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203-096
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 18 Township: 12N Range: 8E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 10038 ft MD Lease No.: ADL0380107 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 3580 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 10029 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 9584 Feet Tbg Cut@ 8271 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Initial 15 min 30 min 45 min Result Tubing NA NA NA IA 1650 1565 1530 OA 430 450 450 Initial 15 min 30 min 45 min Result Drawdown Tubing NA NA NA IA 0 0 0 OA 0 60 70 Remarks: Attachments: Matt Miller P Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Test only, no tag. Pumped 1.2 BBL in and returned 1.0 bbls for MIT. Test was against CIBP at set at 3777 ft MD. A draw down test was also done beeding 7-inch casing to 0 psi and it remained at 0 psi after 30 min test. March 15, 2025 Kam StJohn Well Bore Plug & Abandonment KRU 3S-19 ConocoPhillps Alaska Inc. PTD 2030960; Sundry 324-493 none Test Data: P Casing Removal: rev. 3-24-2022 2025-0315_Plug_Verification_KRU_3S-19_ksj 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9999 999 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.16 14:34:56 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10038'6680' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-4131 Staff Well Intervention Engineer KRU 3S-19 6187' 30' 30' 30', 5501', 6300', 6597', 8274', 8516', 8578', 9620', 9635', N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: jill.simek@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8564' MD and 5123' TVD 9604' MD and 5811' TVD 504' MD and 504' TVD Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544, ADL0380107 203-096 P.O. Box 100360, Anchorage, AK 99510 50-103-20460-00-00 Kuparuk River Field N/A - Suspended (Kuparuk River Oil Pool) ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY N/A- Abandoned (Kuparuk River Oil Pool) TVD Burst 9584' MD 108' 2596' 108' 3580' 6179'10029' 16" 9-5/8" 78' 3550' 8680-8700', 9700-9720' (cemented) 6420-6570' (Perf Wash Cement) 10002' 5188-5199', 5893-5910' (cemented) 4034-4107' (Perf Wash Cement) 7" Perforation Depth TVD (ft): 9/10/2024 3-1/2" Packer: Baker Premier Packer Packer: Baker SAB-3 Perm Packer SSSV: Camco DS Nipple Profile Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:20 am, Aug 27, 2024 Jill Simek Digitally signed by Jill Simek Date: 2024.08.27 07:53:05 -08'00' 324-493 X VTL 9/5/2024 X SFD 9/5/2024 DSR-8/27/24 AOGCC inspection is required after cutoff and before any remedial cementing. 10-407 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.06 14:43:51 -07'00'09/06/24 RBDMS JSB 091024 3S-19 Plug and Abandon Change of Approved Sundry Procedure PTD #203-096 Page 1 of 2 Currently the well is cemented to surface (see aached schema c); however, the producon casing is exhibing sustained surface pressure (OA remains at 0psi). Casing pressure was last bled to 0psi on 8/9/2024, and a buildup test completed as follows: BLED IA FOR BUR, IA GAINED 74 PSI IN 60 MINS (COMPLETE) Inial I/O = SI 482/0 Put IA on open bleed for 3 hrs. SI for 60 min monitor. Start I/O = 0/0 15 min I/O = 20/0 (+20) 30 min I/O = 38/0 (+18) 45 min I/O = 56/0 (+18) 60 min I/O = 74/0 (+18) Final I/O = SI 74/0 NOTE: Steps 1-22 have been completed. Changes to procedure, starting at Step#23 are listed in PURPLE. Procedure Eline 1. MIRU. 2. RIH with CBL and log 7.0” casing to confirm TOC of original cement job. POOH a. If TOC is BELOW Top of Moraine, then do additional production casing x open hole (OA) perf/wash/cement 50’ into Moraine and 100’ into confining zone above it to isolate for a total of ~150’ cement OA plug. 3. RIH and set 7” CIBP at base of perforation zone, approximately 6,596ft KB. POOH. 4. RIH with perf guns and perforate 7.0” casing as required to get exposure to top ~50’ of Coyote formation and ~100’ into the confining zone above it. (Note CIBP set depth and perf intervals may be adjusted, based on log response and/or well conditions encountered) POOH. 5. RDMO Coil 6. MIRU. 7. RIH with wash/cement tool. Gently tag the CIBP. 8. PU and wash perfs per wash/cement tool’s vendor procedure. 9. After wash procedure, cement OA through perforations per wash/cement tool’s vendor procedure. POOH. Job is planned for ~68bbls cement, including excess. 10. Leave Top of Cement in production casing ~150ft above top perforation at ~6,270ft KB (Note, TOC depth may be adjusted, based on log response and/or well conditions encountered). Circ out excess. 11. RDMO. Wait on cement. Slickline 12. Notify the AOGCC Inspector of timing for TOC tag and pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 13. MIRU. 14. SL: RIH and tag top of cement (witnessed) 15. SL: Perform MIT on production casing (witnessed) 16. RDMO. 3S-19 Plug and Abandon Change of Approved Sundry Procedure PTD #203-096 Page 2 of 2 Coil 17. MIRU. 18. Pump cement plug in production casing, from top of cement to surface. Job is planned for 240 bbls cement. 19. RDMO. Pumping 20. MIRU. 21. Perform OA down squeeze to place cement from surface to 3,579ft KB. Job is planned for 121 bbls of cement, including excess. 22. RDMO. Remedial Cementing – Milling (Coil) 23. MIRU. 24. Mill cement in production casing to depth of 3,780ft KB (200ft below surface casing). 25. RDMO Remedial Cementing – Set Plug (Eline) 26. MIRU. 27. Set plug (CIBP or BiSN) at ~3,780ft KB. 28. RDMO Remedial Cementing – Pressure Test (DHD) 29. Notify the AOGCC Inspector of timing for pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 30. Perform MIT on production casing (witnessed) 31. Perform DDT on production casing (witnessed) Remedial Cementing – Place New Cement (Coil) 32. MIRU. 33. Pump cement plug in production casing, from plug to surface. Job is planned for 145 bbls cement. 34. RDMO. Wait on Cement. Wellhead Excavation / Final P&A: 35. Confirm production casing and production casing x surface casing annulus pressures are at 0psi. 36. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 37. Remove the tree, in preparation for the excavation and casing cut. 38. Excavate and remove wellhead and all casing strings at 4 feet below original ground level. 39. Verify that cement is at surface in all strings. Perform cement “top off” job(s) if required. AOGCC witness and photo document required. 40. Send the casing head w/ stub to materials shop. Photo document. 41. Weld ¼” thick cover plate (16” O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 3S-19 PTD #: 203-096 API #: 50-103-20460-00 42. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 43. Obtain site clearance approval from AOGCC. RDMO. Daily Operations Start Date Last 24hr Sum 8/9/2024 (P&A) BLED IA FOR BUR, IA GAINED 74 PSI IN 60 MINS (COMPLETE) 8/8/2024 (P&A) COLLECT 2 IA ISO-TUBE SAMPLES (COMPLETE) DDT IA TO 0 PSI (IN PROGRESS) 4/5/2024 (P&A) MONITOR IA FOR BUR 3/31/2024 (P&A) OBTAINED IA GAS SAMPLE, BLED IA FOR BUR (IN-PROGRESS) 3/3/2024 (P&A) (IN-PROGRESS) IA DDT (IN-PROGRESS) 3/2/2024 (P&A) VERIFIED PSI ON IA & OA, IA @ 23 PSI, OA @ 0 PSI. BLED IA FOR BUR, 36 PSI BUILD UP IN 15 MIN. *NEXT STEP: REPEAT IA DDT* 1/1/2024 (P&A) DDT T X IA TO 0 PSI (PASS) OA DDT TO 0 PSI (PASS) TOC @ SF POOR CEMENT/ICE 12/30/2023 TAGGED CEMENT TOP @ 5464' CTMD. LAY IN 210 BBLS (20 BBLS EXCESS) 15.8 PPG CEMENT (LET 3 BBLS GET AROUND COIL) WHILE PUMPING @ 1.2 BPM & POOH @ 22 FPM TO SU WASHED BOP'S & TREE (CYCLED MASTER). READY FOR DHD IN 48 HRS. 12/29/2023 MIRU CTU 14 W/ 2" COIL & SPOT IN HALLIBURTON CEMENT TRUCKS. 12/26/2023 (P & A) DDT T X IA TO 0 PSI (PASS) 12/26/2023 STATE WITNESSED (ADAM EARL) TAG TOC @ 5474' RKB (GOOD), MITT TO 1710 PSI PASSED. READY FOR CTU. 12/23/2023 LAY IN 1096' CEMENT PLUG PUMPING 42 BBL OF 15.8 PPG CEMENT FROM 6597' RKB CIBP TO 5501' TOP OF CEMENT. PUMP S. DIESEL WHILE POOH TO CIRCULATE/CONTAMINATE PLUG FREEZE PROTECTING 7" PRODUCTION CASING. WAIT MINIMUM 24 HOURS FOR WITNESSED TAG & TEST. JOB IN PROGRESS. 12/22/2023 MIRU ON 3S-19 ATTEMPT TO TEST BOP AND FINISHED UP AT 12-22-23 @23:59 HRS 10/11/2023 *** JOB CONTINUED FROM 10/10/2023 *** COMPLETE IBC/CBL, LOGGED OVER INTERVAL 6630' - 5600', UPLOAD DATA TO TOWN FOR RUSH PROCESSING SET CIBP AT 6598' CCL TO CE = 10.5' CCL STOP DEPTH = 6587.5' JOB COMPLETE 10/10/2023 *** JOB CONTINUED FROM 10/09/2023 *** CONTINUE STANDBY FOR WINDS TO LOWER TO SAFE RIG UP CONDITIONS, CONDUCTED JUNK BASKET RUN WITH 5.9'' GAUGE RING. PLUG WAS NOT TAGGED DUE TO CIBP BEING M DUING COIL OPERATION. CONDUCTED IBC DSLT RUN AT RESOLUTIONS OF 5DEG6'', 5DEG3", AND 5DEG1.5''. FREE PIPE ADJUSTMENT CONDUCTED. *** CONTINUED JOB TO NEXT DAY *** 10/9/2023 STANDBY ON CT TO COMPLETE MILLING ON 3S-19, GET 7" BOP's INSTALLED ON WELL, SPOT IN EQUIPMENT, BEGIN RU 7" LUBRICATOR, STANDBY DUE TO HIGH WINDS. GOT A SMA AND PU GAUGE RING/JUNK BASKET, RIH TO 6660' RKB, CLEAN, LD DUE TO WINDS FOR THE REMAINDER OF DAY & NIGHT. *** JOB CONTINUED TO NEXT DAY *** 10/8/2023 STANDING BY FOR CT TO FINISH MILLING OPERATION IN PREPERATION FOR POST PERF IBC CBL *** JOB CONTINUED TO NEXT DAY *** 10/8/2023 REPAIRED DEPTH COUNTER. SWAPPED TRACTOR ON UNIT. COMPLETED WEEKLY BOP TEST. MILLED DOWN TO 6610'. COME OFF PUMPS. DRIFT DOWN TO 6620'. NO PLUG. P/U UN AND CLEAN OUT 6100'-6600'. FREEZE PROTECT WELL TO 2500 FT. READY FOR ELINE LOGGING. 10/7/2023 CONTINUE MILLING CEMENT FROM 6336'-6537' AVG ROP ~25 FPH. POOH DUE TO ISSUES WITH PUMP AND INJECTOR COUNTER. L/D BHA M/U TEST EQUIP. WEEKLY BOP TEST. 10/6/2023 MIRU. RIH W/ 6.125" OD BEAR CLAW MILL. TAG TOC AT 6125' CTMD. MILL CEMENT FROM 6125'-6336' CTMD AVERAGE ROP ~220 FPH TO 6330' CTMD, THEN SLOWED TO ~60 FPH PROGRESS. 9/24/2023 (P&A) OA DDT TO 0 PSI (COMPLETE), OBTAIN OA TOC (COMPLETE) @ SF 9/23/2023 PRE SW TAG TOP OF CEMENT @ 6120' SLM, GOOD CEMENT SAMPLE IN BAILER, MADE MULTIPLE MIT ATTEMPTS, MIT FAILED ... NEED PLAN FORWARD. 9/21/2023 PUMPED OA CEMENT DOWN SQUEEZE f/ SURFACE TO SHOE w/ 124 BBLS OF 15.8 PPG PERMAFROST CEMENT w/ LCM IN LEAD 50 BBLS OF CEMENT. PERFORM 10 MIN HESITATION LAST OF TAIL CEMENT. READY FOR THE NEXT STEP OF P&A. 9/20/2023 OA INJECTIVITY TEST PUMPED 5 BBLS DIESEL DOWN OA FOR INJECTIVITY TEST, SEE LOG FOR DETAILS JOB COMPLETE 9/19/2023 POOH DISPLACE WELL W/ S/W AND RIH W/ 2500' POOH F/P WELL CLOSE SWAB BLOW DOWN COIL UNIT #6 STRING W/N2 CUT OFF STRING 6800' IN 12' PIECES RDMO COIL UNIT DEADHORSE CREWS WILL RETURN TO COIL UNIT 14 ON 9-19-23 AM 1E-33 FISHING JOB 9/18/2023 MIRU ON 3S-19 TEST BOP's. RIH WITH HYDRAWELL PERF WASH / CEMENT TOOL, TAG AT 6585'. PERFORM 4 PERF WASH PASSES FROM 6580'' TO 6400'. DROP BALL & OPEN CEME 65 BBLS 15.8 CEMENT f/ 6585’ TO 6300' POOH & FLUSH OUT WELL w/ SEAWATER w/ SWEEPS TO SURFACE AND F/P WELL f/ 2500’ TO SURFACE. READY FOR SW TAG AND TEST IN 4 9/15/2023 ***JOB CONTINUED FROM PREVIOUS DAY*** GUN 2 PERFORATED INTERVAL = 6530'-6550' GUN 3 PERFORATED INTERVAL = 6508' - 6528' GUN 4 PERFORATED INTERVAL = 6488' - 6508' GUN 5 PERFORATED INTERVAL = 6466' - 6486' GUN 6 PERFORATED INTERVAL = 6446' - 6466' GUN 7 PERFORATED INTERVAL = 6424' - 6444' GUN 8 PERFORATED INTERVAL = 6420' - 6424' DRIFT WITH 5.91" GAGE RING AND JUNK BASKET - TAGGED AT 6565', ~30' ABOVE CIBP SLUDGE/FORMATION DEBRIS RECOVERED IN JUNK BASKET JOB COMPLETE, READY FOR COIL PWC 9/14/2023 MIRU ELINE. SET CIBP AT 6596' GUN 1 PERFORATED INTERVAL = 6550'-6570' ***JOB CONTINUED*** 9/2/2023 LOG USIT (IBC-CBL) WITH: 5DEG 6", 5DEG 3" AND 5DEG 1.5" RESOLUTION FROM 8271' TO 5500' JOB COMPLETED, POOH 9/1/2023 MOVILIZED EQUIPMENT AND SPOT IN, PERFORM JUNK BASKET RUN WITH 5.91", TAGGED AT 8271', RIH WITH USIT (IBC-CBL) TO PERFORM PRE-PERF CEMENT LOG EVALUATION JOB CONTINUE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 5,446.0 3S-19 12/26/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cement to surface 3S-19 12/30/2023 appleha Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELD SURFACE 9 5/8 8.83 29.5 3,579.6 2,596.0 40.00 L-80 BTC PRODUCTION 7 6.28 26.5 10,028.6 6,178.7 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 8,271.0 Set Depth … 9,584.0 Set Depth … 5,793.8 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,481.0 5,077.6 56.70 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' Camco MMG 2.920 8,534.4 5,107.1 56.45 SEAL ASSY 4.180 BAKER LOCATOR ASSEMBLY w/6' SPACE OUT Baker 80-40 3.000 8,541.4 5,110.9 56.42 PBR 5.880 BAKER 80-40 PBR Baker 80-40 PBR 4.000 8,563.9 5,123.4 56.31 PACKER 5.990 BAKER PREMIER PACKER Baker Premier 2.990 8,618.7 5,153.9 56.12 PRODUCTION 5.968 3 1/2" X 1.5" Camco 'MMG' Camco MMG 2.920 8,674.1 5,184.8 56.01 BLAST RING 4.090 3 1/2" ,9.3#, L-80, IBTM Tubing w/ 30-ft of 4.09" OD carbide blast rings Blast Joint 2.992 8,720.9 5,211.0 55.82 Sleeve - Sliding 3.500 BAKER CMU SLIDING SLEEVE w/ 2.813" "BX" Profile (OPEN 5/8/23) Baker T&C Non- Upset 2.813 9,525.3 5,745.0 34.73 PRODUCTION 5.968 3 1/2" X 1.5" Camco 'MMG' Camco MMG 2.920 9,581.0 5,791.3 32.77 SEAL ASSY 4.180 BAKER 80-40 SEAL ASSEMBLY w/3' SPACEOUT Baker 80-40 3.000 Top (ftKB) 9,584.0 Set Depth … 9,636.2 Set Depth … 5,838.2 String Max No… 5 31/32 Tubing Description TUBING Original Wt (lb/ft) Grade Top Connection ID (in) 4.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,584.0 5,793.9 32.67 PBR 5.968 Baker 3 1/2" 80-40 PBR 4.000 9,603.4 5,810.2 32.00 NIPPLE 4.730 KBH-22 Anchor Tubing Seal Nipple 3.000 9,604.3 5,811.0 31.97 PACKER 5.960 Baker 3 1/2" X 7" SAB-3 permanent packer 5.96" OD x 3.25" ID 3.250 9,609.2 5,815.2 31.80 MILLOUT 4.500 4 1/2" collar 3.720 9,615.3 5,820.3 31.60 XO - Reducing 4.500 Crossover 4 1/2" X 3 1/2" EUE 8rd 3.500 9,628.3 5,831.5 31.21 NIPPLE 4.500 Camco 2.75" "D" Nipple 2.750 9,635.3 5,837.4 31.17 WLEG 4.510 3 1/2" WLEG w/ shearout sub 4.51" OD (bottom at 9647.23-ft) 2.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,597.3 4,120.8 60.48 CIBP 7" CAST IRON BRIDGE PLUG MID-ELEMENT AT 6598', OAL 1.6'. LEGACY HPHB 00056 10- 002 10/11/2023 0.000 6,680.0 4,161.3 61.10 FISH 7" CAST IRON BRIDGE PLUG MID-ELEMENT AT 6596', OAL 1.6'. **FELL DOWNHOLE. SEE COIL WSR 10/8/23. DRIFTED TO 6620' RKB, EL DRIFTED TO ~6680' RKB WITH NO TAG*** ACT2 2- 2212 9/14/2023 0.000 8,271.0 4,964.1 57.89 CUT WELLTEC MECHANCIAL CUT. TATTLE-TAIL INDICATED GREATER THAN 3.5" BLADE EXPANSION 5/21/2023 2.992 8,515.0 5,096.4 56.54 CEMENT RETAINER 2.725" FH CEMENT RETAINER 5/8/2023 0.000 9,620.0 5,824.4 31.43 CEMENT RETAINER 2.75" FH CEMENT RETAINER 5/7/2023 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,420.0 6,444.0 4,033.7 4,045.5 9/15/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASEING 6,446.0 6,486.0 4,046.5 4,066.1 9/15/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASEING 6,488.0 6,528.0 4,067.1 4,086.8 9/15/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASEING 6,530.0 6,570.0 4,087.7 4,107.4 9/14/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60° PHASEING 8,680.0 8,700.0 5,188.1 5,199.3 Moraine, 3S-19 12/24/2012 6.0 APERF 3 3/8" Millenium, 6 spf, 60° phasing, HMX scallop 9,700.0 9,720.0 5,892.9 5,910.1 C-4, 3S-19 7/11/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph 3S-19, 8/26/2024 5:17:58 PM Vertical schematic (actual) PRODUCTION; 26.5-10,028.6 IPERF; 9,700.0-9,720.0 Cement Plug; 9,635.3 ftKB CEMENT RETAINER; 9,620.0 Cement Plug; 9,620.0 ftKB PACKER; 9,604.3 PRODUCTION; 9,525.3 Sleeve - Sliding; 8,720.8 FRAC; 8,680.0 APERF; 8,680.0-8,700.0 PRODUCTION; 8,618.7 Cement Plug; 8,578.0 ftKB PACKER; 8,563.9 Cement Plug; 8,516.5 ftKB CEMENT RETAINER; 8,515.0 GAS LIFT; 8,481.0 Cement Plug; 8,274.0 ftKB CUT; 8,271.0 FISH; 6,680.0 CIBP; 6,597.3 APERF; 6,530.0-6,570.0 APERF; 6,488.0-6,528.0 Cement Squeeze; 6,420.0 ftKB APERF; 6,446.0-6,486.0 APERF; 6,420.0-6,444.0 Cement Plug; 5,501.0 ftKB SURFACE; 29.5-3,579.6 Cement Squeeze; 33.0 ftKB CONDUCTOR; 30.0-108.0 Primary – Full Bore; 30.0 ftKB KUP PROD KB-Grd (ft) 33.03 RR Date 7/4/2003 Other Elev… 3S-19 ... TD Act Btm (ftKB) 10,040.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032046000 Wellbore Status PROD Max Angle & MD Incl (°) 61.56 MD (ftKB) 2,630.84 WELLNAME WELLBORE3S-19 Annotation Last WO: End Date 12/29/2012 H2S (ppm) 96 Date 12/6/2022 Comment SSSV: NIPPLE Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,680.0 8,700.0 1 FRAC 1/26/2013 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,635.3 9,820.0 5,837.4 5,996.4 Cement Plug 49 BBL, 15.8 PPG, CLASS G, BELOW RETAINER 5/8/2023 9,620.0 9,635.3 5,824.4 5,837.4 Cement Plug 5/8/2023 8,516.5 9,620.0 5,097.2 5,824.4 Cement Plug 49 BBL, 15.8 CLASS G CEMENT BELOW RETAINER 5/9/2023 8,578.0 9,604.0 5,131.2 5,810.7 Cement Plug 15,8 CLASS G CEMENT, SELECTIVE ANNULUS 5/9/2023 8,274.0 8,515.0 4,965.7 5,096.4 Cement Plug 2 BBL, 15.8 CLASS G, ABOVE RETAINER 5/9/2023 6,420.0 6,570.0 4,033.7 4,107.4 Cement Squeeze Perf Wash Cement 6420-6570' 9/15/2023 6,300.0 6,595.3 3,972.4 4,119.9 Cement Plug 65 bbls of 15.8 ppg Class G Cement above CIBP. **Milled Out** 10/8/23 to 6600' RKB 9/18/2023 33.0 3,579.6 33.0 2,596.1 Cement Squeeze 124 bbls of 15.8 ppg Class G Cement down OA 9/21/2023 30.0 5,501.0 30.0 3,570.5 Primary – Full Bore 220 BBL, 15.8 PPG, CLASS G CEMENT TO SURFACE. 12/30/2023 5,501.0 6,598.0 3,570.5 4,121.2 Cement Plug 42 BBL, 15.8 PPG, CLASS G, ABOVE CIBP 12/23/2023 3S-19, 8/26/2024 5:17:58 PM Vertical schematic (actual) PRODUCTION; 26.5-10,028.6 IPERF; 9,700.0-9,720.0 Cement Plug; 9,635.3 ftKB CEMENT RETAINER; 9,620.0 Cement Plug; 9,620.0 ftKB PACKER; 9,604.3 PRODUCTION; 9,525.3 Sleeve - Sliding; 8,720.8 FRAC; 8,680.0 APERF; 8,680.0-8,700.0 PRODUCTION; 8,618.7 Cement Plug; 8,578.0 ftKB PACKER; 8,563.9 Cement Plug; 8,516.5 ftKB CEMENT RETAINER; 8,515.0 GAS LIFT; 8,481.0 Cement Plug; 8,274.0 ftKB CUT; 8,271.0 FISH; 6,680.0 CIBP; 6,597.3 APERF; 6,530.0-6,570.0 APERF; 6,488.0-6,528.0 Cement Squeeze; 6,420.0 ftKB APERF; 6,446.0-6,486.0 APERF; 6,420.0-6,444.0 Cement Plug; 5,501.0 ftKB SURFACE; 29.5-3,579.6 Cement Squeeze; 33.0 ftKB CONDUCTOR; 30.0-108.0 Primary – Full Bore; 30.0 ftKB KUP PROD 3S-19 ... WELLNAME WELLBORE3S-19 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:18 Township:12N Range:8E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:10,038 ft MD Lease No.:ADL0380107 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 3580 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 10029 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 9636 Feet Tbg Cut@ 8,271 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 6,597 ft 5474 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 1710 1595 1560 IA OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled out to KRU 3S-19 for P&A operations consisting of a wire-line tag and pressure test. Brent Rogers was the CPAI representative on location. The wire-line tool string was made up w 10 feet of 2 1/8" WB, jars, spanges, and a 2 1/4" ball bailer that was 5 feet long. 200lbs hanging weight. They tagged top of cement @ 5,474 ft MD (5,446 ft WLM). Tubing pressure test passed. December 26, 2023 Adam Earl Well Bore Plug & Abandonment KRU 3S-19 CPAI PTD 2030960; Sundry 323-413 none Test Data: P Casing Removal: Brent Rogers Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2023-1226_Plug_Verification_KRU_3S-19_ae 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 2184' FNL, 3517' FEL S13 T12N R7E 9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" H-40 108'86 sx ArcticCrete 9-5/8" L-80 2596' 7" L-80 6179' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 9620-9820'MD 49 bbls of 15.8 Class G below retainer 48 bbls of 15.8 Class G below retainer 8274-8515'MD 8578-9604'MD 15.8 Class G Selective Annulus ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 250 sx Class G w/GasBlok7" 9584'3.5" 8564'MD/5123'TVD BOTTOM 8516-9620'MD 12-1/4" 440sx AS IIIL, 330sx LiteCrete CASING 50-103-20460-00-00 KRU 3S-19 6/23/2003 10040'MD/6187'TVD 8274'MD/4966'TVD 28' P.O.Box 100360, Anchorage, AK 99510-0360 476091 2542' FNL, 1169' FEL S18 T12N R8E 2176' FNL, 1597' FEL S13 T12N R7E 6/30/2003 1645'MD/1546'TVD SETTING DEPTH TVD 5994268 TOP HOLE SIZE AMOUNT PULLEDTOP 5994258 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 203-096/323-2618/6/2023 PACKER SET (MD/TVD) 42" 5993874 Kaparuk River Field/Kuparuk River Oil Pool/ Torok Oil Pool (Both Suspended) ADL0380107/ ADL0025544 2639 30' 30' 3580' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): WT. PER FT.GRADE 468939 468773 CEMENTING RECORD Suspended If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 8680-8700' MD and 5188-5199' TVD (cemented) 9700-9720'MD and 5893-5910'TVD (cemented) Gas-Oil Ratio:Choke Size: suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A N/A 30' 30' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 27' 62.5# 40# 108' 27' 10029' SIZE DEPTH SET (MD) Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SETTING DEPTH MD 2 bbl of 15.8ppg Class G above retainer Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 8:24 am, Sep 01, 2023 Suspended 8/6/2023 JSB RBDMS JSB 091523 xGDSR-10/25/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1645' 1645' N/A Suspended N/A Suspended N/A Suspended N/A Suspended 31. List of Attachments: Schematic, Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: James Ohlinger Digital Signature with Date: Contact Phone:907-265-1102 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Formation Name at TD: g Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Top of Productive Interval: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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. TPI (Top of Producing Interval). Authorized Name and INSTRUCTIONS Contact Email: james.j.ohlinger@conocophillips.com Authorized Title: CTD Engineer Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@cop.com Reason: I am the author of this documentLocation: Date: 2023.08.31 10:34:37-08'00' Foxit PDF Editor Version: 12.1.2 James J. Ohlinger Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,805.0 3S-19 10/1/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut at 8271' RKB 3S-19 5/21/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 4/27/2009 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELD SURFACE 9 5/8 8.83 29.5 3,579.6 2,596.0 40.00 L-80 BTC PRODUCTION 7 6.28 26.5 10,028.6 6,178.7 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 8,271.0 Set Depth … 9,584.0 Set Depth … 5,793.8 String Ma… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,481.0 5,077.6 56.70 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ DCR- 1 SOV - RKP Latch (SN:270AD04) Camco MMG 2.920 8,534.4 5,107.1 56.45 SEAL ASSY 4.180 BAKER LOCATOR ASSEMBLY w/6' SPACE OUT Baker 80-40 3.000 8,541.4 5,110.9 56.42 PBR 5.880 BAKER 80-40 PBR Baker 80-40 PBR 4.000 8,563.9 5,123.4 56.31 PACKER 5.990 BAKER PREMIER PACKER Baker Premier 2.990 8,674.1 5,184.8 56.01 BLAST RING 4.090 3 1/2" ,9.3#, L-80, IBTM Tubing w/ 30-ft of 4.09" OD carbide blast rings Blast Joint 2.992 8,720.9 5,211.0 55.82 Sleeve - Sliding 3.500 BAKER CMU SLIDING SLEEVE w/ 2.813" "BX" Profile (OPEN 5/8/23) Baker T&C Non- Upset 2.813 9,581.0 5,791.3 32.77 SEAL ASSY 4.180 BAKER 80-40 SEAL ASSEMBLY w/3' SPACEOUT Baker 80-40 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,271.0 4,964.1 57.89 CUT WELLTEC MECHANCIAL CUT. TATTLE-TAIL INDICATED GREATER THAN 3.5" BLADE EXPANSION 5/21/2023 2.992 8,515.0 5,096.4 56.54 CEMENT RETAINER 2.725" FH CEMENT RETAINER 5/8/2023 0.000 9,620.0 5,824.4 31.43 CEMENT RETAINER 2.75" FH CEMENT RETAINER 5/7/2023 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,680.0 8,700.0 5,188.1 5,199.3 Moraine, 3S-19 12/24/2012 6.0 APERF 3 3/8" Millenium, 6 spf, 60° phasing, HMX scallop 9,700.0 9,720.0 5,892.9 5,910.1 C-4, 3S-19 7/11/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,680.0 8,700.0 1 FRAC 1/26/2013 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,635.3 9,820.0 5,837.4 5,996.4 Cement Plug 49 BBL, 15.8 PPG, CLASS G, BELOW RETAINER 5/8/2023 9,620.0 9,635.3 5,824.4 5,837.4 Cement Plug 5/8/2023 8,516.5 9,620.0 5,097.2 5,824.4 Cement Plug 49 BBL, 15.8 CLASS G CEMENT BELOW RETAINER 5/9/2023 8,578.0 9,604.0 5,131.2 5,810.7 Cement Plug 15,8 CLASS G CEMENT, SELECTIVE ANNULUS 5/9/2023 8,274.0 8,515.0 4,965.7 5,096.4 Cement Plug 2 BBL, 15.8 CLASS G, ABOVE RETAINER 5/9/2023 3S-19, 8/29/2023 2:19:33 PM Vertical schematic (actual) PRODUCTION; 26.5-10,028.6 IPERF; 9,700.0-9,720.0 Cement Plug; 9,635.3 ftKB CEMENT RETAINER; 9,620.0 Cement Plug; 9,620.0 ftKB PRODUCTION; 9,525.3 Sleeve - Sliding; 8,720.8 FRAC; 8,680.0 APERF; 8,680.0-8,700.0 PRODUCTION; 8,618.7 Cement Plug; 8,578.0 ftKB PACKER; 8,563.9 Cement Plug; 8,516.5 ftKB CEMENT RETAINER; 8,515.0 GAS LIFT; 8,481.0 Cement Plug; 8,274.0 ftKB CUT; 8,271.0 SURFACE; 29.5-3,579.6 CONDUCTOR; 30.0-108.0 KUP PROD KB-Grd (ft) 33.03 RR Date 7/4/2003 Other Elev… 3S-19 ... TD Act Btm (ftKB) 10,040.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032046000 Wellbore Status PROD Max Angle & MD Incl (°) 61.56 MD (ftKB) 2,630.84 WELLNAME WELLBORE3S-19 Annotation Last WO: End Date 12/29/2012 H2S (ppm) 60 Date 9/4/2015 Comment SSSV: NIPPLE Page 1/2 3S-19 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/4/2023 09:00 8/4/2023 11:00 2.00 MIRU, MOVE PRTS P PT tree 1500 psi for 30 min 0.0 0.0 8/4/2023 11:00 8/4/2023 15:00 4.00 MIRU, MOVE MOB P Move sub base off 3S-18. Move rig mats around to 3S-19. Move sub base over 3S-19. Take on water Rig accepted 15:00 on 8/4/23 0.0 0.0 8/4/2023 15:00 8/4/2023 16:30 1.50 MIRU, WELCTL RURD P Berm rig and prep to circulate KWF 0.0 0.0 8/4/2023 16:30 8/4/2023 18:30 2.00 MIRU, WELCTL DISP P Displace well to 9.6 KWF // PP= 520 psi @ 4 bpm // Lead with 30 bbls deep clean pill followed by 9.6 0.0 0.0 8/4/2023 18:30 8/4/2023 19:00 0.50 MIRU, WELCTL OWFF P OWFF no flow from tubing or IA 0.0 0.0 8/4/2023 19:00 8/4/2023 20:30 1.50 MIRU, WELCTL MPSP P Install BPF w/ test dart // PT 1000psi 10 min 0.0 0.0 8/4/2023 20:30 8/4/2023 21:00 0.50 MIRU, WELCTL SVRG P Service and grease casing tongs for pulling completion 0.0 0.0 8/4/2023 21:00 8/5/2023 00:00 3.00 MIRU, WELCTL NUND P Nipple down production tree, inspect hanger threads for pulling completion, nipple up BOPs 0.0 0.0 8/5/2023 00:00 8/5/2023 01:00 1.00 MIRU, WELCTL NUND P Get RKBs // Install riser to flow line install air boot // Install turn buckles 0.0 0.0 8/5/2023 01:00 8/5/2023 01:30 0.50 MIRU, WELCTL SVRG P Service and grease choke for bop test 0.0 0.0 8/5/2023 01:30 8/5/2023 02:30 1.00 MIRU, WELCTL OTHR P Pick up tools for testing BOPs // flood surface lines 0.0 0.0 8/5/2023 02:30 8/5/2023 08:00 5.50 MIRU, WHDBOP BOPE P Test annular with 3 1/2" test joint to 250/2500 PSI F/5 min. All other test to 250/2500PSI F/5 min each, UVBR with 3 1/2" test joint, Test blinds rams, Choke valves #1 to #16, upper/lower IBOP valves. Test 3-1/2" HT-38 FOSV/Dart Valve, Test 2" rig floor Demco kill valves, Test manual and HCR kill and choke valves.Test two ea 2-1/16" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3200 PSI, after closure = 1550 PSI, 200 PSI attained = 12 sec, full recovery attained = 114 sec. UVBR = 5 sec, Annular = 28 sec, Simulated blinds = 5 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 1950 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Kam St. John witness waived 0.0 0.0 8/5/2023 08:00 8/5/2023 09:00 1.00 COMPZN, RPCOMP RURD P RD test equipment, suck out the stack. 0.0 0.0 8/5/2023 09:00 8/5/2023 09:30 0.50 COMPZN, RPCOMP MPSP P Pull BPV. 0.0 0.0 8/5/2023 09:30 8/5/2023 10:00 0.50 COMPZN, RPCOMP THGR P MU landing joint, BOLDS pull tubing hanger to the rig floor with no overpull. 0.0 0.0 8/5/2023 10:00 8/5/2023 11:30 1.50 COMPZN, RPCOMP OWFF P OWFF, no flow. 0.0 0.0 8/5/2023 11:30 8/5/2023 12:00 0.50 COMPZN, RPCOMP SLPC P Slip and cut drilling line. 0.0 0.0 8/5/2023 12:00 8/5/2023 12:30 0.50 COMPZN, RPCOMP SVRG P Service the top drive. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/6/2023 Page 2/2 3S-19 Report Printed: 8/29/2023 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 8/5/2023 12:30 8/6/2023 00:00 11.50 COMPZN, RPCOMP PULL P Pull 3.5" completion from pre-rig tubing cut at 8271'. 270 jts 1 cut jt 16.23' and 4 GLMs 0.0 0.0 8/6/2023 00:00 8/6/2023 01:00 1.00 COMPZN, WHDBOP CLEN P Clean up from laying down tubing prep for between wells maintenance. 0.0 0.0 8/6/2023 01:00 8/6/2023 01:30 0.50 COMPZN, WHDBOP FRZP P Fill IA with 7.4 bbls diesel. 0.0 0.0 8/6/2023 01:30 8/6/2023 06:30 5.00 COMPZN, WHDBOP OTHR P Perform Between Wells Maintenance on BOPs 0.0 0.0 8/6/2023 06:30 8/6/2023 08:30 2.00 COMPZN, WHDBOP NUND P Nipple down BOPs and secure in cellar 0.0 0.0 8/6/2023 08:30 8/6/2023 11:30 3.00 COMPZN, WHDBOP NUND P Nipple up tree , bots missing for well head, wait on bolts, pull pits off rig 0.0 0.0 8/6/2023 11:30 8/6/2023 12:00 0.50 COMPZN, WHDBOP SVRG P Replace hose on tubing tongs 0.0 0.0 8/6/2023 12:00 8/6/2023 17:00 5.00 COMPZN, WHDBOP PRTS P Attempt to pressure test tree 1500 psi 30 min // Unable to build pressure pump away 20 bbls // consult with town // perform rolling test on tree 1500 for 30 min .2bbl/min injection rate, 27 bbls total pumped into well 0.0 0.0 8/6/2023 17:00 8/6/2023 18:00 1.00 COMPZN, WHDBOP OWFF P Perform no flow test ensure well pressure would not build above test pressure // no flow observed at well head *** Rig released @ 18:00 on 8/6/23 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/6/2023 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10038'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-4131 Staff Well Intervention Engineer KRU 3S-19 6187' 8274' 4966' 1440 psi 8274' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: jill.simek@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8564' MD and 5123' TVD 9604' MD and 5811' TVD 504' MD and 504' TVD Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544, ADL0380107 203-096 P.O. Box 100360, Anchorage, AK 99510 50-103-20460-00-00 Kuparuk River Field N/A - Suspended (Kuparuk River Oil Pool) ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY N/A- Abandoned (Kuparuk River Oil Pool) TVD Burst 9636' MD 108' 2596' 108' 3580' 6179'10029' 16" 9-5/8" 78' 3550' 8680-8700', 9700-9720' (cemented) 10002' 5188-5199', 5893-5910' (cemented) 7" Perforation Depth TVD (ft): 8/1/2023 3-1/2" Packer: Baker Premier Packer Packer: Baker SAB-3 Perm Packer SSSV: Camco DS Nipple Profile Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:33 pm, Jul 19, 2023 323-413 Jill Simek Digitally signed by Jill Simek Date: 2023.07.19 14:39:28 -08'00' X X MDG 7/24/2023 DSR-7/19/23 X 7/24/2023 AOGCC inspection is required after cutoff and before any remedial cementing. 10-407 GCW 07/24/2023JLC 7/24/2023 07/25/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.07.25 09:33:31 -08'00' RBDMS JSB 072523 3S-19 Plug and Abandon Procedure PTD #203-096 Page 1 of 2 General Well info: Wellhead type/pressure rating: FMC Gen 5 Production Engineer: Brian Lewis Surveillance Reservoir Engineer: Lynn Aleshire Estimated Start Date: August 1, 2023 Interventions Engineer: Jill Simek (265-4131/ jill.simek@conocophillips.com) Current Operations: This well is currently suspended with cement across Kuparuk. Rig operations are planned to cut and pull tubing from 8,271ft KB. Well Type: Producer Scope of Work: Perform Plug and Abandonment of 3S-19: Perf/Wash/Cement in production casing x OH annulus, cement well to surface, excavate and remove wellhead. MPSP: 1440 psi using 0.1 psi/ft gradient Static BHP: 1857 psi / 4166’ TVD estimated from 3S-24B BHP. Sl/El/Coil will be exposed to pressure once perf guns are fired. Procedure Eline 1. MIRU. 2. RIH with CBL and log 7.0” casing to confirm TOC of original cement job. POOH a. If TOC is BELOW Top of Moraine, then do additional production casing x open hole (OA) perf/wash/cement 50’ into Moraine and 100’ into confining zone above it to isolate for a total of ~150’ cement OA plug. 3. RIH and set 7” CIBP at base of perforation zone, approximately 6,596ft KB. POOH. 4. RIH with perf guns and perforate 7.0” casing as required to get exposure to top ~50’ of Coyote formation and ~100’ into the confining zone above it. (Note CIBP set depth and perf intervals may be adjusted, based on log response and/or well conditions encountered) POOH. 5. RDMO Coil 6. MIRU. 7. RIH with wash/cement tool. Gently tag the CIBP. 8. PU and wash perfs per wash/cement tool’s vendor procedure. 9. After wash procedure, cement OA through perforations per wash/cement tool’s vendor procedure. POOH. Job is planned for ~68bbls cement, including excess. 10. Leave Top of Cement in production casing ~150ft above top perforation at ~6,270ft KB (Note, TOC depth may be adjusted, based on log response and/or well conditions encountered). Circ out excess. 11. RDMO. Wait on cement. Slickline 12. Notify the AOGCC Inspector of timing for TOC tag and pressure test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 13. MIRU. 14. SL: RIH and tag top of cement (witnessed) 15. SL: Perform MIT on production casing (witnessed) 16. RDMO. 3S-19 Plug and Abandon Procedure PTD #203-096 Page 2 of 2 Coil 17. MIRU. 18. Pump cement plug in production casing, from top of cement to surface. Job is planned for 240 bbls cement. 19. RDMO. Pumping 20. MIRU. 21. Perform OA down squeeze to place cement from surface to 3,579ft KB. Job is planned for 121 bbls of cement, including excess. 22. RDMO. Wellhead Excavation / Final P&A: 23. Confirm production casing and production casing x surface casing annulus pressures are at 0psi. 24. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 25. Remove the tree, in preparation for the excavation and casing cut. 26. Excavate and remove wellhead and all casing strings at 4 feet below original ground level. 27. Verify that cement is at surface in all strings. Perform cement “top off” job(s) if required. AOGCC witness and photo document required. 28. Send the casing head w/ stub to materials shop. Photo document. 29. Weld ¼” thick cover plate (16” O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 3S-19 PTD #: 203-096 API #: 50-103-20460-00 30. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 31. Obtain site clearance approval from AOGCC. RDMO. *If two plugs are deemed to be required due to Moraine formation exposure in the OA to the Coyote, then a lower plug will be performed first with the above steps to isolate top of Moraine. Then a 2nd plug will be performed as described at the top of the Coyote. Current Completion Proposed P&A 3S-19 P&A PTD #: 203-096 16” 62.5# H-40 Conductor @ 108' KB JS 7-18-2023 7" 26# L-80 Production Casing @ 10,028' KB 3-½” 9.3# L-80 Tubing @ 9,635' KB 9 5/8" 40# L-80 Surface Casing @ 3,579' KB Kup C Perfs: 9,700' – 9,720' KB Logged Top of Cement (7"xOH) = 8,400' KB Kuparuk HRZ/Kalubik Shales Moraine 8,648' – 9,006' KB Coyote 6,520' – 7,325' KB Packer depth = 9,604' KB Moraine Perfs: 8,680' – 8,700' KB Torok basinal shales Packer depth = 8,563' KB Tubing cut at 8,271ft KB TOC (tubing) at 8,285ft KB Cement retainer set at 9,620ft KB CIBP @ ~6,596' KB Cement Plug (Production Casing x Open Hole Annulus) Approx. 6,420' – 6,570' KB Cement Plug (Production Casing x Surface Casing Annulus) 3,579' KB to Surface Cement Plug (Production Casing) Approx. 6,596' KB to Surface Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut at 8271' RKB 3S-19 5/21/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 4/27/2009 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELD SURFACE 9 5/8 8.83 29.5 3,579.6 2,596.0 40.00 L-80 BTC PRODUCTION 7 6.28 26.5 10,028.6 6,178.7 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.2 Set Depth … 9,584.0 Set Depth … 5,793.8 String Ma… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.2 24.2 0.00 HANGER 10.812 FMC GEN V TUBING HANGER FMC 3.500 504.4 503.7 6.41 NIPPLE 5.176 CAMCO DS NIPPLE w/2.875" PROFILE Camco "DS" 2.875 3,408.7 2,509.1 59.60 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ Dummy - RK Latch (SN: 278AD04) Camco MMG 2.920 5,672.2 3,653.5 60.59 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ Dummy - RK Latch (SN:262AD04) Camco MMG 2.920 7,169.8 4,400.7 60.87 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ Dummy - RK Latch (SN:258AD04) Camco MMG 2.920 8,083.4 4,865.9 59.01 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ Dummy - RK Latch (SN:269AD04) Camco MMG 2.920 8,481.0 5,077.6 56.70 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ DCR- 1 SOV - RKP Latch (SN:270AD04) Camco MMG 2.920 8,534.4 5,107.1 56.45 SEAL ASSY 4.180 BAKER LOCATOR ASSEMBLY w/6' SPACE OUT Baker 80-40 3.000 8,541.4 5,110.9 56.42 PBR 5.880 BAKER 80-40 PBR Baker 80-40 PBR 4.000 8,563.9 5,123.4 56.31 PACKER 5.990 BAKER PREMIER PACKER Baker Premier 2.990 8,674.1 5,184.8 56.01 BLAST RING 4.090 3 1/2" ,9.3#, L-80, IBTM Tubing w/ 30-ft of 4.09" OD carbide blast rings Blast Joint 2.992 8,720.8 5,211.0 55.82 Sleeve - Sliding 3.500 BAKER CMU SLIDING SLEEVE w/ 2.813" "BX" Profile (OPEN 5/8/23) Baker T&C Non- Upset 2.813 9,581.0 5,791.3 32.77 SEAL ASSY 4.180 BAKER 80-40 SEAL ASSEMBLY w/3' SPACEOUT Baker 80-40 3.000 Top (ftKB) 9,584.0 Set Depth … 9,636.2 Set Depth … 5,838.2 String Ma… 5 31/32 Tubing Description TUBING Original Wt (lb/ft) Grade Top Connection ID (in) 4.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,584.0 5,793.9 32.67 PBR 5.968 Baker 3 1/2" 80-40 PBR 4.000 9,603.4 5,810.2 32.00 NIPPLE 4.730 KBH-22 Anchor Tubing Seal Nipple 3.000 9,604.3 5,811.0 31.97 PACKER 5.960 Baker 3 1/2" X 7" SAB-3 permanent packer 5.96" OD x 3.25" ID 3.250 9,609.2 5,815.2 31.80 MILLOUT 4.500 4 1/2" collar 3.720 9,615.3 5,820.3 31.60 XO - Reducing 4.500 Crossover 4 1/2" X 3 1/2" EUE 8rd 3.500 9,628.3 5,831.5 31.21 NIPPLE 4.500 Camco 2.75" "D" Nipple 2.750 9,635.3 5,837.4 31.17 WLEG 4.510 3 1/2" WLEG w/ shearout sub 4.51" OD (bottom at 9647.23-ft) 2.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,271.0 4,964.1 57.89 CUT WELLTEC MECHANCIAL CUT. TATTLE-TAIL INDICATED GREATER THAN 3.5" BLADE EXPANSION 5/21/2023 2.992 8,515.0 5,096.4 56.54 CEMENT RETAINER 2.725" FH CEMENT RETAINER 5/8/2023 0.000 9,620.0 5,824.4 31.43 CEMENT RETAINER 2.75" FH CEMENT RETAINER 5/7/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,408.7 2,509.1 59.60 1 GAS LIFT DMY RK 1 1/2 0.0 6/3/2013 0.000 5,672.2 3,653.5 60.59 2 GAS LIFT DMY RK 1 1/2 0.0 5/19/2023 0.000 7 169 8 4 400 7 60 87 3 GAS LIFT DMY RK 1 1/2 0 0 6/3/2013 0 000 IPERF; 9,700.0-9,720.0 Cement Plug; 9,635.3 ftKB CEMENT RETAINER; 9,620.0 Cement Plug; 9,620.0 ftKB PACKER; 9,604.3 PRODUCTION; 9,525.3 Sleeve - Sliding; 8,720.8 FRAC; 8,680.0 APERF; 8,680.0-8,700.0 PRODUCTION; 8,618.7 Cement Plug; 8,578.0 ftKB PACKER; 8,563.9 Cement Plug; 8,516.5 ftKB CEMENT RETAINER; 8,515.0 GAS LIFT; 8,481.0 Cement Plug; 8,274.0 ftKB CUT; 8,271.0 GAS LIFT; 8,083.4 GAS LIFT; 7,169.8 GAS LIFT; 5,672.2 SURFACE; 29.5-3,579.6 GAS LIFT; 3,408.7 NIPPLE; 504.4 CONDUCTOR; 30.0-108.0 8,680.0 8,700.0 5,188.1 5,199.3 Moraine, 3S-19 12/24/2012 6.0 APERF 3 3/8" Millenium, 6 spf, 60° phasing, HMX scallop 9,700.0 9,720.0 5,892.9 5,910.1 C-4, 3S-19 7/11/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,680.0 8,700.0 1 FRAC 1/26/2013 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,635.3 9,820.0 5,837.4 5,996.4 Cement Plug 49 BBL, 15.8 PPG, CLASS G, BELOW RETAINER 5/8/2023 9,620.0 9,635.3 5,824.4 5,837.4 Cement Plug 5/8/2023 8,516.5 9,620.0 5,097.2 5,824.4 Cement Plug 49 BBL, 15.8 CLASS G CEMENT BELOW RETAINER 5/9/2023 8,578.0 9,604.0 5,131.2 5,810.7 Cement Plug 15,8 CLASS G CEMENT, SELECTIVE ANNULUS 5/9/2023 8,274.0 8,515.0 4,965.7 5,096.4 Cement Plug 2 BBL, 15.8 CLASS G, ABOVE RETAINER 5/9/2023 IPERF; 9,700.0-9,720.0 Cement Plug; 9,635.3 ftKB CEMENT RETAINER; 9,620.0 Cement Plug; 9,620.0 ftKB PACKER; 9,604.3 PRODUCTION; 9,525.3 Sleeve - Sliding; 8,720.8 FRAC; 8,680.0 APERF; 8,680.0-8,700.0 PRODUCTION; 8,618.7 Cement Plug; 8,578.0 ftKB PACKER; 8,563.9 Cement Plug; 8,516.5 ftKB CEMENT RETAINER; 8,515.0 GAS LIFT; 8,481.0 Cement Plug; 8,274.0 ftKB CUT; 8,271.0 GAS LIFT; 8,083.4 GAS LIFT; 7,169.8 GAS LIFT; 5,672.2 SURFACE; 29.5-3,579.6 GAS LIFT; 3,408.7 NIPPLE; 504.4 CONDUCTOR; 30.0-108.0 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 108' 9-5/8" L-80 2596' 7" L-80 6179' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 250 sx GasBlok7" 9604' MD/ 5811' TVD 9636' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 5/17/2023 203-096/ 323-244 2542' FNL, 1169' FEL, Sec. 18, T12N, R8E, UM 2176' FNL, 1597' FWL, Sec. 13, T12N, R7E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476091 5993874 2184' FNL, 3517' FEL, Sec. 13, T12N, R7E, UM 8274' MD/ 4966' TVD 10038' MD/ 6187' TVD ADL0380107, ADL0025544 2639 50-103-20460-00-00 KRU 3S-19 June 23, 2003 June 30, 2003 9. Ref Elevations: KB: 28" Kuparuk River Field/ Kuparuk River Oil Pool and Torok Oil Pool (Both Suspended) WT. PER FT.GRADE CEMENTING RECORD 5994258 SETTING DEPTH TVD 5994268 TOP HOLE SIZE AMOUNT PULLED 468939 468773 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. BOTTOM N/A 1645' MD/ 1546' TVD N/A 8564' MD/ 5123' TVD PACKER SET (MD/TVD) 42" 12-1/4" 86 sx ArcticCrete 30' 30' 3580'30' 30' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 8274-8515' MD 2 bbl, 15.8 ppg Class G, above retainer Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 8516-9620' MD 9620-9820' MD SUSPENDED 8680-8700' MD and 5188-5199' TVD (cemented) 9700-9720' MD and 5893-5910' TVD (cemented) Gas-Oil Ratio:Choke Size: 48 bbl, 15.8 ppg Class G below reatiner Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 49 bbl, 15.8 ppg Class G, below retainer 8578-9604' MD 15.8 ppg Class G, Selective Annulus 10029' SIZE DEPTH SET (MD) 27' 62.5# 40# 108' 27' 440 sx AS III Lite, 330 sx LiteCrete Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 10:29 am, Jun 08, 2023 Suspended 5/17/2023 JSB RBDMS JSB 060823 56.3 28 xGDSR-6/12/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1645' 1546' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jill Simek Digital Signature with Date:Contact Email:jill.simek@conocophillips.com Contact Phone:(907) 263-4131 Staff Well Integrity Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Suspended Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A - Suspended Authorized Name and Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. 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. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Jill Simek Digitally signed by Jill Simek Date: 2023.06.07 16:53:08 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,805.0 3S-19 10/1/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut at 8271' RKB 3S-19 5/21/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 4/27/2009 lmosbor General Notes: Last 3 entries Com Date Last Mod By TREE: FMC GEN 5 / 5M TREE CAP CONNECTION: TOP 5.75"" ACME with 3.5"" EUE8RD THREAD 7/3/2003 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.0 108.0 108.0 62.50 H-40 WELD SURFACE 9 5/8 8.83 29.5 3,579.6 2,596.0 40.00 L-80 BTC PRODUCTION 7 6.28 26.5 10,028.6 6,178.7 26.00 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.2 Set Depth … 9,584.0 Set Depth … 5,793.8 String Ma… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.2 24.2 0.00 HANGER 10.812 FMC GEN V TUBING HANGER FMC 3.500 504.4 503.7 6.41 NIPPLE 5.176 CAMCO DS NIPPLE w/2.875" PROFILE Camco "DS" 2.875 3,408.7 2,509.1 59.60 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ Dummy - RK Latch (SN: 278AD04) Camco MMG 2.920 5,672.2 3,653.5 60.59 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ Dummy - RK Latch (SN:262AD04) Camco MMG 2.920 7,169.8 4,400.7 60.87 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ Dummy - RK Latch (SN:258AD04) Camco MMG 2.920 8,083.4 4,865.9 59.01 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ Dummy - RK Latch (SN:269AD04) Camco MMG 2.920 8,481.0 5,077.6 56.70 GAS LIFT 5.968 3 1/2" X 1.5" Camco 'MMG' w/ DCR- 1 SOV - RKP Latch (SN:270AD04) Camco MMG 2.920 8,534.4 5,107.1 56.45 SEAL ASSY 4.180 BAKER LOCATOR ASSEMBLY w/6' SPACE OUT Baker 80-40 3.000 8,541.4 5,110.9 56.42 PBR 5.880 BAKER 80-40 PBR Baker 80-40 PBR 4.000 8,563.9 5,123.4 56.31 PACKER 5.990 BAKER PREMIER PACKER Baker Premier 2.990 8,674.1 5,184.8 56.01 BLAST RING 4.090 3 1/2" ,9.3#, L-80, IBTM Tubing w/ 30-ft of 4.09" OD carbide blast rings Blast Joint 2.992 8,720.8 5,211.0 55.82 Sleeve - Sliding 3.500 BAKER CMU SLIDING SLEEVE w/ 2.813" "BX" Profile (OPEN 5/8/23) Baker T&C Non- Upset 2.813 9,581.0 5,791.3 32.77 SEAL ASSY 4.180 BAKER 80-40 SEAL ASSEMBLY w/3' SPACEOUT Baker 80-40 3.000 Top (ftKB) 9,584.0 Set Depth … 9,636.2 Set Depth … 5,838.2 String Ma… 5 31/32 Tubing Description TUBING Original Wt (lb/ft) Grade Top Connection ID (in) 4.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,584.0 5,793.9 32.67 PBR 5.968 Baker 3 1/2" 80-40 PBR 4.000 9,603.4 5,810.2 32.00 NIPPLE 4.730 KBH-22 Anchor Tubing Seal Nipple 3.000 9,604.3 5,811.0 31.97 PACKER 5.960 Baker 3 1/2" X 7" SAB-3 permanent packer 5.96" OD x 3.25" ID 3.250 9,609.2 5,815.2 31.80 MILLOUT 4.500 4 1/2" collar 3.720 9,615.3 5,820.3 31.60 XO - Reducing 4.500 Crossover 4 1/2" X 3 1/2" EUE 8rd 3.500 9,628.3 5,831.5 31.21 NIPPLE 4.500 Camco 2.75" "D" Nipple 2.750 9,635.3 5,837.4 31.17 WLEG 4.510 3 1/2" WLEG w/ shearout sub 4.51" OD (bottom at 9647.23-ft) 2.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,271.0 4,964.1 57.89 CUT WELLTEC MECHANCIAL CUT. TATTLE-TAIL INDICATED GREATER THAN 3.5" BLADE EXPANSION 5/21/2023 2.992 8,515.0 5,096.4 56.54 CEMENT RETAINER 2.725" FH CEMENT RETAINER 5/8/2023 0.000 9,620.0 5,824.4 31.43 CEMENT RETAINER 2.75" FH CEMENT RETAINER 5/7/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,408.7 2,509.1 59.60 1 GAS LIFT DMY RK 1 1/2 0.0 6/3/2013 0.000 5,672.2 3,653.5 60.59 2 GAS LIFT DMY RK 1 1/2 0.0 5/19/2023 0.000 7,169.8 4,400.7 60.87 3 GAS LIFT DMY RK 1 1/2 0.0 6/3/2013 0.000 8,083.4 4,865.9 59.01 4 GAS LIFT OPEN 1 1/2 5/19/2023 3S-19, 6/7/2023 4:34:10 PM Vertical schematic (actual) PRODUCTION; 26.5-10,028.6 IPERF; 9,700.0-9,720.0 Cement Plug; 9,635.3 ftKB CEMENT RETAINER; 9,620.0 Cement Plug; 9,620.0 ftKB PACKER; 9,604.3 PRODUCTION; 9,525.3 Sleeve - Sliding; 8,720.8 FRAC; 8,680.0 APERF; 8,680.0-8,700.0 PRODUCTION; 8,618.7 Cement Plug; 8,578.0 ftKB PACKER; 8,563.9 Cement Plug; 8,516.5 ftKB CEMENT RETAINER; 8,515.0 GAS LIFT; 8,481.0 Cement Plug; 8,274.0 ftKB CUT; 8,271.0 GAS LIFT; 8,083.4 GAS LIFT; 7,169.8 GAS LIFT; 5,672.2 SURFACE; 29.5-3,579.6 GAS LIFT; 3,408.7 NIPPLE; 504.4 CONDUCTOR; 30.0-108.0 KUP PROD KB-Grd (ft) 33.03 RR Date 7/4/2003 Other Elev… 3S-19 ... TD Act Btm (ftKB) 10,040.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032046000 Wellbore Status PROD Max Angle & MD Incl (°) 61.56 MD (ftKB) 2,630.84 WELLNAME WELLBORE3S-19 Annotation Last WO: End Date 12/29/2012 H2S (ppm) 60 Date 9/4/2015 Comment SSSV: NIPPLE Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 8,481.0 5,077.6 56.70 5 GAS LIFT OV RK 1 1/2 0.0 4/12/2014 WFT 0.250 8,618.7 5,153.9 56.12 6 PROD DMY RK 1 1/2 0.0 8/7/2019 0.000 9,525.3 5,745.0 34.73 7 PROD DMY RK 1 1/2 0.0 12/26/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,680.0 8,700.0 5,188.1 5,199.3 Moraine, 3S-19 12/24/2012 6.0 APERF 3 3/8" Millenium, 6 spf, 60° phasing, HMX scallop 9,700.0 9,720.0 5,892.9 5,910.1 C-4, 3S-19 7/11/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 8,680.0 8,700.0 1 FRAC 1/26/2013 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,635.3 9,820.0 5,837.4 5,996.4 Cement Plug 49 BBL, 15.8 PPG, CLASS G, BELOW RETAINER 5/8/2023 9,620.0 9,635.3 5,824.4 5,837.4 Cement Plug 5/8/2023 8,516.5 9,620.0 5,097.2 5,824.4 Cement Plug 49 BBL, 15.8 CLASS G CEMENT BELOW RETAINER 5/9/2023 8,578.0 9,604.0 5,131.2 5,810.7 Cement Plug 15,8 CLASS G CEMENT, SELECTIVE ANNULUS 5/9/2023 8,274.0 8,515.0 4,965.7 5,096.4 Cement Plug 2 BBL, 15.8 CLASS G, ABOVE RETAINER 5/9/2023 3S-19, 6/7/2023 4:34:11 PM Vertical schematic (actual) PRODUCTION; 26.5-10,028.6 IPERF; 9,700.0-9,720.0 Cement Plug; 9,635.3 ftKB CEMENT RETAINER; 9,620.0 Cement Plug; 9,620.0 ftKB PACKER; 9,604.3 PRODUCTION; 9,525.3 Sleeve - Sliding; 8,720.8 FRAC; 8,680.0 APERF; 8,680.0-8,700.0 PRODUCTION; 8,618.7 Cement Plug; 8,578.0 ftKB PACKER; 8,563.9 Cement Plug; 8,516.5 ftKB CEMENT RETAINER; 8,515.0 GAS LIFT; 8,481.0 Cement Plug; 8,274.0 ftKB CUT; 8,271.0 GAS LIFT; 8,083.4 GAS LIFT; 7,169.8 GAS LIFT; 5,672.2 SURFACE; 29.5-3,579.6 GAS LIFT; 3,408.7 NIPPLE; 504.4 CONDUCTOR; 30.0-108.0 KUP PROD 3S-19 ... WELLNAME WELLBORE3S-19 DTTMSTART JOBTYP SUMMARYOPS 5/5/2023 ACQUIRE DATA (P&A) : FUNCTION TESTED T&IC-LDS/GN'S (ALL GOOD), POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED. 5/5/2023 SUPPORT OTHER OPERATIONS DRIFT FOR COIL W/ DUMMY 2.79'' CA2 PLUG TO D-NIPPLE @ 9628'RKB, LRS INJECTIVITY TEST ON TBG, LRS ESTABLISH LIQUID LEAK RATE ON OA, READY FOR COIL. *COMPLETE* 5/7/2023 SUPPORT OTHER OPERATIONS RUN FH1 CEMENT RETAINER W/ 2.75" NO-GO RING. TAG NIPPLE AT 9623' CTMD, CORRECT DEPTH TO 9628' RKB, SET RETAINER AT 9620' RKB. MIX AND PUMP 34.5 BBL OF 15.8 CLASS G CEMENT BELOW RETAINER. RUN 42 BO SHIFTING TOOL, ENGAGED CMU AT 8907' CTMD PAINT FLAG, ATTEMPT TO OPEN, TOOL SHEARED. RIH W/ SECOND 42 BO SHIFTING TOOL AND SHIFTED SLEEVE PERFORMED INJECTIVITY TEST POOH RIH W / UPPER RETAINER 5/9/2023 SUPPORT OTHER OPERATIONS RIH W / UPPER RETAINER TIE INTO FLAG CORRECT + 4' PUH SET RETAINER AT 8515' PUMPED 52 BBLS OF CEMENT 50 BELOW RETAINER & 2 ON TOP DRESS OFF TOP OF CEMENT TO 8285'. FREEZE PROTECT WELL WITH 25 BBL S.DIESEL. RDMO, JOB COMPLETE. 5/16/2023 SUPPORT OTHER OPERATIONS PRE-STATE WITNESS TAG & MITT. TAG TOC @ 8274' W/ SAMPLE BAILER. MITT TO 1500 PSI (PASS). READY FOR STATE WITNESS TAG & TEST. 5/17/2023 SUPPORT OTHER OPERATIONS STATE WITNESS (GUY COOK) TAG @ 8274' SLM. PERFORMED PASSING MIT-T TO 1900 PSI, PULLED GLV @ 5672' RKB. ATTEMPTED TO PULL DV @ 8083' RKB (SHEARED PULLING TOOL). IN PROGRESS. 3S-19 Suspend Summary of Operations MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 18 Township: 12N Range: 8E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 10040 ft MD Lease No.: ADL0380107 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3580 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 10029 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3.5" O.D. Tail@ 9584 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Perforation Retainer 8515 ft 8274 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1925 1890 1875 IA 1370 1370 1370 OA 425 420 420 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Halliburton Slickline was used for the cement tag. They tagged at 8274 ft MD with a 2-1/8 inch toolstring with a 2-1/4 inch drive down bailer. The sample contained no cement, only diesel. The second tag following the MIT-T was at 8274 ft MD as well. A Little Red Services pump truck and calibrated gauges were used to test. 0.42 bbls were pumped and 0.49 bbls returned. May 17, 2023 Guy Cook Well Bore Plug & Abandonment KRU 3S-19 ConocoPhillips Alaska Inc. PTD 2030960; Sundry 323-244 none Test Data: P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2023-0517_Plug_Verification_KRU_S-19_gc 9 9 9 99 9 99 9 9 9 9 9 9 9 9 9 gyg The sample contained no cement, only diesel. James B. Regg Digitally signed by James B. Regg Date: 2023.11.06 15:09:09 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10040'None Casing Collapse Structural Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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 and Digital Signature with Date: AOGCC USE ONLY James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-1102 CTD Engineer Tubing Grade: Tubing MD (ft): Packer: 8564' MD/5123' TVD Packer: 9604' MD/5811' TVD SSSV: None Perforation Depth TVD (ft): Tubing Size: L-80 9584' 6/25/2023 Packer: Baker Premier Packer: Baker SAB-3 permanent packer SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544, ADL0380107 203-096 P.O. Box 100360, Anchorage, AK 99510 50-103-20460-00-00 ConocoPhillips Alaska, Inc. KRU 3S-19 None/SuspendedKuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6189' 9805' 5983' 1638 None MD 108' 2596' 108' 3580' 6179'10029' 16" 9-5/8" 78' 3550' Perforation Depth MD (ft): 8680-8700', 9700-9720' 10002' 5188-5199', 5893-5910' 3-1/2" 7" Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-261 By Kayla Junke at 1:23 pm, May 01, 2023 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2023.05.01 10:35:02-08'00' Foxit PDF Editor Version: 12.0.1 James J. Ohlinger X X MDG 5/24/2023 DSR-5/2/23 10-407 VTL 6/12/2023 BOP test to 2500 psig Annular preventer test to 2500 psig GCW 06/12/2023 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.12 16:08:07 -08'00' RBDMS JSB 051423 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 27, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J Ohlinger Staff Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3S-19 (PTD# 203-096). Well 3S-19 was drilled and completed as a Kuparuk Producer in July 2003. The well has been slated to be P&A'd for development of the Coyote formation. If you have any questions or require any further information, please contact me at +1-907-229-3338. After a traditional Kuparuk P&A (that will have a different sundry), the tubing will be cut above tubing cement retainer/top of cement. Then a rig will come and pull the 3.5" tubing and stack two 7-1/16" valves on the wellhead. This will give eline and coiled tubing access to the 7" casing. The OA cement and final P&A deatils of the well will be submitted in a separate sundry. This sundry is just for the rig portion of the work that requires pulling the 3.5" tubing. 3S-19 RWO Procedure Kuparuk Producer Suspend PTD #203-096 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Cut the tubing above tagged top of cement. 3. Prepare well for rig 48-72 hours before rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3S-19. (No BPV will be install pre-rig due to internal risk assessment for N7ES for MIRU/RDMO without a BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut. a. On POOH with tubing, circulate well over to diesel freeze protect as necessary. 6. Perform 30 minute NFT. ND BOP, NU Tree 7. ND BOPE. NU two 7-1/16” tree valves and any adapter spool. 8. RDMO. Post-Rig Work - Post-rig scope will be submitted as a separate sundry for OA cement job and final P&A. 3S-19 RWO Procedure Kuparuk Producer Suspend PTD #203-096 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen V Production Engineer: Brian Lewis Reservoir Development Engineer: Lynn Aleshire Estimated Start Date: 06/25/2023 Workover Engineer: James Ohlinger (265-11102 James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in the lower Kuparuk is P&A’d Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre-rig cut. Stack two 7-1/16” valves for Eline and coil unit OA cement operations post-rig. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T N/A, none recent. (Well will be P&A’d and tubing will cut for RWO.) MIT N/A, none recent. IA will be tested in pre-rig. MIT-OA none recent. IC POT &PPPOT N/A, to be tested in pre-rig. TBG POT &PPPOT N/A, to be tested in pre-rig. MPSP: 1638 psi using 0.1 psi/ft gradient Static BHP: 2153 psi / 5154’ TVD measured on 7/26/2019. Rig work should be done over P&A’d well and not exposed to formation pressure during Rig portion of work. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 9,805.0 10/1/2017 3S-19 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull SPG Set DV 8/7/2019 3S-19 jhansen8 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELD Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 29.5 Set Depth (ftKB) 3,579.6 Set Depth (TVD) … 2,596.0 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.5 Set Depth (ftKB) 10,028.6 Set Depth (TVD) … 6,178.7 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 24.2 Set Depth (ft… 9,584.0 Set Depth (TVD) (… 5,793.8 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 24.2 24.2 0.00 HANGER FMC GEN V TUBING HANGER 3.500 504.4 503.7 6.41 NIPPLE CAMCO DS NIPPLE w/2.875" PROFILE 2.875 8,534.4 5,107.1 56.45 SEAL ASSY BAKER LOCATOR ASSEMBLY w/6' SPACE OUT 3.000 8,541.4 5,110.9 56.42 PBR BAKER 80-40 PBR 4.000 8,563.9 5,123.4 56.31 PACKER BAKER PREMIER PACKER 2.990 8,674.1 5,184.8 56.01 BLAST RING 3 1/2" ,9.3#, L-80, IBTM Tubing w/ 30-ft of 4.09" OD carbide blast rings 2.992 8,720.8 5,211.0 55.82 Sliding Sleeve - Closed BAKER CMU SLIDING SLEEVE w/ 2.813" "BX" Profile (CLOSED 02-22-18) 2.810 9,581.0 5,791.3 32.77 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY w/3' SPACEOUT 3.000 Tubing Description TUBING Original String Ma… 5 31/32 ID (in) 4.00 Top (ftKB) 9,584.0 Set Depth (ft… 9,636.2 Set Depth (TVD) (… 5,838.2 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,584.0 5,793.9 32.67 PBR Baker 3 1/2" 80-40 PBR 4.000 9,603.4 5,810.2 32.00 NIPPLE KBH-22 Anchor Tubing Seal Nipple 3.000 9,604.3 5,811.0 31.97 PACKER Baker 3 1/2" X 7" SAB-3 permanent packer 5.96" OD x 3.25" ID 3.250 9,609.2 5,815.2 31.80 MILLOUT 4 1/2" collar 3.720 9,615.3 5,820.3 31.60 XO - Reducing Crossover 4 1/2" X 3 1/2" EUE 8rd 3.500 9,628.3 5,831.5 31.21 NIPPLE Camco 2.75" "D" Nipple 2.750 9,635.3 5,837.4 31.17 WLEG 3 1/2" WLEG w/ shearout sub 4.51" OD (bottom at 9647.23-ft) 2.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,680.0 8,700.0 5,188.1 5,199.3 Moraine, 3S-19 12/24/2012 6.0 APERF 3 3/8" Millenium, 6 spf, 60° phasing, HMX scallop 9,700.0 9,720.0 5,892.9 5,910.1 C-4, 3S-19 7/11/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Frac Summary Start Date 1/26/2013 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 1/26/2013 Top Depth (ftKB) 8,680.0 Btm (ftKB) 8,700.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,408.7 2,509.1 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/3/2013 2 5,672.2 3,653.5 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 2,012.0 7/27/2013 3 7,169.8 4,400.7 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/3/2013 4 8,083.4 4,865.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/2/2013 5 8,481.0 5,077.6 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 4/12/2014 6 8,618.7 5,153.9 Camco MMG 1 1/2 PROD DMY RK 0.000 0.0 8/7/2019 7 9,525.3 5,745.0 Camco MMG 1 1/2 PROD DMY RK 0.000 0.0 12/26/2012 Notes: General & Safety End Date Annotation 4/27/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Comment SSSV: NIPPLE 3S-19, 8/8/2019 5:05:11 AM Vertical schematic (actual) PRODUCTION; 26.5-10,028.6 IPERF; 9,700.0-9,720.0 WLEG; 9,635.3 NIPPLE; 9,628.3 MILLOUT; 9,609.2 PACKER; 9,604.3 NIPPLE; 9,603.4 PBR; 9,584.0 SEAL ASSY; 9,581.0 PRODUCTION; 9,525.3 APERF; 8,680.0-8,700.0 FRAC; 8,680.0 PRODUCTION; 8,618.7 PACKER; 8,563.9 PBR; 8,541.4 SEAL ASSY; 8,534.4 GAS LIFT; 8,481.0 GAS LIFT; 8,083.4 GAS LIFT; 7,169.8 GAS LIFT; 5,672.2 SURFACE; 29.5-3,579.6 GAS LIFT; 3,408.7 NIPPLE; 504.4 CONDUCTOR; 30.0-108.0 HANGER; 24.2 KUP PROD KB-Grd (ft) 33.03 Rig Release Date 7/4/2003 Annotation Last WO: End Date 12/29/2012 3S-19 H2S (ppm) 60 Date 9/4/2015... TD Act Btm (ftKB) 10,040.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032046000 Wellbore Status PROD Max Angle & MD Incl (°) 61.56 MD (ftKB) 2,630.84 WELLNAME WELLBORE3S-19 3S-19 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Conductor 108 108 16" 15.06" 62.5 H-40 Surface 3580 2596 9-5/8" 8.83" 40 L-80 Production 10029 6179 7" 6.28" 26 L-80 Liner 9636 5838 3-1/2" 2.992" 9.3 L-80 Tubing 9584 5794 3-1/2" 2.992" 9.3 L-80 COMPLETION 3-1/2" completion to be removed based on associated sundry to be submitted seperately Install qty. 2: 7-1/16" Gate Valves Baker 3-1/2" 80-40 PBR 8541' RKB (4" ID) Baker Premier Packer @ 8564' RKB (2.99" ID) 3-1/2" Camco MMG gas lift mandrels @ 8619' RKB Blast Rings @ 8674' RKB (30.93' jt) Baker CMU Sliding Sleeve @ 8721' RKB (2.813" ID) 3-1/2" Camco MMG gas lift mandrels @ 9525' RKB Original Completion Baker 80-40 PBR @ 9584' RKB KBH-22 Anchor Tubing Seal nipple @ 9603' RKB (3.00" ID) Baker SAB-3 Permanent Packer @ 9604' RKB (3.25" ID) 4-1/2" MOE @ 9609' RKB (3.72" ID) 3-1/2" Camco D-nipple @ 9628' RKB (2.750" ID) 3-1/2" WLEG @ 9635' RKB Surface Casing Production/Intermediate Casing Conductor C-sand perfs 9700' - 9720' RKB Moraine Perfs 8680'-8700' RKB Tubing Cut ~8514' RKB Qty. 2: 7-1/6" Gate Valves ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10040'None Casing Collapse Structural Conductor Surface Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8680-8700', 9700-9720' 10002' 5188-5199', 5893-5910' 3-1/2" 7" 16" 9-5/8" 78' 3550' Perforation Depth MD (ft): MD 108' 2596' 108' 3580' 6179'10029' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6189' 9805' 5983' 1638 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544, ADL0380107 203-096 P.O. Box 100360, Anchorage, AK 99510 50-103-20460-00-00 ConocoPhillips Alaska, Inc. KRU 3S-19 None/SuspendedKuparuk River Oil Pool Kuparuk River Field N/A Tubing Grade: Tubing MD (ft): Packer: 8564' MD/5123' TVD Packer: 9604' MD/5811' TVD SSSV: None Perforation Depth TVD (ft): Tubing Size: L-80 9584' 5/1/2023 Packer: Baker Premier Packer: Baker SAB-3 permanent packer SSSV: None 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 and Digital Signature with Date: AOGCC USE ONLY Jill Simek jill.simek@conocophillips.com (907) 263-4131 Staff Well Intervention Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-244 By Kayla Junke at 9:08 am, Apr 21, 2023 Digitally signed by Will Earhart DN: OU=Engineering Supv, O=Well Integrity and Intervention, CN=Will Earhart, E=william.c.earhart@conocophillips.comReason: I have reviewed this documentLocation: Date: 2023.04.21 07:38:25-08'00' Foxit PDF Editor Version: 12.0.1 Will Earhart 10-407 DSR-4/24/23VTL 4/26/2023 X Suspension approved through 12/31/2023. P&A, including surface abandonment must be completed by 12/31/2023 X SFD 4/24/2023JLC 4/26/2023 4/26/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.26 11:53:25 -08'00' RBDMS JSB 042723 JS Date: April 19, 2023 Subject: 3S-19 Suspend Procedure Network Number: 10450479 Prepared By: Jill Simek Telephone: 907 980-7503 Approved By: Will Earhart Telephone: 540 448-1789 Procedure Justification: Producer 3S-19 (PTD: 203-096) was drilled and completed in the Kuparuk C4 in 2003. It was recompleted with a selective completion to also assess the Moraine in 2012. The well has been shut-in since December 2022 and has since been identified as a P&A candidate, to allow for slot recovery and slot optimization for Coyote Development. 3S-19 will require rig-assisted P&A operations which are currently being developed. Due to 2023 rig schedule constraints and upcoming planned 3S Pad Sim-Ops, ConocoPhillips plans to perform rigless suspension operations on 3S-19 immediately, with P&A operations to follow later in the year. Suspension operations will reduce the work scope and timeline for future P&A operations, thus limiting Sim-Ops during the high pad activity planned later this year. The well is completed with 3 ½” tubing run to 9,635ft KB. The upper production packer is set at 8,563ft KB and the lower packer of the selective completion at 9,604ft KB. Surface casing is 9-5/8”, and production casing is 7”. Perforations are from 8,680ft to 8,700ft KB and 9,700ft to 9,720ft KB. Per this procedure, suspend operations will be performed by pumping 2 squeezes to isolate the Kuparuk and Moraine. A total of 80 bbls of 15.8 ppg Class “G” cement througha cement retainers at approximately 9,620ft KB and 8,515ft KB to treat both the Kup C and Moraine, respectfully. A tag and pressure test will confirm integrity post-job of the combined plug. Well Status/History: x The well is currently shut-in. x Last MITs: MIT-T passed to 3,500psi on 1/10/2013; MIT-IA passed to 3,500psi on 1/10/2013; MIT-OA failed 7/8/2006 (LLR = 1.75bpm at 1600psi due to open shoe) x SBHP = 3,285psi @ 6,200ft SS. (7/6/2015) x Min ID = 2.75” @ 9,628ft KB (Camco D Nipple w/ 2.75” No-Go) x Last Drift/Tag: Drift clean to 9,635ft KB (8/7/2019) JS Procedure: Slickline/Little Red Services: Objective: Drift for cement retainer, perform injectivity test to confirm adequate rates for cementing operations 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and PT Equipment as required. 3. RIH with dummy cement retainer tool string to Camco D-nipple at 9,628ft KB. 4. Rig up LRS. With ~20 bbls diesel pumping down tubing, perform step rate injectivity test from 0.5 – 3 bpm, in ½ bpm increments, up to a maximum pressure of 3,000 psi, to ensure adequate rates for cementing operations. Record Results. DISCUSS RESULTS WITH WELL INTERVENTIONS ENGINEER 5. Establish/confirm OA LLR for cement downsqueeze (previous LLR = 1.75bpm at 1600psi, performed 7/8/2006) 6. RDMO. Coiled Tubing / Cementing: Objective: Place cement across the perforations and squeeze some cement into perforations. Plug #1: Kuparuk Isolation Cement Volume Calculations (TOC approximately 9,620ft KB in tubing): x 7” production csg, 100ft below perfs to tubing tail: (0.03826 bbl/ft) * (9,820ft – 9,365) = 17.4 bbls x 3 ½” tubing, tubing tail to TOC: (0.008696 bbl/ft) * (9,635ft – 9,620ft) = 0.2bbl bbls x Squeeze volume = 12.4 bbls x Total volume = 17.4 + 0.2 + 12.4 = 30 bbls Plug #2: Moraine Isolation Cement Volume Calculations (TOC approximately 8,285ft KB in tubing): x 3 ½” tubing, tubing tail to TOC: (0.008696 bbl/ft) * (9,620ft – 8,285ft) = 11.6 bbls x Selective annulus: (0.02956 bbl/t) * (9,604ft – 8,563ft) = 30.7 bbls x Squeeze volume = 7.7 bbls x Total volume = 11.6 + 30.7 + 7.7 = 50 bbls Plug #1 Top Moraine: ~8,648' MD SFD 4/24/2023 Top Kup C: ~9,700' MD SFD 4/24/2023 JS 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Cementers a week before the scheduled Suspend date, to allow adequate time for pilot testing of the P&A cement design. The job is designed for a total of 80 bbls of 15.8# Class “G” cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 8/8/2019 schematic and tubing details for depth correlation. Use Camco D-nipple at 9,628ft KB for correlation. 6. RIH with cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 9,620ft KB (middle of pup joint, above D- nipple), or as deep as the retainer will safely drift. 8. Close in the CT x tubing annulus, and line up to pump down the coil tubing. 9. Pump 20 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 10. Pump 10 bbls freshwater spacer 11. Pump 30 bbls of 15.8 ppg Class “G” Cement through the cement retainer. If squeeze pressure is seen before pumping total cement volume, stop pumping and begin next step. 12. Shut down, un-sting from retainer 13. POOH above TOC. Circulate CTU clean. 14. Wash up surface equipment. Plug #2 1. RIH and shift open CMU sliding sleeve at 8,720ft KB to access the Moraine selective. 2. RIH with cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 3. Set cement retainer at approximately 8,515ft KB (middle of full joint, above seal assembly), or as deep as the retainer will safely drift. 4. Close in the CT x tubing annulus, and line up to pump down the coil tubing. 5. Pump 20 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 6. Pump 10 bbls freshwater spacer 7. Pump 48 bbls (50 bbl job volume) of 15.8 ppg Class “G” Cement through the cement retainer. If squeeze pressure is seen before pumping total cement volume, stop pumping and begin next step. 8. Shut down, un-sting from retainer 9. Lay in remaining 2.0 bbls cement above retainer (equates to ~ 230’ of cement above the retainer, leaving TOC ~8,285ft KB) 10. POOH above TOC. Circulate CTU clean. 11. Wash up surface equipment. RDMO. Slickline / Little Red Objective: State witnessed tag of TOC, MIT-T, CMIT-TxIA, DDT-T JS 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 8,285ft KB. Record Results. TAG MUST BE AOGCC WITNESSED Note: Job will be deemed successful for as long as cement is tagged above retainer. 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-T to 1,500 psi. Record results. PRESSURE TEST MUST BE AOGCC WITNESSED 7. Perform CMIT-TxIA to 1,500 psi. Record results. 8. Perform DDT-T. Record results. 9. Report issues and results to Well Interventions Engineer. 10. RDMO JS Schematic: JS Suspend Diagram: Current Completion Proposed Suspend 3S-19 Suspend PTD #: 203-096 16” 62.5# H-40 Conductor @ 108' KB WCE 4-20-2023 7" 26# L-80 Production Casing @ 10,028' KB 3-½” 9.3# L-80 Tubing @ 9,635' KB Cement Plug (Perforations, Casing, & Tubing) ~8,285' – 9,820' KB 15.8 ppg Class “G” 9 5/8" 40# L-80 Surface Casing @ 3,579' KB Kup C Perfs: 9,700' –9,720' KB Plug #2: Cement Retainer at ~8,515' KB Logged Top of Cement (7" x Open Hole) = 8,400' KB Kuparuk HRZ/Kalubik Shales Moraine 8,648' –9,006' KB Coyote 6,520' – 7,325' KB Packer depth = 9,604' KB Moraine Perfs: 8,680' – 8,700' KB Torok basinal shales Packer depth = 8,563' KB Plug #1:Cement Retainer at ~9,620' KB • 111111 Ur N O LL L ,g 'Lr WVI 'r C O x ro P ? c��Z v O a) N 3 _ s hV F Y al) �'' ID ° a O as w -O r O %- •g- ' a- e- r n- N Ca 0 0 (3) L 0 a` a c c - O a) c > t ro 4_, co 'c i_, a va rI- o a Q Q -J ❑ r U a D ❑ Q Fs nCO LLI(0 r N N N ti e- O UNY a s '7 r 7 ' E 0 N n OOOOO c u a) l, h c) o . . o. . o p 9 +� LII Z Q N CO U -O r0 p N Ce O ra U ' O F- 73 O ❑ ❑ ❑ ❑ ❑ ❑ c v N v U W J J J J J J J OD c 4 ❑ O y W W W W W W W ,) N C. 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M M � VI O O 0 COD a 6 Q F- a a F SOF T4 • w\����yy�s� THE STATE Alaska Oil and Gas 7 ofA A , ^® Conservation Commission StF __ 333 West Seventh Avenue "> ` Anchorage, Alaska 99501-3572 �� GOVERNOR BILL WALKER g OFtr,}" Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Roger Mouser SCANNED AUG 0 1 R017, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-19 Permit to Drill Number: 203-096 Sundry Number: 317-333 Dear Mr. Mouser: 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 Commissioner DATED this day of July, 2017. RBDMS i JUL 2 7 2017 • 0 RECEIVED . JUL 202 17 STATE OF ALASKA OTS 7/2 / qz ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon LI Plug Perforations U Fracture Stimulate H Repair Well ❑ Operations shutdown H Suspend H Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well H Alter Casing ❑ Other: Conductor extensior0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 1 , 203-096 3.Address: Stratigraphic H Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 501032046000 • 7.If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- Will planned perforations require a spacing exception? Yes IllNo L! KRU 3S-19 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025544/ADL0380107 Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effectiv ,[ t p: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,028' 6,179' 0 6,' .517712h2514 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 108' 108' Surface 3,550' 9.625" 3,580' 2,596' Intermediate Production 10,002' 7" 10,029' 6,179' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,680-9,720 , 5,188'-5,910' 3.500" L-80 9,635' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): No SSSV(Camco"DS"Nipple w/2.875") MD=504',TVD=504' 1 PACKER-BAKER PREMIER PACKER MD=8564'TVD=5123' , 12.Attachments: Proposal Summary 0 Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development • Service ❑ 14.Estimated Date for 9/15/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑� ` WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown H Abandoned H 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: Roger Mouser Contact Name: Roger Mouser/Roger Winter Authorized Title: Well Integrity Field Supervisor Contact Email: N1927@COP.com Contact Phone: (907)659-7506 �f Authorized Signature: ' �jinerle,e,e01 Date:07/19/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317- 33 Plug Integrity H BOP Test ❑ Mechanical Integrity Test H Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Er RBDMS LL--JUL 1 7 2017 Spacing Exception Required? Yes ❑ No 2( Subsequent Form Required: !Q•of P+ P^ APPROVED BY Approved by: w• ) COMMISSIONER THE COMMISSION Date:? ,_/ ?M �/� /,7- % `lam q12 /177-- Form 7 oR -� Submit Form and Form 10-403 Revised 4/2017 O 1 tion is valid for 12 months from the date of approval. Attachments in Duplicate • • '✓ RECEIVED ConocoPhillips JUL 2 0 2017 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 July 19, 2017 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3S-19, PTD 203-096 conductor extension. Please contact Roger Mouser or Roger Winter at 659-7506 if you have any questions. Sincerely, 411 Roger Mouser/Roger Winter ConocoPhillips Well Integrity Field Supervisor • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska, Inc. Kuparuk Well 3S-19 (PTD 203-096) SUNDRY NOTICE 10-403 APPROVAL REQUEST July 19, 2017 This application for Sundry approval for Kuparuk well 3S-19 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 15". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Field Supervisor s KUP PROD • 3S-19 ConocoPhillips ° Well Attributes Max Angle&MD TD AldiKa,Inc Wellbore API/UWI Field Name Wellbore Status Incl(°) MO(ftKB) Act She(Eke) r_ etlpg 501032046000 KUPARUK RIVER UNIT PROD 61.56 2,630.84 10,040.0 -•- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 3S-19.3G/2017 3:45:17 PM SSSV:NIPPLE 60 9/4/2015 Last WO: 12/29/2012 33.03 7/4/2003 Vertical schematic(ac Wap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,797.0 2/23/2017 Rev Reason:TAG pproven 3/3/2017 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER;24.2- ap'Pt CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELD Ia Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 29.5 3,579.6 2,596.0 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 26.5 10,028.6 6,178.7 26.00 L-80 BTCM Tubing Strings W p No JYW Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection jsM ,TUBING WO 31/2 2.992 24.2 9,584.0 5,793.8 9.30 L-80 EUE Completion Details Nominal ID CONDUCTOR;30.0-108.0-4 '' Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) - 24.2 24.2 0.00 HANGER FMC GEN V TUBING HANGER 3.500 NIPPLE;504.4 504.4 503.7 6.41 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 8,534.4 5,107.1 56.45 SEAL ASSY BAKER LOCATOR ASSEMBLY w/6'SPACE OUT 3.000 8,541.4 5,110.9 56.42 PBR BAKER 80-40 PBR 4.000 8,563.9 5,123.4 56.31 PACKER BAKER PREMIER PACKER 2.990 GAS LIFT;3,408.7 III 6,674.1 5,184.8 56.01 BLAST RING 3 1/2",9.3#,L-80,IBTM Tubing w/30-ft of 4.09"OD 2.992 carbide blast rings 8,720.8 5,211.0 55.82 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.813""BX"Profile 2.813 I 7 (CLOSED12/28/14) 9,581.0 5,791.3 32.77 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY w/3'SPACEOUT 3.000 SURFACE;29.5-3,579.6-•Ail l Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING Original 5.968 4.000 9,584.0 9,636.2 5,838.2 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT5,672.2 '7 9,584.0 5,793.9 32.67 PBR Baker 31/2"80-40 PBR 4.000 � 9,603.4 5,810.2 32.00 NIPPLE KBH-22 Anchor Tubing Seal Nipple 3.000 9,604.3 5,811.0 31.97 PACKER Baker 3 1/2"X 7"SAB-3 permanent packer 5.96"OD x 3.250 3.25"ID • GAS LIFT:7,169139,609.2' 5,815.2 31.80 MILLOUT 4 1/2"collar 3.720 - 9,615.3 5,820.3 31.60 XO-Reducing Crossover4 1/2"X 3 1/2"EUE 8rd 3.500 GAS LIFT;8,063.4 C 9,628.3 5,831.5 31.21 NIPPLE Camco 2.75""D"Nipple 2.750 C 9,635.3 5,837.4 31.17 WLEG 3 1/2"WLEG w/shearout sub 4.51"OD(bottom at 2.950 9647.23-ft) Perforations&Slots GAS LIFT;8,481.0 4 Shot Den Top(TVD) atm(TVD) (shots/f Top(ftKB) _ Oboe(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,680.0 8,700.0 5,188.1 5,199.3 Moraine,3S- '12/24/2012 6.0 APERF 3 3/8"Millenium,6 spf, SEAL ASSY;8,534.4 19 60°phasing,HMX scallop PBR;8,541.4 - - PACKER;8,563.9 9,700.0 9,720.0 5,892.9 5,910.1 C-4,30-19 7/11/2003 6.0 (PERF 2.5"HSD 2506 PJ,60 deg ph Stimulations&Treatments PRODUCTION;8,618.7 Proppant Designed(Ib) Proppant In Formation(Ib) Date 1/26/2013 Stimulations&Treatments Min Top Max Btm Top(TVD) atm(TVD) Vol Clean Vol Slurry Depth(ftKB) Depth(ftKB) (ftKB) (ftKB) Stg 0 Date Stim/Treat Fluid Pump(bbl) (bbl) 8,680.0 8,700.0 5,188.1 5,199.3 1 1/26/2013 APERF;8,680.0-8,700.0 FRAC;e,000.0�_ J Mandrel Inserts Sl ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com SLEEVE-C;8,720.8 1 3,408.7 2,509.1 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 6/3/2013 2 5,672.2 3,653.5 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 2,012.0 7/27/2013 3 7,169.8 4400.7 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 6/3/2013 _ 4 8,083.4 4,865.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/2/2013 PRODUCTION;9,525.3 . 5 8,481.0 5,077.6 Camco MMG 11/2 GAS LIFT OV RK 0.250 0.0 4/12/2014 6 8,618.7 5,153.9 Camco MMG 11/2 PROD DMY RK 0.000 0.0 1/2/2017 7 9,525.3 5,745.0 Camco MMG 11/2 PROD DMY RK 0.000 0.0 12/26/2012 SEAL ASSY;9,581.0 Notes:General&Safety PBR:9,584.0 S 5 End Date Annotation NIPPLE;9,603.4 - 4/27/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PACKER;9,604.3 MILLOUT;9,6092 ra a NIPPLE;9,628.3 M. V WLEG;9,635.3ir - IPERF;9,700.0-9,720.0- PRODUCTION;26.5-10,028.6 • • ! Bettis, Patricia K (DOA) From: NSK Well Integrity Field Supv <N1927@conocophillips.com> Sent: Thursday, July 20, 2017 3:13 PM To: Bettis, Patricia K(DOA) Cc: NSK Well Integrity Supv CPF1 and 2; NSK Well Integrity Supv CPF3 and WNS Subject: RE: [EXTERNAL] KRU 3S-19 (PTD 203-096): Sundry Application Good afternoon Patricia, The TD was drilled to 10,038' MD on 6/30/2003. The 7" production casing was ran to 10,028'on 7/2/2003. The current Effective depth for 3S-19 PTD 203-096 as of 2/23/2017 was: MD=9,797" and TVD=5,977'. Respectfully, Roger Mouser/Roger Winter CPAI WI Field supervisor Office (907) 659-7506 Cell (907) 943-1055 N1927@ COP.com From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,July 20, 2017 10:44 AM To: NSK Well Integrity Field Supv<N1927@conocophillips.com> Subject: [EXTERNAL] KRU 3S-19 (PTD 203-096): Sundry Application Good morning Roger, On Form 10-403, Box 11,the effective depth of the well is listed as 10,028' MD (6,179'TVD). However, on Form 10-407 received January 29, 2013 and Form 10-404 dated July 23, 2015,the effective depth of KRU 3S-19 is listed as 9,862' MD (6,033'TVD). Please verify the current effective depth of the well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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 1 • S Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Thursday, July 20, 2017 10:44 AM To: NSK Well Integrity Field Supv Subject: KRU 3S-19 (PTD 203-096): Sundry Application Good morning Roger, On Form 10-403, Box 11,the effective depth of the well is listed as 10,028' MD (6,179'TVD). However,on Form 10-407 received January 29, 2013 and Form 10-404 dated July 23, 2015,the effective depth of KRU 3S-19 is listed as 9,862' MD (6,033'TVD). Please verify the current effective depth of the well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 v wI`¢ .n 0 C 3 w v ,- 0 c•s4 ^(J`` ( I CO �n Y co O c N F Y o ry .-,U v7 O Y N O - Ifa c n ui, = -o o O a) a) Q O r n r N r` N. 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UO u 0 0 0 0 0 0 O O O O O r+ ~ C O co ro N N N N N9 O O )f) N N O v C O O CD w14 1251 I- 01 U v - a G w Y w E E (13 ro T0 Y Z m Q O V M O� 0 N N O ... E G) a) a) 0 = WC d QO J N N M N zO O w N C (O O COD nl. 3 Q FR a s H - STATE OF ALASKA AL1111 OIL AND GAS CONSERVATION COM.SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate rAlter Casing r Change Approved Program r Rug for Redrill r' Perforate New Pool r` Repair Well Re-enter Susp Well Other: Moraine Isolated I- 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory Fr. 203-096 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20460-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL380107;ADL025544 KRU 3S-19 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10038 feet Plugs(measured) None true vertical 6187 feet Junk(measured) None Effective Depth measured 9862 feet Packer(measured) 8564, 9604 true vertical 6033 feet (true vertical) 5123, 5811 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108 108 SURFACE 3550 9.625 3580 2596 PRODUCTION 10002 7 10029 6179 IUL 2 4 2015 Perforation depth: Measured depth: 9700-9720 SC��A E CL:C' A i..� True Vertical Depth: 5893-5910 Tubing(size,grade,MD,and TVD) 3.5, L-80, 9636 MD, 5838 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 8564 MD and 5123 TVD PACKER-BAKER 3 1/2"X 7"SAB-3 PERMANENT PACKER 5.96"OD X 3.25"ID©9604 MD and 5811 TVD SSSV-CAMCO DS NIPPLE w/2.875"PROFILE @ 504 MD and 504 TVD 12.Stimulation or cement squeeze summary: 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 Subsequent to operation 162 22 484 1000 175 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r 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.O.Exempt: 312-475 Contact Bob Christensen/Darrell Humphrey Email n1139conocophillips.com Printed Name Robert D. Christensen Title NSK Production Engineering Specialist Signature W0/64_44Phone:659-7535 Date VTL- /0/21/ 1 - �UL24 2015 Form 10-404 Revised 5/2015 f��.. 0.3(/‘ TPA' riginal my • • RECEIVED Robert Christensen/Darrell Humphrey NSK Production Engineering Specialists NPV Greater Kuparuk Unit,NSK-69 )U L. 2 201',J PO Box 196105 ConocoPh illi PS AQ G CCAnchoage,AK Phone:age,6 9-7535 6105 Fax:659-7314 July 23, 2015 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Subject: 3S-19 return to KRU Oil Pool production(Post Moraine Flow test) ConocoPhillips Alaska, Inc. has completed flow testing of the 3S-19 Moraine well (Torok Oil Pool). The Moraine formation has been isolated indefinitely. Well 3S-19 was returned to Kuparuk River Oil Pool production on July 8th, 2015. Enclosed you will find 10-404 Sundry Report for ConocoPhillips Alaska, Inc. regarding KRU Well 3S-19 (PTD#203-0960). If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659-7535. Sincerely, Robert D Christensen Attachments Sundry Report Well schematic • • 3S-19 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/28/14 TAGGED @ 8739' SLM. CLOSED CMU @ 8721' RKB. MIT TBG 2500 PSI, PASSED. READY FOR CTU. 04/01/15 PERFORMED FCO TO 9558' CTMD USING DIESEL AND DIESEL GEL SWEEPS. MAINTAINED 1:1 RETURNS. LIGHT SOLIDS/MUD IN RETURNS. WELL FREEZE PROTECTED. JOB COMPLETE. 04/05/15 TAGGED FILL @ 9543' SLM (EST. 35'ABOVE CATCHER). OBTAINED SAMPLE OF DRILLING MUD. IN PROGRESS 04/06/15 BAIL DRILLING MUD FROM CATCHER @ 9553' SLM; ENCOUNTER OBSTRUCTION @ 8683' SLM. JOB SUSPENDED DUE TO WEATHER. IN PROGRESS 04/09/15 MADE 2.5" DD BAILER RUNS BEGINNING @ 6754' SLM & ENDDING @ 4607' SLM, RETURNS OF MUD. COMPLETE 04/20/15 PULLED CATCHER SUB @ 9554' CTMD, NO APPARENT FILL ON IT. PUMP BOTTOMS UP FROM A-2 @ 9628' RKB WITH DIESEL & DIESEL GEL LATCHED A-2 PRONG @ 9628' RKB, TBG PRESSURE DROPPED FROM 1300 PSI TO 800 PSI BUT CAME OUT OF THE HOLE WITHOUT A-2 PRONG. TURN OVER TO SLICKLINE TO FISH, WELL FREEZE PROTECTED WITH DIESEL. 04/23/15 BAILED MUD & FRAC SAND FROM 9578'TO 9584' SLM. CA-2 PLUG @ 9628' RKB. ENCOUNTERED TBG RESTRICTION @ 8687' SLM WITH 10'x 2.5" DRIFT. IN PROGRESS. 06/28/15 PERFORM FILL CLEANOUT FROM 9046' CTMD TO CA-2 PLUG AT 9630' CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS AT 2 BPM WHILE MAINTAINING 1:1 RETURNS THOUGHOUT CLEANOUT. LIGHT SAND CONCENTRATIONS OBSERVED WITH GEL SWEEPS. EST. TOTAL SOLIDS VOLUME AT 1 BBL, F/P TBG TO 9630', READY FOR S/L, JOB COMPLETE. 07/06/15 BAILED FRAC SAND & PULLED CA-2 PLUG @ 9628' RKB; MEASURED SBHP @ 9711' RKB (2552 PSI). JOB COMPLETE 07/08/15 Open Well - Return to Kuparuk River Oil Pool Production • ii KUP PROD • 3S-19 voy r ConocoPhillips a Well Attributes Max Angle&MD TD Alaska Inc, Wellbore API/UWI Field Name Wellbore Status Incl I) MD(ftKB) Act Btm(ftKB) c„,_,A Tg, 501032046000 KUPARUK RIVER UNIT PROD 61.56 2,630.84 10,040.0 "°. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 35-19,7m20151;13;41 PM SSSV:NIPPLE 100 10/22/2014 Last WO: 12/29/2012 33.03 7/4/2003 Vedical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,543.0 4/5/2015 Rev Reason'TAG,PULL CATCHER 8 PLUG hipshkf 7/7/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth IftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread , e �E■- CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H-40 WELD HANGERzaz- ■ 9 ! Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread i t-,---- 6 SURFACE 95/8 8.835 29.5 3,579.6 2,596.0 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 26.5 10,028.6 6,178.7 26.00 L-80 BTCM Tubing Strings Tubing Description Stnng Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection „, „11 „,/11.11„ 1111 ago,TUBING WO 3 1/2 2.992 24.2 9,584.0 5,793.8 9.30 L-80 EUE �i FP s Completion Details aNominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR;30.0-106.0 242 24.2 0.00 HANGER FMC GEN V TUBING HANGER 3.500 f 1 504.4 503.7 6.41 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 NIPPLE;504.4 " 8,534.4 5,107.1 56.45 SEAL ASSY BAKER LOCATOR ASSEMBLY w/6'SPACE OUT 3.000 8,541.4 5,110.9 56.42 PBR BAKER 80-40 PBR 4.000 4 8,563.9 5,123.4 56.31 PACKER BAKER PREMIER PACKER 2.990 I 8,674.1 5,184.8 56.01 BLAST RING 3 1/2",9.38,L-80,IBTM Tubing w/30-f of 4.09"OD 2.992 GAS LIFT;3,408.7 carbide blast rings 8,720.8 5,211.0 55.82 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.813""BX"Profile 2.813 (CLOSED12/28/14) 9,581.0' 5,791.3 32.77 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY w/3'SPACEOUT 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING Original 5.968 4.000 9,584.0 9,636.2 5,838.2 SURFACE;29 53,579.6- ( Completion Details �: Nominal ID Top(ftKB) Top(ND)(ftKB) Top not(°) Item Des Corn (in) GAS LIFT;5,672.2 9,584.0 5,793.9 32.67 PBR Baker 3 1/2"80-40 PBR 4.000 9,603.4 5,810.2 32.00 NIPPLE KBH-22 Anchor Tubing Seal Nipple 3.000 - 9,604.3 5,811.0 31.97 PACKER Baker 3 1/2"X 7"SAB-3 permanent packer 5.96"OD x 3.250 3.25"ID GAS LIFT;7,169.8 9,609.2 5,815.2 31.80 MILLOUT 4 1/2"collar 3.720 9,615.3 5,820.3 31.60 XO-Reducing Crossover 4 1/2"X 3 1/2"EUE 8rd 3.500 9,628.3 5,831.5 31.21 NIPPLE Camco 2.75""D"Nipple (CA-2 plug installed) 2.750 GAS LIFT,8,083.4 9,635.3 5,837.4 31.17 WLEG 3 1/2"WLEG w/shearout sub 4.51"OD(bottom at 2.950 9647.23-ft) - Perforations&Slots Shot GAS LIFT;8.481.0 T Dens Top(ND) Btm(ND) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,680.0 8,700.0 5,188.1 5,199.3 Moraine,3S- 12/24/2012 6.0 APERF 3 3/8"Millenium,6 spf, 19 60"phasing,HMX SEAL ASSY;8,534.4S. scallop PER;8,541.4 9,700.0 9,720.0 5,892.9 5,910.1 C-4,3S-19 7/11/2003 6.0 IPERF 2.5"HSD 2506 PJ,60 PACKER;8,563.9 -'" deg ph Stimulations&Treatments Min Top Max Btm PRODUCTION;8,618.7 Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 8,680.0 8,700.0 5,188.1- 5,199.3 FRAC 1/26/2013 FRACTURE STIMULATION OF THE MORAINE. PUMPED LINEAR/CROSSLINKED GEL 1-8 PPA AT 20 BPM,4700 PSI MAX TREATING PRESSURE. PLACED 154,482 LBS OF 16/20 PROPPANT E BEHIND PIPE(103%OF DESIGN). APERF;8,680.0-8,700.0 FRAC;0.680.o� ' I 1 Mandrel Inserts St ati Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com SLEEVE-C,8.7zo.e { 3,408.7 2,509.1 Camco MMG 11/2 GAS LIFT DMY RK 0.000 0.0 6/3/2013 2 5,672.2 3,653.5 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 2,012.0 7/27/2013 I 3 7,169.8 4,400.7 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/3/2013 4 8,083.4 4,865.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/2/2013 5 8,481.0 5,077.6 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 4/12/2014 PRODUCTION,9,525.3 a6 8,618.7 5,153.9 Camco MMG 11/2 PROD DMY RK 0.000 0.0 3/20/2013 7 9,525.3 5,745.0 Camco MMG 11/2 PROD DMY RK 0.000 0.0 12/26/2012 Notes:General&Safety SEAL ASSY;9,581.0 _ End Date Annotation PBR;9,584.0 :. 4/27/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 NIPPLE;9,603.4 z 11/10/2014 NOTE:DHSIT to close 11/14/2014 at 11:13AM and reopen on 12/16/2014 at 11:13AM PACKER;9,604.3 - MILLOUT;9,609.2 ril I a NIPPLE;9,628.3 . ` a WLEG;9,635.3 (PERF;9,700.0-9,720.0 PRODUCTION; 6.--i pro 203 -09 � Loepp, Victoria T (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent Friday,July 17, 2015 3:59 PM To: Loepp, Victoria T(DOA) Subject 3S-19 Sundry question PTD 203-096 Follow Up Flag: Follow up Flag Status: Flagged Victoria—we returned 3S-19 to production on 7/8/15.The Moraine sands have been closed and we are producing from the Kuparuk C sands. I need to file a sundry with you and this raised a couple of questions. I think I need to file a 10-404 with you for the Kuparuk production but was wondering if I needed to file anything for the Moraine production. It looks like you received your previously requested flow test data for the Moraine in a letter dated 7/24/14 sundry 312-475. Please let me know what I need to file with AOGCC Thanks, Darrell Humphrey I Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) scoNED 1 ., STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COM•SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon fl Repair w ell l Plug Perforations r Perforate E Other r Alter Casing I""" Pull Tubing I`"`" Stimulate - Frac li Waiver r Time Extension '"" Change Approved Program 1 Shutdow n f Stimulate - Other 1- Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory 1;4- • 203 -096 3. Address: 6. API Number: Stratigraphic F Service E' P. O. Box 100360, Anchorage, Alaska 99510 ' 50 103 - 20460 - 00 OQ 7. Property Designation (Lease Number): S m 8. Well Name and Number: ' ADL 25544 ' C3 to 7 z t v 3S - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): 1 none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10038 feet Plugs (measured) 9628 true vertical 6187 feet Junk (measured) none Effective Depth measured 9862 feet Packer (measured) 8564, 9604 true vertical 6033 feet (true vertical) 5123, 5811 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108 108 SURFACE 3550 9.625 3580 2596 PRODUCTION 10002 7 10029 6179 !RECEIVED Perforation depth: Measured depth: 8680'- 8700', 9700' -9720' SCANNED APR 17 2013 FEB 2 6 2613 True Vertical Depth: 5188'- 5199', 5893' -5911' AC Tubing (size, grade, MD, and TVD) 3.5, L - 80, 9584 MD, 5794 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 8564 MD and 5123 TVD PACKER - BAKER SAB -3 PERMANENT PACKER @ 9604 MD and 5811 TVD SSSV - CAMCO DS NIPPLE @ 504 MD and 504 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8680' -8700' / Treatment descriptions including volumes used and final pressure: J 154,482# of 16/20 proppant 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation none Subsequent to operation flowback in progress 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory I✓ Development 14 ' Service I Stratigraphic r 16. Well Status after work: ` Oil Ii Gas E WDSPL E Daily Report of Well Operations XXX GSTOR E WINJ E WAG r GINJ E SUSP j"' SPLUG E 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 312 -475 Contact T son Wiese ta7 263 -4250 Email Tvson .M.Wiese(cr�conocophillibs.com Printed Name T son se Title Wells Engineer Signature ��\� Phone: 263 -4250 Date 1419n:06 c Form 10 -404 Revised 12/ 12 DMS FEB 2 W2' Submit Original Only 41(2413 r /4:1 S -19 Well Work Summary DATE SUMMARY • 1/8/2013 TAGGED SAND PLUG & SET AVA CATCHER @ 9571' WLM; PULLED SHEARED SOV AND SET DV @ 8481' RKB. ( FAILED PT) . IN PROGRESS 1/9/2013 PULLED AND RE -SET DV @ 8481' RKB ( TESTED ); PULLED DV @ 8619' RKB AND SET SPG. IN PROGRESS. 1/10/2013 MITT TO 3500 ( PASS ). MIT IA TO 3500 PSI ( PASS ); PULLED CATCHER @ 9572' SLM. OPENED CMU @ 8721' RKB. READY FOR FRAC 1/20/2013 Rigged up Stinger tree -saver equipment. Mobbed SLB frac crew from PRB and rigged same. Hot Oil completed heating fluigs. Began pre -job safety meeting @ 20:30. Postponed job as weather deteriorating (just turned Phase 1) and lateness of start time. Will return in A.M. after 8hrs off for 1/21/2013 Performed breakdown, scour, and Datafrac stages of procedure. Attempted frac, had extreme fluid foaming issues in the PCM during pad; shut down to investigate cause (still unknown). Unable to continue due to late hour /crew being "timed" out. Secured well and equipment and shut down for the night. Will resume in the A.M weather permiting. 1/22/2013 Phase I weather on access road & pad. Mobilized frac crew to location. Hot oil re- heated diesel. Pad conditions deteriorated due to drifting snow; Phase 2/3 weather declared for all Kuparuk roads & pads. Shut down and return to camps. 1/23/2013 Phase 2 / 3 weather, unable to access pad. Job on hold. 1/24/2013 Perform snow removal on pad; dig out hardline and equipment. Job on hold. 1/25/2013 FINISHED DIGGING OUT EQUIPMENT. CIRCULATED WARM DIESEL THRU HARDLINE, ATTEMPTED TO P/T. MULTIPLE LEAKS. LAST LEAK IN CHECK VALVE CAP; CHANGE OUT SEALS. RE- PRESSURE TEST, STILL LEAKING. NO MORE REDRESS PARTS ON LOCATION, WILL BE TOO LATE ONCE PARTS ARRIVE FROM PRB TO RESUME. SHUT DOWN FOR THE NIGHT, MAKE ARRANGEMENT TO HAVE ANOTHER TESTED CHECK VALVE AND PARTS ON LOCATION IN A.M. DISCONNECT HOSES, SECURE WELL. TREE -SAVER INSTALLED, NOTIFY 1/26/2013 PERFORMED FRACTURE STIMULATION OF THE MORAINE. PUMPED LINEAR / CROSSLINKED GEL 1 -8 PPA AT 20 BPM, 4700 PSI MAX TREATING PRESSURE. PLACED 154,482 LBS OF 16/20 PROPPANT BEHIND PIPE (103% OF DESIGN). UNDERFLUSHED, ONLY ABLE TO GET 5 BBLS FREEZE PROTECT AWAY (UNABLE TO SQUEEZE IN ANY ADDITIONAL). 1/28/2013 CONITNUED RIG DOWN OF FRAC EQUIPMENT AND SITE CLEANUP. ATTEMPTED TO REMOVE TREESAVER, FROZEN IN PLACE. WRAP TREE AND HEAT; WILL RETURN IN A.M. AND ATTEMPT TO PULL. 2/2/2013 Mill Ice job / FCO postponed until morning due to equipment issues. Job in progress. 2/3/2013 Ran Mill down to 5,100' CTMD to clear alledged ice, but none found . POOH and changed BHA to peform FCO. Tagged top of sand © 5,591' CTMD (Could be sand bridge ? ?). Performed FCO down to 5,702' CTMD. Delays due to clogged nozzle filled with several pieces of hard rubber. After clearing, made another bite and POOH. Well freeze protected. Will return in morning to continue 2/4/2013 CTU FCO down to CA -2 plug @ 9,608' CTMD using slick diesel and diesel gel. Maintained 1:1 returns with good amount of frac sand. Estimate about 500' of sand in TBG on top of plug. Well freeze protected. Job complete. 2/10/2013 ENCOUNTERED FRAC SAND @ 2286' SLM. MAKE SEVERAL BAILER RUNS RECOVERING FULL RETURNS W/ LITTLE PROGRESS. ABLE TO PUMP AND MOVE WHAT APPEARS TO BE SUSPENDED FRAC SAND BRIDGE DOWN TO 9583' SLM. IN PROGRESS. 2/11/2013 SET CATCHER SUB @ 9578' SLM, REPLACE HES SPG w/ SAME @ 8619' RKB (GOOD DATA), PULL DV @ 3393' RKB, IN PROGRESS. 2/12/2013 PULLED DV'S @ 8083 AND 7170' RKB. SET GLV'S @ 7170', 3409', AND OV @ 8083' RKB. BAIL FILL ON TOP OF CATCHER 9578' SLM (APPROX. 8' OF FILL ON TOP OF CATCHER ) 2/13/2013 BAIL FILL ON TOP OF CATCHER @ 9571' RKB ( EST. 852' BELOW CMU @ 8720' AND 54' ABOVE CA -2 PLUG) . UNABLE TO PULL RECOVER CATCHER. READY FOR PTS FLOWBACK. t KUP 3S -19 ConocoPhillips 4 Well Attributes Max Angle & MD TD Alaska Inc Wellbore APUUWI Field Name Well Status Inc! (°) MD (RKB) Act Btm (MB) `q 501032046000 KUPARUK RIVER UNIT PROD 61.56 2,630.84 10,040.0 ` - " ' Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date SSSV: NIPPLE 80 11/14/2012 Last WO: 12/29/2012 33.03 7/4/2003 Well Conro - 3S -19 2/20/2013 1:11'.50 PM Schematic -Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,792.0 12/1/2012 Rev Reason: FRAC, SET CATCHER osborl 2/20/2013 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H - 40 WELD Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd HANGER, z4 SURFACE 95/8 8.835 29.5 3,579.6 2,596.1 40.00 L -80 BTC -- z t Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) .. String Wt... String String Top Thrd PRODUCTION 7 6.276 26.5 10,028.6 6,178.7 26.00 L -80 BTCM IIII Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO I 3 1/2 I 2.992 I 24.2 I 9,584.0 I 5,793.7 9.30 L -80 EUE Completion Details Top Depth (TVD) Top Intl Need... CONDUCTOR, Top (ftKB) ("13) ( °) Item Description Comment !D (in) 30 -108 24.2 24.2 -021 HANGER FMC GEN V TUBING HANGER 3.500 I 504.4 503.7 6.41 NIPPLE CAMCO DS NIPPLE w/2.875" PROFILE 2.875 t NIPPLE, 504 _. _- I: .,s:. 8,534.4 5,107.1 56.45 SEAL ASSY BAKER LOCATOR ASSEMBLY w /6' SPACE OUT 3.000 IIIII 8,541.4 5,111.0 56.42 PBR BAKER 80-40 PBR 4.000 8,563.9 5,123.4 56.31 PACKER BAKER PREMIER PACKER 2.990 GAS314F 8,674.1 5,184.8 56.05 BLAST RING 31/2" ,9.3#, L -80, IBTM Tubing w/ 30-ft of 4.09" OD carbide blast rings 2.992 E 8,720.9 5,211.1 55.82 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/ 2.813" "BX" Profile (OPEN 2.813 1/10/2013) 9,581.0 5,791.1 31.53 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY w/3' SPACOUT 3.000 Tubing Description !String 0... String ID ... Top (RKB) S Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE,_ ' ' TUBING Original Str 5.968 I 4.000 9,584.0 ISM 9,636.2 I 5,838.2 zs -3sa° Completion Details Top Depth (-/ (ND) Top Intl Noml... Top (ttKB) (RKB) ( ° ) Item Description Comment ID (in) GAS LOT 9,584.0 5,793.7 31.51 PBR Baker 31/2' 80-40 PBR 4.000 5 672 9,603.4 5,810.2 31.38 NIPPLE KBH-22 Anchor Tubing Seal Nipple 3.000 MI 9,604.3 5,811.0 31.37 PACKER Baker 31/2' X 7' SAB-3 permanent packer 5.96" OD x 3.25" ID 3.250 GAS LIFT _._ 9,6092 5,815.1 31.34 MILLOUT 4 1/2" collar 3.7201 7.170 9,615.3 5,820.3 31.30XO- Reducing 'Crossover41/2 "X312 " EUE 8rd 3.500 = 9,628.3 5,831.5 31.21 NIPPLE Camco 2.75" "D" Nipple (CA -2 plug installed) 2.750 - 9,635.3 5,837.4 31.17 WLEG 3 12" WLEG w/ shearout sub 4.51" OD (bottom at 9647.23 -ft) 2.950 GAS LIFT, Pu 7 @��` °', 8,083 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etir ,,,,, ,,, „.r�� Top Depth (ND) Top Inc! Top OMB) (RKB) ( ^) Description Comment Run Date ID (in) GAS LIFT, 8 ,618.7 5,154.1 56.31 GAUGE RESET GAUGE SET IN PRODUCTION MANDREL, POST 2/11/2013 0.000 8,481 FRAC SEAL ASSY. P 9,578.0 5,788.6 31.55 CATCHER CATCHER 2/11 /2013 0.000 9,628.3 5,831.4 31.21 PLUG 2.75" CA -2 PLUG 12/2/2012 0.000 8.534 I Perforations & Slots BR P. 8,541 Shot PACKER, 8,564 _ Top (ND) Bdn (ND) Dens -� Top (ORB) Bins (ORB) (RKB) (MB) Zone Date Oh- Type Comment 8,680.0 8,700.0 5,188.1 5,199.3 UNIT D, 3S - 19 12/24/2012 6.0 APERF 33/8' Millenium, 6 spf, 60° phasing, GAUGE. 8,619 MN PRODUCTION, la HMX scallop 0.819 9,700.0 9,720.0 5,892.9 5,910.9 C -4, 3S -19 7/11/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph MI MI Stimulations & Treatments Bottom APERF, Mm Top Max Btm Top Depth Depth 8,680 -8,700 Depth Depth (ND) (TVD) FRAC,8,680 ®, (ORB) (RKB) (RKB) (RKB) Type Date Comment it 8,680.0 8,700.0 5,188.1 5,199.3 FRAC 1/26/2013 FRACTURE STIMULATION OF THE MORAINE. It PUMPED LINEAR / CROSSLINKED GEL 1 -8 PPA AT 20 BPM, 4700 PSI MAX TREATING PRESSURE. II PLACED 154,482 LBS OF 16/20 PROPPANT SLEEVE-o, 8,721 BEHIND PIPE (103% OF DESIGN). MI - Notes: General & Safety End Date Annotation PRODUCTION, 4.2/ 2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 9,525 CATCHER. 9.578 IP!d-I SEAL ASSY, 9,581 PBR, 9.584 NIPPLE, 9,603 j i 41. PACKER, 9,604 _ _ Mandrel Details MILLOU ,.: Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run It N... Top (ttKB) (RKB) ( °) Make Model (in) Sets Type Type (in) (psi) Run Date Com... it 1 3,408.7 2,509.6 60.01 Camco MMG 1 12 GAS LIFT GLV RK 0.188 1,839.0 2/12/2013 PLUG. 9,828 2 5,672.2 3,653.5 60.59 Camco MMG 1 12 GAS LIFT DMY RK 0.000 0.0 12/26/2012 NIPPLE. 9,629` :- 3 7,169.8 4,400.7 61.00 Camco MMG 1 12 GAS LIFT GLV RK 0.188 1,781.0 2/12/2013 illi WLEG, 9,635 31 II 4 8,083.4 4,865.9 58.96 Camco MMG 1 12 GAS LIFT OV RK 0.188 0.0 2/12/2013 5 8,481.0 5,077.7 56.71 Camco MMG 1 12 GAS LIFT DMY RKP 0.000 '1 1/9/2013 IPERF, 9,700--99,7720 20 a.- - 6 8,618.7 5,154.1 56.31 Camco MMG 1 12 PROD Gauge 0.000 0.0 2/112013 7 9,525.3 5,745.0 34.73 Camco MMG 1 12 PROD DMY RK 0.000 0.0 12/26/2012 PRODUCTION. 26-10,029N TD, 10.040 v of • 1 , 7 ,-. THE STATE Alaska Oil and Gas vi Of L C servat o li Commission - _ =- GOVERNOR SEAN PARNELL ,,,',.... 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Tyson Wiese Wells Engineer SCANNED JAN 16 2013 ConocoPhillips Alaska, Inc. '1 03 - 0 ,6 P.O. Box 100360 oC Anchorage, AK 99510 e _ . ........ .k ..a..,,,.. kiwi Re: Kuparuk River Field, Kuparuk River Oil Pool, 3S - 19 Sundry Number: 312 -475 Dear Mr. Wiese: 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, - ° 4 7 Daniel T. Seamount, Jr. Commissioner DATED this � day of January, 2013. Encl. a_REC E1VED STATE OF ALASKA C 1V D • AlKA OIL AND GAS CONSERVATION COM•SION a: DEC 13 2012 APPLICATION FOR SUNDRY APPROVALS ' ' 20 AAC 25.280 AOGCC 1. Type of Request: Abandon r Rug for Redrill fl Perforate New Pool f Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well f Stimulate - Alter casing g r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory 1' 203 -096 • 3. Address: Stratigraphic fl Service r" 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20460 -00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes E No j 3S -19 • 9. Property Designation (Lease Number): a 10. Field /Pool(s): ADL 25544 , 3 8 0 / o? 111 Kuparuk River Field / Kuparuk River 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): 10038 6187 9862' 6033' 9639' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108' 108' SURFACE 3550 9.625 3580' 2596' PRODUCTION 10002 7 10029' 6179' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9700' -9720' 5893' -5911' 3.5 L - 9647 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SAB -3 PACKER MD= 9615 TVD= 5820 SSSV - CAMCO DS NIPPLE MD =499 TVD =499 12. Attachments: Description Summary of Proposal r . 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory 14: Stratigraphic E Development • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/13/2013 Oil r• e Gas r WDSPL r Suspended [ 16. Verbal Approval: Date: WINJ r GINJ r- WAG I • 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: Tyson Wiese @ 263 -4250 Email: Tvson.M.Wiese(conocoohillios.com Printed Name T on iese Title: Wells Engineer Signature ` I Phone: 263 -4250 Date 11-13 ..7Q Commission Use Only Sundry Number: 312 - L 7S Conditions of approval: Notify Commission so that a representative may witness Plug Integrity J BOP Test r Mechanical Integrity Test r Location Clearance r RSDAAS JAN 0 4 2013 4ii 1 Other: ti Spacing Exception Required? Yes ❑ No rf Subsequent Form Required: \ (o,W , n Id A.- ' -n ,j Au zE w 111/6‘1-1- A1'-PA,a °� of cc�w>n�s; on Q ® APPROVED BY AO Approved by: . COMMISSIONER THE COMMISSION Date: / Approded application is valid for 12 months from the date of approval. �n� 0 R G4rtr i l L/2012) 2 Submit Form and Attac in Duplicate 0 \ \ �f l - // / /' "� \ \� s �: Imo✓ Q� • 3S -19 Moraine Frac Permit to Drill #: 203 -096 3S -19 was originally completed in 2003, as a single C -sand producer. A RWO is planned for December 2012, in which the C -sand completion will be pulled, the Moraine interval will be perforated, and a selective Kuparuk/Moraine completion will be installed. The primary objective of this project is to determine the productivity and water cut of the Moraine at 3S. If successful, this work could lead to a multi -well development program. The Moraine Interval at drill site 3S is est. to contain approx. 31 million bbls of oil. Proposed Moraine Frac Procedure: Schlumberger Pumping Services: (Moraine Frac) 1. Ensure that the 10 -403 Sundry has been approved by the AOGCC. 2. MIRU 5 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 2,000 bbls are required). 3. RU SLB Equipment and Support Equipment. Install Stinger Tree Saver. 4. Pressure Test Surface Lines to 8,000 psi. 5. Pump 200 bbl Breakdown stage with Schlumberger's YF125ST (25# gel) fluid system. 6. Pump 150 bbl Scour stage with YF125ST fluid and approx. 4,000 Ibs of 16/20 if breakdown stage shows high pert friction pressure. May not pump this stage if friction pressures are acceptable. 7. Pump 300 bbl DataFRAC stage with YF125ST fluid, following the Schlumberger pump schedule. 8. Adjust pad volume as determined by DataFRAC information. 9. Pump the following schedule @ 20 BPM with a maximum expected surface pressure of approx. 4,000 psi. Add breaker as per lab results. Maintain 3,500 psi on the IA during the treatment. • 357 bbls YF125ST Pad (or adjusted volume after DataFRAC) • 224 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 214 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 263 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 226 bbls YF125ST w/ 6 ppa 16/20 Carbolite • 169 bbls YF125ST w/ 8 ppa 16/20 Carbolite • Flush with 78 bbls of linear fluid (WF125) and freeze protect Total Sand: Approx. 150,000 Ibs 16/20 Carbolite 10. Monitor the surface pressure fall -off at the end of the job for 30 min (or until closure if verified), if the well does not screen out. 11. RDMO. Freeze protect the well if screen out occurred, and was unable to be done during flush. Slickline / CTU: (Post Frac Drift and Tag / FCO / Install GLD) 1. RU Slickline. RIH and drift and tag. 2. If fill volume is significant, call out CTU to perform FCO. If not, bail fill down to XN plug. 3. After the FCO is completed, install new GLD. 4. RDMO, Well is Ready for Moraine Flow back. TW • . ConocoPhillips Well: 3S -19 Moraine Test 2012 RW4 Proposed Completion ilmir I 16" 62# H-40 to 108' MD I —mai . 1 �s I9 -518" 40# L -80 to 3,580' MD 1111- ■ New 3-1/2" Gas Lift Completion 7" Casing Patch 3 -112' 2 3r= L -87 E'JE Ord Tub ng Camco 2.676 ''OS' Nipple 6 -500' M7 Cameo 1-1/2" MMG Gas Lift Mandrels Upper Squeeze Perfs ...' . Baker GBH -22 Seal Assy. (15' seals) Moraine Straddle Assy. Baker 80 40 PER, 20' bng Baker 3.5" z 7" Premier Pkr La' XXXX' MD Propcsed Moraine perfs 8.680' - 8.70'0' MD __ _ Campo 1 -1,2' MMG Gas Lfi (Prod.l141ancrel 0 it i1 Baker CMU Sliding Sleeve w 2.e 13' X Profile Camco 2.813 ''X' Nipp e • re I i; Baker 3.5" x 7" Premier Pkr XXXX' MD ",• ° j - Camco 1 - 1/2' MMG Gas Lift Mandrel ILooer Squeeze Perfs I w w Baker CMU Sliding Sleeve 2.813" X Prof It • r.- Baker GBH - Seal Assy. ;15' seals) •�• • Existing 3 -112" 80-40 PBR (.:i ; 9,595' MD • I = 4 Existing SAB-3 Packer (a 9,615' MD P II 4-2.75" D Nipple f —WLEG (a 9,646' MD f IC-4 sand perfs 9700' -9720' MD 1 - -. . E :2 17" 26# L -80 shoe at 10,029' MD I �_ Updated By: B. Packer Last Update: 11115112 TW KUP 3S -19 ' - ' COnocoPhillips ,' Well Attributes Max Angle & MD TD Alaska Inc Wellbore API /UWI Field Name Well Status Inc! I') MD (ftKB) Act Btm (ftKB) L.m�cdtbiaPS _., 501032046000 KUPARUK RIVER UNIT PROD _ 61.56 2,630.84 10,040.0 ' Comment H2S (ppm) Date Annotation End Date KBGrd (ft) Rig Release Date "' SSSV: NIPPLE 80 11/16/2011 Last WO: 33.03 7/4/2003 Well Co 8a: - 39 -19, 12/6/20121220.53 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,792.0 12/1/2012 Rev Reason: TAG, GLV C /O, OPEN CMU ninam 12/6/2012 Casing Strings Casing Description String 0... String ID .. Top (ftKB) Set Depth (f... Set Depth (ND)... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H WELD "" Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 29.5 3,579.6 2,596.1 40.00 L - 80 BTC HANGER, 24 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String .. String Top Thrd PRODUCTION 7 6.276 26.5 10,028.6 6,178.7 26.00 L -80 BTCM s- Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND)... String Wt... String ... String Top Thrd TUBING 3 1/2 2.992 24.1 9,647.2 5,847.7 9.30 L -80 EUE 8RD Completion Details Top Depth (ND) Top Inc! Nomi... Top (01KB) (ftKB) C) Item Description Comment ID (in) 24.1 24.1 -0.21 HANGER FMC GEN 5 TUBING HANGER 3.500 499.2 498.5 6.31 NIPPLE CAMCO DS NIPPLE w/ 2.875 NO GO 2.875 9,545.8 5,761.3 31.77 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.81Z NO GO (OPEN 2.812 CONDUCTOR, 12/2/12) 30-108 9,593.1 5,801.4 31.45 SEAL ASSY LOCATOR SUB 8, PBR SEAL ASSEMBLY (SPACED OUT 7 ABOVE 1000 NIPPLE, 499 FULLY LANDED) 9,595.1 5,803.1 31.44 PBR BAKER 80-40 PBR 3.250 9,614.4 5,819.6 31.31 NIPPLE KBH -22 ANCHOR TUBING SEAL NIPPLE 3.000 GAS LIFT, 9,615.3 5,820.4 31.30 PACKER BAKER SAB-3 PACKER 3.250 3,393 9,620.2 5,824.6 31.27 EXTENSION 80-40 MILL OUT EXTENSION 3.720 9,625.7 5,829.2 31.23 COLLAR 4.5" COLLAR 3.720 [ 9,626.3 5,829.7 31.23 XO- Reducing CROSSOVER 3- 1/2"x4 -1/7' 3.500 I 9,639.4 5,840.9 31.14 NIPPLE CAMCO D NIPPLE w/ 2.75" NO GO 2.750 i■ 9,646.3 5,846.9 31.09 WLEG WIRELINE ENTRY GUIDE w/ SHEAR OUT SUB 2.950 SURFACE, ■ I Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) 29 -3,580 Top Depth (ND) Top Incl Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 9,639 5,841.0 31.14 PLUG 2.75" CA -2 PLUG 12/2/2012 0.000 Perforations & Slots GAS LIFT, Shot 5,876 it Top (TVD) Btm (ND) Dens Top (ftKB) Btm (ftKB) MB) (ftKB) Zone Date (oh... Type Comment 9,700 9,720 5,892.9 5,910.9 C -4, 3S -19 7/11/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph AIL In Notes: General & Safety End Date Annotation GAS LIFT, 4/27/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 7,672 III lin GAS LIFT, 8,850 GAS LIFT, 9,494 I SLEEVE -O, i , , I 9,546 i SEAL ASSY, 9,593 PBR, 9,595 NIPPLE, 9,814 PACKER, 9,815 _ EXTENSION, 9,620 COLLAR, 9,626 r Mandrel Details NIPPLE, 9,639 Top Depth Top Port PLUG, 9,839 Ill ' ' (TVD) Inc! OD Valve Latch Size TRO Run r� Stn Top (ftKB) (MKB) C) Make Model (in) Sery Type Type (in) (psi) Run Date Coin... 1 3,393.4 2,502.1 60.13 Camco KBUG -M 1 GAS LIFT DMY BK 0.000 0.0 12/1/2012 WLEG, 9,646 J 2 5,875.6 3,754.6 59.86 Camco KBUG -M 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2007 3 7,672.4 4,652.0 58.42 Camco KBUG -M 1 GAS LIFT DMY BK 0.000 0.0 12/1/2012 IPERF. _ - 4 8,849.8 5,284.2 55.49 Camco KBUG-M 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2007 9,700 - 9,720 5 9,493.7 5,719.6 36.16 Camco MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/2/2012 PRODUCTION, 28- 10.029 TD, 10,040 - ■ , 1 110 • Ferguson, Victoria L (DOA) From: Wiese, Tyson M [ Tyson .M.Wiese ©conocophillips.com] Sent: Wednesday, December 26, 2012 12:48 PM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: RE: 3S -19 (PTD 203 -096, Sundry 312 -475) Attachments: 3S -19 0.25 mile radius.ppt; 3S -19 Moraine Test FracCADE Design.pdf; 3S -19 RCBL Moraine Interval Review.pdf; Halliburton CAST -M Moraine Interval Bond Log Summary Page.pdf Victoria, 1.) Attached is a 3S Pad map, with 1/4 mile radius drawn to scale, which shows no offset well penetrations within that range. 2.) Attached is the FracCADE program that Schlumberger had developed which details planned fracture half length, fracture height, and other simulation results. 3.) Attached are pdf files of relevant pages of recent RCBL and CAST -M logs that were used to evaluate cement across the 3S -19 Moraine Interval during the ongoing RWO. Both logs showed good cement bond across the planned Moraine Frac interval from 8720' - 8740' MD. The logs did not get down across the C -sand interval, but good cement was shown down to 9,500' MD, which is approx 200' above the C -sand perforations © 9,700'- 9,720'. 4.) For the work scope involved with this sundry (Frac /Post Frac well prep) we are only planning to test the Moraine formation, with the C -sand isolated. If that changes in the future, and commingles production is considered, we will start a new sundry for that approval. Please let me know if there is any other information that you need. Thanks /00 0 ` 6c - 7 /1/1 1 C Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 Ce11:1 -907- 230 -5388 From Ferguson, Victoria L (DOA) f mailto:victoria.ferguson(a alaska.govl Sent: Thursday, December 20, 2012 9:10 AM To Wiese, Tyson M Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: [EXTERNAL]3S -19 (PTD 203 -096, Sundry 312 -475) Tyson, For the fracture stimulation of this well could you please provide the following: 1. Map showing wellbore penetrations within % mile radius. 2. Engineering review of the fracture modeling results showing that the frac fluids will remain in the target zone. Include frac length and frac propagation. 3. Engineering review of the cement in the subject well and wells within % mile radius. 4. Also note that commingled production of the Moraine and Kuparuk requires AOGCC approval. 1 -7 ""*"....""."- l a-Gi la-GSA 39•C4 ,s 3fi,3 3H 36.17 "eac • 0 - 11 . 7A ie - IIIIIIIII IIIIIIIIp% 1141ih: �► 1644 " • "3sC3G LeganC _ - p0 i461` Surtace L4catan SW S ".aces c -: ./f , �SJE�'�3e3 Wel TD 31111 , 1 pa 1111mm11111m�11111��11111m�11111��11111mo1111111�11111�1111111•�1111111% z ,WAv • • 3 s Kuparuk River Unit ' ""''"'" y t!Nl,G C 3S i�ad �.�:$��; November 20, 20 1 E ' s soenle3 a'FSr.3'1 /g ARV Vi*.': S'JNe j'. • �e 11 C : ()_ .' r i 6 K.'C3.R !Vie.' 41l' Miles �J K L . oa ."n c/a L;o. ".. e . • • Schlumberger �r FracCADE STIMULATION PROPOSAL Operator : CPAI Well : 3S -19 Field Formation : Moraine Well Location : County : North Slope Borough State : Alaska Country : United States Prepared for : Ashok Misshra Service Point : Prudhoe Bay Proposal No. Business Phone : 907 -659 -2434 Date Prepared : October 23, 2012 FAX No. : 907 -659 -2538 Prepared by : Mike Martin Phone : 907 - 265 -6205 E -Mail Address : martin13@slb.com *Mark of Schlumberger Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. 0 • Client : CPAI Well 3S -19 Schl n rgnr Formation : Moraine District : Prudhoe Bay Country : United States Loadcase : MM pxd Section 1: Propped Fracture Schedule Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half - length (X,) of 381.4 ft with an average conductivity (K,w) of 3855 md.ft. Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. Name Rate Volume Conc. Type and Mesh Conc. (bbl /min) (gal) (Ib /mgal) (PPA) PAD 20.0 YF125ST 15000 25.0 0.00 1.0 PPA 20.0 YF125ST 9000 25.0 16/20 C -Lite 1.00 2.0 PPA 20.0 YF125ST 8250 25.0 16/20 C -Lite 2.00 4.0 PPA 20.0 YF125ST 9375 25.0 16/20 C -Lite 4.00 6.0 PPA 20.0 YF125ST 7500 25.0 16/20 C -Lite 6.00 8.0 PPA 20.0 YF125ST 5250 25.0 16/20 C -Lite 8.00 FLUSH 20.0 WF125 3260 25.0 0.00 Please note that this pumping schedule is under - displaced by 3.1 bbl. Fluid Totals 54375 gal of YF125ST 3260 gal of WF125 Proppant Totals 150000 Ib of 16/20 C -Lice Pad Percentages % PAD Clean 27.6 % PAD Dirty 24.6 Job Execution Step Step Cum. Fluid Step Cum. Step Cum. Avg. Step Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume (Ib) (Ib) Pressure (min) (min) (gal) (bbl) (bbl) (psi) PAD 15000 15000 357.1 357.1 0 0 3665 17.9 17.9 1.0 PPA 9000 24000 223.7 580.8 8998 8998 3666 11.2 29.0 2.0 PPA 8250 32250 213.7 794.5 16500 25498 3653 10.7 39.7 4.0 PPA 9375 41625 262.4 1056.9 37500 62998 3668 13.1 52.8 6.0 PPA 7500 49125 225.6 1282.5 45000 107998 3738 11.3 64.1 8.0 PPA 5250 54375 168.9 1451.4 42000 149998 3856 8.4 72.6 FLUSH 3260 57635 77.6 1529.0 0 149998 3392 3.9 76.5 2 • 1 Client : 3S-1 9 Well Schl rge 3S -1 Formation : Moraine District : Prudhoe Bay Country : United States Loadcase : MM pxd Section 2: Propped Fracture Simulation The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3 -0 Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Initial Fracture Top TVD 5170/ ft 4o ✓ Initial Fracture Bottom TVD 5210.0 ft Propped Fracture Half- Length 381.4 ft EOJ Hyd Height at Well 126.3 ft Average Propped Width 0.171 in Average Gel Concentration 408.7 Ib /mgal Average Gel Fluid Retained Factor 0.50 Net Pressure 132 psi Efficiency 0.460 Effective Conductivity 5225 md.ft Effective Fcd 27.4 Max Surface Pressure 3946 psi Simulation Results by Fracture Segment From To Prop. Conc. Propped Propped Frac. Frac. Fracture (ft) (ft) at End of Width Height Prop. Gel Conc. Conductivity Pumping (in) (ft) Conc. (Ib /mgal) (md.ft) (PPA) (Ib /ft2) 0.0 95.4 8.7 0.168 95.7 1.50 395.4 5444 95.4 190.7 6.5 0.197 95.7 1.77 359.9 4898 190.7 286.1 4.8 0.176 95.7 1.57 403.8 4007 1 286.1 381.4 2.7 0.142 89.9 1.28 475.9 1708 Proppant packed at 381 ft after 99 bbl in step 6 Fracture Geometry Data Per Zone for Production Prediction Zone Name Top Top Gross Net Fracture Fracture Fracture MD TVD Height Height Width Length Conductivity (feet) (feet) (ft) (in) (ft) (md.ft) Overburden 8500.0 5088.1 82.1 .0 0.025 378.3 580 Top Moraine 8648.0 5170.2 39.8 5.0 0.231 381.4 5225 Target 1 8719.0 5210.0 6.0 6.0 0.393 381.4 8614 Marginal 8729.7 5216.0 5.0 1.0 0.419 381.4 8983 Target 2 8738.6 5221.0 15.0 15.0 0.304 381.4 6581 Marginal 8765.2 5236.0 140.0 17.0 0.028 380.1 573 Base Moraine 9006.6 5376.0 100.0 100.0 0.000 .0 0 3 • • Client : CPAI Well 3S -19 Schlumhcrgcr Formation : Moraine District : Prudhoe Bay Country : United States Loadcase : MM pxd Section 3: Propped Fracture Simulation Results (1) ACL Fracture Profile and Proppant Concentration Plot FracCADE' ca "' 35, ppxx -.m Profile and PropPent Concentntlon O 2012 3100 5150 c OA IGR2 1• OA -041.2 a 5200 OA- 0.9114Ifp 0 3 -1 1 2 1.8 - 2.21.2 71 1 a 21 - 2.] IDM2 � 1 5 2.7 - 3.11DM2 MI 3.1 - 3.5114512 e1 >3.51144112 6300 Fre..1 Initiation MD= 8983.52 n 5350 3200 r r r -0.4 A.2 1 02 0.4 0 150 300 <50 600 ]50 514¢4 -q A2 VA. et Wellboie - in FncNre Half-Len. in 'Mark of Schlumber0er Schlumberger (2) Design Pressures Deskat Plessfaes 9111aeeAWtla - FrelbnPreeare - Hydrostatic 09091fe 4000 • • 3000 • 2000 -- 1000 • 10 20 30 40 50 80 70 00 00 100 110 120 130 140 150 Trealr.entTrre• rrn 4 • E, mol r7m�� t7s- �7 r- vI ' E, i i b I $ I g w, t ' -5 1 Com CONOC• ILLIPSALASKA, INC, I 3 -al a < ' . ' 3 T o r r 0 m. s Well 3S -1 J I6 — m oga ° e °° 3 I - E ` 3 c @ n i n p a m m. 2 7— a Field PALI a r ! a `R m I> m . 5' a 3 to , �,; , T I -I 3 ; g Borough N. SLOPE State ALASKA r • I m 1 1 r T l77 i ' o CO 4j -. m - 1 , I _ 8 - O _ 0 I j — DI e 3 I b ( 4'A EwI N O ' 0 �' C I1�a 1°1 I �olar4im ,,�' tv a , { 1 l imi 1 n 7 7 {p;g r`.) p o ..< 4 i j I I rr, I . 0.O 0 r cs � --I —I 0 • �! o ' ,, N I ; i ce W - '�� � � c 2 I I I i D � i° ,� -I I I m 0' C) I o, - -+- p 'IV —t- - - - f- m — i 1 I v n jZ m `o ' I {0 m $' I I I v m I TJ Q7 •n�Q�ra I an m I� a d I � fo = in1 ' N I I I cO I -l< 4 C I • Q j # //� t J un I � I�� nSQ Oi I 0 XI r �wj ti t3. ( I c g o (n ^ C �° I a t �' C 7 Z 0 K D --1 ! 0 I a i _ T C I C I I y 01 - 2 - Ippp oawTW( A L� (.ti ^� 1„ c cc Xf 7 i D 1-- w w I- SID r-- - T �+ J 4 D n g (4 f s � , ,_ I ; l o D ^ ,� /— 7 rn � i r --I 9 r- D 0 0 Z rnm a n n f � � Li �i Z i �' m Z R Z r - t� c _ . ' 7 0 r — i l ' a D m 1 I I i l i 2, , �i I i ,« Fold Here ,=.> HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA. CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OR WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS. OR RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR VNLLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF_ Comments LOG CORRELATED TO SPERRY -SUN MWD DUAL GAMMA RAY DATED 20 JAN 2004 CAST -M IN CEMENT INSPECTION MODE CONFIGURED VW 4 -3/8" HEAD AND 350 HZ TRANSDUC LOG FROM 9550' TO SURFACE TOP OF CEMENT FOUND AT 3573' AREAS OF PATCHY CEMENT FROM 3718'- 4348', 4504' - 4830', 5086'- 5272', AND 6522' -6558' YOUR CREW TODAY: N. HENDRICKSON, M. KING - CARROLL, T. PARKER. R. GOODWIN THANK YOU FOR CHOOSING HALLIBURTON ENERGY SERVICES SUMMARY Objective: LOG CAST -M IN CEMENT INSPECTION MODE FROM 9550' TO SURFACE PreJob PreJob PreJob _Tbq Press. If+. Pres:., OA Press, Tie-In Correlated to (Iog/dale.lewelry, eIc) I Primary Marker ,snarl joint, iGLM. etiI: IWA 0 0 MWD DUAL GAMMA RAY DATED 20 JAN 2004 GAMMA RAY PostJob PostJob PoslJob Additional Informal on CEMENT TOP FOUND AT 3573' Tby Press IA Press. OA Press AREAS OF PATCHY CEMENT FROM 37tB'- 4348', 497d'- 4Et30', rte'- 5272', AND R'5+22F658'. 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Remarks: CORRELATED TSPERRY SUN MWD DUAL GAMMA RAY LOG DATED 20 JAN 2004 THANK YOU FOR CHOOSING HALLIKURION ENERGY SERVICES. HA1LELFITC1 D i M 3 NAT GUARANTEE Ti- A_PAGY CF K O ' IF/11.1-FRETATION CF THE LCA3 D T P , ,, i)-amERuinni CF LOG DATA TO PHYSICAL ROCK PAPMETERS OR RECONNBCATiCOIS Mil C1-1 MAY BE ZIMEN BY HAW BLRT,]1 PEP SONIMEL CFI HIO-1 APPEAR ON TI-E OM CsR ri ANY OTHER FORM. Al* LeaR OF SUCH DATA INIERPREIATICHE% CLIICII 1 09 R EC OWNP e I ,I:) AT I 0145 Ar:keES THAT FtPLLIBLRTC:N IE NDT RESPDNSIELE e..).,LAO-1 VVI OW TO criObEit NEGLI CiENCE OR 0•1 LLPJ- MISCONDLCT, FOR ANY LOSS, =ACES, CR E2PENSES RESLLTING FR( THE USE 11-ERECF HALL IEJJP TGAI a El Z W ' 4,1 1 o , ' I ( 1 W 1 I I . + ti a N , i I 10 �i i 1 a 1 a 1 lip 1 , a • g 6.0 va W N, CA Cs 11111 t . C - d......- ii---' . - -.... .. Yri�..r. - -.. -- 0 - -fit`. . - ar.... 0 ..� _ 1, . - ty��.ss atiNgligliffilin W .-7 .. !mac' -say -1 t- .a 4 C �-.vc _ ;a.r . - fJ H ? 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( l' i , " l 1t 1 i it I i ' 4 ' ti` 1 i, i , a • • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, December 24, 2012 7:08 PM To: Nelson, Erik Q Subject: Re: Kuparuk Well 3S -19 (PTD# 203 -096) (Sundry# 312 - 412)... Erik, As we discussed you can proceed with the completion as proposed. Forward cement logs and a schematic as soon as practical. Guy SCANNED APR 1 1 2013 Sent from my iPhone On Dec 24, 2012, at 12:13 PM, "Nelson, Erik Q" < Erik.Nelson @conocophillips.com> wrote: Guy, This e-mail is a follow -up to our phone conversation on Saturday, 22 December. As discussed we feel a cement bond log has indicated we have adequate cement isolating the Moraine interval so that we will not have to proceed with the squeeze cementing operations as proposed in the Sundry. We are currently ready to perf the Moraine and are waiting for the weather to clear up before setting the guns off. Also, the completion will change somewhat as the casing patches and lower selective packer are no longer needed. The C- sand will be isolated from the Moraine by the existing Baker SAB -3 packer that is still in the well and a Baker Premier permanent packer will isolate it from surface. As requested ConocoPhillips will submit a copy of a cement bond log at your convenience. Hope you and yours have a Merry Christmas! Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #2040 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 12/26/2012 OF ,T4 Alaska Oil and Gas y�, \�\ Iy /�s TH STATE � N - - °f K. 1 Conservation Commission a _= ALAS GOVERNOR SEAN PARNELL wR' > � 333 West Seventh Avenue °P Anchorage, Alaska 99501 -3572 F- Main: 907.279.1433 U> Z4' [L Fax: 907.276.7542 J. Brett Packer Workover Engineer ConocoPhillips Alaska, Inc. � — 0 Ci P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3S -19 Sundry Number: 312 -412 Dear Mr. Packer: 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, r Jo i K. • man Commissioner DATED this L day of November, 2012. Encl. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 August 24, 2012 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Well 3S -19 (PTD# 203 -096). Producing well 3S -19 was originally completed in July 2003 as a single 3 V2" gas lift producer. There is nothing currently wrong with this well, in fact, the well is still online producing an average of —170 bopd. This well was chosen as an exploration project to test the viability of the Moraine interval in this area. Log data exists for the Moraine interval across drillsite 3S as well as the nearby Kalubik #2 and Colville Delta #3 wells. The Moraine reservoir interval is comprised of thinly bedded and laminated siltstones and shales. The top of the Moraine interval lies between -4,876 ft SSTVD in the area of the Oooguruk drillsite and -5,829 ft SSTVD in the distal portions of the Kuparuk River Unit. There are more than 200 logged Moraine penetrations, including several exploration wells to the west of Kuparuk. The Moraine interval is thickest, with a gross section of 280 ft, in one of Pioneer's Oooguruk wells. A 10 ft thick interval is still detectible on logs as far as 11 miles away on KRU Drillsite 2U. �+p t ''or. However, since the Moraine has never been flow tested in the immediate vicinity of drillsite 3S, and log data is insufficient to correlate to the flow tests in the Oooguruk area, the objective of this workover is to set the well up with a selective completion so that the Moraine can be fracture stimulated and flow tested. The proposed workover plans are to pull the 3 'h" tubing, and then run a cement bond log (CBL) to locate the top of cement outside the 7" casing. We will cement squeeze the Moraine interval and above, then run another CBL to verify adequate coverage across the Moraine and above. This Sundry is intended to document the perforations of the new zone, and the subsequent fracture stimulation, as well as request approval to workover the well. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r" Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Rill Tubing Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate . Iter (o•t cas l J"- Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 203 -096 3. Address Stratigraphic r Serv r. 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20460 - 00 7. If perforating, _ r 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool ? �� / � w '� c' Will planned perforations require spacing exception? Yes r No PI .' /) 'J x' 3S -19 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25544 Kuparuk River Field / Kuparuk River 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): 10038 6187 9862' 6033' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108' 108' SURFACE 3550 9.625 3580' 2596' ;:: ^" PRODUCTION 10002 7 10029' 6179' -. „ , > Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9700' -9720' 5893' -5911' 3.5 L - 9647 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - 3 1/2" X 7" BAKER SAB -3 PACKER MD= 9615 TVD= 5820 SSSV - CAMCO 'DS' NIPPLE MD= 499 TVD =496 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory r Stratigraphic r Development P Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/16/2012 Oil l✓ Gas r WDSPL r Suspended r 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: Brett Packer @ 265 -6845 Email: J .Brett.Packer @conocophillips.com Printed Name J. Brett Packer Title: Workover Engineer Signature �_ol c„•&c.,...__ Phone: 265 -6845 Date /G) /Z'; /. / Commission Use Only /J Sundry Number l Z _ J / ( 2 Conditions of approval: Notify Commission so that a representative may witness 1 "I Plug Integrity r BOP Test 57 Integrity Test r Location Clearance r Other: 3 000 / o S G °" JC S 7 Q �vG �/1c,C_ � fi>�Gs c.t 5-74--..-- • re �a. Spacing Exception Required? Yes ❑ No [it Subsequent Form Required: /4 yG 7 9I 1 'C. / Approved by: ISSIONER THE COMMISON Date: / //! / Approve pp - f - is valid1tJff2 months from the date of approval. Form 10-403 (Revised�l0�20 OUPLr Ct T!BDMS OCT 31 ZQ4 ubmit Form and Attachments,in Duplicate s KUP 3S -19 , ConocoPhillips Well Attributes Max Angle & MD TD Alaska II1C . r Wellbore API /UWI Field Name Well Status Inci (°) MD (ftKB) Act Btm (ftKB) ° fanmPh69ps 501032046000 KUPARUK RIVER UNIT PROD 61.56 2,630.84 10,040.0 - -- -- Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NIPPLE 85 11/27/2009 Last WO: 33.03 7/4/2003 Well Confiq. - 3S -19, 182010 schematic 7/-Actual 7:47 06 AM Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,821.0 7/15/2010 Rev Reason: TAG, GLV C/O Imosbor 7/18/2010 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 30.0 108.0 108.0 62.50 H - 40 WELD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _ SURFACE 95/8 8.835 29.5 3,579.6 2,596.1 40.00 L -80 BTC HANGER, 24 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 Tubing Description String 0... !String TUBING 26.5 10,028.6 6,178.7 26.00 L -80 BTCM Tubing Strings ID ... Top (ftKB) 'Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 3 1/2 I 2.992 I 24.1 I 9,647.2 I 5,847.7 I 9.30 I L -80 EUE 8RD Completion Details Top Depth (TVD) Top Inc/ Nomi... Top (RKB) (RKB) ( °) Item Descripti Comme ID (In) 24. 24.1 -0.21 HANGER FMC 31/7' GEN 5 Tbg Hanger w 3-1 tbg. Pup (2.60') on btm 3.500 499.2 498.5 6.31 NIPPLE 3.5" Camco "DS" Nipple w/2.875" NO GO 2.875 9,545.8 5,761.3 31.77 SLEEVE 3.5" Baker CMU sliding sleeve w /Camco 2.817' no go profile, EUE 8RD 2.812 CGND 30-108 9,593.1 5,801.4 31.45 SEAL ASSY Locator Sub & PBR Seal Assembly ( Spaced out 2' above fully landed) 3.000 i 9,595.1 5,803.1 31.44 PBR Baker 312 "80 -40PBR 3.250 NIPPLE, 499 1- I I 9,614.4 5,819.6 31.31 NIPPLE KBH -22 Anchor Tubing Seal Nipple 3.000 9,615.3 5,820.4 31.30 PACKER 3 1/7' x 7" Baker SAB -3 Packer 5.96" OD x 3.25" ID 3.250 9,620.2 5,824.6 31.27 EXTENSION 4 -1/2" 80-40 Mill out Extension 3.720 GAS LIFT, 3,393 9,625.7 5,829.2 31.23 COLLAR 4-1/2" Collar 3.720 9,626.3 5,829.7 31.23 XO- Reducing CROSSOVER 3-1/7' x 4 -1/2" 3.500 • 9,639.4 5,840.9 31.14 NIPPLE 3.5" Camco "D" Nipple w2.75" NO GO 2.750 fl n 9,646.3 5,846.9 31.09 WLEG 312" WLEG with Shear out Sub 4.51" OD 2.950 LI �J Perforations & Slots Shot SURFACE, _y Top (ND) Btm (TVD) Dens 29 -3,580 Top (ftKB) Btm (ftKB) (ftKB) (RKB) Zone Date (sh... Type Comment 9,700 9,720 5,892.9 5,910.9 C -4, 3S -19 7/11/2003 6.0 IPERF 2.5" HSD 2506 PJ, 60 deg ph Notes: General & Safety End Date Annotation 4/27/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 5,878 GAS LIFT, { r 7,672 GAS LIFT. 8,850 cext GAS LIFT, I 9,494 SLEEVE. 9,548 { SEAL ASSY, _ 9,593 PBR, 9,595 NIPPLE. 9,614 MI PACKER, 9,615 -- EXTENSION, 9,620 ll COLLAR. 9.626 ili Illr Mandrel Details Top Depth Top Port NIPPLE. 9.639 (ND) Intl OD Valve Latch Size TRO Run MI Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type IiN (psi) Run Date Corn... 1 3,393.4 2,502.1 60.13 Camco KBUG -M 1 GAS LIFT GLV BK 0.156 2,117.0 7/16/2010 WLEG, 9,646 J 2 5,875.6 3,754.6 59.86 Camco KBUG -M 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2007 3 7,672.4 4,652.0 58.42 Camco KBUG -M 1 GAS LIFT GLV BK 0.188 2,289.0 7/16/2010 IPERF, 111 4 8,849.8 5,284.2 55.49 Camco KBUG -M 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2007 9,700 -9,720 5 9,493.7 5,719.6 36.16 Camco MMM 1 1/2 GAS LIFT OV rdo20 0.188 0.0 7/16/2010 PRODUCTION, 26- 10.029 TD, 10,040 • 3S-19 Rig Workover Pull Tubing, Cement Squeeze Moraine, Install Selective, Patch Casing, Run Tubing (PTD #: 203 -096) Current Status: This well is currently online producing —170 bopd average. Scope of Work: Pull the 3 'h" tubing above the packer, cement squeeze the Moraine interval, install a selective completion across the Moraine, patch the upper squeeze perfs, run new 3 'A" tubing. General Well info: Well Type: Producer MPSP: 1,655 psi using 0.1 psi /ft gradient (Most recent SITP = 397 psi on 8/23/12) Reservoir Pressure /TVD: 2,245 psi / 5,905' TVD (7.31 ppg) from Panex gauges on 4/2/09. Wellhead type /pressure rating: FMC Gen 5, 11" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -OA failed on 7/8/06, CMIT TxIA to be obtained prior to RWO. Earliest Estimated Start Date: November 16, 2012 Production Engineer: Evan Reilly / Jeremy Mardambek Workover Engineer: Brett Packer (265 -6845 / j.brett.packer @conocophillips.com) Pre -Rig Work 1. Shut -in well, freeze protect. Wait 3 days prior to starting pre -rig prep. 2. RU Slickline: a. Pull GLV's & OV from GLM's #1, #3, and #5 and install DV's in same. b. RIH w/ shifting tool and open CMU sliding sleeve at 9,546' MD. c. RIH w/ dual Panex gauges to 9,711' MD, obtain 30 min. SBHP, pull up hole to 9,593' MD and obtain 15 min. gradient stop. d. Install CA -2 plug in D nipple at 9,639' MD. e. CMIT TxIA to 3,000 psi. f. Dump bail 15' of sand on top of plug. (During the RWO, a 7" casing patch will be installed which requires milling out the low- debris aluminum shoe of the patch. Any debris which falls downhole can be milled on top of the sand plug and circulated out with CTU post -rig.) 3. PT tubing and casing packoffs, FT LDS's. 4. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate seawater. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV & blanking plug, ND tree, NU BOPE & test to 250/3,000 psi. 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH laying down 3 '' /z" tubing. a. If tubing will not pull free, RU E -line: Fire a string shot and cut the tubing in the middle of the first full joint above the PBR. b. If tubing was cut, RIH w/ overshot & grapple and pull seal assembly from PBR. 6. Run 7" casing scraper & muleshoe down to the PBR at 9,595' MD. Circulate well clean. POOH. 7. RU E -line: Run 40 -arm caliper, gyro, and RCBL and log from 9,500' back to surface. Determine top of cement behind 7" casing. RD E -line. • 3S-19 Rig Workover Pull Tubing, Cement Squeeze Moraine, Install Selective, Patch Casing, Run Tubing (PTD #: 203 -096) -- Proposed Procedure Continued 8. Set RBP below top of cement. Pressure test to 2,500 psi and drawdown test to 0 psi. Dump 50' sand on top of RBP. POOH. 9. RU E -line: RIH w/ 5 ft perf guns, perforate above TOC as determined in Step #7. POOH. RU another 5 ft of perf guns, RIH to 8,140' MD and perforate 7" casing. POOH. RD E -line. 10. RIH w/ cement retainer, set cement retainer above bottom set of squeeze perfs. 11. RU SLB cementers, establish good circulation rate through squeeze interval taking returns out the IA., pump 10 bbl spacer followed by –50 bbls Class G cement. Un -sting from cement retainer, lay in 1 bbl cement on top of retainer. Reverse circulate remaining cement out of drillpipe. POOH. WOC 6 hrs or until reaches 500 psi compressive strength. 12. RU E -line: RIH w/ RCBL to verify good cement across the Moraine. RD E -line. 13. Mill out cement & cement retainer, dry drill remaining debris on top of sand. Circulate sand from atop the RBP. POOH. 14. RIH w/ RBP retrieving tool, pull RBP. POOH. 15. RU E -line: RIH w/ 20' deep penetrating perf guns, shoot Moraine interval from 8,680' – 8,700' MD. RD E- line. 16. Run 7" casing scraper & muleshoe down to the PBR at 9,595' MD. Circulate well clean. POOH. 17. MU dual Premier packer selective straddle assembly, RIH on drillpipe to just above the PBR. Spot corrosion inhibited seawater in the IA behind the straddle completion. Sting into PBR, space out 7' from fully located. Pressure up to set Premier packers. Release from packer assembly, POOH. 18. RIH & set an IBP 200' below the upper squeeze perfs. Spot 50' of sand on top. 19. Install 7" casing patch across upper squeeze perfs. 20. Mill out patch shoe. PT casing to 2,500 psi. Continue down to sand, mill up any remaining debris. Circulate sand out of well. 21. RIH and pull IBP. 22. MU seal assembly and 3 ' /2" gas lift completion, RIH to PBR until fully located, pull up to neutral weight plus 7', pull out of PBR. 23. Space out w/ pups, MU hanger. Load the IA w/ corrosion inhibited seawater. Land the hanger, RILDS. 24. PT the tubing to 3,000 psi, bleed tubing to 2,500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. Bleed tbg to zero, then IA. 25. Pull the landing joint, install BPV. 26. ND BOPE, NU tree. Pull BPV, install tree test plug. Test tree. Pull tree test plug. 27. Freeze protect through the SOV, set BPV. 28. RDMO. Post -Rig Work 1. Pull BPV. 2. RU Slickline: Pull SOV, replace w/ DV. Open sliding sleeve in selective. D 3. RU SLB Frac Crew: Frac the Moraine interval. —� � i c wow' j 4. RU PTS: Flow test the Moraine interval. U 5. RU Slickline: Close the sliding sleeve. Run GLD. Bail sand from above CA -2 plug. Pull plug. 6. Return well to operations. ConocoPhillips Well: 3S -19 Moraine Test 2012 RWO Proposed Completion )los i 16" 62# H -40 to 108' MD 9 -5/8" 40# L -80 to 3,580' MD J_ ■ New 3 -1/2" Gas Lift Completion 7" Casing Patch 3 -1/2" 9.3# L -80 EUE 8rd Tubing Camco 2.875" 'DS' Nipple @ —500' MD Camco 1 -1/2" MMG Gas Lift Mandrels Upper Squeeze Perfs f;: ■• Baker GBH -22 Seal Assy. (15' seals) ! .7: ieftroist Moraine Straddle Assy. Baker 80 -40 PBR, 20' long Baker 3.5" x 7" Premier Pkr @ XXXX' MD Proposed Moraine perfs: 8,680' - 8,700' MD 0 0 0 - Camco 1 -1/2" MMG Gas Lift (Prod.) Mandrel • !, �0 Baker CMU Sliding Sleeve w/ 2.813" X Profile Camco 2.813" 'X' Nipple Baker 3.5" x 7" Premier Pkr @ MD Lower Squeeze Perfs o • a+': Baker GBH -22 Seal Assy. (15' seals) Existing 3 -1/2" 80-40 PBR @ 9,595' MD I J 4 Existing SAB -3 Packer @ 9,615' MD ))I o 2.75" D Nipple WLEG @ 9,646' MD C -4 sand perfs 9700' - 9720' MD 7" 26# L -80 shoe at 10,029' MD _. • • ;^ -.. F ..^,. Y _'°` ~- ~~ ~_ ~.. ~- ,> ~_. MICROFILMED 03/0112008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\I.aserFiche\CvrPgs_Inserts\Microfilm Marker.doc 11 / I _---- __ __ ~¿~~~==-- 01/02/07 ScblumbBI'DBI' NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 iCANNED JAN 0 8 2007 Company: c:S63 -000 Field: Kuparuk . '..' ~'_'~'~"""__~~"""'"""'..-4'.~.... Well Job # Log Description Date BL Color CD 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N-304 11296737 FBHP SURVEY 11/04/06 1 1D-109 N/A INJECTION PROFILE 11/27/06 1 1J-136 (REDO) 11534188 USIT 12/10/06 1 1R-18 N/A SBHP/DD 12/18/06 1 1G-16 11551836 INJECTION PROFILE 12/19/06 1 1D-103 11548555 INJECTION PROFILE 12/20/06 1 3K-09A N/A SBHP SURVEY 12/22/06 1 3K-26 N/A SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N-326 11551840 SBHP SURVEY 12/24/06 1 35·19 11548564 PRODUCTION PROFILE 12/25/06 1 2M·10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12/26/06 1 2A-20 11548565 INJECTION PROFILE 12/26/06 1 2M-15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J-184 11538775 PRODUCTION PROFILE 12/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . '~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 ;~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 "," t, " ,II- !\) 1-\ ED w ...J f",~, 1, l~· ,J aÖ3-oqlo '3$- ,q Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 cement top-fill operation was completed on November 18, 2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ::Z~ ~ ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field August 7,2006 Well Name Initial top Vol. of cement Final top of Cement top PTD # of cement um ed cement off date ft bbls ft RG casing filler vol. al Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 11, 2004 [ ~Le'15 RE: MWDFormationEvaluationLogs 3S-19, AK-MW-251309 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3~ .--;; C' -} f1 . J;) vI Digital Log Images 50-103-20460-00 }03- oC¡[p 1 CD Rom G /'~ , ; \ ---.-----::¡ '.f> ,_. , :D,~~ "ð/,:?~/ 0& Types Electric or Other Logs Run: GR/Res/Dens-Neut Well Log Information: Log/ Electr Data Digital Dataset .T~Med/Frmt Number Name rnpt·· - 0 Asc Directional Survey (~Pt ~g r: ED þD ,J ED (RPt I \ Rpt (Pt j ~Pt I t ~ L> '&_ DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 AP~ I!. ~3~:6~=O ~ ~ Permit to Drill 2030960 Well Name/No. KUPARUK RIV UNIT 35-19 Operator CONOCOPHILLlPS ALASKA INC MD 10038 ~ TVD 6187"- Completion Date 7/11/2003------- Completion Status 1-01L UI(;) Current Status 1-01L -- -------- --- -- -------~ ------- REQUIRED INFORMATION Mud Log No Directir- ..~ (data taken from Logs Portion of Master Well Data Maint) Samples No - - - -- -- - --- --~ - . - - - - -- - ----- DATA INFORMATION ED 0 Asc Directional Survey Perforation 0 Las 12396 I nd uction/Resistivity 0 Las 12396 Neutron 0 Las 12396 Density 0 Las 12396 Rate of Penetration Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments final 0 10038 Open 7/24/2003 MWD final 0 10038 Open 7/24/2003 5 Blu 9430 9851 Case 8/8/2003 CULLED 2 3558 10005 2/12/2004 GR, EWR4, CNP, SLD, Rap 2 3558 10005 2/12/2004 GR, EWR4, CNP, SLD, ROP 2 3558 10005 2/12/2004 GR, EWR4, CNP, SLD, ROP 2 3558 10005 2/12/2004 GR, EWR4, CNP, SLD, ROP 2 3558 10005 2/12/2004 GR, EWR4, CNP, SLD, ROP 2 3558 10005 2/12/2004 GR, EWR4, CNP, SLD, Rap 2 3558 10005 2/12/2004 GR, EWR4, CNP, SLD, Rap 2 3558 10005 2/12/2004 GR, EWR4, CNP, SLD, ROP Sample Set Sent Received Number Comments ~ c__ I nd uction/Resistivity y ))~~ \J'~{~~ , ~tron \ \, -). ~\I) ~ Density Rate of Penetration ----- - -- --- Well Cores/Samples Information: Name Interval Start Stop Permit to Drill 2030960 MD 10038 TVD 6187 ADDITIONAL INFORMATION Well Cored? Y,® Chips Received? ~ '---- Analysis ~ Received? --- --- ----- --- ---- - ~~- - -------- Comments: -- --- - --- -------- --------- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Well Name/No. KUPARUK RIV UNIT 3S-19 Operator CONOCOPHILLlPS ALASKA INC Completion Date 7/11/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? QyN ~/N Formation Tops 1-0 I Date: API No. 50-103-20460-00-00 UIC N -/ ~~ MÀ.J~j1- '-'" ) ) (J03-09Co WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas ConseIVation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 20, 2003 RE: MWD Formation Evaluation Logs 3S-19, AK-MW-2513099 1 LDWG· formatted Disc with verification listing. =# Jd3 c¡ ~ PùPI#: 50-103-20460-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Artn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Sign~~,--~~~ RECEIVED FI'"-.., 1 r' r'tO~ ·1 -- .-- ; -! ',n t ~ l ....u .... L v(..~ P;J,2~ka Œ! &; Gas Cons. Commission ,~¡fírh~e -'~~-S:J\j\ ~ ) ConocJPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26,2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ) ~~cs· C.. 711E:D A ·0 'r. . Vø,tl1 o¡Z. ' 2003 4Gas~ ~, Dear Mr. Maunder: Enclosed please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on November 18,2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high-pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. ::;; ~( MJZ / ConocoPhillips Problem Well Supervisor Attachment :t:.\- '\ ~ ~~ «.. ~,~(""\.~" ~''-.<t ~\\.\-. +0 Cr k\\ 'o~c...~" cA<:t..~ ~<:tl~~ ';>~<!:. <¡, s1;...) \ \ '-I c..~ ""«. ,",~d -\0 S"'~. 14\\ o~+~ "T()<-'" ~-\-\-..s~~ \::>Q,"' (f\<2..o. \" .\- \....<ë. Sú ~<:.Q:... \--.J 0 .Çù ,-\- \.....~, C\. c...\ \ 0 '"' f'..<l.ct. ~~, '{ , #)!/JlÝ/I~ Á - å ~ ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field Well Well TOC Volume 8acks Name PTD# Type ft BBLS Cement 38-03 2030910 Prod 8 0.6 3.6 38-07 2021870 Prod 8 1.5 9.1 38-09 2022050 Inj 14 2.5 15.1 38-10 2022320 Prod 12 1.5 9.1 38-14 2022210 Inj 3 1.5 9.1 38-15 2022540 Prod 8 0.8 4.8 38-17 A 2030800 Prod 12 1.1 6.6 38-18 2022060 Prod 10 1.1 6.6 3S-19 2030960 Prod 5 1.1 6.6 38-21 2030310 Inj 5 0.5 3.0 38-22 2030110 Inj 7 0.9 5.4 38-23 2030450 Prod 2 0.3 1.8 ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged D Abandoned D 20AAC 25.105 No. of Completions _ GINJ D 2. Operator Name: WINJ 0 WDSPL 0 ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 2542' FNL, 1169' FEL, Sec. 18, T12N, R8E, UM At Top Productive Horizon: 2184' FNL, 3517' FEL, Sec. 13, T12N, R7E, UM Total Depth: 2176' FNL, 1597' FWL, Sec. 13, T12N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476091 y- TPI: x- 468939 y- Total Depth: x· 468773 y- 18. Directional Survey: Yes 0 NoU 5993874 5994258 5994268 Zone-4 Zone-4 Zone-4 21. Logs Run: GR/Res/Dens-Neut 22. Suspended 0 WAG 0 20AAC 25.110 Other 5. Date Comp., Susp., ¡ I AÒ or Aband.: July;l(2003 6. Date Spudded: June 23,2003 7. Date TD Reached: June 30, 2003 8. KB Elevation (ft): RKB 28' 1 87' AMSL 9. Plug Back Depth (MD + TVD): 9862' MD 1 6033' TVD 10. Total Depth (MD + TVD): 10038' MD 1 6187' TVD 11. Depth where SSSV set: Land Nipple @ 499' 19. Water Depth, if Offshore: N/A feet MSL CASING SIZE WT. PER FT. 16" 62.5# 9.625" 40# 7" 26# GRADE B L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 3579' Surface 10029' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 9700' - 9720' MD 5893' - 5910' TVD 6 spf HOLE SIZE 1b. Well Class: Development 0 Exploratory 0 Service D Stratigraphic Test 0 12. Permit to Drill Number: 203-096 1 13. API Number: 50-1 03-20460-00 14. Well Name and Number: 3S-19 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25544 17. Land Use Permit: ALK 2639 20. Thickness of Permafrost: 1645' MD 42" 86 sx ArcticCrete CEMENTING RECORD AMOUNT PULLED 7" 440 sx AS III Lite, 330 sx LiteCrete 250 sx GasBlok 12.25" 24. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 9647' PACKER SET (MD) 9615' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 7,2003 Flowing Date of Test Hours Tested Production for Oll-BBL GAS-MCF WATER-BBL 8/9/2003 12.5 hours Test Period --> 1034 397 189 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBl press. 264 psi 309 24-Hour Rate -> 1855 931 362 27. CORE DATA CHOKE SIZE GAS-Oil RATIO 502 100% OIL GRAVITY - API (corr) not available ~.- --:-'·-'-=--~T~;'~; ~~i·l 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". I ~';: ;t::; : 7'1(t?3~ _:lÄ~;:.:... ~ NONE Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE OQIGINAL 0: i' :1.'"1:3 RBDMS SFL / \..... G AU6 S2b~t i~jate 28. ') 29. ) GEOLOGIC MARKERS 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". 38-19 Kuparuk Unit C Kuparuk Unit 0 Kuparuk Unit B 9701' 9701' 9719' 5894' 5894' 5909' 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: Skip Coyner 265-6074 Printed Na~ R. T~omas . Title: Signature \ ~Ç..~ \ \"~ne J-I(..il /";, t'ß'.. -:? ~_....~_. - Kuparuk Drilling Team Leader Date -g' ((elo7 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 Oq~GtNAL ) ') . . ... . . ... : .....: "."":.":.': :..: "."... ",."..". . ..... . ":" ".' ...... ... ...... ... ..... ,." . ..... ... '" .. ...... . . . ..' . .... . .... ...... ..", . .. .... ........",.". " . ...... . . ... ... . .. "li'f' ',. '" mºrî:ç~~~illipR¡~I~~~~::\i·l i,','.···.·i··.·" ¡Qp~r-ª~i().,~~P.......roªr-yR~pp·rt: ..' . Rigged down and moved rig to 3S-19. Rigged up. Set berms around Ball mill and injection skid. Took on water in mud pits. Nippled up riser and set berms around rig. Loaded BHA into pipe shed. Serviced rig and top drive. Connected blower hose to TD. Picked up and oriented BHA #1. Rigged up slick line for Gyro. Filled riser and tested surface line. Checked riser and flowline for leaks. Drilled 12 1/4" Directional hole from 108' to 759'. ART 2.01 Hrs. AST 3.03 Hrs. TD RPM 60, WOB 25 K, GPM 450, PP 1177 PSI. Up wt. 63 K, Down 63 K, Rot. 63 K. Torque Off Btm. 1000, On 2500 Ft. Lbs. Used Gyro survey to -400'. Drilled 12 1/4" Directional hole from 759' to 1350'. ART .95 Hrs. AST 2.94 Hrs. TO RPM 60, WOB 25 K, GPM 450, PP 1200 PSI. Up wt. 75 K, Down 65 K, Rot.70 K. Torque Off Btm. 2000, On 5000 Ft. Lbs. Circulated while repairing motor on shale shaker. Drilled 12 1/4" Directional hole from 1350' to 3070'. ART 5.87 Hrs. AST 6.3 Hrs. TD RPM 60, WOB 25 K, GPM 563, PP 2044 PSI. Up wt. 85 K, Down 69 K, Rot. 80 K. Torque Off Btm. 4000, On 8000 Ft. Lbs. Drilled 12 1/4" Directional hole from 3070' to 3590'. ART 2.6 Hrs. AST 1.32 Hrs. TO RPM 90, WOB 25 K, GPM 563, PP 2044 PSI. Up wt. 98 K, Down 77 K, Rot. 86 K. Torque Off Btm. 5000, On 9000 Ft. Lbs. Circulated pumped back to back sweeps. Lost 500 PSI pump rressure while circulating. POOH to 909', laid down wash out 8 stands out, washed out in slip area. Back reamed from 1742' to 1340'. POOH HWDP and laid down BHA. Rigged up to run casing and PJSM. Ran 43 Jts 9 5/8" 40# L-80 BTC casing. Jt # 4 would not make up. Changed out Jt. 4 and replaced with one of the same length. Broke circulation every 1000'. Washed and worked down Jts 37 - 40. Ran Jt 41 and 42. Working through bridge from 1764' to 1767'. Slow progress. Continiued working through bridge. Ran 42 Jts casing 40# L-80 BTC to 3550'. Picked up landing Jt. and landed casing on the hanger. Rigged down casing fill up tool and rigged up cement head. Circulated and conditioned mud for cementing. RU Dowell, Pumped 10 bbls CW 100 Chern Wash, Tested Lines to 3,500 Psi, Pumped 40 bbls CW 100 Chem Wash at 8.3 ppg @ 6 Bpm @ 175 Psi, Red Dye in CW 100 Spacer, Dropped Btm Plug, Mixed & Pumped 327.7 bbls, 440 sxs of Lead Cmt. Arctic Set @ 10.7 ppg & 4.28 Yield, Ave rate 6.3 bpm @ 260 Psi, , Observe Nut Plug at Shaker followed by red dye. Switched to Tail Cmt, Pumped 330 sxs (134 bbls) of Lite Crete Cmt @ 12.0 ppg & 2.29 Yield, Pumped @ 6.4 Bpm @ 230 Psi, Dropped Top Plug & Dowell Pumped 20 bbls Wash Water, Turned over to Rig, Rig Pumped 245.0 bbls of 9.5 ppg mud, Ave Disp Rate 7.5 bpm @ 500 Psi, Reciprocated Pipe Until Lead Cmt was at surface -Landed Csg, Slowed to 4 bpm @ 400 Psi, Bumped Plug with 930 PSI, Used 95% Eft on Rig Pumps to calc.displacement, Had 140 bbls of 10.7 ppg Cmt back to Surface, Had Full Returns throughout Job- CIP at 0930 Hrs 6/26/03, Check Floats & Held 1.75 CASE RURD SURFAC Flushed flowline and riser. Rigged down cement head. Backed out Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-19 3S-19 ROT - DRILLING N1268@ppco.com Nabors 7ES . .. ...". . "." ". . '. ," ..... .. .... [)~te ... ·.FrÖm.J1"ò. HölJrs ..cöde8oU:é Phase.· 6/23/2003 00:00 - 05:00 5.00 MOVE MOVE MOVE 05:00 - 08:00 3.00 MOVE RURD RIGUP 08:00 - 11 :30 3.50 WELCTL NUND RIGUP 11 :30 - 12:30 1.00 RIGMNT RSRV SURFAC 12:30 - 15:30 3.00 DRILL PULD SURFAC 15:30 - 16:00 0.50 DRILL OTHR SURFAC 16:00 - 00:00 8.00 DRILL DRLG SURFAC 6/24/2003 00:00 - 06:00 6.00 DRILL DRLG SURFAC 06:00 - 07:45 1.75 RIGMNT RGRP SURFAC 07:45 - 00:00 16.25 DRILL DRLG SURFAC 6/25/2003 00:00 - 05:45 5.75 DRILL DRLG SURFAC 05:45 - 08:00 2.25 DRILL CIRC SURFAC 08:00 - 12:00 4.00 DRILL TRIP SURFAC 12:00 - 15:00 3.00 DRILL TRIP SURFAC 15:00 - 17:15 2.25 CASE RURD SURFAC 17:15 - 22:00 4.75 CASE RUNC SURFAC 22:00 - 00:00 2.00 CASE RUNC SURFAC 6/26/2003 00:00 - 00:45 0.75 CASE RUNC SURFAC 00:45 - 03:00 2.25 CASE RUNC SURFAC 03:00 - 03:30 0.50 CASE PUTB SURFAC 03:30 - 04:15 0.75 CASE RURD SURFAC 04:15 - 07:00 2.75 CEMENTCIRC SURFAC 07:00 - 09:45 2.75 CEMENT PUMP SURFAC 09:45 - 11 :30 Start: 6/23/2003 Rig Release: 7/4/2003 Rig Number: Spud Date: 6/23/2003 End: 7/11/2003 Group: : :".:. . . .:....:.".: .." : ... .....", ".... . . .. . peSGript~()nc)f()þê.r~tidns Printed: 8/12/2003 3:52:10 PM ) ) landing Jt. and rigged down casing tools. Nippled down riser and installed FMC speed head. Nippled up BOP. Tested BOP's, Choke Manifold, Rams, & Valves to 250 psi Low, 5,000 Psi High, Annular to 250/3,500 psi, with Test Pump, Note: Chuck Shivie with AOGCC Witnessed Test, RD Test Tools. Installed wear bushing. Picked up and stood back 63 Jts. of drill pipe. Rigged up to pick up BHA. Picked up BHA # 2. RIH Flex collars and HWDP. Slipped and cut drilling line, serviced rig and top drive. changed saver sub in top drive. RIH picking up DP to 3453' tagged cement. CBU. Rigged up and tested casing to 2600 PSI for 30 min. Drilled out shoe track and cleaned rat hole. Drilled 20' of new hole to 3610'. Displaced LSND mud into hole. Did FIT to 18 PPG EMW. Drilled 8 1/2" Directional hole from 3610' to 4797'. ART 5.48 Hrs. AST .99 Hrs. TD RPM 100, WOB 15/25 K, GPM 550, PP 1800 PSI. Up wt. 133 K, Down 78 K, Rot. 95 K. Torque Off Btm. 7000, On 7500 Ft. Lbs. Drilled 81/2" Directional hole from 4797' to 5134'. ART 2.75 Hrs. AST 0 Hrs. TD RPM 100, WOB 20 K, GPM 563, PP 2144 PSI. Up wt. 120 K, Down 77 K, Rot. 100 K. Torque Off Btm. 7000, On 8000 Ft. Lbs. Circulated while changed swab in mud pump #2. Drilled 8 1/2" Directional hole from 5134' to 5928'. ART 3.33 Hrs. AST .17 Hrs. TO RPM 100, WOB 20 K, GPM 563, PP 2200 PSI. Up wt. 130 K, Down 78 K, Rot. 100 K. Torque Off Btm. 8000, On 8000 Ft. Lbs. Circulated while changing swab in #1 pump. Cleaned suction screens in both pumps. Drilled 81/2" Directional hole from 5928' to 6900'. ART 6.18 Hrs. AST .3 Hrs. TD RPM 100, WOB 20 K, GPM 550, PP 2200 PSI. Up wt. 150 K, Down 93 K, Rot. 108 K. Torque Off Btm. 9500, On 10,000 Ft. Lbs. Drilled 81/2" Directional hole from 6900' to 8401'. ART 7.61 Hrs. AST .67 Hrs. TO RPM 100, WOB 20 K, GPM 550, PP 3000 PSI. Up wt. 150 K, Down 93 K, Rot. 114 K. Torque Off Btm. 10000, On 11,500 Ft. Lbs. Circulated while changed swab in pump #2 and cleaned suction screens in both pumps. Resuned circulation and lost 800 PSI. Checked pumps and surface equipment. Tripped for wash out. Found hole in slip area 23 stands out. Changed out bad joint and RIH. Drilled 8 1/2" Directional hole from 8401' to 8628'. ART 1.63 Hrs. AST .0 Hrs. TD RPM 100, WOB 20 K, GPM 550, PP 3000 PSI. Up wt. 153 K, Down 93 K, Rot. 123 K. Torque Off Btm. 10,000, On 10,000 Ft. Lbs. At 8550' started control of ECD from 2.5 over MW to 2 PPG over MW. 15.25 DRILL DRLG INTRM1 Drilled 8 1/2" Directional hole from 8628' to 9683'. ART 6.58 Hrs. AST 2.72 Hrs. TO RPM 100, WOB 20 K, GPM 500, PP 3000 PSI. Up wt. 170 K, Down 106 K, Rot. 126 K. Torque Off Btm. 12,500, On 13,500 Ft. Lbs. Continiued control of ECD to 2 PPG over MW. 2.00 DRILL CIRC INTRM1 Monitored hole for losses. Mixed LCM and loss declined to less than 10 Legal Well Name: 3S-19 Common Well Name: 3S-19 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7ES . . .. . ... .. .... . ·SÜb ,Date . Ftbm...To . Hours·. ·..Còqè ··CÓdé ,Phase 6/26/2003 09:45 - 11 :30 1.75 CASE RURD SURFAC 11 :30 - 13:30 2.00 WELCTL NUND SURFAC 13:30 - 15:00 1.50 WELCTL NUND SURFAC 15:00 - 18:00 3.00 WELCTL BOPE SURFAC 18:00 - 18:30 0.50 DRILL OTHR SURFAC 18:30 - 23:45 5.25 DRILL PULD SURFAC 23:45 - 00:00 0.25 DRILL PULD SURFAC 6/27/2003 00:00 - 03:00 3.00 DRILL PULD SURFAC 03:00 - 03:45 0.75 DRILL TRIP SURFAC 03:45 - 06:30 2.75 RIGMNT RSRV SURFAC 06:30 - 09:30 3.00 DRILL TRIP SURFAC 09:30 - 09:45 0.25 DRILL CIRC SURFAC 09:45 - 11 :00 1.25 DRILL OTHR SURFAC 11 :00 - 12:30 1.50 DRILL DRLG SURFAC 12:30 - 13:00 0.50 DRILL CIRC SURFAC 13:00 - 13:45 0.75 DRILL FIT SURFAC 13:45 - 00:00 10.25 DRILL DRLG INTRM1 6/28/2003 00:00 - 04:00 4.00 DRILL DRLG INTRM1 04:00 - 04:30 0.50 RIGMNT RGRP INTRM1 04:30 - 13:00 8.50 DRILL DRLG INTRM1 13:00 - 14:00 1.00 RIGMNT RGRP INTRM1 14:00 - 00:00 10.00 DRILL DRLG INTRM1 6/29/2003 00:00 - 15:15 15.25 DRILL DRLG INTRM1 15:15 - 16:30 1.25 RIGMNT RGRP INTRM1 16:30 - 17:30 1.00 DRILL OTHR INTRM1 17:30 - 19:45 2.25 DRILL TRIP INTRM1 19:45 - 00:00 4.25 DRILL DRLG INTRM1 6/30/2003 00:00 - 15:15 15:15 - 17:15 Start: 6/23/2003 Rig Release: 7/4/2003 Rig Number: Spud Date: 6/23/2003 End: 7/11/2003 Group: . .. .' .' ."... . . ... ... ...... . . . . . ... ". .... ........". .". . ". ...... ... .. ... ... ............. ..... .. . . . ... . '[)è~criþtiøh blÇ>þ~réltionS··· Printed: 8/12/2003 3:52:10 PM ) ) . ... .. . ."' ... .". .. . .. ..... . ..... ..... . . ..".. ... .. .. . . ... .", . .:" : ":'" ....:..... .. ... ... . ... ....... '" . ......... . . . . . .... .. ....... ". .. .." .. .. . .. .. '>:i~···,·,i~.·.·.¡Ç9~RÇ~~hlI1iþ~~I,~~kª<¡..¡ ... ...,.. ... .L ..... '··:gp~rª_iøl1$:J~qmQ1Ç1rY!I~P9r~ "..". 2.00 DRILL CIRC INTRM1 Bbls Hr. Max gas 400 IU. 5.25 DRILL DRLG INTRM1 Drilled 8 1/2" Directional hole from 9683' to 10038'. ART 3.97 Hrs. AST o Hrs. TO RPM 100, WOB 20 K, GPM 500, PP 3000 PSI. Up wt. 170 K, Down 106 K, Rot. 126 K. Torque Off Btm. 14,500, On 15,000 Ft. Lbs. Continiued control of ECD to 2 PPG over MW. Top of C sand 9701' MD 5894' TVD. Base 9719' MD 5909' TVD. Losses increased when we enrered the sand and had 2500 IU gas while drilling. Drill rates slowed for logs. Pumped sweep and circulated out. POOH to wipe hole. Back reamed to prevent swabbing. Wipe hole to 8468'- Pumped out to 9595' due to mild swabbing, Pulled to 9128' (40K drag @ 9100'), Pumped out fl 9128' to 8752', Pulled to 8468', RIH went good, Precautionary ream fl 9972' to 10038' Circ. & condo mud fl 7" casing, Pump 25 bb114.3 ppg Hi-Vis sweep, Circ total of 4.5 btm's up wI 500 gpm @ 2800 psi, Trip gas 450 units, Spot 40 bbls 15 ppb G-Seal pill on btm. Monitor well, POOH (SLM) to BHA, Monitor well PJSM, Remove RA Sourse, Down load MWD, Lay down BHA Pull wear bushing Rig to run 7" casing, PJSM wI crew Run 7",26#, L-80, BTCM casing & centralizers to 2945' Run 7",26#, L-80, BTCM casing fl 2,945' to 10,000' running speed 30/40 fpm, Break circ every 15 jts.f/15 min. (Displacement returns full then declining to zero after 15 jts.- but displacement improved after passing C-40 @ 6491'), Circ btm's up @ 3545' & 7825'. Make up hanger & landing joint, Land shoe @ 10,028' Circ & condo mud, stage pump rate up fl 2.5 bpm @ 800 psi to 5 bpm @ 780 psi, Had 110 units trip gas on btm's up, Condition mud to 11.5 ppg, 50 vis, PV 16, YP 17, Gels 4/8/12, Lossing 12-15 bph mud. Rig down Franks tool & Rig up Dowell cmt. head PJSM wI all crews, Circ @ 5 bpm wI 630 psi while batch mix cmt. Rig Dowell, Batch mix 40 bbls CW1 00 @ 8.3 ppg, 40 bbls MudPUSH @ 12.5 ppg, 250 sxs (52.0 bbls) @ 15.8 ppg Class "G" GasBLOK wI .300%BWOC D155, .350%BWOC D65, 2.000 gal/sk D600G, .200 gal/sx 047, Pump 10 bbls CW100, Test lines to 3500 psi, Pump 30 bbls CW100, Pump 40 bbls MudPUSH at rate of 5 bpm at 730 psi, Drop btm plug, Pump 52.0 bbls cmt at rate of 5 bpm @ 760 - 530 psi, Shut down, Flush lines to rig floor wI sea water, Drop top plug, Dowell displaced 360 bbls seawater at rate of 5.5 bpm @ 1360 psi until 20 bbls prior to bumping plug, Slowed rate to 3 bpm @ 1300 psi & bumped plug wI total of 390.0 bbls, Bumped plug wI 2000 psi, Bled back 2.75 bbls for a total of 387.2 total bbls displaced (Calculated 387.4 bbls), CIP @ 1835 hrs 7/2/2003, Had good circ. thru out job - no noticeable mud loss, Displaced entire job wI Dowell, Worked casing 15 thru out job until last 20 bbls of displacement, then landed in hanger, Floats head good, Check flow- well static. Flush stack wI fresh water, Rig down Dowell cmt. head, Landing joint, Casing equip. Rig & run FMC 7" x 9-5/8" Pack off, Test same to 5000 psi-OK PJSM, Rig to run 3-1/2" completion string Pick up & run 3-1/2" completion string. PU and RIH with completion on 303 Jts 3 1/2" 9.3# L 80 EUE tubing to 9647'. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-19 3S-19 ROT - DRILLING N 1268 @ ppco.com Nabors 7ES . ....,........,....,. .......... ·S.·t.l.,.b.··.·.... HOUts" ·.,GÖd~ COde' Phase ..,. 6/30/2003 15:15 - 17:15 17:15 - 22:30 22:30 - 23:30 1.00 DRILL CIRC INTRM1 23:30 - 00:00 0.50 DRILL WIPR INTRM1 7/1/2003 00:00 - 03:45 3.75 DRILL WIPR PROD 03:45 - 07:00 3.25 DRILL CIRC PROD 07:00 - 14:00 7.00 DRILL TRIP PROD 14:00 - 16:45 2.75 DRILL PULD PROD 16:45 - 17:15 0.50 CASE RURD PROD 17:15 - 18:45 1.50 CASE RURD PROD 18:45 - 00:00 5.25 CASE RUNC PROD 7/2/2003 00:00 - 11 :15 11.25 CASE RUNC PROD 11:15-11:30 0.25 CASE RUNC PROD 11 :30 - 15:00 3.50 CEMENT CI RC PROD 15:00 - 15:30 0.50 CEMENT PULD PROD 15:30 - 16:45 1.25 CEMENT PUMP PROD 16:45 - 18:45 2.00 CEMENT PUMP PROD 18:45 - 20:45 2.00 CEMENT RURD PROD 20:45 - 21 :30 0.75 CASE DEQT PROD 21 :30 - 22:30 1.00 CMPL TN RURD PROD 22:30 - 00:00 1.50 CMPL TN RUNT PROD 7/3/2003 00:00 - 08:15 8.25 CMPL TN RUNT PROD Start: 6/23/2003 Rig Release: 7/4/2003 Rig Number: Spud Date: 6/23/2003 End: 7/11/2003 Group: ... :." .....:":.:.:" ..".."... .".' ..... .... ..... . .. ... ... ... . .. .... .... ......... ... [)èsÞriptiqnötq>Þ~rati()r~L···.' .. Printed: 8/12/2003 3:52:10 PM ) ) . ·.""0......" .... . .. . .. . ..... ... ... ",.. . . .. ..... . .' .... .. ...... .. ........ .. .. .. ....... ",. .' .... .... .. .......... ...... . ."... .... '.,. . ..... ... ..... ... ..."..... .. 0""·.... ..".. ... . ..... . . .. ... .. . . . ....... ....... ......." .. ............. ...... ..", ... ... ....... ..' . '. ·C'.'i;r·;,.·.·i;.t.rmøpp~~~þill.iP~:~ITI~~~j·:.,~··..·.,t;..,;,.., .... · ..··¡'~pc:!r~tiC?n.!>$I.II'1"IQ1.éJtyf'fëp()~~.·: Note: Released rig at 1200 hrs to begin stack out procedures. Cleaned front side of C- section wind walls, Cleaned inside of C- section torque - tube side of derrick, Cleaned out pipe racks drip pans, Washed down top drive, Drawworks drip pan, Rigged down ball mill. Worked on stack out procedures on ball mill, Injection skid, Cleaned pits & under shakers, Cleaned under rig floor drip pans, Replace seals in clutchs on drawworks, UD bails & elevators, Broke out pump-in sub on test joint, Cleaned rig floor, Took tongs down, Installed spreader in A-leg, Made up 5' pup on top drive & set in rotary table. Performed stack out procedures on rotary table & traveling blocks. Laid down kelly hose, Disconnected blocks f/ top drive, Installed bridle line in derrick, Broke out stand pipe & cement lines, Performed visual inspection on derrick. Removed directional shack on top of rig, Rigged to lay down derrick, PJSM & laid down derrick. Worked on stack out procedures on iron roughneck, top drive, choke manifold, cleaned derrick, acidized boiler #2. Worked on stack out procedures in pits, Motors, Top drive & rig floor, Also washed derrick, apply bridle line lube to bridle line, Blew down, water & steam in ball mill, Electrician installing VCI in electric boxes, Pulled 2 brine pumps, Tore out mud lines between the mud pits. 12.00 MOVE DMOB MOVE Worked on stack out procedures in pits, Acidize boiler #2, Cleaned on derrick & ball mill. 12.00 MOVE DMOB MOVE Work on stack out procedures, Clean on derrick and rig floor, Install Legal Well Name: 38-19 Common Well Name: 38-19 Event Name: ROT - DRILLING Contractor Name: N1268@ppco.com Rig Name: Nabors 7ES .. . .......... ··..···.·.Sub båte .FrÒn1.~tÒHQl.Irs9?9~ -¢qq~.. Phå$e 7/3/2003 08:15 - 09:30 09:30 - 1 0:45 1.25 CMPL TN DEOT PROD 1.25 CMPL TN PCKR PROD 10:45 - 12:00 1.25 CMPL TN SOHO PROD 12:00 - 13:00 1.00 CMPL TN DEOT PROD 13:00 - 14:00 1.00 CMPL TN RURD PROD 14:00 - 17:15 3.25 CMPL TN NUND PROD 17:15 - 20:45 3.50 CMPL TN NUND PROD 20:45 - 22:30 1.75 CMPL TN NUND PROD 22:30 - 00:00 1.50 CMPL TN FRZP PROD 7/4/2003 00:00 - 02:00 2.00 CMPL TN FRZP PROD 02:00 - 03:00 1.00 CMPL TN OTHR PROD 03:00 - 12:00 9.00 MOVE DMOB MOVE 12:00 - 00:00 12.00 MOVE DMOB MOVE 7/5/2003 00:00 - 06:00 6.00 MOVE DMOB DEMOB 06:00 - 09:00 3.00 MOVE DMOB DEMOB 09:00 - 12:00 3.00 MOVE DMOB DEMOB 12:00 - 18:00 6.00 MOVE DMOB DEMOB 18:00 - 00:00 6.00 MOVE DMOB DEMOB 7/6/2003 00:00 - 12:00 12.00 MOVE DMOB MOVE 12:00 - 00:00 7/7/2003 00:00 - 12:00 Start: 6/23/2003 Rig Release: 7/4/2003 Rig Number: Spud Date: 6/23/2003 End: 7/11/2003 Group: .. .... .... .. ",.. ......... ...... ....... [)~~criþti()h>of()per~ti()rl$ .. Rig & test 7" casing to 3500 psi for 30 min.- OK Drop Baker 2" packer setting ball. Will set SAB-3 packer @ 9647.23', Slowly pressure 3-1/2" tbg. to 2500 psi. Wait 5 min., Bleed pressure to zero. Slack off to 40K (20K on pkr) to comfirm packer set, then pressure tbg string to 3000 psi and hold 5 min. Bleed pressure to 1500 psi. PU to 125K (PBR sheared), Slack back off to 40K. Check & tag locator w/ 15K. Pressure tbg to 3800 psi to shear ball seat- Very good indication of ball sheared. Bleed off all pressure. (Note; Perform injectivity test on 7" x 9-5/8" annulus, EMW of 15.2 ppg using 11.5 ppg mud with 500 psi @ 9-5/8" shoe 3580' MD & 2595' TVD) Pull jt. #304 out of hole (pulling 17' out of PBR). M/U 3-1/2" FMC tubing hanger on jt. # 303, Use jt. #304 as landing jt., RIH & land tubing w/ locator 2' above fully located in PBR, RILDS. Rig pumping lines. (Note; Flush 7" x 9-5/8" annulus with 200 bbls fresh water & freeze protect with 70 bbls diesel) Pressure 3-1/2" tubing to 3500 psi f/ 15 min. Bleed pressure to 1500 psi. Pressure 3-1/2" x 7" annulus to 3500 psi f/ 15 min (Pressure on tubing increase to 2000 psi). Bleed tbg pressure to zero, DCR valve sheared, Bleeding both sides to zero. All test were charted. Blow down all lines, Rig down all lines, Lay down landing joint, Set TWC Remove all rams and clean same Nipple down BOP - Remove BOP lift ring from hydril Nipple up & test tree to 5000 psi- OK Pull TWC, Rig & freeze protect well with 145 bbls diesel down tubing. Continued to freeze protect well w/ 145 bbls diesel while slipping & cutting drilling line 127', Blew down & rigged down all lines. Rigged lubricator & set BPV, secured tree Rig & lay down drill pipe from derrick Printed: 8/12/2003 3:52: 10 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-19 3S-19 ROT - DRILLING N 1268 @ ppco.com Nabors 7ES Start: 6/23/2003 Rig Release: 7/4/2003 Rig Number: Spud Date: 6/23/2003 End: 7/11/2003 Group: From-"TPHPursùöde£Jle .Ph~se . 7/7/2003 00:00 - 12:00 12:00 - 00:00 7/8/2003 00:00 - 12:00 12.00 MOVE DMOB MOVE 12.00 MOVE DMOB MOVE 12.00 MOVE DMOB MOVE 12:00 - 00:00 12.00 MOVE DMOB MOVE 7/9/2003 00:00 - 12:00 12.00 MOVE DMOB DEMOB 12:00 - 00:00 12.00 MOVE DMOB DEMOB 7/1 0/2003 00:00 - 23:00 23.00 MOVE DMOB DEMOB 23:00 - 00:00 1.00 MOVE DMOB DEMOB . .. .. - ... . .. . . . ... ··..D~sçHptiqnof öp~råtiÒnš·· VCI in ball mill, Clean on cellar area, Remove FMC riser connector from 20" riser, Eletricians working on taking out touch screens from console, Pitwatcher change out mud hopper, Check tire pressure on pits, ball mill & sub. Work on stack out procedures, Clean on motor room, Work on RAA- SAA products in pits & rig, Clean pipe shed, Remove hydralic lines on BOPE. Finish break nuts on stack, Pick up & clean in cellar area, Working on stack out procedures, Blow down pits & ball mill, Pull last brine water pump, Check brine water tanks for solids-OK, pick up & put away tools, Pump out & clean hot well, Straighten up around parts house. Follow rig stack out procedures, Help rig elect. and mech. work on boilers, blow down steam on sub complex, work on SAA - RAA items, Cover stacks and vents on pits and sub complexes. Continued Nabors' "cold Stack" procedure. Covered stacks, build boxes for shipping, cleaned up location, disconnected electric lines between modules and moved ball mill, pits. Cleaned cellar area, washd down cellar area and windwalls, plugged vents, prepared for rig move. Continued with Nabors' cold stack procedures: cleaned and secured rig equipment while waiting on Peak's trucks to return from Doynon 141. Peak trucks returned at 23:00 hours. Tied on to camp to moving same. Printed: 8/12/2003 3:52:10 PM Date 07/10/03 07/11/03 ') ) 35-19 Event History Comment DRIFTED TBG WI 22' X 2.5" HC DMY GUN & TAGGED @ 9858' RKB, EST. 138' BELOW TARGET PERF OF 9720' RKB. SET DV @ 9493' RKB. Pff TBG & IA 3000 PSI, BOTH GOOD. [TAG, GLV, PT TBG-CSG] PERFORATING. FIRST RUN: LOG JEWELRY FROM TD (*** TAGGED AT 9852' ****) TO 9450'. SBHP @ 1300 PSI WHP WAS 3650 PSI. SECOND RUN: SHOOT INTERVAL: 9700' - 9720'. CORRELATED TO SS MWD DGR I EWR LOG FINISHED 4 JULY 2003. WHP = 0 PSI AT TIME OF FIRING & WELL SHUT IN. ESTIMATED 1100 PSI UNDERBALANCE WHP 250 PSIIMMEDIATEL Y AFTER FIRING, 1250 PSI STABLE. 2.5" HSD 6 SPF, 60 DEG PHASING, 2506 POWERJET HMX CHARGES. ALL SHOTS FIRED. THIRD RUN: STATIC BHP @ 9710' (CENTER OF PERFS) WAS 3413 PSIA, BHT=162 DEGF. WELL LEFT SHUT IN. ..... Page 1 of 1 8/13/2003 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3S-19 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 10,038.00 I MD (if applicable) ) 20-Jul-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) t-1J 3 ·-D q <0 RECEIVED JUL 24 2003 þJ88kaœ~~~ Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 35 Pad 35-19 Job No. AKZZ0002513099, Surveyed: 30 June, 2003 Survey Report 17 July, 2003 Your Ref: API 501032046000 Surface Coordinates: 5993874.02 N, 476091.01 E (70023' 39.8133" N, 150011'40.3099" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 993874.02 N, 23908.99 W (Grid) Kelly Bushing: 56.03ft above Mean Sea Level Elevation relative to Project V Reference: 56.03ft Elevation relative to Project V Reference: 56.03ft ·""'-'I'Y-SLJr1 DRIL.LING SERVices A Halliburton Company DEFINITIVE -. -. Survey Ref: svy2050 Sperry-Sun Drilling Services )EF N TIVE Survey Report for Kup,ruk 38 Pad - 38-19 Your Ref: AP/501032046000 Job No. AKZZOOO2513099, Surveyed: 30 June, 2003 ConocoPhiflips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -56.03 0.00 0.00 N 0.00 E 5993874.02 N 476091.01 E 0.00 Tolerable Gyro 82.00 0.000 0.000 25.97 82.00 0.00 N O.OOE 5993874.02 N 476091.01 E 0.000 0.00 179.00 0.350 270.000 122.97 179.00 0.00 N 0.30W 5993874.02 N 476090.71 E 0.361 0.30 AK-6 BP _IFR-AK 294.89 2.730 289.300 238.81 294.84 0.91 N 3.26W 5993874.94 N 476087.76 E 2.073 3.30 384.69 4.350 296.820 328.44 384.47 3.16 N 8.31 W 5993877.20 N 476082.71 E 1.873 8.47 ""..- 477.12 5.880 295.640 420.49 476.52 6.79 N 15.71 W 5993880.86 N 476075.32 E 1.659 16.04 .- 568.89 7.660 291.050 511.62 567.65 11.02 N 25.66 W 5993885.12 N 476065.39 E 2.026 26.20 659.04 10.870 287.810 600.58 656.61 15.78 N 39.36 W 5993889.92 N 476051.70 E 3.606 40.13 749.49 13.940 285.100 688.91 744.94 21.22 N 58.00 W 5993895.43 N 476033.07 E 3.454 59.04 840.11 16.220 284.380 776.41 832.44 27.21 N 80.81 W 5993901.49 N 476010.29 E 2.524 82.12 936.20 18.120 284.590 868.21 924.24 34.31 N 108.27 W 5993908.68 N 475982.85 E 1.978 109.92 1030.05 21.490 280.490 956.50 1012.53 41.12N 139.31 W 5993915.58 N 475951.84 E 3.882 141.27 1123.33 24.300 275.610 1042.43 1 098.46 46.11 N 175.22 W 5993920.69 N 475915.94 E 3.633 177.39 1220.69 25.330 275.490 1130.80 1186.83 50.06 N 215.89 W 5993924.77 N 475875.28 E 1.059 218.21 1313.09 28.670 273.650 1213.12 1269.15 53.36 N 257.69 W 5993928.20 N 475833.49 E 3.726 260.13 1407.07 30.730 274.490 1294.75 1350.78 56.68 N 304.14 W 5993931.67 N 475787.06 E 2.236 306.69 1502.12 32.900 274,250 1375.51 1431.54 60.49 N 354.10 W 5993935.64 N 475737.11 E 2.287 356.78 1594.96 37.000 273.480 1451.59 1507.62 64.06 N 407.15 W 5993939.38 N 475684.07 E 4.442 409.94 1687.94 41 .430 272,380 1523.62 1579.65 67.03 N 465.84 W 5993942.54 N 475625.39 E 4.823 468.71 1783.88 43.640 274.720 1594.31 1650.34 71.08 N 530.56 W 5993946.79 N 475560.68 E 2.833 533.55 1877.20 45.820 276.340 1660.61 1716.64 77.42 N 595.92 W 5993953.35 N 475495.34 E 2.636 599.16 1971.60 50.130 276.410 1723.79 1779.82 85.21 N 665.60 W 5993961.36 N 475425.69 E 4.566 669.14 2064.85 54.41 0 275.880 1780.84 1836.87 93.09 N 738.91 W 5993969.47 N 475352.40 E 4.612 742.77 2160.61 56.610 274.750 1835.06 1891.09 100.39 N 817.49 W 5993977.03 N 475273.85 E 2.495 821.62 -- 2253.41 59.860 273.120 1883.91 1939.94 105.79 N 896.19 W 5993982.67 N 475195.16 E 3.807 900.50 2348.49 60.780 272.730 1930.99 1987.02 110.00 N 978.69 W 5993987.15 N 475112.68 E 1.031 983.10 2444.24 60.940 272.970 1977.62 2033.65 114.16 N 1062.22 W 5993991.58 N 475029.17 E 0.275 1066.73 2536.57 61 .200 273.230 2022.28 2078.31 118.53 N 1142.90 W 5993996.20 N 474948.49 E 0.374 1147.54 2630.85 61 .560 273.190 2067.44 2123.47 123.16 N 1225.54 W 5994001.10 N 474865.87 E 0.384 1230.30 2723.01 60.290 272.790 2112.22 2168.25 127.37 N 1305.97 W 5994005.56 N 474785.45 E 1.429 1310.85 2817.49 60.220 272.320 2159.10 2215.13 131.02 N 1387.92 W 5994009.48 N 474703.52 E 0.438 1392.87 2910.45 60.500 273.610 2205.07 2261.10 135.20 N 1468.61 W 5994013.92 N 474622.84 E 1.243 1473.67 3002.99 60.210 273.210 2250.85 2306.88 139.99 N 1548.89 W 5994018.96 N 474542.58 E 0.489 1554.09 3097.94 60.500 272.120 2297.81 2353.84 143.82 N 1631.32 W 5994023.06 N 474460.16 E 1.043 1636.61 3190.67 60.720 271.890 2343.32 2399.35 146,65 N 1712.07 W 5994026.14 N 474379.42 E 0.321 1717.39 17 July, 2003 - 16:16 Page 2 0'6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad· 3S·19 Your Ref: AP/501032046000 Job No. AKZZ0002513099, Surveyed: 30 June, 2003 ConocoPhil/ips Western North Slope Measured 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) r/100ft) 3284.83 59.410 270.150 2390.31 2446.34 148.11 N 1793.64 W 5994027.87 N 474297.85 E 2.121 1798.94 3379.79 59.640 270.270 2438.4 7 2494.50 148.41 N 1875.49 W 5994028.43 N 474216.01 E 0.266 1880.68 3475.95 59.500 269.840 2487.17 2543.20 148.49 N 1958.40 W 5994028.77 N 474133.10 E 0.412 1963.49 3521.97 59.150 269.320 2510.65 2566.68 148.20 N 1997.98 W 5994028.61 N 474093.52 E 1.234 2003.00 3600.97 59.680 269.800 2550.85 2606.88 147.68 N 2065.98 W 5994028.31 N 474025.51 E 0.851 2070.88 3698.19 58.950 268.040 2600.46 2656.49 146.11 N 2149.57 W 5994027.00 N 473941.92 E 1.728 2154.27 -- 3792.92 58.140 267.810 2649.90 2705.93 143.18 N 2230.33 W 5994024.34 N 473861.15 E 0.880 2234.77 3887.79 58.640 271.400 2699.63 2755.66 142.63 N 2311.10 W 5994024.04 N 473780.38 E 3.265 2315.40 3981.38 57.930 271.330 2748.83 2804.86 144.53 N 2390.69 W 5994026.20 N 473700.79 E 0.761 2394.98 4075.59 58.430 274.610 2798.51 2854.54 148.68 N 2470.62 W 5994030.60 N 473620.88 E 3.005 2475.01 4168.33 59.310 275.230 2846.46 2902.49 155.49 N 2549.71 W 5994037.67 N 473541.81 E 1.108 2554.35 4263.07 58.570 275.430 2895.34 2951.37 163.03 N 2630.51 W 5994045.46 N 473461.03 E 0.802 2635.44 4358.33 60.670 275.170 2943.51 2999.54 170.62 N 2712.34 W 5994053.31 N 473379.23 E 2.217 2717.55 4451.98 60.160 274.840 2989.75 3045.78 177.73 N 2793.47 W 5994060.68 N 473298.13 E 0.625 2798.94 4545.48 59.380 274.330 3036.82 3092.85 184.18 N 2873.99 W 5994067.40 N 473217.62 E 0.958 2879.69 4639.96 61.370 274.340 3083.52 3139.55 190.39 N 2955.88 W 5994073.87 N 473135.75 E 2.106 2961.80 4731.45 61.010 274.730 3127.61 3183.64 196.73 N 3035.80 W 5994080.46 N 473055.86 E 0.543 3041.93 4826.29 60.520 274.440 3173.93 3229.96 203.35 N 3118.29 W . 5994087.34 N 472973.38 E 0.581 3124.66 4920.68 59.880 274.460 3220.84 3276.87 209.70 N 3199.95 W 5994093.95 N 472891.74 E 0.678 3206.54 5015.30 59.690 274.040 3268.46 3324.49 215.76 N 3281.49 W 5994100.28 N 472810.22 E 0.433 3288.29 5109.27 59.690 273.800 3315.88 3371.91 221.31 N 3362.43 W 5994106.08 N 472729.31 E 0.220 3369.40 5204.25 59.510 273.910 3363.95 3419.98 226.81 N 3444.16 W 5994111.85 N 472647.59 E 0.214 3451.31 5297.90 59.100 273.910 3411.75 3467.78 232.31 N 3524.51 W 5994117.60 N 472567.27 E 0.438 3531.83 5391.78 58,740 273.960 3460.22 3516.25 237.82 N 3604.72 W 5994123.37 N 472487.07 E 0.386 3612.23 - 5485.31 61.300 271.490 3506.95 3562.98 241.65 N 3685.63 W 5994127.46 N 472406.17 E 3.567 3693.22 5579.17 61.090 271.620 3552.18 3608.21 243.88 N 3767.84 W 5994129.95 N 472323.96 E 0.255 3775.44 5674.34 60.580 271.930 3598.56 3654.59 246.46 N 3850.91 W 5994132.79 N 472240.91 E 0,607 3858.53 5768.96 60.170 271.390 3645.33 3701.36 248.84 N 3933.12 W 5994135.44 N 472158.70 E 0.659 3940,76 5862.69 59.900 270.320 3692.15 3748.18 250.05 N 4014.31 W 5994136.91 N 472077.52 E 1.030 4021.90 5956.10 59.590 269.760 3739.21 3795.24 250.11 N 4095.00 W 5994137.23 N 471996.83 E 0.615 4102.48 6047.57 59.110 269.370 3785.84 3841.87 249.51 N 4173.69 W 5994136.88 N 471918.14 E 0.640 4181.03 6142.58 58,810 269.940 3834.83 3890.86 249.02 N 4255.09 W 5994136.65 N 471836.74 E 0.603 4262.29 6236.71 58.880 269.800 3883.53 3939.56 248.84 N 4335.65 W 5994136.73 N 471756.18 E 0.147 4342.73 6330.61 58.530 268.960 3932.31 3988.34 247.97 N 4415.88 W 5994136.12 N 471675.95 E 0.850 4422.80 6424.51 60.580 270.040 3979.89 4035.92 247.27 N 4496.82 W 5994135.68 N 471595.00 E 2.398 4503.60 ---------------- 17 July, 2003 - 16:16 Page 3 of6 Dril/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk3S Pad - 3S..19 Your Ref: AP/501032046000 Job No. AKZZ0002513099, Surveyed: 30 June, 2003 ConocoPhilUps Western North Slope Measured 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) (0/100ft) 6520.39 60.580 270.570 4026.98 4083.01 247.72 N 4580.34 W 5994136.39 N 471511.49 E 0.481 4587.02 6614.44 60.460 269.740 4073.27 4129.30 247.94 N 4662.21 W 5994136.87 N 471429.62 E 0.779 4668.79 6708.33 61.380 271.520 4118.90 4174.93 248.85 N 4744.25 W 5994138.04 N 471347.58 E 1.925 4750.77 6802.79 61.300 270.980 4164.21 4220.24 250.66 N 4827.12 W 5994140.11 N 471264.72 E 0.509 4833.62 6896.78 60.960 270.720 4209.59 4265.62 251.88 N 4909.42 W 5994141.60 N 471182.42 E 0.435 4915.87 '- 6990.78 60.360 270.710 4255.65 4311.68 252.90 N 4991.35 W 5994142.88 N 471100.49 E 0.638 4997.75 "-'-' 7085.08 59.760 270.390 4302.71 4358.74 253.69 N 5073.06 W 5994143.93 N 471018.78 E 0.701 5079.39 7180.67 61.010 272.400 4349.95 4405.98 255.72 N 5156.13 W 5994146.23 N 470935.72 E 2.248 5162.45 7274.66 61.080 274.180 4395.46 4451.49 260.44 N 5238.23 W 5994151.21 N 470853.63 E 1.659 5244.69 7368.82 60.450 273.930 4441 .44 4497.47 266.25 N 5320.19 W 5994157.28 N 470771.69 E 0.708 5326.84 7462.59 59.820 274.030 4488.14 4544.17 271.89 N 5401.32 W 5994163.19 N 470690.59 E 0.678 5408.14 7557.57 59.240 274.010 4536.30 4592.33 277.63 N 5482.98 W 5994169.19 N 470608.95 E 0.611 5489.99 7651.57 58.590 273.910 4584.83 4640.86 283.19 N 5563.29 W 5994175.00 N 470528.66 E 0.697 5570.48 7746.40 57.940 274.050 4634.71 4690.74 288.79 N 5643.74 W 5994180.86 N 470448.22 E 0.697 5651.12 7841.35 57.330 273.670 4685.54 4741.57 294.19 N 5723.76 W 5994186.51 N 470368.22 E 0.726 5731.31 7935.70 59.750 272.380 4734.78 4790.81 298.42 N 5804.12 W 5994191.01 N 470287.87 E 2.818 5811.79 8028.61 59.400 273.010 4781.83 4837.86 302.19 N 5884.15 W 5994195.03 N 470207.86 E 0.696 5891.90 8119.45 58.760 272.510 4828.51 4884.54 305.94 N 5961.99 W . 5994199.03 N 470130.03 E 0.848 5969.83 8215.69 58.240 272.050 4878.79 4934.82 309.21 N 6043.98 W 5994202.56 N 470048.05 E 0.677 6051.88 8307.77 57.660 272.660 4927.66 4983.69 312.41 N 6121.96 W 5994206.01 N 469970.08 E 0.844 6129.92 8403.82 57.060 272.390 4979.46 5035.49 315.98 N 6202.76 W 5994209.84 N 469889.29 E 0.668 6210.80 8499.15 56.620 272.620 5031.61 5087.64 319.47 N 6282.49 W 5994213.58 N 469809.57 E 0.504 6290.60 8593.04 56.170 272.300 5083.57 5139.60 322.82 N 6360.61 W 5994217.18 N 469731.46 E 0.557 6368.79 8687.53 55.980 272.010 5136.31 5192.34 325.77 N 6438.96 W 5994220.38 N 469653.12 E 0.324 6447.19 8780.64 55.530 271,610 5188.70 5244.73 328.20 N 6515.89 W 5994223.06 N 469576.20 E 0.600 6524.14 8875.64 55.050 271.180 5242.80 5298.83 330.11 N 6593.96 W 5994225.21 N 469498.14 E 0.627 6602.20 8968.68 53.450 271.960 5297.15 5353.18 332.17 N 6669.44 W 5994227.52 N 469422.67 E 1.849 6677.69 9063.07 51.500 271.690 5354.65 5410.68 334.56 N 6744.26 W 5994230.14 N 469347.86 E 2.078 6752.53 9156.39 48.420 272.910 5414.67 5470.70 337.40 N 6815.64 W 5994233.22 N 469276.49 E 3.449 6823.95 9250.41 45.030 273.180 5479.12 5535.15 341.04 N 6883.98 W 5994237.07 N 469208.15 E 3.612 6892.40 9343.60 41 .650 273.800 5546.88 5602.91 344.92 N 6947.81 W 5994241.16 N 469144.33 E 3.656 6956.34 9437.51 38.720 274.800 5618.62 5674.65 ~~49.44 N 7008.23 W 5994245.88 N 469083.93 E 3.195 7016.92 9528.73 34.570 274.930 5691.79 5747.82 354.06 N 7062.47 W 5994250.66 N 469029.71 E 4.550 7071.32 9625.87 31.230 274.850 5773.34 5829.37 358.56 N 7115.03 W 5994255.33 N 468977.16 E 3.439 7124.05 9719.88 30.600 273.940 5854.00 5910.03 362.26 N 7163.19 W 5994259.19 N 468929.02 E 0.834 7172.33 17 July, 2003 - 16:16 Page 40f6 DrillQuest 3.03.02.005 Western North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9814.64 30.240 272.760 5935.71 5991.74 9908.17 29.150 272.730 6016.96 6072.99 9971.21 28.440 272.970 6072.20 6128.23 10038.00 28.440 272.970 6130.93 6186.96 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 35-19 Your Ref: AP/501032046000 Job No. AKZZOO02513099, Surveyed: 30 June, 2003 ConocoPhil/ips Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) eft) eft) eft) (0/100ft) 365.07 N 7211.09 W 5994262.15 N 468881.13 E 0.736 7220.31 367.29 N 7257.37 W 5994264.52 N 468834.86 E 1.166 7266.64 368.80 N 7287.69 W 5994266.12 N 468804.53 E 1.141 7297.01 370.44 N 7319.46 W 5994267.87 N 468772.77 E 0.000 7328.81 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 RKB = 56.03' MSL. Northings and Eastings are relative to 2542' FNL-1169' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. .'-" The Dogleg Severity is in Degrees per 1 00 feet (US Survey). Vertical Section is from 2542' FNL-1169' FEL and calculated along an Azimuth of 273.000° (True). Magnetic Declination at Surface is 25.056°(23-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10038.00ft., The Bottom Hole Displacement is 7328.83ft., in the Direction of 272.897° (True). Comments Measured Depth (ft) Station Coordinates TVD Northin9s Eastin9s ~) ~ ~ 10038.00 6186.96 370.44 N 7319.46 W Projected Survey .~-"J 17 July, 2003 - 16:16 Comment Page 50'6 DrmQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 35 Pad - 35-19 Your Ref: AP/501032046000 Job No. AKZZ0002513099, Surveyed: 30 June, 2003 Western North Slope ConocoPhi/lips Survey tool program for 35-19 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 179.00 0.00 179.00 179.00 10038.00 179,00 Tolerable Gyro 6186.96 AK-6 BP _IFR-AK -' _.> 17 July, 2003 - 16:16 Page 60'6 DrillQuest 3.03.02.005 ') AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) 20-Jul-03 Re: Distribution of Survey Data for Well 3S-19 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00 I MD 0.00' MD 10,038.00 I MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~03-()qfp RECEIVED JUL 24 2003 ^\..L '~'º("'~. ?_¡~~. "'r"'I"" ·0 1"'118rJ:"I.ß I..J:¡ ù: -':;:~\.;'. '" . .; I ~t'~v .~ \r £? 1 M\ ~ Sperry-Sun Drilling Services ~ Western North Slope ConocoPhillips Kuparuk 38 Pad 35-19 MWD Job No. AKMW0002513099, Surveyed: 30 June, 2003 Survey Report 17 July, 2003 /- Your Ref: API 501032046000 Surface Coordinates: 5993874.02 N, 476091.01 E (70° 23' 39.8133" N, 150° 11' 40.3099" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 993874.02 N, 23908.99 W (Grid) Kelly Bushing: 56.03ft above Mean Sea Level Elevation relative to Project V Reference: 56.03ft Elevation relative to Project V Reference: 56.03ft SPE!r"I'Y-SUfl DRIL.L.ING SERVices A Halliburton Company Survey Ref: svy2055 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-19 MWD Your Ref: AP/501032046000 Job No. AKMW0002513099, Surveyed: 30 June, 2003 ConocoPhillips Western North Slope Measured 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) 0.00 0.000 0.000 -56.03 0.00 0.00 N 0.00 E 5993874.02 N 476091.01 E 0.00 Tolerable Gyro 82.00 0.000 0.000 25.97 82.00 0.00 N 0.00 E 5993874.02 N 476091.01 E 0.000 0.00 179.00 0.350 270.000 122.97 179.00 0.00 N 0.30W 5993874.02 N 476090.71 E 0,361 0.30 MWD Magnetic 294.89 2.730 289.770 238.81 294.84 0.93 N 3.25W 5993874.96 N 476087.77 E 2.074 3.29 .-'" 384.69 4.350 297.780 328.44 384.47 3.24N 8.27W 5993877.29 N 476082.75 E 1.882 8.43 477.12 5.880 296.360 420.49 476.52 6.98N 15.62 W 5993881.05 N 476075.41 E 1.661 15.96 568.89 7.660 292.270 511.62 567.65 11.39 N 25.49 W 5993885.49 N 476065.56 E 2.008 26.05 659.04 10.870 288.960 600.58 656.61 16.43 N 39.09 W 5993890.57 N 476051.97 E 3.608 39.90 749.49 13.940 286.640 688.91 744.94 22.32 N 57.60 W 5993896.52 N 476033.48 E 3.438 58.69 840.11 16.220 284.600 776.41 832.44 28.64 N 80.31 W 5993902.91 N 476010.79 E 2.583 81.70 936.20 18.120 285.280 868.21 924.24 35.96 N 107.72 W 5993910.32 N 475983.41 E 1.988 109.45 1030.05 21.490 280.940 956.50 1012.53 43.07 N 138.68 W 5993917.53 N 475952.47 E 3.915 140.75 1123.33 24.300 275.890 1042.43 1098.46 48.28 N 174.56 W 5993922.86 N 475916.61 E 3.673 176.85 1220.69 25.330 275.030 1130.80 1186.83 52.16 N 215.23 W 5993926.87 N 475875.94 E 1.121 217.67 1313.09 28.670 272.730 1213.12 1269.15 54.95 N 257.08 W 5993929.79 N 475834.11 E 3.787 259.60 1407.07 30.730 274.340 1294.75 1350.78 57.84 N 303.54 W 5993932.83 N 475787.65 E 2.350 306.16 1502.12 32.900 273.450 1375.52 1431.55 61.24 N 353.53 W 5993936.39 N 475737.67 E 2.336 356.25 1594.96 37.000 273.680 1451.60 1507.63 64.55 N 406.60 W 5993939.87 N 475684.62 E 4.418 409.42 1687.94 41 .430 272.440 1523.62 1579.65 67.65 N 465.29 W 5993943.16 N 475625.94 E 4.838 468.19 1783.88 43.640 275.350 1594.32 1650.35 72.09 N 529.98 W 5993947.81 N 475561.27 E 3.084 533.02 1877.20 45.820 276.440 1660.61 1716.64 78.85 N 595.30 W 5993954.77 N 475495.97 E 2.476 598.61 -- 1971.60 50.130 276.490 1723.79 1779.82 86.75 N 664.96 W 5993962.89 N 475426.33 E 4.566 668.59 2064.85 54.410 276.510 1780.84 1836.87 95.09 N 738.22 W 5993971.47 N 475353.10 E 4.590 742,19 2160.61 56.610 275.270 1835.07 1891.10 103.18N 816.73 W 5993979.81 N 475274.62 E 2.533 821 .01 2253.41 59.860 273.410 1883.92 1939.95 109.13 N 895.39 W 5993986.01 N 475195.98 E 3.895 899.87 2348.49 60.780 273.360 1931.00 1987.03 114.00 N 977.85 W 5993991.15 N 475113.53 E 0.969 982.4 7 2444.24 60.940 273.680 1977.62 2033.65 119.14N 1061.32 W 5993996.55 N 475030.08 E 0.336 1066.10 2536.57 61.200 276.020 2022.29 2078.32 125.97 N 1141.83 W 5994003.64 N 474949.59 E 2.236 1146.86 2630.85 61.560 274.360 2067.45 2123.48 133.46 N 1224.25 W 5994011.39 N 474867.20 E 1.592 1229.55 2723.01 60.290 274.420 2112.24 2168.27 139.62 N 1304.56 W 5994017.81 N 474786.91 E 1.379 1310.08 2817.49 60.220 275.220 2159.11 2215.14 146.51 N 1386.30 W 5994024.97 N 474705.19 E 0.739 1392.06 2910.45 60.500 274.170 2205.09 2261.12 153.13 N 1466.82 W 5994031.84 N 474624.69 E 1.027 1472.82 3002.99 60.210 275.060 2250.86 2306.89 159.60 N 1546.99 W 5994038.56 N 474544.54 E 0.893 1553.22 3097.94 60.500 273.400 2297.83 2353.86 165.68 N 1629.28 W 5994044.91 N 474462.27 E 1.550 1635.72 3190.67 60.720 269.960 2343.34 2399.37 168.05 N 1710.02 W 5994047.54 N 474381.54 E 3.241 1716.47 -------------~_..----_. -- -_..~---~ --------- 17 July, 2003 - 16:20 Page 2 of6 DrillQlIest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 35-19 MWD Your Ref: API 501032046000 Job No. AKMW0002513099. Surveyed: 30 June. 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3284.83 59.410 270.830 2390.33 2446.36 168.61 N 1791.61 W 5994048.35 N 474299.94 E 1.605 1797.98 3379.79 59.640 270.170 2438.49 2494.52 169.32 N 1873.45 W 5994049.33 N 474218.11 E 0.646 1879.75 3475.95 59.500 269.850 2487.20 2543.23 169.33 N 1956.37 W 5994049.61 N 474135.20 E 0.322 1962.55 3521.97 59.150 268.450 2510.67 2566.70 168.75 N 1995.94 W 5994049.15 N 474095.62 E 2.725 2002.04 3600.97 59.680 269.160 2550.87 2606.90 167.33 N 2063.93 W 5994047.95 N 474027.62 E 1.024 2069.86 ~, ---. 3698.19 58.950 267.760 2600.49 2656.52 165.09 N 2147.51 W 5994045.97 N 473944.04 E 1 .448 2153.20 3792.92 58.140 268.330 2649.92 2705.95 162.33 N 2228.27 W 5994043.47 N 473863.27 E 0.997 2233.71 3887.79 58.640 271.530 2699.65 2755.68 162.24 N 2309.05 W 5994043.64 N 473782.49 E 2.920 2314.37 3981.38 57.930 272.450 2748.85 2804.88 165.00 N 2388.61 W 5994046.66 N 473702.94 E 1.129 2393.97 4075.59 58.430 275.750 2798.54 2854.57 170.73 N 2468.44 W 5994052.64 N 473623.13 E 3.023 2473.99 4168.33 59.310 276.120 2846.48 2902.51 178.94 N 2547.40 W 5994061.10 N 473544.20 E 1.008 2553.27 4263.07 58.570 278.410 2895.36 2951.39 189.19N 2627.90 W 5994071.62 N 473463.73 E 2.213 263420 4358.33 60.670 278.680 2943.54 2999.57 201.40 N 2709.16 W 5994084.09 N 473382.51 E 2.218 2715.99 4451.98 60.160 277.710 2989.77 3045.80 213.01 N 2789.77 W 5994095.96 N 473301.94 E 1.053 2797.09 4545.48 59.380 275.600 3036.85 3092.88 222.38 N 2870.00 W 5994105.58 N 473221.74 E 2,121 2877.70 4639.96 61.370 275.510 3083.55 3139.58 230.33 N 2951.74 W 5994113.79 N 473140.02 E 2.108 2959.75 4731.45 61.010 276.160 3127.64 3183.67 238.48 N 3031.49 W 5994122.19 N 473060.30 E 0.736 3039.81 482629 60.520 274.760 3173.96 3229.99 246.36 N 3113.87 W 5994130.33 N 472977.95 E 1.388 3122.49 4920.68 59.880 269.530 3220.90 3276.93 249.43 N 3195.68 W 5994133.67 N 472896.15 E 4.855 3204.35 5015.30 59.690 273.210 3268.53 3324.56 251.38 N 3277.40 W 5994135.89 N 472814.43 E 3.367 3286.06 510927 59.690 273.260 3315.95 3371.98 255.96 N 3358.39 W 5994140.72 N 472733.45 E 0.046 3367.19 -. 5204.25 59.510 272.010 3364.02 3420.05 259.73 N 3440.22 W 5994144.75 N 472651.63 E 1.151 3449.10 5297.90 59.1 00 272.500 3411.82 3467.85 262.90 N 3520.69 W 5994148.18 N 472571.18 E 0.628 3529.62 5391.78 58.740 270.500 3460.29 3516.32 265.00 N 3601.06 W 5994150.54 N 472490.82 E 1.864 3609.99 5485.31 61.300 269.690 3507.02 3563.05 265.13 N 3682.07 W 5994150.93 N 472409.81 E 2.838 3690.90 5579.17 61.090 270.150 3552.25 3608.28 265.02 N 3764.31 W 5994151.07 N 472327.56 E 0.484 3773.02 5674.34 60.580 271.310 3598.63 3654.66 266.07 N 3847.41 W 5994152.40 N 472244.47 E 1.192 3856.06 5768.96 60.170 270.640 3645.40 3701.43 267.47 N 3929.65 W 5994154.06 N 472162.24 E 0.753 393826 5862.69 59.900 269.800 369222 3748.25 267.79 N 4010.85 W 5994154.63 N 472081.04 E 0.828 4019.36 5956.10 59.590 269.440 3739.28 3795.31 267.25 N 4091.53 W 5994154.36 N 472000.35 E 0.470 4099.91 6047.57 59.110 269.130 3785.91 3841.94 266.27 N 4170.22 W 5994153.63 N 471921.67 E 0.600 4178.44 6142.58 58.810 269.180 3834.90 3890.93 265.07 N 4251.61 W 5994152.69 N 471840.27 E 0.319 4259.66 6236.71 58.880 269.740 3883.60 3939.63 264.31 N 4332.16 W 5994152.18 N 471759.72 E 0.515 4340.06 6330.61 58.530 269.120 3932.38 3988.41 263.51 N 4412.40 W 5994151.64 N 471679.48 E 0.676 4420.14 6424.51 60.580 270.030 3979.96 4035.99 262.92 N 4493.34 W 5994151.31 N 471598.53 E 2.338 4500.94 ------.--.----- -----.---- - 0- __.__ _ ,___ _____ 17 July, 2003 - 16:20 Page 3 of6 DrillQ/Jest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 38-19 MWD Your Ref: API 501032046000 Job No. AKMWOO02513099, Surveyed: 30 June, 2003 ConocoPf1i/llps Western North Slope Measured 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) (0/100ft) 6520.39 60.580 271.220 4027.05 4083.08 263.83 N 4576.85 W 5994152.49 N 471515.03 E 1.081 4584.38 6614.44 60.460 272.060 4073.34 4129.37 266.17 N 4658.69 W 5994155.09 N 471433.20 E 0.788 4666.23 6708.33 61.380 272.150 4118.97 4175.00 269.19 N 4740.69 W 5994158.37 N 471351.21 E 0.983 4748,28 6802.79 61.300 271.720 4164.28 4220.31 271.99 N 4823.52 W 5994161.43 N 471268.38 E 0.408 4831.15 ----. 6896.78 60.960 271.770 4209.66 4265.69 274.49 N 4905.80 W 5994164.20 N 471186.12 E 0.365 4913.44 6990.78 60.360 270.360 4255.72 4311.75 276.02 N 4987.72 W 5994165.99 N 471104.20 E 1 .455 4995.33 7085.08 59.760 269.450 4302.78 4358.81 275.88 N 5069.43 W 5994166.12 N 471022.48 E 1.051 5076.92 7180.67 61.010 272.480 4350.03 4406.06 277.30 N 5152.51 W 5994167.80 N 470939.42 E 3.050 5159.96 7274.66 61.080 272.140 4395.53 4451.56 280.61 N 5234.68 W 5994171.37 N 470857.25 E 0.325 5242.19 7368.82 60.450 273.430 4441.52 4497.55 284.60 N 5316.75 W 5994175.62 N 470775.20 E 1.370 5324.36 7462.59 59.820 271.600 4488.21 4544.24 288.17 N 5397.98 W 5994179.46 N 470693.98 E 1.821 5405.67 7557.57 59.240 272.250 4536.38 4592.41 290.92 N 5479.80 W 5994182.47 N 470612.17 E 0.849 5487.51 7651.57 58.590 272.760 4584.91 4640.94 294.44 N 5560.22 W 5994186.24 N 470531.76 E 0.833 5568.01 77 46.40 57.940 272.850 4634.79 4690.82 298.39 N 5640.78 W 5994190.45 N 470451.22 E 0.690 5648.66 7841.35 57.330 271.270 4685.62 4741.65 301.27 N 5720.92 W 5994193.59 N 470371.08 E 1.545 5728.85 7935.70 59.750 272.900 4734.86 4790.89 304.21 N 5801.34 W 5994196.79 N 470290.68 E 2.958 5809.31 8028.61 59.400 272.830 4781.91 4837.94 308.22 N 5881.35 W 5994201.05 N 470210.67 E 0.382 5889.42 8119.45 58.760 272.160 4828.59 4884.62 311.61 N 5959.21 W . 5994204.69 N 470132.83 E 0.947 5967.35 8215.69 58.240 271.230 4878.87 4934.90 314.04 N 6041.23 W 5994207.38 N 470050.82 E 0.985 6049.38 8307.77 57.660 271.570 4927.74 4983.77 315.95 N 6119.25 W 5994209.54 N 469972.80 E 0.703 6127.40 8403.82 57.060 273.630 4979.55 5035.58 319.61 N 6200.04 W 5994213.46 N 469892.02 E 1.911 6208.27 ~. 8499.15 56.620 275.380 5031.69 5087,72 325.88 N 6279.60 W 5994219.98 N 469812.49 E 1.605 6288.04 8593.04 56.170 270.250 5083.68 5139.71 329.72 N 6357.66 W 5994224.08 N 469734.44 E 4.575 6366.20 8687.53 55.980 272.410 5136.42 5192.45 331,54 N 6436.03 W 5994226.15 N 469656.07 E 1.907 6444.56 8780.64 55.530 271.620 5188.82 5244.85 334.25 N 6512.95 W 5994229.10 N 469579.16 E 0.852 6521.52 8875.64 55.050 271.450 5242.91 5298.94 336.34 N 6591.02 W 5994231.44 N 469501.10 E 0.526 6599.59 8968.68 53.450 270.510 5297.27 5353.30 337.64 N 6666.51 W 5994232.98 N 469425.61 E 1.905 6675.05 9063.07 51.500 271.070 5354.76 5410.79 338.67 N 6741.36 W 5994234.25 N 469350.77 E 2.119 6749.85 9156.39 48.420 270.050 5414.79 5470.82 339.38 N 6812.79 W 5994235.19 N 469279.34 E 3.405 6821.22 9250.41 45.030 270.650 5479.23 5535.26 339,79 N 6881.23 W 5994235.81 N 469210,90 E 3.635 6889.59 9343.60 41.650 272.980 5547.00 5603.03 341 .77 N 6945.14 W 5994238.00 N 469147.00 E 4.012 6953.51 9437.51 38.720 274.350 5618.74 5674.77 345,62 N 7005.61 W 5994242.05 N 469086.54 E 3.259 7014.09 9528.73 34.570 275.070 5691.91 5747.94 350.08 N 7059.86 W 5994246.67 N 469032.31 E 4.574 7068.50 9625.87 31.230 274.650 5773.46 5829.49 354,55 N 7112.42 W 5994251.32 N 468979.76 E 3.446 7121.23 9719.88 30.600 273.750 5854.12 5910.15 358.10 N 7160.59 W 5994255.02 N 468931.60 E 0.831 7169.52 ------------.--- - "___0_______.. 17 July, 2003 - 16:20 Page 4 of6 DrillQuest 3.03.02.005 Western North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9814.64 30.240 273.250 5935.83 5991.86 9908.17 29.150 272.910 6017.08 6073.11 9971.21 28.440 273.690 6072.32 6128.35 10038.00 28.440 273.690 6131.05 6187.08 --~- Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-19 MWD Your Ref: AP/501032046000 Job No. AKMW0002513099, Surveyed: 30 June, 2003 Local Coordinates Northings Eastings (ft) (ft) 361.03 N 363.52 N 365.26 N 367.31 N 7208.48 W 7254.75 W 7285.06 W 7316.80 W Global Coordinates Northings Eastings (ft) (ft) 5994258.10 N 5994260.74 N 5994262.58 N 5994264.73 N All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.03' MSL. Northings and Eastings are relative to 2542' FNL-1169· FEL. 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 2542' FNL-1169' FEL and calculated along an Azimuth of 273.000° (True). Magnetic Declination at Surface is 25.056°(23-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10038.00ft., The Bottom Hole Displacement is 7326.02ft., in the Direction of 272.874° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) ~. 10038.00 6187.08 367.31 N 7316.80 W Projected Survey 17 July, 2003 - 16:20 Comment Page 5 of 6 468883.72 E 468837.46 E 468807.16 E 468775.42 E ConocoPhillips Dogleg Vertical Rate Section r/1 DOn) 0.464 1.179 1.274 0.000 Comment 7217 .50 7263.83 7294.19 7326.00 Projected Survey ---~------------ -- - --------------- DrillQuest 3.03,02.005 Sperry-Sun Drilling Services Survey Report for Kuparuk 38 Pad - 35-19 MWD Your Ref: API 501032046000 Job No. AKMWOO02513099, Surveyed: 30 June, 2003 ConocoPhillips Western North Slope Survey tool program for 35-19 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) '-~ 0.00 179.00 0.00 179.00 179.00 10038.00 179.00 Tolerable Gyro 6187.08 MWD Magnetic .- -.--------- -- --------" ". ---------- 17 July, 2003 - 16:20 Page 60f6 DrillQ/Jest 3.03.02.005 Schlumberger NO. 2926 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 07/31/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Color 1 B-1 0 ) ¡:)), I :~~) SBHP 07/21/03 1 1 C-27 Cfq-C'i._~ TEMP/PRESS SURVEY 07/22103 1 1 D-140 ?CL'"-\~(O SBHP 07/22/03 1 1J-10 3c:\ -c~-t ( SBHP 07121/03 1 2B-01 \ () )...\ '"-, \.c, PRODUCTION PROFILE . 07/19/03 1 2B-02 \'X!..\' \~~ PRODUCTION PROFILE 07/20/03 1 2B-14 \ ~ ~ ' \ \ L PRODUCTION PROFILE 07/23/03 1 2E-11 \ ~~.-9-~ '"' PRODUCTION PROFILE 07/18103 1 3F-13A \~ ·'-C...tr- LDL 07/17/03 1 3K-08 \ (c - \~ Lb LDL 07/25/03 1 3M-03 ~7-0IL\ LDL 07/24/03 1 3S-19 "'~<.c¡ ~ PERF/JEWELRY/& INITIAL SBHPS 07/11/03 1 SIGNE~0,l~_~~...s.: ~_I"'y"""'\ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk CD .-/ ~ ) ) ~ fK\ n ¡® ~ [f( Æ\ u lj-\j LS~fÒ CO) !J~ Lr"Ù FRANK H. MURKOWSK/, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 333 w. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit 3S-19 ConocoPhillips (Alaska), Inc. Permit No: 203-096 Surface Location: 2542' FNL, 1169' FEL, Sec. 18, TI2N, R8E, UM Bottomhole Location: 2176' FNL, 1615' FWL, Sec. 13, TI2N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development 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 witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, æ~ ,~~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this~ day of June, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ~~ .) ConocoPhillips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com May 20, 2003 Alaska Oil and Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, producer 38-19 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well, KRU 38-19, a development well. Note that it is planned to drill the surface hole without a diverter. There have been 14 wells drilled on 38 pad with no significant indication of gas or shallow gas hydrates. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). The spud date is expected to be approximately 6/15/03. If you have any questions or require any further information, please contact 8kip Coyner at 265-6074. Sincerely, ~~~ Randy Thomas GKA Drilling Team Leader RECEIVED MAY 2 7 2003 Alaska Oil & Gas Cons Comm' . . ISSlon Anchorage 1a. Type of Work: Drill0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) PERMIT TO DRILL 20 AAC 25.005 Redrill U 1b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 2542' FNL, 1169' FEL, Sec. 18, T12N, R8E, UM Top of Productive Horizon: 2182' FNL, 3515' FWL, Sec. 13, T12N, R7E, UM Total Depth: 2176' FNL, 1615' FWL, Sec. 13, T12N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476091 16. Deviated wells: Kickoff depth: 200 18. Casing Program Size Hole Casing 42" 30" x 16" 12.25" 9.625" 8.5" 7" 19 Total Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee 0 Property Plat D y- 5993874 ft. Maximum Hole Angle: Weight 62.5# 40# 26# Specifications Grade Coupling H-40 Weld L-80 BTC L-80 BTC-M Zone- 60° Length 80' 3506' 9975' ás!~ Exploratory[j Development Oil ~ Multiple Zone D Service 0 Development Gas 0 Single Zone 0 5. Bond: W' ~Ianket U Single Well 11. Well Name and Number: Bond No. ).V' 59-52-180 3S-19 6. Proposed Depth: 12. Field/Pool(s): MD: 10003' TVD: 6151' Kuparuk River Field 7. Property Designation: ALK 25544 8. Land Use Permit: ADL 2639 9. Acres in Property: 2560 10. KB Elevation 4 (Height above GL): 28 feet 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 3476 psig Setting Depth Kuparuk River Pool 13. Approximate Spud Date: 6/15/2003 14. Distance to Nearest Property: 1765' at Target 15. Distance to Nearest I 2'- -{ì~1 > 2øcc 2À.. Well within Pool: ~~ />1!7 1 Max. Surface Pressure: 2828 psig Quantity of Cement c. f. or sacks (including stage data) 9 cy High Early 440 sx AS Lite & 310 sx LiteCrete 240 sx Class G PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Length Size BOP Sketch U Diverter Sketch 0 21. Verbal Approval: Commission Representative: Drilling Program~ Seabed Report D 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name R. Thomas Signature ~~ Permit to Drill Number: 2-0 3 - é) 9.6 Conditions of approval : Top Bottom MD TVD MD TVD 28' 28' 108' 108' 28' 28' 3534' 2596' 28' 28' 10003' 6151' Cement Volume MD ~D Perforation Depth TVD (ft): Time v. Depth Plot 0 Drilling Fluid Program 0 Date: kJ-Ct-IVED MAY ? 7 2003 Alaska Uil & Gas Cons. Commis~¡nl1 Anchorage Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 Contact Skip Coyner 265-6074 Title Kuparuk Drilling Team Leader Phone Date" I' e...5-('ê) ~ PreDared bv Sharon AlIsuD-Drake Commission Use Only Permit Approval Date: ./:ßÓ J Mud 10~qU~ ,- Directional survey required API Number: 50-103 -20ý"6{)r~ DYes j(fNO DYes Ø"NO Samples required Hydrogen sulfide measures Other: -:SÇOÙ ~'?<.\ M~"",\~~"" ~a\' -\(,{~ ~ . 'J ,//1 , Approvedby. ¡r7 ¡t7~~ Form 10-401 Reviseâ 3/2003 · COMMISSIONER II. 1 J ,'~¡ f ~ ~:'~ .,1 ì ~ ,': ' '. t, ..,.. te~, ì \;.'" f ¡ : ,. BY ORDER OF THE COMMISSION l See cover letter for other requirements .0 Yes ¡g No !'Q Yes 0 No Date: ~pJ Submit in duplicate ) Ar 'tItion for Permit to Drill, Well 3S-19 , Revision No.O , Saved: 20-May-03 Permit It - Kuparuk Well 35-19 Application for Permit to Drill Document MClximizE We-II VgIUE; Table of Contents 1. Well Name...................................................... ...............................................................2 Requirements of 20 AAC 25.005 (f) ....................................................................................................2 2. Locati on Su m mary ....................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................ 2 Requirements of 20 AAC 25.050(b) .................................................................................................... 2 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25. 005(c) (3) ................................................................................................ 3 4. Dri II i ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ............................................................................................... 3 5. Procedure for Conducting Formation Integrity Tests.............................................3 Requirements of 20 AAC 25.005 (c)(5) ............................................................................................... 3 6. Casing and Cementing Program. ........ .......... ...... .... ..... ......... ........ ....... ....... ...... .........4 Requirements of 20 AA C 25.005(c)(6) ................................................................................................ 4 7. Diverter System Information ............ .......... ......... .... ..... .......... ....... ....... ....... ...... .........4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................ 4 8. Dri II i ng Flu i d Prog ram................................................................................................. 4 Requirements of 20 AA C 25.005(c)(8) ................................................................................................ 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 Cond ition Analysis....... ........ ...... .......... .............. ..... ........ .... ............... ........... 6 Requirements of 20 AAC 25.005 (c)(11) .............................................................................................6 12. Evi den ce of Bon ding ........................................................................................ ..~......... 6 Requirements of 20 AAC 25.005 (c)(12) .............................................................................................6 13. Proposed Dri II ing prog ram... ............ .... ........... ........ ...... ......... ........ ..... ........ ...... .........6 ,. R'.··· . ..,'! r- ., ~ íl L )ì~ " ~ ~'! ~ ìN\;,l;i·~i·;.· 3$-19 PERMIT IT.DOC Page 1 of 7 Printed: 20-May-03 ) Ap' ,tion for Permit to Drill, Well 38-19 } Revision No.O Saved: 20-May-03 Requirements of 20 AAC 25.005 (c)(13) .... .............. ..... .... ....... ........ ....... ................ ........ ..... ........ ....... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6 Requirements of 20 AAC 25.005 (c)(14) ............................................................................................. 6 15. Attach ments.................................................................................................................. 7 Attachment 1 Directional Plan............................................................................................................ 7 Attachment 2 Drilling Hazards...... .. . ..... . ... .,. .. . .. .... . . .. .. ... ... . . . ... . . ... _ .. ... . ...... .. . ..... . .. . ... .. _. . . . _ _. . .6 Attachment 3 Well Schematic..... _. _. . _....... .................. ......... ......... ..................... ...................6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a u[¡¡que name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a Vilell with multiple well branch~ each branch must similarly be Identified by a unique name and API number by adding a suffìx to the nàme designated for the well by the operator and to the number assigned to the well by the commission. The well for which this appli,cation is submitted will be designated as 3S-19. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to DillI inust 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 propertYéJnd 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 secti,òil, 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 NatiQna/ Geodetic Survey in the National Oceanic and Atmospheric Administration/ (C) the proposed depth of the weJi at the top of each objective formation and at total depth/ Location at Surface NGS Coordinates Northings: 5,993,874 12542' FNL, 1169' FEL, Sec 18, T12N, R8E, UM RKB Elevation Eastings: 476,091 Pad Elevation 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "c" Sand) NGS Coordinates Northings: 5,994,260 2182' FNL, 3515' FWL, Sec 13, T12N, R7E, UM Eastings: 468,940 Measured Depth RKB: Total Vertical Depth, RKB: Total Vertical Depth 55: 9703' 5891' 5835' Location at Total Depth 12176' FNL, 1615' FWL, NGS Coordinates Northings: 5,994,267 Eastings: 468,790 Sec 13, T12N, R7E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 10003' 6151' 6095' and (D) other information required by 20 MC 25.050(b),- Requirements of 20 AAC 25.050(b) Ifa well is to be intentionally deviated the app/¡cation for a PermIt to Drill (Form 10-401) must (1) include a pla0 drawn to a suiiabie scale, showing the path of the proposed wellbor~ including all adjacent wellbores wIthin 200 feet of any portion of the proposect we/~' Please see Attachment 1: Directional Plan OR ~ ..l"\ .~ Ie.. ~ ,~ L . îlli!ii(]l~l, 3S-19 PERMIT IT. DOC Page 2 of 7 Printed: 20-May-03 ) ¡ '):ation for Permit to Drill, Well 3S-19 .,' Revision No.O Saved: 20-May-03 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mall; 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 DNI must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.035; 20 AAC 25.03(i or 20 MC 25.037, as applicable; Please reference BOP schematics on file for Nabors 7E5. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) 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 applìcation: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it¡ and maximum potential surface pressure based on a methane gradient; A pressure build-up test performed on Palm 1A (35-26) in 4/01 indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or 11.9 ppg EMW (equivalent mud weight). Due to pressure depletion, the predicted reservoir pressure for 35-19 is predicted at 3450 psi at 5891' tvd, 0.59 psi/ft or 11.3 ppg EMW. The maximum potential surface pressure (MP5P) while drilling 35-19 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5891' tvd: MP5P =(5891 ft)*(0.59 - 0.11 psi/ft) = 2828 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 - Drilling Hazards 5ummary 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}; A procedure is on file with the commission for performing LOT's. For 35-19 the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0 ppg EMW maximum will not be observed. (see step 6 in the procedure) . J lJ j /1 ~~, 11 L \_ n I U H: J Ij / 1, ö, 3$-19 PERMIT IT. DOC Page 3 of 7 Printed: 20-May-03 ) / \cation for Permit to Drill, Well 38-19 .,J Revision No.O Saved: 20-May-03 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 installed; Casing and Cementing Program Hole Top Btm CsglTbg Size Weight Length MDITVD MDITVD OD (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early Insulated 9-5/8 12-1/4 40 L-80 BTC 3506' 28'/28' 3534'/2596' Lead: 440 sx 10.7 ppg AS Lite Tail: 310 sx 12.0 ppg 'LiteCRETE'. (Yield=2.40 cuft/sk) Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 9975' 28'/28' 10003'/6151' 240 sx 15.8 ppg 'G' w/ add. Planned TOC= 8903' 3-1/2 9.3 L-80 EUE 8rd 9575' 28' / 28' 9603'/5805' SAB- 3 packer set at Mod 9603' MD. If 7" casing must be top-set above the Kuparuk C sand, 6 1/8" hole would be drilled to total depth and a 3 112" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. 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 of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please reference diverter schematic on file for Nabors 7ES. ConocoPhillips plans not to use a diverter on well 35-19. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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 using mud systems having the following properties: OR t .~ .' .'~ ..<1. , .' . j. ,.;', ,',i ' " .. , . t , ~.'. ~ ~~¡¡ I .' ,1. \~~ 3S-19 PERMIT IT.DOC Page 4 of 7 Printed: 20-May-03 ) !,,"cation for Permit to Drill, Well 3S-19 / Revision No.O Saved: 20-May-03 Surface Hole mud properties Spud to Base of Permafrost Initial Value Final Value 8.6 9.0* 120-130 120-130 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second Gel Strength (lb1100 sf) 10 minute Gel Strength (lb1100 sf) pH 8-9 API Filtrate(cc) 12-15 Solids (%) 6-9 * 9.8 if hydrates are encountered Base of Permafrost to Total Depth Initial Value Final Value 9.0* 9.4* 120-130 120-130 35-45 8-15 27 -40 25-35 20-30 11-22 15-30 15-30 10-25 10-25 10-25 25-55 20-40 15-35 8-9 8-9 8-9 7-8 7-8 7-8 6-12 6-12 6-12 1 0-30 25-55 Production Hole mud properties initial C40 Top Morraine Top HRZ Kuparuk Density (ppg) 8.8 10.2 10.6 10.8 11.8 Funnel Viscosity 40-55 42-55 42-58 42-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 20-25 20-25 (cP) Plastic Viscostiy 6-12 8-15 8-16 8-18 15-25 (lb1100 sf) 10 second Gel 2-5 3-6 3-6 4-7 4-8 Strength (lb1100 sf) 10 minute Gel 4-10 7-10 7-112 7-12 8-16 Strength (lb1100 sf) pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <6 <4 <4 Solids (%) 6-11 9-14 1 0-1 5 1 0-1 5 15-19 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 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); N/ A - 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 Of/II 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 AAC 25.061(a); N/ A - Application is not for an exploratory or stratigraphic test well. O~ .~".,·,."itl ¡' 1,1 ,:'),., E /1 II.. ..... ~.'~ J ; "1' '.'~~' ' ~_,' ~ _ ,,~1 ~ ,',1 ,.r'~ "!~_ 3S-19 PERMIT IT.DOC Page 5 of 7 Printed: 20-May-03 ) ~r \~tion for Permit to Drill, Well 3S-19 } Revision No.O Saved: 20-May-03 11. Seabed Condition Ana,lysis Requirements of 20 AAC 25.005 (c)(11) 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 ,ppplication: (11) for a well drilled from an offsfujre platform/ mobile bottom-founded structure/ jack-up rift or floating drilling vessel an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A - 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 Orìll must be accompanied by each of the following items/ except for an item already on file with the commission and identified in the appilcation: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met,· Evidence of bonding for Phillips 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 Drllf ml/st be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 7ES. 2. N/U riser (no diverter). 3. Drill 12-1/4" hole to 9-5/S" surface casing point according to directional plan. No LWD logging equipment required. 4. Run and cement 9-5/S" 40#, L-SO BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill S-1/2" hole to total depth according to directional plan. Run LWD logging equipment with GR, resistivity, and density-neutron. Run 7" 26# L-SO BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 7. Run 3-1/2" 9.3#, L-SO Srd EUE Srd-Mod completion assembly w/ SAB-3 permanent packer and PBR. Set packer 100' above top planned perforation, shear out of PBR, P/U tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 V2" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. S. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to On/I 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 dnlling 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 down a permitted annulus on 35 pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 35 pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. O R···~1 .(ß"lj rr '~ ,;~~ l \ . " ~ \:,::1 ,¡ ,;i ,. ¡!SO! 3$-19 PERMIT IT. DOC Page 6 of 7 Printed: 20-May-03 ) p \&;ation for Permit to Drill, Well 38-19 ) Revision No.O Saved: 20-May-03 At the end of drilling operations, an application may be submitted to permit 35-19 for annular pumping of fluids occurring as a result of future drilling operations on 35 pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. O [~ ..-, ..~ '^" ~ ¡, , .. ... ri ~~1 ¡ J j /-<~ 3S-19 PERMIT IT. DOC Page 7 of 7 Printed: 20-May-03 a ::t-. -.. r:;~-~~_ ~ ~~ ~-~-..., ~--- Sperry-Sun Drilling Service, ",",~:z-"";i~ Western North ~t~l';e,? Conoco~lJi'i~oo:,~jF- .-. 35-19 Pia -c:/i<;(f! (wp04) posal Report 19 May, 2003 Surface Coordinates: 5993874.02 N, 476091.01 E (70023'39.8133" N, 150011'40.3099" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 55. 80ft above Mean Sea Level 5i-n=J .. ·Y-SUI! DFlILLING SERVices A Halliburton Company -~ -----' Proposal Ref: pro2029 Sperry-Sun Drilling Services Proposal Report for 35-19 Plan - 35-19 (wp04) Revised: 9 May, 2003 ConocoPhíllíps Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eas Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft 0.00 0.000 0.000 -55.80 0.00 0.00 N 0.00 E 5993874.02 0.00 SHL (2542.17' FNL & 1168.69' FEL, -., SEC. 18- T12N - R8E) 100,00 0,000 0.000 44.20 100.00 0.00 N 0.00 E 5993874.0Z~N '476091.01 E 0.000 0.00 200.00 0.000 0.000 144.20 200.00 0.00 N 0.00 E 5993374.pZ:N yt76091.01 E 0.000 0.00 KOP Begin Dir @ 2.0000/100ft : ;:§99#??4;Ø2 N 200.00ft MD, 200.00ft TVD 300.00 2.000 290.000 244.18 299.98 0.60 N 476089.37 E 2.000 1.67 400.00 4.000 290.000 344.04 399.84 2.39 N i$9938'Tèc~43 N 476084.46 E 2.000 6.67 ~ 500.00 6.000 290.000 443.65 499.45 5.37 N 476076.28 E 2.000 15.01 600.00 8,000 290.000 542.90 598.70 9.54 N 476064.84 E 2.000 26.66 Increase Dir Rate @ 3.0000/100ft : .:~5j4-=t;';:"7,,-" 600.00ftMD,598.70ftTVD 700.00 10.878 284.775 641 .54 ·J4~32 fÎ.'c 5993888.48 N 476049.19 E 3.000 42.56 a 800.00 13.808 281.731 739.22 , ......... 1~l*? t{-~ 5993893.38 N 476028.39 E 3.000 63.59 :JD 900.00 16,762 279.740 835.67 . "{24:02N . 5993898.33 N 476002.51 E 3.000 89.72 1000.00 19.729 278.332 930.63 "28.91 N 119.50 W 5993903.31 N 475971.60 E 3.000 120.85 ~c... 1100.00 22.705 277.281 1,º2,~.84 33.80 N 155.35 W 5993908.32 N 475935.77 E 3.000 156.91 ~--,: L) ....,¡¿---~~ 1200.00 25,687 276.461 /,~~fl&'XQ? 38.69 N 196.04 W 5993913.34 N 475895.09 E 3.000 197.80 ~, .jJ 1300.00 28.671 275.8Q3\ {lg04J~\ 43.55 N 241.45 W 5993918.35 N 475849.70 E 3.000 243.40 ~----:;::.., 1400.00 31 .659 275.268:' l29Ó';45"! 48.39 N 291.46 W 5993923.34 N 475799.70 E 3.000 293.59 :~ . . ". f~ 1500.00 34.6!,48ó 274.799 ':';,Ù.13i~.'f6 1429.96 53.17 N 345.93 W 5993928.30 N 475745.25 E 3.000 348.24 1600.00 3'7;639'2 274:404 '::1454.90 1510.70 57.89 N 404.72 W 5993933.21 N 475686.48 E 3.000 407.20 1644.73.. 3Ö,:a?~~ :. ~274.245 1490.00 1545.80 59.99 N 432.37 W 5993935.39 N 475658.84 E 3.000 434.91 B. Permafrost 1700;ÖÖ ... ~ 40.632' ??,74.060 1532.46 1588.26 62.55 N 467.66 W 5993938.06 N 475623.56 E 3.000 470.29 180Ô.ÓO' ·4-~.6~5¿' ;'273.755 1606.62 1662.42 67.11 N 534.57 W 5993942.84 N 475556.66 E 3.000 537.35 1900.00,; 4ß.618 273.482 1677.17 1732.97 71.58 N 605.28 W 5993947.53 N 475485.96 E 3.000 608.20 2000.00 49.613 273.234 1743.92 1799.72 75.93 N 679.60 W 5993952.13 N 475411.66 E 3.000 682.64 "--- 2100.00 52.608 273.008 1806.70 1862.50 80.17 N 757.31 W 5993956.61 N 475333.96 E 3.000 760.47 2200.00 55.603 272.799 1865.32 1921.12 84.27 N 838.20 W 5993960.97 N 475253.08 E 3.000 841 .47 2300.00 58.598 272.604 1919.63 1975.43 88.22 N 922.06 W 5993965.19 N 475169.23 E 3.000 925.42 2341.90 59.854 272.526 1941.07 1996.87 89.83 N 958.03 W 5993966.92 N 475133.27 E 3.000 961.42 End Dir, Start Sail @ 59.854° : 2341.90ftM 0, 1996.87ftTVD 2369.64 59.854 272.526 1955.00 2010.80 90.89 N 981.99 W 5993968.05 N 475109.32 E 0.000 985.40 T. West Sak 2400.00 59.854 272.526 1970.25 2026.05 92.05 N 1008.22 W 5993969.29 N 475083.09 E 0.000 1011.66 2500.00 59.854 272.526 2020.47 2076.27 95.86 N 1094.61 W 5993973.38 N 474996.71 E 0.000 1098.13 2600.00 59.854 272.526 2070.69 2126.49 99.67 N 1181.00 W 5993977.4 7 N 474910.33 E 0.000 1184.60 19 May, 2003 - 15:47 Page2of9 DríllQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for 35-19 Plan - 35-19 (wp04) Revised: 9 May, 2003 ConocoPhillips Western North Slope Measured Depth (ft) Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eas (ft) (ft Inel. Azlm. Comment 2700.00 2800.00 2900.00 3000.00 3100.00 59.854 59.854 59,854 59.854 59.854 272.526 272.526 272.526 272.526 272.526 2120.91 2171.13 2221.35 2271.58 2321.80 2176.71 2226.93 2277.15 2327.38 2377.60 103.48 N 107.29 N 111.10 N 114.92 N 118.73 N 1267.39 W 1353.78 W 1440.17W 1526.56 W 1612.95 W 5993981.55 5993985.64 5993989.7 59~.8 ~~ . p003991~90 N~ 474823.96 474737.58 E 74651.20 E 4564.82 E 0°, ~ 474478.45 E 1271.07 1357.54 1444.01 1530.48 1616.96 - :- - ._"."_.= o~_ c-:-_ ~ '-'.- '''="-. --, i~~99400r99 N 94004.27 N 94006.08 N 5994010.17 N 5994014.26 N .--- 3200.00 3255.72 3300.00 3400.00 3500.00 59.854 59.854 59.854 59.854 59.854 272,526 272,526 272.526 272.526 272.526 2372.02 2400.00 2422.24 2472.46 2522.68 2427.82 2455.80 2478.04 2528.26 2578.48 474392.07 E 474343.94 E 474305.69 E 474219.31 E 474132.93 E 0.000 0.000 0.000 0.000 0.000 1703.43 1751.61 B.WestSak 1789.90 1876.37 1962.84 a --v~ ~"-,...iJ ~..... ~~. _'J_ ,..;) 3534.04 59.854 272.526 2539.78 5994015.65 N 474103.53 E 0.000 1992.28 9-5/8" Csg Pt ... Drill out 8-1/2" Hole: 3534.04ft MD, 2595.58ft TVD 9 5/8in Casing 3600.00 3634.04 3700.00 3800.00 59.854 59.854 59.854 59.854 272.526 272.526 272.526 272.526 2044.90 W 2074.31 W 2131.30 W 2217.69 W 2572.90 5QggßO ~2823:{~2 :-2ß7a~$;, .~?~,~::,.. -, 5994018.34 N 5994019.73 N 5994022.43 N 5994026.52 N 474046.56 E 474017.15 E 473960.18 E 473873.80 E 0.000 0.000 0.000 0.000 2049.31 2078.75 2135.78 2222.26 C-80 (K-1 0) ..'-4_-·....··J4 -"''i;(_,i.';;..o.-'''r_ ~..~ -}. 27~ª~.ª7{ ',~:<2773:79 c7'2824.01 2874.23 2924.45 3900.00 59.854 272.526 4000.00 59.,Ø5~:.. 272.526 4100.00 59;854' 272.526 4200.90 5~,8~1}272.526 4300;00, . 59.854'-'272.526 2779.37 2829.59 2879.81 2930.03 2980.25 149.22 N 153.03 N 156.84 N 160.65 N 164.46 N 2304.08 W 2390.47 W 2476.86 W 2563.25 W 2649.64 W 5994030.61 N 5994034.69 N 5994038.78 N 5994042.87 N 5994046.96 N 473787.42 E 473701.05 E 473614.67 E 473528.29 E 473441.91 E 0.000 0.000 0.000 0.000 0.000 2308.73 2395.20 2481.67 2568.14 2654.61 ~--- 59.854 59.854 59.854 59.854 59.854 168.27 N 172.09 N 175.90 N 179.71 N 183.52 N 4400.00 4500.00 4600.00 4700.00 4800.00 272.526 272.526 272.526 272.526 272.526 2974.67 3024.89 3075.12 3125.34 3175.56 3030.47 3080.69 3130.92 3181.14 3231.36 2736.03 W 2822.42 W 2908.81 W 2995.20 W 3081.59 W 5994051.04 N 5994055.13 N 5994059.22 N 5994063.31 N 5994067.40 N 473355.53 E 473269.16 E 473182.78 E 473096.40 E 473010,02 E 0.000 0.000 0.000 0.000 0.000 2741.09 2827.56 2914.03 3000.50 3086.97 ~-- 4900.00 5000.00 5100.00 5200.00 5300,00 59.854 59.854 59.854 59.854 59.854 272.526 272.526 272.526 272,526 272,526 3225.78 3276.00 3326.22 3376.44 3426.66 3281.58 3331.80 3382.02 3432.24 3482.46 187.33 N 191.14N 194.95 N 198.77 N 202.58 N 3167.98 W 3254.37 W 3340.76 W 3427.15 W 3513.54 W 5994071.48 N 5994075.57 N 5994079.66 N 5994083.75 N 5994087.83 N 472923.64 E 472837.27 E 472750,89 E 472664.51 E 472578.13 E 0.000 0.000 0.000 0.000 0.000 3173.44 3259.91 3346.39 3432.86 3519.33 19 May, 2003 - 15:47 DrillQuest 3.03.02.002 Page 3 of9 Western North Slope Measured Depth (ft) 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 a 6400.00 6491.40 6500.00 6600.00 6700.00 ::P~"i -r- . S-_ 6800.00 6900.00 7000.00 7100.00 7200.00 ,.--= OJ 730o;ÖtV~ 7400;00,'" 7500,00 7600.00>- 7700.00 7800.00 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8651.85 19 May, 2003 - 15:47 Incl. 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59.854 59,854 59,.8M, 59;8'54: 5'g.ås¿{ ,. ?~,a5:4_,' '59.854 59.854 59,854 59.854 59.854 59.854 59.854 59,854 59,854 59.854 59.854 59.854 59.854 Azim. 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272,526 272.526 272.526 272.526 272.526 272.526 Sub-Sea Depth (ft) 3476.88 3527.11 3577.33 3627.55 3677.77 3727.99 3778.21 3828.43 3878.65 3928.88 3979.10 4025.00 4029.32 4079.54 4À4~. 76 - - ~- 272.529'~'~J 7~ig~:, ;~;:~~f';~,:~~;;:i; 272.526i;'\4330~·64 27g.ß26 '~4380.87 ,,-.",< ;S272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 272.526 4431.09 4481.31 4531.53 4581.75 4631.97 4682.19 4732.41 4782,64 4832.86 4883.08 4933.30 4983.52 5033.74 5083.96 5110.00 Vertical Depth (ft) 3532.68 3582.91 3633.13 3683.35 3733.57 3783.79 3834.01 3884.23 3934.45 3984.68 4~.78 4286.00 4336.22 4386.44 4436.67 4486.89 4537.11 4587.33 4637.55 4687.77 4737.99 4788.21 4838.44 4888.66 4938.88 4989.10 5039.32 5089.54 5139.76 5165.80 Sperry-Sun Drilling Services Proposal Report for 35-19 Plan - 35-19 (wp04) Revised: 9 May, 2003 Local Coordinates Northings Eastings (ft) (ft) 206.39 N 210.20 N 214.01 N 217.82 N 221.63 N 259.75 N 263.56 N 267.37 N 271.18N 274.99 N 278.80 N 282.62 N 286.43 N 290.24 N 294.05 N 297.86 N 301.67 N 305.48 N 309.30 N 313.11 N 316.92 N 320.73 N 324.54 N 328.35 N 330.33 N 3599.93 W 3686.32 W 3772.71 W 3859.10 W 3945.49 W 4463.84 W 4542.80 W 4550.23 W 4636.62 W 4723.01 W 4809.40 W 4895.79 W 4982.18 W 5068.57 W 5154.96 W 5241.35 W 5327.74 W 5414.13 W 5500.52 W 5586.91 W 5673.30 W 5759.69 W 5846.08 W 5932.4 7 W 6018.86 W 6105.25 W 6191.65 W 6278.04 W 6364.43 W 6409.22 W Page 4 of9 Global Coordinates Northings Eas . . (ft) (ft 5994091.92 472491.76 5994096.01 N- '>' 472405.38 E 59941 00.1 Q.N 472319.00 E 59911jþ4.,HrJ\j}472232.62 E :59$4100'Æ? N;~.;- 472146.24 E - - - :5994'1'f2iß6 N 94116.45 N 94120.53 N 5994124.62 N 5994128.71 N 5994132.80 N 5994136.53 N 5994136.89 N 5994140.97 N 5994145.06 N 5994149.15 N 5994153.24 N 5994157.32 N 5994161.41 N 5994165.50 N 5994169.59 N 5994173.67 N 5994177.76 N 5994181.85 N 5994185.94 N 5994190.02 N 5994194.11 N 5994198.20 N 5994202.29 N 5994206.38 N 5994210.46 N 5994214.55 N 5994218.64 N 5994222.73 N 5994224.85 N 472059.87 E 471973.49 E 471887.11 E 471800.73 E 471714.36 E 471627.98 E 471549.03 E 471541.60 E 471455.22 E 471368.84 E 471282.47 E 471196.09 E 471109.71 E 471023.33 E 470936.96 E 470850.58 E 470764.20 E 470677 .82 E 470591.44 E 470505.07 E 470418.69 E 470332.31 E 470245.93 E 470159.56 E 470073.18 E 469986.80 E 469900.42 E 469814.04 E 469727.67 E 469682.88 E 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ConocoPhillips Comment 3605.80 3692.27 3778.74 3865.22 3951.69 4038.16 4124.63 4211 .10 4297.57 4384.04 ~- 4470.52 4549.55 C-40 (K-3) 4556.99 4643.46 4729.93 4816.40 4902.87 4989.34 5075.82 5162.29 5248.76 5335.23 5421.70 5508.17 5594.65 .......,./ 5681.12 5767.59 5854.06 5940.53 6027.00 6113.47 6199.95 6286.42 6372.89 6417.72 Top Morraine DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Proposal Report for 35-19 Plan - 35-19 (wp04) Revised: 9 May. 2003 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northin9s Eastings Northings Eas '. Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft 8700.00 59.854 272.526 5134.18 5189.98 332.16 N 6450.82 W 5994226.81 469641 .29 8708.37 59.854 272.526 5138.39 5194.19 332.48 N 6458.05 W 5994227.16N· , 469634.06 E Begin Dir @ 3.00001100ft : 8708.37ft MD. 5194.19ft TVD 8800.00 57.105 272.526 5186.29 5242.09 335.92 N 6536.07 W 599c~~.p5;1J :;469556.04 E 3.000 6544.70 8900,00 54.105 272.526 5242.77 5298.57 339.56 N 6618.50 W ,59Wf2?4H5N: . 469473.63 E 3.000 6627.20 9000.00 51.105 272.526 5303.50 5359.30 343.06 N 6697.86 ~59~'238.5ö N 469394.28 E 3.000 6706.64 . -- - ~ 9100.00 48.105 272.526 5368.29 5424.09 346.42 N 94242.10 N 469318.22 E 3.000 6782.78 9200.00 45.1 05 272.526 5436.99 5492.79 349.62 N 994245.54 N 469245.64 E 3.000 6855.44 9235.11 44.051 272.526 5462.00 5517.80 350.71 N ' 5994246.70 N 469221.02 E 3.000 6880.08 Top HRZ 9300.00 42.105 272.526 5509.39 5565.19 ;~:~~~'c; 5994248.80 N 469176.76 E 3.000 6924.39 9400.00 39.105 272.526 5585.30 5641 .1 0 5994251.87 N 469111.76 E 3.000 6989.47 9490.68 36,384 272.526 5657.00 9.,~1?·8O c>'.~ ·~7:g.?¿N'· 7035.88 W 5994254.50 N 469056.32 E 3.000 7044.97 Base H RZ a 9500.00 36.105 272.526 5664.52 -- --. ~58.2~tJ 7041.38 W 5994254.76 N 469050.81 E 3.000 7050.48 ~ 9600.00 33.105 272.526 5746.82 ~':360. 72 N 7098.11 W 5994257.44 N 468994.09 E 3.000 7107.26 "'-c. 9627.54 32.278 272.526 QtZ9·00 361.38 N 7112.97 W 5994258.14 N 468979.23 E 3.000 7122.14 K-1 ~.-~) 9700.00 30.1 05 272.526 ;~ãg4Ä9.a 363.03 N 7150.46 W 5994259.92 N 468941.75 E 3.000 7159.66 ----- " 9703.49 30.000 272,52~'· 5835Jiff 5890.80 363.11 N 7152.21 W 5994260.00 N 468940.00 E 3.000 7161.41 TARGET: 9703.49ft MD. 5890.80ft ---< TVD (2182' FNL & 3515' FWL. See 1~ T12N-R7E) . Kuparuk j..-......'.""'<>-.... Target - 3S-19, 150.00 Radius.. Currel Target 9725.43> .30.000 . 272.526 5854.00 5909.80 363.59 N 7163.17 W 5994260.52 N 468929.04 E 0.000 7172.38 Miluveach 9800.00 'go.odo 272.526 5918.58 5974.38 365.23 N 7200.42 W 5994262.28 N 468891.80 E 0.000 7209.66 9900.00. 30.000 272.526 6005.18 6060.98 367.44 N 7250.37 W 5994264.64 N 468841.86 E 0.000 7259.66 , I 10000.00 '30.000 272.526 6091.78 6147.58 369.64 N 7300.32 W 5994267.01 N 468791.91 E 0.000 7309.66 - 10003.49 30.000 272.526 6094.81 6150.61 369.72 N 7302.06 W 5994267.09 N 468790.17 E 0.000 7311.40 Total Depth : 10003.49ftMD,6150.61ftTVD 7in Casing 19 May, 2003 - 15:47 Pages of9 DrillQuest 3.03.02.002 D-· < '"""",,- ¿~] ~~---""" ~-~~- Western North Slope Sperry-Sun Drilling Services Proposal Report for 35-19 Plan - 35-19 (wp04) Revised: 9 May, 2003 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 3S-19. North ings and Eastings are relative to 3S-19. 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 3S-19 and calculated along an Azimuth of 273.000° (True). Magnetic Declination at Surface is 25.101 0(09-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10003.49ft., The Bottom Hole Displacement is 7311.41ft., in the Direction of 272.899° (True). -'"-o~:Y~''-.,~o-> -' ~- - . --- _._c; _: _ = .~ "_ _._ 0"_ 7_ ~ The Along Hole Displacement is 7314.48ft, the Planned Tortuosity is 1.303°/1 OOft and tP#Öirè(~Oon~~~Îfficulty Index is 5.7. Comments Measured Depth (ft) ) 0.00 200.00 600.00.' - 2341.90; .3ߧ4:04- 87Öà.37; 9793.49: 9703.49 10003.49 19 May, 2003 - 15:47 - ; Station Coordi TVD Nortþ:!~s (ft)[::~~tt f'~;~~'.. 0.00 200.00 -- -598.70 cl996.a? ;25~5.58 5:194.19 5890.80 5890.80 6150.61 - . ·Ô~bQ;~ - {j[()()iN 9.54 N 89.83 N 135.27 N 332.48 N 363.11 N 363.11 N 369.72 N 0.00 E 0.00 E 26.20 W 958.03 W 1987.92 W SHL (2542.17' FNL & 1168.69' FEL, SEC. 18- T12N - R8E) KOP Begin Dir @ 2.0000/100ft : 200.00ft MD, 200.00ft TVD Increase Dir Rate @ 3.0000/100ft : 600.00ftMD,598.70ftTVD End Dir, Start Sail @ 59.854°: 2341.90ftMD,1996.87ftTVD 9-5/8" Csg Pt... Drill out 8-1/2" Hole: 3534.04ft MD, 2595.58ft TVD 6458.05 W 7152.21 W 7152.21 W 7302.06 W Begin Dir @ 3.0000/100ft : 8708.37ft MD, 5194.19ft TVD End Dir, Start Sail @ 30.000° : 9703.49ftMD,5890.80ftTVD TARGET: 9703.49ft MD, 5890.80ft TVD (2182' FNL & 3515' FWL, See 13-T12N-R7E) Total Depth: 10003.49ftMD,6150.61ftTVD Page 60f9 ConocoPhillips .---- ~ DrillQuest 3.03.02.002 Western North Slope Formation Toøs Formation Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dim. Profile Measured Vertical Depth Depth (ft) (ft) 1490.00 0.000 0.000 1644.73 1955.00 0.000 0.000 2369.64 2400.00 0.000 0.000 3255.72 2590.00 0.000 0.000 3634.04 4025.00 0.000 0.000 6491.40 5110.00 0.000 0.000 8651.85 5462.00 0.000 0.000 9235.11 5657,00 0,000 0,000 9490.68 CJ 5770.00 0,000 0.000 9627.54 5835.00 0.000 0.000 9703.49 -~"~~=:-- ,,",=-Ij, ~' _ 4 5854,00 0.000 ._, tf'- ~ë Casing det~ils~ f;-~'~ \,": ~-.::;-:.~:..- ,... "F'r~ôiYI; Mea~µr~cI ... Vf!rtfcal Depth" '-'Depth (ft) , (ft) To Measured Vertical Depth Depth (ft) (ft) 1545.80 2010.80 2455.80 2645.80 4080.80 <Surface> <Surface> 3534.04 2595.58 3534.04 2595.58 <Run-TO> <Run-TO> 19 May, 2003 - 15:47 Sperry-Sun Drilling Services Proposal Report for 35-19 Plan - 35-19 (wp04) Revised: 9 May, 2003 Penetration Point Sub-Sea Depth Northings (ft) (ft) 1490.00 1955.00 2400.00 2590.00 4025.00 363.59 N Casing Detail 9 5/8in Casing 7in Casing Page 7of9 B. Permafrost T. West Sak B. West Sak C-80 (K-10) C-40 (K-3) 6409.22 W Top Morraine 6871.14 W Top HRZ 7035.88 W Base HRZ 7112.97 W K-1 7152.21 W Kuparuk 7163.17 W Miluveach ConocoPhiJ/ips .-", - Dri/IQuest 3.03.02.002 Western North Slope Targets associated with this welllJath Target Name 38-19 (Fault2) (~ ~-.J -:b 1':- .) --~ =i~---",:;;r~~- 38-19 (Fault 1) 19 May, 2003 - 15:47 Sperry-Sun Drilling Services Proposal Report for 3S-19 Plan - 3S-19 (wp04) Revised: 9 May, 2003 ConocoPhillips inates Eastings Target Target (ft) Shape Type 102.37 N 7381.38 W Polygon Current Target Mean 8ea Level/Global Coordin 5994000.00 N 468710.00 E ~ Geographical C~?rq¡o? 700 23' 40.7844" N 150015' 16.5176" W Target _Bqtmdâßt PoirJt1f:1 5690.80 102.37 N 7381.38 W . o':<~fo'#2 5690.80 4756.348 7038.36 W #3 5690.80 4757.058 7038.36 W #4 5690.80 101.66 N 7381.37 W obal Coordinates #1 5635.00 5994000.00 N 468710.00 E #2 5635.00 5989140.22 N 469037.47 E #3 5635.00 5989139.50 N 469037.47 E #4 5635.00 5993999.29 N 468710.00 E Geographical Coordinates #1 70023' 40.7844" N 150015' 16.5176" W #2 700 22' 52.9983" N 1500 15' 06.3365" W #3 700 22' 52.9913" N 1500 15' 06.3364" W #4 70023' 40.7774" N 150015' 16.5175" W 5890.80 363.11 N 7152.21 W Circle Current Target Mean 8ea Level/Global Coordinates: 5835.00 5994260.00 N 468940.00 E Geographical Coordinates: 70023' 43.3511" N 150015' 09.8124" W Target Radius: 150.00ft - 5690.80 753.20 N 7123.46 W Polygon Current Target Mean 8ea Level/Global Coordinates: 5635.00 5994650.00 N 468970.00 E Geographical Coordinates: 70023'47.1883" N 150015' 08.9811" W Target Boundary Point #1 5690.80 753.20 N 7123.46 W #2 5690.80 4105.51 S 6780.44 W #3 5690.80 4106.22 S 6780.44 W #4 5690.80 752.49 N 7123.45 W Page Bof9 Dri/lQuest 3.03.02.002 'Q -;r-.. '~'-.J ~~ g=~' c) -, c .~ "-~ ~~- Western North Slope Targets associated with this well path (Continued) 19 May, 2003 - 15:47 Sperry-Sun Drilling Services Proposal Report for 35-19 Plan - 35-19 (wp04) Revised: 9 May, 2003 Mean Sea Level/Global Coordinates #1 #2 #3 #4 5635.00 5635.00 5635.00 5635.00 Page 9 of9 . - ConocoPhllllps 5994650. 5989790.22 . 5989789.50 N ~J5994649.29 N "·-'(œ"23'47.1883" N 150015' 08.9811" W 7Õ~ 22' 59.4021" N 1500 14' 58.8040" W 700 22' 59.3950" N 1500 14' 58.8039" W 70023' 47.1813" N 150015' 08.9810" W .~ ,--,/ DrlllQuest 3.03.02.002 WELL DETAILS ANTI COLLISION SETTINGS COMPANY DETAILS SURVEY PROGRAM WELIPATH DETAILS Name +N/S +V W NorOimg Eastng Latitude Longaudr Sbt PluThitlaska Inc . Depth Fm Depth To Survey/Plan Tool Pao.3S -19 Interpolation Method:MD Interval: 50.00 g Plan: 3S -19 29.88 - 361.12 5993874.02 476091.01 70 °23'39.813N 150°11'40.310W N/A Depth Range From: 28.10 To: 10003.49 Pik 2R 10 1150.00 Planned: 3S-I9 (wp04) V5 CB- GYRO -SS Erg N7ES Maximum Range: 1197.54 Reference: Plan: 3S - 19(W 04) 1150.00 10003.49 Hamd:3S- 19(wp04)V5 WO Rd. Datum: RIB= 55.8'MSL 55.808 g P Calcuhron Method: Minimum Curvature �� Error system: ISCWSA V.s ec4on pN7 origin Starm�q Scan Method: Tray Cylinder North Angk W ?X S FM From TVD Error Surface Rkl +Casing Waning Method: Ruules o Based 273.00' 000 0.00 0.00 From Colour To MD 0 250 LEGEND 2 500 3s -08 (35-08), Ma' r Rkk 500 • 7$0 3S-08 (3S-08A), Major Rnk 750 • 1000 ... 35-08 (3S -08B), Mayor Rsk 35-09 (3S-09), Major Rsk 10(10 1250 3S -10 (35 -10), Major Rsk 0 1250 1 500 •••--- 3S -14 (3S-14), Major Rsk 121 1500 1750 - 3S-I5 (3S -15). Major Rsk II 61 From Colour To MD 3S -16(36 16), Major Rsk 1750 • 2000 0 2 5 0 44.ww 3S-17 (3517), Major Rsk \ 2000 2250 3S- 17(3S17A), Major Rsk 331 0 2250 • 2500 500 500 3S -21(3S 21), Major Ask 100 2500 • 2750 3S -22 (3S-22), Mapr Rsk 750 1000 - 3S -23 (3S-23), Major Rsk / � Ar 2750 • 3000 1000 1250 --- 36 -26 (3S-26), Mawr Risk r • 0 v 3000 • 3250 1250 1500 - P 3si9 Errors / / /3 3250 • 3500 1500 1750 ••••••• Plan 3S20 (Platt 3S -20), Mayor Risk Plan: 3S 24 (3S 24 FD DO NOT USE 3S -03 A/C), Ma / / /� N f � 4' 1 � � 3500 • 3750 1750 - 2000 P m.3s,74 Pan. 35 -a4 >, Mayo Rsk ! f ► 2000 ( 99 75 2250 Plan: „ r"- p . ' 4 P 4• t 2250 2500 ya Plan: 3S-19 (Plan 3S-I9F) 2500 2750 � 10 r , 4 0 2750 3000 3( '0 6111110 .. r • 1 - 19.5 3000 32$0 59 p��� , r l 8 ' 33, //// 0 3250 3500 50 y� / / � % .. // � 3500 3750 / � '` , �' ` 14", \ - 15.0 )11 ,; ley' .. / I 1oL��, 4•�� �. / 0311 Ifs 25 "44 11111' ::: t f 1,!;', to S �� w 0 270 � „ v v 1 -M ■ 1 �� r J � ' _ _ '\ ■ � \ VLO :?)*V.:' \ (;:- ■?,,- 1 t ttttyttf fplVilllt.''. 0' • + - 4 - 15.0 _ : rte „ • - .. 240 4 lir A -i . �..� : ' '120 211 150 r j � + w� -19.5 181 ,.. 0 \ ( --•_ ta...,-- 1.7 III. „..„,,,. ..... loo � 71) vv.- A 50 121 180 Plan : 3S -19 (wp04) (Plan. 3S- 19/Plan. 3S -19) Created By: Ban Goff Dine: 05/09/2003 Checkd: Dare: - Travelling Cylinder Azimuth (TFO +AZI) [deg] vs Centre to Centre Separation [15ft/ill eVC.m - -- Date- Approved - Date:__ - SECTION DETAILS ■ Sec MD Inc Ad TVD +N/ -S +Er -W DLog TFace VSce Target Travelling Cylinder Azimuth (TFO+AZI) de vs Centre to Centre Separation 50ft/i aration n 1 28.10 0.00 0.00 28.10 000 0.00 0.00 0.00 0.00 g y ( ) [ g] F [ ] 2 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 3 600.00 8.00 290.00 598.70 9.54 -26.20 2.00 290.00 26.66 4 -+ ''''r '''''' ( 4 2341.90 59.85 272.53 1996.87 89.83 - 958.03 3.00 340.83 961.42 6 9703. / S 8708.49 30.0037 59.85 272 27253 53 5194.14 589075 363. 33209 47 - 6458152.24 .08 0.00 3.00 1800.0000 0. 671466.63 61.44 }� ' y , M x 4 , i 7 10003.49 30.00 27253 6150.56 369.70 - 7302.09 000 0.00 7311.44 , � � ,.#r ',- .-- .� ks - .tea .:M1 ' ::. w' S ,,x'% ,,..,_ a , . ) Sperry-SUD Anticollision Report '> Có~pany: ,F.ïeld: Reference·· Site: Reference Well: Refere,ri<:e Wellpath: Phillips· ,A.la$kalnc. Kupf;trukHiver Unit Kuparuk3S Pad Plan:3S-19 Plan: 3S~1.9 Date:, 05/09/2003 1 Co-ordil)atetNE) Reference: Vertical (TVD) Re(etence: Well: Plan: . 3S~ 19; l"ru$ No~h . RK6= 55$ M$L55;8 ' Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 28.10 to 10003.49 ft Maximum Radius: 1197.54 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM 18CW8A Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 05/15/2002 Validated: No Planned From To Survey ft ft 28.10 1150.00 Planned: 3S-19 (wp04) V5 1150.00 10003.49 Planned: 3S-19 (wp04) V5 Version: 2 Toolcode Tool Name CB-GYRO-SS MWD Camera based gyro single shot MWD - Standard Casing Points '1\1.(0 í,t 10431.70 T\.U: 'DiaQieter ft,.· ,..,' '" 'in .., 0.00 7.000 8.500 7" Summary <r;:'-":"~-~-~~~-~~':"--- ... ÖffsetWellpath ··~~-"~~'~;-·-~-~-"~I"~~"?" , .~erer~n(:e Offs¢t.., dt~çtr...·"No.Go, ' ÁlIOWAbl~, '.., Site·.., Well WeIl~atb ·.........,MD ',MD I)iS\~Ulçe ' '. Are~ . J)~riati~n ' . ,. ....,' ··,ft' , ft 'ft ... '.tr' ff ,. , Kuparuk 3S Pad 3S-08 38-08 V5 246.92 250.00 220.09 4.55 215.55 Pass: Major Risk Kuparu k 3S Pad 38-08 3S-08A V3 246.92 250.00 220.09 4.55 215.55 Pass: Major Risk Kuparu k 3S Pad 38-08 3S-08B V4 246.92 250.00 220.09 4.55 215.55 Pass: Major Risk Kuparuk 3S Pad 3S-09 3S-09 V2 199.99 200.00 201.06 3.66 197.40 Pass: Major Risk Kuparuk 3S Pad 38-10 3S-10 V6 199.98 200.00 180.60 3.80 176.80 Pass: Major Risk Kuparuk 3S Pad 38-14 38-14 V2 248.58 250.00 100.34 4.37 95.97 Pass: Major Risk Kuparuk 3S Pad 3S-15 38-15 V4 346.53 350.00 81 .40 6.04 75.37 Pass: Major Risk Kuparu k 38 Pad 3S-16 38-16 V4 249.12 250.00 61.11 4.64 56.47 Pass: Major Risk Kuparu k 38 Pad 3S-17 38-17 V6 249.41 250.00 40.74 4.66 36.08 Pass: Major Risk Kuparu k 3S Pad 38-17 38-17A V2 249.41 250.00 40.74 4.77 35.97 Pass: Major Risk Kuparu k 3S Pad 38-18 3S-18 V4 771.04 775.00 20.18 14.70 6.60 Pass: Major Risk Kuparu k 38 Pad 3S-21 3S-21 V4 325.92 325.00 41.37 5.80 35.58 Pass: Major Risk Kuparu k 3S Pad 3S-22 3S-22 V1 754.70 750.00 32.61 12.34 20.29 Pass: Major Risk Kuparuk 3S Pad 38-23 3S-23 V4 661.35 650.00 76.09 11.52 64.81 Pass: Major Risk Kuparuk 3S Pad 3S-26 3S-26 V2 985.68 975.00 67.87 16.58 51.33 Pass: Major Risk Kuparuk 38 Pad 38-26 3S-26A V3 985.68 975.00 67.87 16.58 51.33 Pass: Major Risk Kuparuk 38 Pad Plan: 3S-19 Plan 3S-19F V3 Plan: 3 3900.00 3900.00 0.00 0.96 -0.71 FAIL: No Errors Kuparuk 38 Pad Plan: 38-20 Plan: 38-20 V2 Plan: 3 350.73 350.00 20.17 6.16 14.02 Pass: Major Risk Kuparuk 3S Pad Plan: 38-24 3S-24 FB DO NOT USE 3S 557.78 550.00 98.10 9.31 88.96 Pass: Major Risk Kuparuk 3S Pad Plan: 38-24 Plan: 38-24 V7 Plan: 3 557.78 550.00 98.10 9.42 88.72 Pass: Major Risk Site: Kuparuk 38 Pad Well: 38-08 Rule Assigned: Major Risk Wellpath: 38-08 V5 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 28.10 28.10 28.10 28.10 0.00 0.00 76.82 76.82 9.625 220.10 0.76 219.35 Pass 50.00 50.00 50.00 50.00 0.02 0.02 76.82 76.82 9.625 220.09 1.10 218.98 Pass 75.00 75.00 75.00 75.00 0.05 0.05 76.81 76.81 9.625 220.04 1.50 218.54 Pass 100.00 100.00 100.00 100.00 0.08 0.08 76.80 76.80 9.625 219.95 1.90 218.06 Pass 125.00 125.00 125.00 125.00 0.14 0.11 76.81 76.81 9.625 219.87 2.37 217.50 Pass 150,00 150.00 150.00 150.00 0.20 0.14 76.86 76.86 9.625 219.80 2.85 216.95 Pass 175.00 175.00 175.00 175.00 0.25 0.17 76.95 76.95 9.625 219.74 3.32 216.42 Pass 199.99 199.99 200.00 199.99 0.31 0.20 77.06 77.06 9.625 219.69 3.79 215.90 Pass 223.47 223.47 225.00 224.98 0.35 0.22 77.27 147.27 9.625 219.77 4.17 215.60 Pass 246.92 246.91 250.00 249.96 0.39 0.24 77.60 147.60 9.625 220.09 4.55 215.55 Pass 270.32 270.32 275.00 274.91 0.42 0.26 78.06 148.06 9.625 220.65 4.94 215.74 Pass 293.68 293.66 300.00 299.84 0.46 0.28 78.63 148.63 9.625 221.46 5.33 216.16 Pass 316.98 316.95 325.00 324.76 0.50 0.31 79.28 149.28 9.625 222.48 5.73 216.79 Pass 340.23 340.18 350.00 349.66 0.54 0.34 80.00 150.00 9.625 223.71 6.13 217.63 Pass ORi "\" ~ ~ .,' ; \ ~ ~ ; \ ~. !i \: ...:.;1 ,~ ;:.;;~~ c=;c"-~ r~'"-) ~:c.... "'--:J ~..':-~ ........ L~ r-- Sp&!r'f""'Y-SLJI1 u....IL-'-IN~ :.:.eRVICeS A Halliburton Company ScaJe: 1inch = 1500ft -7500 -6000 I I Total Depth h"ì g'>'OO.OO. "900.00 10003.49ftMD ~ \ 38-19 (wp04) 6150.61ftTVD <0 g¡ ~ -I ~ 7inCasing """ a. ~» 0 g' 1ooo3A9ftMD g 0 "T1:D 9=' (Q 6150.611tTVD :;:. _:::;' Z ~ ~ 5' <0 en ï -I ;:; ;:;- Qo., ~º ~Q) 0<0 "'" P~~'èf'P @ ~. ~.O!¡~ ~ 8@ II ~ ~ g o ---1¿SHL (2~42.17' F~JL & 116!.69' FE~; SEC'1!- T12N..: RaE) ~ ~ ~ ~ :.. ~ _ _ _ _ __ /KOP Begin Dir @ 2.0000/100ft : 200.00ft MD, 200.00ft TVD -I 0 Ccf?u ~ g <g ()O'I<;:; Oo.....lEo /Increase Dir Rate @ 3.0000/100ft: 600.00ftMD,598.70ftTVD (.ù 0 ..:..¡~ I ~g ~~ ~O J!! õ) T- en £?. .£: Õ. 3000 - Q) o (ij () '-e Q) > 8 ~ II .J::: (.) ~ 6000 - Qj 13 (f) DrillQuest 3.03.02.002 Western North Slope ConocoPhillips Kuparuk 3S Pad 35-19 Wp 4 Conoc~illips 1500 - Sperry-Sun Drilling Services -4500 I Eastings(3S-19) -3000 I ...j!.oo.oo ';900.00 ,¡¡.ooo.oo End Dir, Start Sail @ 59.854°: 2341.90ftMD,1996.87ftTVD -5/8" Csg Pt ... Drill out 8-1/2" Hole: 3534.04ft MD, 2595.58ft TVD 4500 - N c:?~ 05) (True North) Section Azimuth: 273.0000 o Scale: 1inch = 150011 I 1500 I 3000 Vertical Section (3S-19) I 4500 I 6000 7500 Section Azimuth: 273.000· (True North) Total Depth: 10003.49ftMD 6150.61ftTVD Current Well Properties 3$-19 Plan Wen: Horizonlal Coordinates: Ref. Global Coordinates: 5993874.02 N, 476091.01 E Ref. Project H Reference: 993792.47 N. 27087.63 W Ref. Geograptical Coordimtes : 70' 23' 39.8133· N. 150' 11' 40.3099' W RKB Elevation: 55.8011 above Mean Sea Level North Reference : Units : True North Feet (US Survey) ¿<EOO.oo fr c'24oo.00 <0 Ó1 ~ () (f) (Q ::2 ~ o S. ~ rq I o <D (.ù 0'1 (.ù . >. o . >. ;::r ~ .0 I\) 0'1 <0 0'1 è.n CO ;::r -I < o Begin Dir @ 3.0000/100ft 8708.37ft MD, 5194.19ft TVD TARGET: 9703.49ft MD, 5890.80ft TVD (2182' FNL & 3515' FWL Sec 13-T12N-R7E) End Dir, Start Sail @ 30.000° 9703.49ftMD ,5890.80ftTVD -1500 I (0 o ;::r ~ P DrillQuestN o I I / .J90~ k- 0 g¡ :J^ ~ a. () 0 r º m"U Ñ ."'" en OJ (Jl ÇQ <D~ it ~ . ~ 5~ :_4 (J) :DO ~ ~ ~ ~ @ I\) Qo (.ùg § ~ g ~o Þq C;§f 'T1 §f ~~ m IV r (J)g (j) go m o g 0 g~ ~o cp ~~ <00 9='0 ~g JJ ~<! Æ 00 0'1 <0 ~ 0'1 ~ I\) (.ù ~ <0 <0 (J) ~ ~ < o õ) en C'? ìñ 0> c:: :E t o Z -~ ---i N Z - ) ) 35-19 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" CasinQ Interval Event Broach of Cond uctor Gas Hydrates Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb / water flow around 1200' Lost Circulation Risk Level J u. Mi~i9.ation Strél~~9Y Low Monitor cellar continuously during interval. Low Moderate Moderate Low Low 8-1/2" Hole / 7" CasinQ Interval Event Shale stability in HRZ, K-1, and Miluveach High ECD and swabbing with higher MW's required Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation Risk Level Low Moderate Low Moderate Moderate Moderate If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM Mitigation Strate~y Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 3S-19 Drilling Hazards Summary. doc prepared by Scott Lowry 7/30/02 1"'\ p"", ·7 ~. ~ '\ , '1 L ,/ r: '. ~ <: ~ " t 1 i ;',."; y ~\;~ ~ ~ (,1 /" ~ .. Page 1 of 1 ., KRU - 35-19 Prc~t.cer Proposed Completion Schematic Single Completion wI Jet Pump Contingency 16"x30" insulated I I conductor@ ~~ ~ +1- 109' MD ~ ! ~ TAM 9-5/8" portM ~ Collar Stnd Grade B TC fà Threads(+~ ~ 1000' MD/TVD) ~ Surface csg. I 9-5/8"40# L-80 j BTC (3534' MD I ....a 2596' TVD) Casing point 100' above the C80 sand C Sand Peñs (to be done after rig moves off) Production csg. 7" 26# L-80 BTCM (+1- 10003' MD) ¡ I r I ( ~ .. ~I ~ ~ ~,~ ~ ~ ~ I h I h_ i I I I I~ ~ ~ ~ ~ I ~ ~ ~ ! I ~ ~ ~ ~ i ~ ~ ~ ~ 2 ~ ~ ~ I i ~ ~ ~ i I ~ ~ ~ ~ I I i ~ i ~ ~ ~ ~ ~ ~ ~ ~ ! ~ ~ ~ ~~~ ~ ~ ~ ~ i~~ ~ ~' ~ ~ ~ ~ ~ i 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~------'- J r it" -- - ,-:-- r-- ~ ~ ~ ~ ~ ~ I. ~ 3:: ~ ~ WW(:_¡_ ._~ ~ ~ ~ ~ ~ ~ ~ ¥. i~ :C~~~t .J1Í...: C· ) ~Ph·· ..... ,ell'· onooo: J ·.pS 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-112", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" Cameo DS Landing Nipple with 2.875" ID No-Go profile set @ +1- 500' MD. Use of port collar at the discretion of the drilling team. GLM Placement: Valves #1-4: 3-W' x 1" KBUG Place gas-lift mandrels at the following depths: TVD Approximate MD Placement TBD Valve #5: 3-1/2" x 1-1/2" 'MMG' GLM wi DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandreL 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Baker 'CMU' sliding sleeve w/2.813" Cameo No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +1- 100' MD above top planned perf. Minimum ID through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9,3# EUE 8rd Mod Tubing. 3-1/2" Camco 'D' nipple wi 2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" WL Re-entry Guide wi shear out sub. Tubing tail 50' above top planned perforation. TD @ 10003' MD /6151' TVD OD;¡''-;-\ , , I~ fl' li ¡) i \. J"/ I j i 1 ( Scott L Lowry 5120/03 I"""...-! ) ) s. K. ALLSUP-DRAKE 1044 CONOCOPHILLlPS 711 G STREET - AT01530 Hi ANCHORAGE AK 99501 DATE . ~/2 ~ 2(£)'1 62-14/311 6~1~~ ¿~E'STI{T E () r II LAsrl4 /14 C)(-l ('( I $ /to. C<:) ____ L-~'-€ fUPk-c.l Þ'-é cl cJô l¿:í_f;. ,~¡J ./"LAc:' /rCJô c:c------DOLLARS tÌI ~~ CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars ~, 200Whlto Clay Cant., Dr. Nowa'k DE 19711 ._Si~~'Úé~ yl4» H4k I: 0 3 . .00 . ~ ~ I: 2 . aDO 0 0 ~ 2 7 2 5 7111 . 0 ~ ~ MEMO ... ) ') TRANSMITAL LETTER CHECK'LIST CIRCLE APPROPRIATÊ LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER l;:/2IÆ.S S ~/1 ZO~ -096 WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) Pß..,OT (PH) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number, stated above. BOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated In both 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 Rev: 07/10/02 C\j ody\templates The permit is approved subject to fun compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST Company _~Qr.·LQC_QE.HIL..LIP~A.LASKA INC Well Name: KUPARUK RIV UNIT 3_5.::19 Program DEV Well bore seg D PTD#: 2030960 Field & Pool ~UPARUK RIVER, KUPARUK RV OIL - 490100 Initial ClasslType DEV 11-01L GeoArea 890 Unit 11160 On/Off Shore _O~l_ Annular Disposal D Administration 1 P.ßrmit. fee attached. _ _ _ . . . . . . . . . . . . . . . . . . . _ _ _ _ _ . . . . . . . . _ . . . . . . . . Y.ß$ . . . . . . . . . . . . _ . . . . _ . . _ _ . _ . . . .. . . . . . . _ . _ . _ _ _ . _ _ . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . 2 .Leas.ß.number _appropriat.e. . . _ . . . . . . . _ .. _ .. _ . .. . . . .. . . . _ . . . . . . .. . _ . . . _ .. _ Y.ß$ _ _ . _ .. _ .. . . . . . . . . . .. .. . . . .. _ . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . _ .. _ .. _ . . _ . . _ . . . . . . . 3 .u.ni.que weILn.arn.ß.and oumb..er . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . .. . . _ . _ . _ _ Y.ß$ . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . _ .. . . . . _ .. _ . . . . . . . . . _ . . . _ . .. . .. . . . . . . . . . . .. . 4 .W~IIJQcat.ßd in.a. d.efil1ed .pool.. . _ . . . . . . _ .. _ _ . . . . _ . . . .. . . . . . . . . .. _ .. _ .. _ _ _ . Y.ß$ _ . . . ,. . . . . .. .. . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . _ . . . . .. . . . . . . _ . _ _ . _ . . _. .. . _ . . . . . . . . 5 .W~II JQcated prpper .distance.from. qriJling unit.b_oundary. . _ . .. . . _ _ . . . _ _ . . _ _ . .. _ . .. . Y.ß$ . . .. . . . . . . . . . . . . _ . .. . . . . . . . . . _ . . _ . . . . . . . .. _ . . . _ . . . . . . . .. . . . . _ . .. . . . . . . _ . . _ . _ . . . . 6 .W~II JQcat.ßd peoper .distance. from. Qtb~r wells. . _ .. . . _ . . . . . . .. . .. . . . . . . . _ . . .. . _ . Y.ß$ . . . . .. . . . _ _ _ . . _ . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . _ . . .. .. . . . . . .. . . . _ . _ . _ . . . . _ . . .. . . . . 7 .S.utfiçiel1t acreag.e.aYailable in.drilJiog unH. . . . . . _ . . . . . . . . . . . . . . . . . . . .. . . . . .. Y.ß$ . _ . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . _ _ .. . . . . . .. .. . . . 8 .If.deviated, .is. weJI bQre platJnc.!uded . . . . . . . . . . . _ . .. . . . .. .. . _ . . . . . . . . . . . . . . Y.ß$ . . . . . . . . . . .. . . . . . . . . . .. _ . .. _ . . . . . . . . _ _ _ . . .. _ . . _ . . . . . . . _ . . . .. .. . . . . . .. _ _ . . . . . . . . . 9 .Oper:.ator only- affected party. . . .. ..... _ . _ . . . . . . . . . . . . _ . . _ . _ . .. . . _ . . . Y.ß$ . . _ . . . . . . . . . . . . . . . . . .. _ . . _ . . . . . . _ . . _ . . . _ _ _ _ _ _ . . . . . . . . . _ . . . . _ . . . . . . _ . . . . . . . . . 10 .Oper:.ator bas.appropriate. Q.ond in JQrc~ . .. . . . . . . . . . _ . _ _ . . . . _ . . . . . . . . . . . . . Y.ß$ . . . . . . . . . . .. . . . _ _ . . . . _ _ _ _ . _ . . . _ . . . . _ . . . _ _ . . . . . . . . . . . . . . . . .. . . . . . . . . . .. . 11 P.ßrmit. c.a(1 be iS$ueØ wHI)Qut conserva.tion order. . _ . . _ .. . _ . . . . . . . . . . . . . . . . . . . Y.ß$ . _ _ .. .. . .. .. _ . _ .. . _ _ . _ . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . _ . . . . . . . . . _ . _ . . _ . _ . . _ . . . . . . . Appr Date 12 P.ßrmit. c.a(1 be iS$ueØ wHbQut ad.mil1i$tr:.atÌ\le.approvaJ .. . . . . .. . .. _ _ . _ . . . _ . . .. . . . . . Y.ß$ . . . . . . . . . . . . .. . . . . _ . . . _ . _ _ . _ _ . _ _ . . _ . . _ . . _ . . . .. . . . . _ . . . . . . . . . _ . .. _ . _ .......... ) 5/29/2003 13 .C.a(1 permjt..be apPJQved before .15-Øay. wajt. . _ . . . . . . . . . . . . . . . . . . . . .. .. . . . _ _ _ Y.ß$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . _ .. _ . _ . _ .. . . _ . . . . _ . . . . . . . . . . . . . . . . . . . . 14 .W~IIJQcat.ßd wi.thil1 area al1.d.strÇlta authori.zed b.y.lojeGtioo Ord.ßr # (put. 10# in.cPlJ1rn.ßotsUFor. .NA . . . . . . . . . . . . _ . . _ _ _ _ . . _ . . . . _ _ . . . .. . .. _ _ _ . _ . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . .. _ . . . . . 15 .All wells. withi.n .1 l4.llJil.e.are.a.of (eyiew id.ßotified (For:. serv.ic.ß .well c;>I1IY-L .. . . . . .. . . _ . . . _ _ NA.. .. . . . . _ . . . . . . .. .. . _ _ . . . . . . . . . . .. . . . . . . . . _ _ .. . _ .. . . . _ . . . . . .. _ . . . . . . _ . . . . . . . _ . . . . . 16 Pr~-produ.ced. injector; .duratio.n.of pre-p(oduGtiOI1I.ß$s.. than. 3 months. (For.service well. QnJy) . _ _NA . . .. . . .. _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . _ _ _ . . . . . . . . . . 17 .A.cMP. F:indjng .of CQn_sißtenGy.ha$ be.en Jssued.for.tbi$ prpiect. . . . . . . . . . . . . . . . . . . . NA . . . . . . . . . . . .. . . .. . . . . . . . .. . . . . . . . .. . . . _ . . . _ . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . .. . . . . 18 .C.o(1du.ctor $tring.PJQvided . . . . . . . . . . . . . . . _ . . _ _ .. _ . _ . . . . . . . . . . . . . _ . . . Y.ß$ _ . . . . . . . .. . . . . . . _ . . .. . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . .. . . . . . _ _ . . . _ . . _ _ . . . . . . . . . . . 19 .S.ud'ac.ß.casing.PJQtec.ts..all.knQwn.USQW$.... _.... _. _............... _. _.. _ NA...... .All.aq!,JifeJ&expempteq40.CF:R14.7,1P2(b)(3)................ _ _.......... _......... _.... 20 .CMT. v.ot adequ.ate.to circ!,Jlate.on .cond.uçtor. & $uJf_csg _ . . . . . . . . .. .. . . . .. . . . . . . . . _ Y.ß$ . _ . . . . . .. . . . . .. . . . .. . . . . _ . . .. . . .. . . . . _ . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . .. . 21 .CMT.vpl.adeQu.ate.totie-LnJQngßtringto..s!Jr:.f~g.. _ _.............................. _ _ _.... NA............ ..Al1n.!..ltardi~p..o$al!Jltim;;ltelyplaoneØ._........ _. _ _ _.. _........................................................ 22 .CMT.will GoYer_aH .koo.wn,pro..dUGtiye bQri?on.s. . . . . . _ . .. . . _ . . . . . . . . . . . . .. .. _ . . . Y.ß$ . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . .. . . _ . . _ . . . . . . . . _ . . . . . . . . . _ . _ _ . . . . . . . . . . . 23 .G.asi(1g d~s¡gns ad..eç lJat~ for C,.T~ 8.&. p.erllJafrp$t. . . _ . _ . . . _ . . . . _ . .. . .. . . . . . . . . Y.ß$ . . . . _ . . . . . . . . . . . . . . _ . . _ . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . 24 .Adequate..tan.kage.oJ re.serve pit . . . . . . . . . . . _ . . _ _ . .. _ . . . _ . . . . . . . . . .. . .. . . Y.ß$ . . . . . . . Rig .ßQUiPP.ßd wi.th steeJ pits, Np JeS.ß(vß pit plal1n.ßd.. Waste to.a.n.approved .anouJu.s.or disposal wet!.. . . . . . . . 25 .If.a.re-Ø(ill~ has.a. 1.0A03 fQr aba.nØon..me_nt be.ßO apPJQved _ . _ . . . . _ . _ . . .. . . . . .. . .. _ . NA . . . . . _ . . . . . . . . . . . _ . . . _ . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 .Adequate..wellbore. separatjon .proposeø. . . . . . . . . _ . . _ . . . . . . . . . . . . . .. . .. . . . . Y.ß$ . _ . . . . . Pro~imity. anaIY$i$ p~rfprrT)e.d, Close apprQacheß Jd.entjfi.ed.. Traveling cyIJn..der:. plQt jn.cLud~d, .Gyros possible. . .. . 27 Jf.djv.erterJequiJ~d.dQesjt.rneet.reguJa.tions...................... _.. _..... NA...... .OS3Shas.b.eeograotedadiy~rt.ßrwaiver....................... _.................... 28 Dril.liogflujd.prQgrallJ$c.hemati.c.&.eq!,JipJi$t.aØequat.ß........................... Y.ß$. . . . . . . Max expecte.d.B.HP. 1.1 ,3.EMW.. Pla(1nedMW ~1.8in.Kuparuk.. . . . _ . . . . _ . . .. ........ 29 .S.O.P.E$,. d.o .they meet r~guJa.tiOI1 . . . . . . . . . . . . _ . . . . . . . . . . . . _ . . . . . .Y.ß$ . . . . . . . . . . . _ . . . . . . .. . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . . . . . . _ . . . . . . . _ . . . . . 30 .BOP.E.pre.ss ra.tiog appropriate; .testto.(pu.t psig in .comment$). . . . . . . . . . . . . . . . _ . . . .Y.ß$ . . .. . . . . MAS!? caIGulate.d.at 2828 psi, 35QO.psLapprppriate.. PPCo Ijk.ßly.tQ t.esUQ 50.00 P$i.. .. . . . . . . . . . . . . . . . . . 31 .C.hoke.manjfold cQmpJies. w/API.RP-53 (May 84). . . . . . . . . _ .. . . . . . . . . . . . . . . . . . .Y.ß$ . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . 32 WQrk will oCC.!..lr without..operation .shutdown. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . .Y.e$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . _ . . . . . . . . . . . . . . . _ . . . . . . . 33 .Is presence. Qf H2S gaS. Rrob.able. . . . . . . . . . . . . . . . . . . . . .. . _ . . . . . . . . . . . . . No.. . _ . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ....... 34 Meçba.ni.CÇlI.coodWo[l o{ w~lIs within AOR verified. (For.s..e(Vice w~1) QnJy). . . . . . _ . . . . . . . No. . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . Engineering Appr Date -)1 5/30/2003 j-CShù Geology Appr SFD Date 5/29/2003 Geologic Commissioner: 075 --------- 35 136 137 138 i39 P.elJlJit. c;an be issu.eØ w/o. hyØrogen. s.ul.fide meas!,Jres. . . . . . . . . . . . _ . . . . . _ . . . . . . Y.ßs . . _ . . . . . . . . . . . . . . . . . . . . . . . . . .. . .. . . . . . . . . . . . . . . . _ . . . .D.ata. pre.seoted on. pote.ntial overpres.sur.e .zones. . . . . . . . . . . . .. . .. . . . . . . . . . . . .. . .Y.ß$ . . . . . . . Expected. r.e$eJ"Voir .pressu.re is .11.3 ppg EMW; will be drilled with. 1.1,8. ppg muø.. . . . . . . . . . . . S.ßi,srn[c.analys.is. Qf sba.llow gas.zones. . . . . _ . . . .. . . . . _ . . . . NA . . _ . . . . . . . . . . . .S.eabed .condition survey.(if off-shore) . . . . . . _ . . . . .. . . . . . . . . . . . . . . . . . _ . . . . NA . . . . . . . . . . . . . . . .. . . . . . .. .. . . . . . . .. . . . . . . . . . . . . . . . . . .. . . . . . .. . . . _ . . . .. .......... . CQnta.ct nam.elphone.for.week.ly progress.reports [exploratory .only]. . . .. . . . . . . . . . .. . . . NA . . . .. . . . . . . . . . . . . . .. . . . _ . . . . . . . . . . . . . . .. . . _ . . . . . . . . . . . . . . . . . _ . . . . . . _ . . . . . . . . . . Date: Engineering Commissioner: Date Operator plans to drill well without diverter. Public Commissioner Date o~/ó?J(O) ~~ ~\~~'J ) ') Well History File APPENDIX Information of detailed nature that is not particulariy germane to the Well Pennitling Process but is part of the history file. To improve the readability of the Well History file and to sinlplify finding infomlation, infomlation 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. '\ ì I " ~ ð3 -ocr 0 $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 20 10:18:18 2004 .; I~)~~ l \ Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/01/20 Origin.................. .STS Reel Name................UN~~OWN Continuation Number......Ol Previ.ous Reel Name.......UNKNOWN Comments.................STS LIS Writi.ng Library. Scientific Technical Services Tape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/01/20 Origin. . . .. . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOr: Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3S-19 501032046000 ConocoPhillips Alaska, Inc. Sperry Sun 19-JAN-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002513099 E. QUAM L. HILL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 12N 8E 2542 1169 .00 56.06 27.70 RECEIVED # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3580.0 6.000 9.625 3580.0 r-·r-rì 1/-, "on - ~~. LJ ~ ~ L j C 4 ,;:Vaska on & Gas Cons. Commismnn Am:hM'age # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOT ED. ? ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. ~~~ '^ ' \ --.:.~ .\..~ \ \ " ~ ) ) 4. MWD RUNS 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND STABILIZED LITHO-DENSITY (SLD). 5. MWD DATA ARE CONSIDERED PDC PER GKPA GEOSCIENCE GROUP. CTN DATA ARE CALCULATED USING THE LESSER OF ACOUSTIC AND SLD CALIPERS FOR HOLE SIZE INDICATION. 6. MWD RUNS 1-3 REPRESENT WELL 3S-19 WITH API#:50-103-20460-00. THIS WELL REACHED A '1'OTAL DEPTH (TO) OF 10038 rMD I 6187'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 (DEEP RESISTIVITY) . 'I'NPS = SMOOTHED THERMAL NEUTRON POROSI'l'Y (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA SMOO1.'HED AVERAGE OF FAR DE'l'ECTOR' S COUN'l' 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 = SMOOTHED MINIMUM OF .ACOUSTIC CALIPER AND SLD CALIPERS. SLDSLIDE = NON-ROTATED INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL DATA MUD WEIGHT: 10.0 PPG MUD SALINITY: 1200 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/0l/20 Maximum Physical Record..65535 File Type.. ..............LO Previous File Name.......STSLIB.OOO Comment Record FILE HE}\OER FILE NUMBER: 1 EDITED MERGED HWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE CALA ROP NCNT . FCNT NPHI GR FET RPD RPM RPS RPX PEF DRHO RHOB $ ) START DEPTH 3516.0 3558.5 3558.5 3558.5 3558.5 3558.5 3570.0 3570.0 3570.0 3570.0 3570.0 3570.0 3580.5 3580.5 ') STOP DEPTH 9951.5 10037.5 9949.0 9949.0 9949.0 10005.5 9998.0 9998.0 9998.0 9998.0 9998.0 9962.5 9962.5 9962.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ # REMARKS: BIT RUN NO MERGE TOP 2 3516.0 MERGED MAIN PASS. $ MERGE BASE 10037.5 # 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 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 MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHt1M 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD GICM 4 1 68 44 12 DRHO MWD GICM 4 1 68 48 13 PEF MWD S/E 4 1 68 52 14 CALA MWD IN 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3516 10037.5 6776.75 13044 3516 10037.5 ROP MWD FT/H 2.25 420.88 171.918 12959 3558.5 10037.5 GR MWD API 48.26 468.58 123.225 12895 3558.5 10005.5 RPX MWD OHfvlM 0.44 170.21 4.13641 12857 3570 9998 RPS fvlWD OHMtvl 0.06 2000 4.41249 12857 3570 9998 RPM MWD OHMM 0.15 109.69 4.26977 12857 3570 9998 RPD HWD OHMI'I 0.15 2000 5.91103 12857 3570 9998 FET MWD HOUR 0.1575 117.186 0.908204 12857 3570 9998 NPHI MWD PU-S 18.89 66.22 38.516 12782 3558.5 9949 ) ) FCNT MWD CNTS 5:\2.4 2232.9 992.836 12782 3558.5 9949 NCNT MWD CNTS 111469 192505 141842 12782 3558.5 9949 RHOB MWD G/CM 1.789 3.091 2.31001 12765 3580.5 9962.5 DRHO MWD G/CM -0.421 0.385 0.0443054 12765 3580.5 9962.5 PEF MWD B/E 1. 65 13.47 3.41976 12786 3570 9962.5 CALA MWD IN 8.5 11. 3189 8.6667 12509 3516 9951.5 First Reading For Entire File..........3516 Last Reading For Entire File...........10037.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04101/20 Maximum Physical Record..65535 Fil e 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.......04/01/20 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 CALA ROP NCNT FCNT NPHI GR PEF FET RPD RPM RPS RPX DRHO RHOB $ 2 header data for each bit run in separate files. 2 .5000 S'I'A.RT DE PTH 3516.0 3558.5 3558.5 3558.5 3558.5 3558.5 3570.0 3570.0 3570.0 3570.0 3570.0 3570.0 3580.5 3580.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUH ANGLE: J'v1A:'\IMUM ANGLE: TOOL STRING (TOP TO BOTTOM) STOP DEPTH 9951. 5 10037.5 9949.0 9949.0 9949.0 10005.5 9962.5 9998.0 9998.0 9998.0 9998.0 9998.0 9962.5 9962.5 30-JUN-03 Insite 0.43 Memory 10038.0 3516.0 10038.0 28.4 61. 4 ) VENDOR TOOL CODE DGR EWR4 SLD CTN $ 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 (L8/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 DENSI'I'Y: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O 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 Abs en t va 1 ue. . . . . . . . . . . . . . . . . . . . . . - 9 9 9. 25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Speci fication Blocl<: sub-type... 0 ) TOOL NUMBER 124724 56933 15184: 181190 8.500 3580.0 LSND 11. 80 53.0 9.0 500 3.4 1.100 .613 .900 1. 800 80.0 149.0 80.0 80.0 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 OI-IMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1. 68 44 1.2 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BIE 4 1 68 52 14 CALA MWD020 IN 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3516 10037.5 6776.75 13044 3516 10037.5 ROP MWD020 FT/H 2.25 420.88 171.918 12959 3558.5 10037.5 GR MWD020 API 48.26 468.58 123.225 12895 3558.5 10005.5 RPX ¡V¡WD020 OHMM 0.44 170.21 4.13641 12857 3570 9998 RPS MWDO:20 OHMM 0.06 2000 4.41249 12857 3570 9998 RPM MWDO:20 OHMJvl 0.15 109.69 4.26977 12857 3570 9998 RPD MWD020 OHMM 0.15 2000 5.91103 12857 3570 9998 ) ) FET MWD020 HOUR 0.1575 117.186 0.908204 12857 3570 9998 NPHI MWD020 PU-8 18.89 66.22 38.516 12782 3558.5 9949 FCNT MWD020 CNTS 532.4 2232.9 992.836 12782 3558.5 9949 NCNT MWD020 CNTS 111469 192505 141842 12782 3558.5 9949 RHOS MWD020 G/CM 1.789 3.091 2.31001 12765 3580.5 9962.5 DRHO MWD020 G/CM -0.421 0.385 0.0443054 12765 3580.5 9962.5 PEF MWD020 SIE 1. 65 13.47 3.41976 12786 3570 9962.5 CALA MWD020 IN 8.5 11.3189 8.6667 12509 3516 9951. 5 First Reading For Entire File..........3516 Last Reading For Entire File...........10037.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/01/20 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.003 Physical Eor Tape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/01/20 Origin...................ST8 T ape Name................ UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scienti fie Techni.cal Services Reel Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/01/ 2 0 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Next Reel Name...........UN!\.NOWN Comments. ................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
