/01/11 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI CALA PEF DRHO RHOB GR RPD RPS FET RPM RPX ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 2744.0 2744.0 2744.0 2748.0 2757.0 2757.0 2757.0 2795.0 2842.0 2842.0 2842.0 2842.0 2842.0 2895.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 4091.0 4091.0 4091.0 4095.5 4105.0 4105.0 4105.0 4142.5 4135.0 4135.0 4135.0 4135.0 4135.0 4180.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 08-DEC-04 Insite 6.02 Memory 2894.5 4180.5 71. 0 77.7 TOOL NUMBER 124724 . EWR4 SLD CTN $ ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ............0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point..... ....... ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. ......... ...... ..... .-999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 56933 125704 105918 8.500 2425.0 Water Based 9.00 54.0 8.5 17000 6.6 .320 .281 .240 .400 62.0 71.6 62.0 62.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 FET MWD020 HRS 4 1 68 24 7 NPHI MWD020 PU-S 4 1 68 28 8 FCNT MWD020 CTS/ 4 1 68 32 9 NCNT MWD020 CTS/ 4 1 68 36 10 RHOB MWD020 G/CM 4 1 68 40 11 DRHO MWD020 G/CM 4 1 68 44 12 PEF MWD020 B/E 4 1 68 48 13 CALA MWD020 IN 4 1 68 52 14 RPD MWD020 OHMM 4 1 68 56 15 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2744 4180.5 3462.25 2874 2744 4180.5 ROP MWD020 FT/H 0 1096.82 265.539 2571 2895.5 4180.5 GR MWD020 API 38.21 401. 15 70.8649 2696 2795 4142.5 RPX MWD020 OHMM 3.01 17.46 9.97994 2587 2842 4135 RPS MWD020 OHMM 4.97 19.86 11.0758 2587 2842 4135 RPM MWD020 OHMM 5.68 25.61 11.5191 2587 2842 4135 FET MWD020 HRS 0.09 10.55 0.999625 2587 2842 4135 NPHI MWD020 PU-S 25.19 69.58 40.5395 2695 2744 4091 FCNT MWD020 CTS/ 602 1415 932.614 2695 2744 4091 NCNT MWD020 CTS/ 128000 176339 148155 2695 2744 4091 RHOB MWD020 G/CM 1. 56 2.567 2.08055 2697 2757 4105 DRHO MWD020 G/CM -0.051 0.241 0.0254334 2697 2757 4105 PEF MWD020 B/E 1. 02 2.68 1.7549 2697 2757 4105 CALA MWD020 IN 8.24 11.23 8.72895 2671 2748 4095.5 RPD MWD020 OHMM 6.43 29.55 12.1537 2587 2842 4135 First Reading For Entire File......... .2744 Last Reading For Entire File.......... .4180.5 File Trailer Service name.... ........ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name... ..... ...STSLIB.004 Physical EOF File Header Service name........ .... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .05/01/11 Maximum Physical Record..65535 File Type............... .LO Previous File Name.. .... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI NCNT FCNT CALA PEF RHOB DRHO FET RPD 4 header data for each bit run in separate files. 3 .5000 START DEPTH 4092.5 4092.5 4092.5 4095.0 4107.0 4107.0 4107.0 4136.0 4136.0 STOP DEPTH 8948.0 8948.0 8948.0 8951. 5 8961. 0 8961. 5 8961.5 8992.5 8992.5 . RPM RPS RPX GR ROP $ 4136.0 4136.0 4136.0 4143.5 4181.0 8992.5 8992.5 8992.5 9000.0 9038.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ...... ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.. ............ ...... .60 .1IN . 11-DEC-04 Insite 6.02 Memory 4180.5 9038.0 32.6 78.8 TOOL NUMBER 124724 56933 125704 105918 8.500 2425.0 FloPro 9.00 53.0 9.0 17500 6.8 .300 .205 .270 .460 64.0 96.8 64.0 64.0 . . Max frames per record....... ..... . Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 FET MWD030 HRS 4 1 68 24 7 NPHI MWD030 PU-S 4 1 68 28 8 FCNT MWD030 CTS/ 4 1 68 32 9 NCNT MWD030 CTS/ 4 1 68 36 10 RHOB MWD030 G/CM 4 1 68 40 11 DRHO MWD030 G/CM 4 1 68 44 12 PEF MWD030 B/E 4 1 68 48 13 CALA MWD030 IN 4 1 68 52 14 RPD MWD030 OHMM 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4092.5 9038 6565.25 9892 4092.5 9038 ROP MWD030 FT/H 0 672.09 198.69 9715 4181 9038 GR MWD030 API 28.01 143.21 77.5261 9714 4143.5 9000 RPX MWD030 OHMM 1.12 2000 10.1419 9714 4136 8992.5 RPS MWD030 OHMM 1.18 2000 12.4731 9714 4136 8992.5 RPM MWD030 OHMM 1.12 1809.23 14.9316 9714 4136 8992.5 FET MWD030 HRS 0.1 15.5 0.666112 9714 4136 8992.5 NPHI MWD030 PU-S 11.44 78.75 38.7808 9712 4092.5 8948 FCNT MWD030 CTS/ 572 3897 1024.18 9712 4092.5 8948 NCNT MWD030 CTS/ 123886 227006 153196 9712 4092.5 8948 RHOB MWD030 G/CM 1. 442 2.68 2.17483 9710 4107 8961. 5 DRHO MWD030 G/CM -0.082 0.278 0.040662 9710 4107 8961. 5 PEF MWD030 B/E 0.47 3.12 1. 69619 9709 4107 8961 CALA MWD030 IN 8.13 11.43 8.6876 9714 4095 8951. 5 RPD MWD030 OHMM 1. 37 2000 15.0834 9714 4136 8992.5 First Reading For Entire File...... ... .4092.5 Last Reading For Entire File.......... .9038 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ..... .05/01/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number...... .... .1.0.0 . Date of Generation.... ...05/01/11 Maximum Physical Record..65535 File Type.. .... ....... ...LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MESP VEXP MEXP VESP VEMP MEMP VEDP MEDP $ 5 . header data for each bit run in separate files. 99 .5000 START DEPTH 7800.5 7800.5 7800.5 7800.5 7800.5 7800.5 7800.5 7800.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 8990.5 8990.5 8990.5 8990.5 8990.5 8990.5 8990.5 8990.5 TOOL STRING (TOP TO VENDOR TOOL CODE EWR4 $ BOTTOM) TOOL TYPE ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 07-JAN-05 VRE Computed 7800.5 8990.5 33.0 75.0 TOOL NUMBER 56933 . . HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ............0 Data Specification Block Type.....O Logging Direction....... ..... ... ..Down Optical log depth units..... ......Feet Data Reference Point.. ......... ...Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 VEXP MWD099 OHMM 4 1 68 4 2 MEXP MWD099 OHMM 4 1 68 8 3 VESP MWD099 OHMM 4 1 68 12 4 MESP MWD099 OHMM 4 1 68 16 5 VEMP MWD099 OHMM 4 1 68 20 6 MEMP MWD099 OHMM 4 1 68 24 7 VEDP MWD099 OHMM 4 1 68 28 8 MEDP MWD099 OHMM 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7800.5 8990.5 8395.5 2381 7800.5 8990.5 VEXP MWD099 OHMM 0.327 55.487 7.21782 2381 7800.5 8990.5 MEXP MWD099 OHMM 0.937 44.51 7.37133 2381 7800.5 8990.5 VESP MWD099 OHMM 0.498 105.855 8.58652 2381 7800.5 8990.5 MESP MWD099 OHMM 1.18 62.46 8.18568 2381 7800.5 8990.5 VEMP MWD099 OHMM 0.831 110.489 8.89548 2381 7800.5 8990.5 MEMP MWD099 OHMM 1.137 59.392 8.49751 2381 7800.5 8990.5 VEDP MWD099 OHMM 0.854 87.716 8.67701 2381 7800.5 8990.5 MEDP MWD099 OHMM 1.389 47.837 8.29181 2381 7800.5 8990.5 First Reading For Entire File......... .7800.5 Last Reading For Entire File.......... .8990.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation.... ...05/01/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer . . Service name....... ..... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/11 Origin.................. .STS Tape Name............. ...UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name... ......... .LISTPE Date.................... .05/01/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments. ... .... ........ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File