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206-043
2025-0104_Surface_Abandon_KRU_3S-23A_jh Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:1/4/2025 P. I. Supervisor FROM:Josh Hunt SUBJECT:Surface Abandonment Petroleum Inspector KRU 3S-23A ConocoPhillips Inc. PTD 2060430; Sundry 324-492 1-4-2025: I traveled to location and met with ConocoPhillips representative Brennen Green. The excavation was complete, and the wellhead was cut off and removed. The cut appears to have been done with a torch and was not the cleanest I’ve see, but deemed acceptable for welding the marker plate I had Brennen go down and pound on each cement interval with a heavy steel bar. The cement was hard in all of them. This well has a 16-inch insulated conductor with a 30- inch OD, followed by 9-5/8 inch surface casing, 7-inch intermediate casing, and a 4-1/2 inch tubing. The marker plate was 30 inches by ¼-inch with all the information found accurate and legible. The cut was 177 inches below the top of the shoring and the pad grade was 29 inches below the top of the shoring, leaving the cut 148 inches below pad grade. Tundra is 66 inches below pad grade which puts the cut at 82 inches (6.75 feet) below original ground level. I gave the go ahead to proceed with welding the marker plate on and departed location. Subsequent approval was given to backfill after I received a picture of the plate as installed. Attachments:Photos (3) 9 9 9 9 9 9 pg cut at 82 inches (6.75 feet)below original ground level. James B. Regg Digitally signed by James B. Regg Date: 2025.01.08 15:09:47 -09'00' 2025-0104_Surface_Abandon_KRU_3S-23A_jh Page 2 of 3 Surface Abandonment – KRU 3S-23A (PTD 2060430) Photos by AOGCC Inspector J. Hunt (except as noted) 1/4/2025 Measuring from top of shoring pipe to top of cut – 177 inches Cutoff showing insulated conductor and hard cement in each interval 2025-0104_Surface_Abandon_KRU_3S-23A_jh Page 3 of 3 Marker plate after welding on cutoff well – photo courtesy of CPAI 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: Service CTU Rig Elevation: Total Depth: 14144 ft MD Lease No.: ADL0380107 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ na Feet Surface: 9 5/8" O.D. Shoe@ 4040 Feet Csg Cut@ na Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ na Feet Production: 7" O.D. Shoe@ 10472 Feet Csg Cut@ na Feet Liner: 4 1/2" O.D. Shoe@ 14144 Feet Csg Cut@ na Feet Tubing: 3 1/2" O.D. Tail@ 10333 Feet Tbg Cut@ 9805 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Annulus Bridge plug 4241 ft 4240 ft N/A Initial 15 min 30 min 45 min Result MIT Tubing 1670 1660 1655 IA 1670 1660 1655 OA 373 396 397 Initial 15 min 30 min 45 min Result DDT Tubing 0 0 0 IA 0 0 0 OA 17 19 19 Remarks: Attachments: I traveled to KRU 3S-23A to witness a MIT and drawdown test (DDT) on the CIBP set @ 4240 ft MD after milling out old cement. Tubing was cut and removed so tubing and inner annulus are same bore void. Next step is to pump cement plug from CIBP to surface. December 18, 2024 Adam Earl Well Bore Plug & Abandonment KRU 3S-23A CPAI PTD 2060430; Sundry 324-492 none Test Data: P Casing Removal: John Condio P Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-1218_Plug_Verification_KRU_3S-23A_ae 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): 14144'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-23A 5900' 29' 29' 1440 29', 5660', 6392', 10048', 10322' 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): 10270' MD and 5834' TVD 530' Md and 529' TVD Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544, ADL0380107 206-043 P.O. Box 100360, Anchorage, AK 99510 50-103-20453-01-00 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 10333' MD 108' 2606' 108' 4040' 5852'10472' 16" 9-5/8" 78' 4011' 10475-14091' (cemented) 6542-6692' (Perf Wash Cement) 10443' 4-1/2" 5852-5901' (cemented) 4030-4117' (Perf Wash Cement) 7" Perforation Depth TVD (ft): 9/10/2024 14144'3874' 3-1/2" 5900' Packer: HR ZXP Liner Top Packer SSSV: Camco DS Nipple w/ NoGo 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 8:10 am, Aug 27, 2024 Jill Simek Digitally signed by Jill Simek Date: 2024.08.26 17:17:11 -08'00' 324-492 DSR-8/27/24 AOGCC inspection is required after cutoff and before any remedial cementing. SFD 8/28/2024 10-407X X VTL 9/5/2024 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.06 14:43:05 -07'00'09/06/24 RBDMS JSB 091024 3S-23A Plug and Abandon Procedure PTD #206-043 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 63 PSI IN 60 MINS (COMPLETE) Inial I/O = SI 172/0 Put IA on open bleed for 3 hrs. SI for 60 min monitor. Start I/O = 0/0 15 min I/O = 30/0 (+30) 30 min I/O = 45/0 (+15) 45 min I/O = 57/0 (+12) 60 min I/O = 63/0 (+6) Final I/O = SI 63/0 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 6,718ft 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 ~6,392ft 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-23A Plug and Abandon Procedure PTD #206-043 Page 2 of 2 Coil 17. MIRU. 18. Pump cement plug in production casing, from top of cement to surface. Job is planned for 245 bbls cement. 19. RDMO. Pumping 20. MIRU. 21. Perform OA down squeeze to place cement from surface to 4,040ft KB. Job is planned for 134 bbls of cement, including excess. 22. RDMO. Remedial Cementing – Milling (Coil) 23. MIRU. 24. Mill cement in production casing to depth of 4,240ft KB (200ft below surface casing). 25. RDMO Remedial Cementing – Set Plug (Eline) 26. MIRU. 27. Set plug (CIBP or BiSN) at ~4,240ft 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 162 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-23A PTD #: 206-043 API #: 50-103-20453-01 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 63 PSI IN 60 MINS (COMPLETE) 8/8/2024 (P&A) COLLECT 2 IA ISO-TUBE SAMPLES (COMPLETE) DDT IA TO 0 PSI (IN PROGRESS) 3/31/2024 (P&A) OBTAIN IA GAS SAMPLE, BLED IA FOR BUR (IN-PROGRESS) 3/19/2024 (P&A) DEGAS THE OA (COMPLETE) DEGAS THE T X I (IN PROGRESS) CEMENTED THE OA TO SURFACE (COMPLETE) 3/3/2024 (P&A) (IN-PROGRESS) REMOVED TREE VALVES, CEMENT BRIDGE INSIDE SWAB VALVES, TOC @ 5'9", ~1' OF FLUID IN IA. 3/2/2024 (P&A) VERIFY 0 PSI ON IA & OA, VERIFIED TOC THROUGH TREE CAP (CEMENT JUST BELOW SWAB VALVE) REMOVED CASING VALVES(CEMENT VISIBLE @ IA CASING SPOOL) *NEXT STEP: DEMO SCAFFOLDING & REMOVE DOUBLE SWAB VALVES* 2/27/2024 TAGGED TOC @ 5628' CTMD & LAY IN 239 BBLS (24 BBLS EXTRA) OF 15.8 CLASS G CEMENT TO SURFACE, (CONFIRMED 15.8 PPG CEMENT). WASHED UP BOP'S & TREE (CYCLED MASTER VALVES). READY FOR DHD IN 48 HR 2/26/2024 FINISH RIG UP; ATTEMPT BOP TEST AND UNABLE TO OBTAIN TEST DUE TO HYDRAULIC LEAK ON UPPER SHEAR RAM BONNET; STANDBY FOR REPLACEMENT BOP'S FROM DEADHORSE; OBTAIN PASSING BOP TEST (FUNCTION TEST, FULL BODY, & PUSH PULL) ON NEW SET. 2/25/2024 STANDBY FOR DHD & VALVE CREW RIGGED UP ON 3S-624 BLOCKING 3S-23; RIG UP CTU 14 W/ 2" COIL. 2/19/2024 (P&A) T x IA DDT(PASS), OA DDT (PASS) 2/14/2024 STATE WITNESS TAG @ 5616' RKB, GOOD CEMENT, PERFORMED PASSING PRODUCTION CASING TEST. READY FOR CTU. 2/10/2024 CLEAR ICE PLUG IN COIL. RIH W/ 2.5" CEMENTING NOZZLE, LAY IN 40 BBL OF 15.8 PPG CLASS G CEMENT FROM TAG AT 6,707' CTMD TO 5,660' CTMD. PUMP 20 BBL POWERVIS PILL AND CHASE RETURNS TO SURFACE. FREEZE PROTE WELL WHILE POOH. READY FOR WITNESSED TAG AND TEST IN 48 HRS. 2/9/2024 RIG UP. MAKE UP TO WELL FOR PRESSURE TEST. ICE PLUG PREVENTING PUMPING FLUIDS THROUGH COIL. HEAT CO REEL WHILE PUMPING METHANOL SPIKES TO COIL. 10/12/2023 *** CONTINUE JOB FROM 10/11/2023 *** CONTINUE LOGGING WITH IBC-DSLT, CONDUCTED REPEAT PASS AT 5DEG6'', 5DEG3'', 5DEG1.5'' RESOLUTIONS FRO 6698' TO 5600' (~6' BELOW DEEPEST PERF INTERVAL WITH IBC MEASURE POINT), POOH AND DROP IBC TOOLSTRIN RUN BACK IN HOLE WITH DSLT ONLY AND TAG AT 6710', LOG UP FROM 6710' TO 5600' (~ 8' BELOW DEEPEST PERF INTERVAL WITH CBL MEASURE POINT ) UPLOAD DATA FOR RUSH PROCESSING JOB COMPLETE 10/11/2023 PERFORM JUNK BASKET RUN WITH 5.90'' GAUGE RING. TAGGED AT 6701.5' (~16' ABOVE CIBP. RECOVERED A COUP CUPS OF CEMENT IN JUNK BASKET). PERFORM IBC-DSLT PASS AT 5DEG6'' RESOLUTION FROM 6698' TO 5600' (~6' BELOW DEEPEST PERF INTERVAL WIT IBC MEASURE POINT) *** JOB CONTINUED TO NEXT DAY *** 10/10/2023 CONTINUE MILLING FROM 6682' TO CIBP AT 6717'. POOH. PICK UP 6.25" UNDERREAMER. COMPLETE 4 PASSES WIT UR FROM 6350'-6715'. READY FOR ELINE LOGGING. 10/9/2023 SPOT IN UNIT AND TANKS. RIG UP. MAKE UP 6.125" BEAR CLAW MILL. TAG TOC AT 6392'. MILL CEMENT FROM 639 6682'. JOB IN PROGRESS. 9/30/2023 (P&A) OA DDT PASSED TO 0 PSI, OA TOC 42'3". 9/26/2023 PUMPED OA CEMENT DOWN SQUEEZE f/ SURFACE TO SHOE w/ 103 BBLS OF 15.8 PPG PERMA FROST CEMENT w/ LCM IN LEAD 50 BBLS. PERFORMED 10 MIN SHUT DN HESITATION & PUMP THE LAST OF THE TAIL CEMENT. READY FOR THE NEXT STEP OF P&A. 9/23/2023 OA INJECTIVITY TEST PUMPED 8 BBLS DSL DWN OA INJECTS 2 BPM @ 1325 PSI 9/19/2023 PERFORM PRE AOGCC MIT (FAIL) 9/19/2023 TAG @ 6370' SLM, LRS COMPLETING TESTING TO 1500 PSI. COMPLETE. 9/15/2023 CONTINUE WASHING ACROSS PERFS FROM 6,542' TO 6,692'. MAKE 4 TOTAL PASSES. RIG UP CEMENTERS AND LAY IN 70 BBL OF 15.8 PPG CEMENT FROM CIBP AT 6,717' TO 6,392'. PUMP GEL SWEEP AND CHASE EXCESS CEMENT TO SURFACE. LAY IN DIESEL FREEZE PROTECT FROM 2,500' TO SURFACE. READY FOR TAG AND TEST IN 48 HRS. 9/14/2023 MIRU CTU, RIH AND TAG UP AT CIBP AT 6,717'. WASH ACROSS PERFS FROM 6,692' TO 6,542'. 9/14/2023 ***CONTINUED FROM PREVIOUS DAY*** GUN 5: PERFORATED INTERVAL 6588'-6608' GUN 6: PERFORATED INTERVAL 6568'-6588' GUN 7: PERFORATED INTERVAL 6546'-6566' GUN 8: PERFORATED INTERVAL 6542'-6546' JUNK BASKET RUN WITH 5.91'' GAUGE RING. TAGGED AT 6692', BOTTOM OF LOWEST PERF INTERVAL, NOTHING RECOVERED IN JUNK BASKET JOB COMPLETE, READY FOR COIL PWC 9/13/2023 SET CIBP AT 6718' GUN 1: PERFORATED INTERVAL 6672' - 6692' GUN 2: PERFORATED INTERVAL 6652'-6672' GUN 3: PERFORATED INTERVAL 6630'-6650' GUN 4: PERFORATED INTERVAL 6610'-6630' ***JOB CONTINUED*** 9/4/2023 RIG DOWN LOGGING TOOLS AND PCE, PACK EQUIPMENT 9/3/2023 RIG UP AND RIH JUNK BASKET WITH 5.91" GAUGE RING, TAGGED AT 9384' LOG USIT (IBC-CBL PRE-PERF CEMENT EVALUATION LOG, PERFORM PASSES AT 5DEG 6", 5DEG 3" AND 5DEG 1.5" FROM 9384' TO 5600', JOB COMPLETED Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:10,288.0 3S-23A 8/7/2006 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: P&A CEMENT TO SURFACE 3S-23A 2/27/2024 condijw 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 29.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 4,040.2 2,605.6 40.00 L-80 BTC PRODUCTION 7 6.28 28.7 10,471.8 5,851.7 26.00 L-80 BTCM LINER 4 1/2 3.96 10,269.9 14,143.6 5,900.4 12.60 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 9,805.0 Set Depth … 10,333.4 Set Depth … 5,840.1 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 10,294.5 5,836.3 84.24 LOCATOR 5.000 BAKER LOCATOR 3.000 10,321.9 5,839.0 84.60 SEAL ASSY 3.750 BAKER BONDED SEAL ASSEMBLY w/ 15' STROKE 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) 6,717.4 4,131.7 53.90 CIBP 5.61" CIBP MID-ELEMENT AT 6718' RKB, OAL = 1.6' LEGACY HPBP 00056 10- 002 9/13/2023 0.000 9,805.0 5,747.9 74.55 CUT WELLTEC MECHANICAL TUBING CUT (TATTLE-TAIL INDICATED GREATED THAN 3.5" BLADE EXAPANSION) 5/15/2023 2.992 10,315.0 5,838.4 84.51 CEMENT RETAINER 2.725" FH CEMENT RETAINER 5/6/2023 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,269.9 5,833.8 83.85 PACKER 7.000 HR ZXP LINER TOP PACKER 3.958 10,290.2 5,835.9 84.19 NIPPLE 5.500 RS PACKOFF SEAL NIPPLE 3.958 10,321.4 5,839.0 84.59 BUSHING 5.580 TKC XO BUSHING 3.920 14,095.1 5,900.6 90.14 PACKOFF 5.200 BAKER PACKOFF & CROSSOVERS 2.390 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,542.0 6,566.0 4,029.7 4,043.5 9/14/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEGREE PHASEING 6,568.0 6,608.0 4,044.7 4,067.8 9/14/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEGREE PHASEING 6,610.0 6,650.0 4,069.0 4,092.2 9/13/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEGREE PHASEING 6,652.0 6,692.0 4,093.4 4,116.7 9/13/2023 21.0 APERF 4.72" POWERFLOW HSD, 21 SPF, 60 DEGREE PHASEING 10,475.0 14,091.0 5,852.0 5,900.6 C-4, 3S-23A 5/31/2006 32.0 SLOTS SLOTTED LINER Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,321.9 14,091.0 5,839.0 5,900.6 Cement Plug 80 BBL, 15.8 PPG, CLASS G, BELOW RETAINER 5/7/2023 10,048.0 10,321.9 5,802.5 5,839.0 Cement Plug 2.3 BBL, 15.8 PPG, CLASS G, ABOVE RETAINER 5/7/2023 6,542.0 6,692.0 4,029.7 4,116.7 Cement Squeeze Perf Wash Cement 6542-6692' 9/14/2023 6,392.0 6,717.4 3,944.1 4,131.7 Cement Plug 15.8 PPG CLASS G CEMENT **MILLED OUT 10/10/23** 9/15/2023 29.0 5,660.0 29.0 3,519.6 Plug – Plug Back / Abandonment Plug 239 BBLS, 15.8 CLASS G CEMENT 2/27/2024 5,660.0 6,707.0 3,519.6 4,125.5 Plug – Plug Back / Abandonment Plug 40 BBLS, 15.8 CLASS G CEMENT 2/10/2024 Horizontal, 3S-23A, 8/26/2024 4:52:06 PM Vertical schematic (actual) LINER; 10,269.9-14,143.6 GUIDE SHOE; 14,142.3- 14,143.6 PACKOFF; 14,095.1-14,100.6 SLOTS; 10,475.0-14,091.0 PRODUCTION; 28.7-10,471.8 FLOAT SHOE; 10,470.3- 10,471.8 FLOAT COLLAR; 10,386.0- 10,387.3 SEAL ASSY; 10,321.9 BUSHING; 10,321.4-10,323.3 Cement Plug; 10,321.9 ftKB CEMENT RETAINER; 10,315.0 SBE; 10,302.5-10,321.4 HANGER; 10,292.7-10,302.5 LOCATOR; 10,294.5 NIPPLE; 10,290.2-10,292.7 PACKER; 10,269.9-10,290.2 Cement Plug; 10,048.0 ftKB CUT; 9,805.0 CIBP; 6,717.4 APERF; 6,652.0-6,692.0 APERF; 6,610.0-6,650.0 Cement Squeeze; 6,542.0 ftKB APERF; 6,568.0-6,608.0 APERF; 6,542.0-6,566.0 Plug – Plug Back / Abandonment Plug; 5,616.0 ftKB SURFACE; 28.8-4,040.2 FLOAT SHOE; 4,038.5-4,040.2 FLOAT COLLAR; 3,962.0- 3,963.4 CONDUCTOR; 29.0-108.0 HANGER; 28.8-31.4 HANGER; 28.7-31.0 Plug – Plug Back / Abandonment Plug; 29.0 ftKB KUP PROD KB-Grd (ft) 32.69 RR Date 4/20/2003 Other Elev… 3S-23A ... TD Act Btm (ftKB) 14,144.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045301 Wellbore Status PROD Max Angle & MD Incl (°) 92.85 MD (ftKB) 11,929.30 WELLNAME WELLBORE3S-23A Annotation Last WO: End DateH2S (ppm) 130 Date 11/3/2017 Comment SSSV: NIPPLE 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:na Rig Elevation:na Total Depth:14,144 ft MD Lease No.:ADL 0380107 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 4040 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 10472 Feet Csg Cut@ Feet Liner:4-1/2"O.D. Shoe@ 14144 Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 10333 Feet Tbg Cut@ 9805 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 6717 ft 5616 ft 9.6 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1750 1675 1640 IA 1750 1675 1640 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I met with John Hansen (CPAI) at KRU 3S-23A for a tag and test. We discussed the plan forward and proceded. They picked up 10 ft of weight pipe, 13 ft of oil jars and spangs, and a 5ft bailer with a 2-1/2" OD and a flapper valve/ mule shoe. Estimated weight of 200 lbs measuring 30 ft in length. Tagged up at 5616 ft RKB which is the corrected depth. Cement sample looked good, a little on the squishy side but had a solid tag. MIT performed and went well. February 15, 2024 Josh Hunt Well Bore Plug & Abandonment KRU 3S-23A ConocoPhillips Alaska Inc. PTD 2060430; Sundry 323-416 Photo Test Data: P Casing Removal: John Hanson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0215_Plug_Verification_KRU_3S-23A_jh Plug Verification - KRU 3S-23A (PTD 2060430) Photo by AOGCC Inspector J. Hunt 2/15/2024 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: 276' FNL, 1800' FWL S24 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" B 108'65bbls ArcticCrete 9-5/8" L-80 2604' 7" L-80 5852' 4-1/2" L-80 5901' 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 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 2.3 bbl of 15.8ppg Class G above retainer Suspended If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): Slotted Liner: 10475-14093'MD and 5852-5900'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 31' 31' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 14144' 31' 5833' 62.5# 40# 108' 31' 10471' SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 42" 5993856 Kaparuk River Field/Kuparuk River Oil Pool ADL0380107/ ADL0025544/ADL0025551 ALK 2639, ALK2616 31' 12.6# 31' 10266' 4040' 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 468963 467913 CEMENTING RECORDTOP 5990886 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 206-043/323-2638/6/2023 10269'MD/5834'TVD BOTTOM 10315-14091' 12-1/4" 616sx AS Lite, 341sx LiteCrete CASING 50-103-20453-01-00 KRU 3S-23A 4/30/2006 14144'MD/5901'TVD 10048'MD/5715'TVD 31' P.O.Box 100360, Anchorage, AK 99510-0360 476013 2560' FNL, 1246' FEL S18 T12N R8E 1435' FSL, 763' FWL S24 T12N R7E 5/29/2006 1707'MD/1545'TVD SETTING DEPTH TVD 5987322 TOP HOLE SIZE AMOUNT PULLED 80 bbls of 15.8 Class G below retainer 10048-10315' 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, Slotted Liner (Cemented)6-1/8" TUBING RECORD 217 sx Class G 8-1/2" 10333'3.5" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 9:43 am, Sep 06, 2023 Suspended 8/6/2023 JSB RBDMS JSB 091523 xGDSR-9/29/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1707' 1545' 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: 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. 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 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: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by James J. OhlingerDN: 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: 2023.09.06 08:51:32-08'00' Foxit PDF Editor Version: 12.1.2 James J. Ohlinger Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:10,288.0 3S-23A 8/7/2006 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut at 9805' RKB (Welltec Mechanical) 3S-23A 5/15/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/27/2010 ninam 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 29.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 4,040.2 2,605.6 40.00 L-80 BTC PRODUCTION 7 6.28 28.7 10,471.8 5,851.7 26.00 L-80 BTCM LINER 4 1/2 3.96 10,269.9 14,143.6 5,900.4 12.60 L-80 BTCM 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) 9,805.0 5,747.9 74.55 CUT WELLTEC MECHANICAL TUBING CUT (TATTLE-TAIL INDICATED GREATED THAN 3.5" BLADE EXAPANSION) 5/15/2023 2.992 10,315.0 5,838.4 84.51 CEMENT RETAINER 2.725" FH CEMENT RETAINER 5/6/2023 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,269.9 5,833.8 83.85 PACKER 7.000 HR ZXP LINER TOP PACKER 3.958 10,290.2 5,835.9 84.19 NIPPLE 5.500 RS PACKOFF SEAL NIPPLE 3.958 10,321.4 5,839.0 84.59 BUSHING 5.580 TKC XO BUSHING 3.920 14,095.1 5,900.6 90.14 PACKOFF 5.200 BAKER PACKOFF & CROSSOVERS 2.390 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,475.0 14,091.0 5,852.0 5,900.6 C-4, 3S-23A 5/31/2006 32.0 SLOTS SLOTTED LINER Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,321.9 14,091.0 5,839.0 5,900.6 Cement Plug 80 BBL, 15.8 PPG, CLASS G, BELOW RETAINER 5/7/2023 10,048.0 10,321.9 5,802.5 5,839.0 Cement Plug 2.3 BBL, 15.8 PPG, CLASS G, ABOVE RETAINER 5/7/2023 Horizontal, 3S-23A, 9/5/2023 2:39:21 PM Vertical schematic (actual) LINER; 10,269.9-14,143.6 SLOTS; 10,475.0-14,091.0 PRODUCTION; 28.7-10,471.8 Cement Plug; 10,321.9 ftKB CEMENT RETAINER; 10,315.0 Cement Plug; 10,048.0 ftKB CUT; 9,805.0 SURFACE; 28.8-4,040.2 CONDUCTOR; 29.0-108.0 KUP PROD KB-Grd (ft) 32.69 RR Date 4/20/2003 Other Elev… 3S-23A ... TD Act Btm (ftKB) 14,144.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045301 Wellbore Status PROD Max Angle & MD Incl (°) 92.85 MD (ftKB) 11,929.30 WELLNAME WELLBORE3S-23A Annotation Last WO: End DateH2S (ppm) 130 Date 11/3/2017 Comment SSSV: NIPPLE Page 1/2 3S-23 Report Printed: 9/5/2023 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) 8/8/2023 12:00 8/8/2023 20:30 8.50 MIRU, MOVE MOB P Pull off 3S-22, set rig mats for pulling over 3S-23A. Spot pits and RU to take on fluids. 0.0 0.0 8/8/2023 20:30 8/8/2023 22:30 2.00 MIRU, WELCTL RURD P Take on 9.6 ppg NaCl to pits. Accept rig at 20:30 on 8/8/2023. 0.0 0.0 8/8/2023 22:30 8/9/2023 00:00 1.50 MIRU, WELCTL KLWL P Displace well to 9.6# brine 425 bbls = 125% well capacity 0.0 0.0 8/9/2023 00:00 8/9/2023 01:00 1.00 MIRU, WHDBOP OWFF P OWFF no flow 0.0 0.0 8/9/2023 01:00 8/9/2023 02:00 1.00 MIRU, WHDBOP MPSP P Set BPV and test dart // Test 1000 psi 10 min 0.0 0.0 8/9/2023 02:00 8/9/2023 04:00 2.00 MIRU, WHDBOP NUND P Nipple down production tree // Nipple up BOPs 0.0 0.0 8/9/2023 04:00 8/9/2023 04:30 0.50 MIRU, WHDBOP BOPE P Flood lines // Shell test BOPs 3500 psi 0.0 0.0 8/9/2023 04:30 8/9/2023 10:00 5.50 MIRU, WHDBOP BOPE P Test BOPE Test annular with 3 1/2" test joint to 250/3500 PSI F/5 min. All other test to 250/3000PSI F/5 min each, UVBR and LVBR 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 = 3000 PSI, after closure = 1500 PSI, 200 PSI attained = 13 sec, full recovery attained = 113 sec. UVBR = 5 sec, Annular = 25 sec, Simulated blinds = 5 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 2000 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Brian Bixby witness waived. 0.0 0.0 8/9/2023 10:00 8/9/2023 11:00 1.00 MIRU, WHDBOP RURD P Rig down test equipment 0.0 0.0 8/9/2023 11:00 8/9/2023 11:30 0.50 COMPZN, RPCOMP MPSP P Pull BPV and test dart 0.0 0.0 8/9/2023 11:30 8/9/2023 12:30 1.00 COMPZN, RPCOMP THGR P Pick up landing joint make up to hanger // Set down 10K // BOLDS // Pull hanger to floor Pu wt. 130K 9,805.0 9,780.0 8/9/2023 12:30 8/9/2023 14:00 1.50 COMPZN, RPCOMP CIRC P Circulate B/U to clean up mud 9,780.0 9,780.0 8/9/2023 14:00 8/10/2023 00:00 10.00 COMPZN, RPCOMP PULL P Lay down hanger and landing jt // Pull and lay down 3.5" completion F9805' T/1572' 9,780.0 1,572.0 8/10/2023 00:00 8/10/2023 01:30 1.50 COMPZN, RPCOMP PULL P L/D Tubing from 1572' T/surface 1,572.0 0.0 8/10/2023 01:30 8/10/2023 02:15 0.75 COMPZN, WHDBOP RURD P R/D Tubing handdling EQ. R/U to perform BWM Install Tbg. hgr in wellhead secure. 0.0 0.0 8/10/2023 02:15 8/10/2023 02:30 0.25 COMPZN, WHDBOP SFTY P PJSM to start BWM 0.0 0.0 8/10/2023 02:30 8/10/2023 07:30 5.00 COMPZN, WHDBOP RURD P Start BWM. 0.0 0.0 8/10/2023 07:30 8/10/2023 10:30 3.00 COMPZN, WHDBOP NUND P Nipple down BOPs , nipple up 7" dry hole tree 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/10/2023 Page 2/2 3S-23 Report Printed: 9/5/2023 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) 8/10/2023 10:30 8/10/2023 11:30 1.00 COMPZN, WHDBOP PRTS P Rig up LRS // Test tree 1500 psi 30 min good test // Pull pits away from rig for move 0.0 0.0 8/10/2023 11:30 8/10/2023 12:00 0.50 COMPZN, WHDBOP SVRG P Replace hose on roughneck 0.0 0.0 8/10/2023 12:00 8/10/2023 18:00 6.00 DEMOB, MOVE DMOB P Clean under rig floor and steam tables, prep sub to move. Jack up sub, pull off well, relocate to end of well row. Clean around cellar and well location. Relocate rig mats spot sub base and move pits up to sub. Rig released at 1800. 0.0 0.0 8/17/2023 18:00 8/17/2023 18:30 0.50 DEMOB, MOVE SFTY P Cruz on location at 1730. safety meeting to move pit complex, shop and office. 8/17/2023 18:30 8/18/2023 00:00 5.50 DEMOB, MOVE MOB P Hook up to pit complex, shop and office complex. Mobilize Pit complex to 3G, Continue with office and shop to 2M. 8/18/2023 00:00 8/18/2023 10:30 10.50 DEMOB, MOVE MOB P Mobilize pits and stage at 3G spot in office complex and shop. Start sub base to 3G at 0830. Road blew out under 6" mats at tires of sub base at 1030. 8/18/2023 10:30 8/19/2023 00:00 13.50 DEMOB, MOVE MOB P Start working to get rig unstuck. ply wood under tires. Attempt to back rig out of hole using rig and weighted sow holes continued to grow in size. Staged more plywood under tires and reconfigure mats. stage dozer infront of rig called out 2 additional weighted sows to pull rig out of hole. 8/19/2023 00:00 8/20/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. 8/20/2023 00:00 8/21/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. soft road conditions sunk in road at 2100. Called Cruz at 10:00 PM mobilized sows to get out of hole. Cribbed under mats and built up to get mats back to grade. Worked rig free fell through 2 more times with sows attached and pulling rig. 8/21/2023 00:00 8/22/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. 8/22/2023 00:00 8/23/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. Rig became detained. Place dunnage and plywood, phone for Weighted SOW's to return. Hook up Weighted SOW's to the front of rig and pull forward. Continue Moving Rig towards 3G-pad 8/23/2023 00:00 8/24/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. 8/24/2023 00:00 8/24/2023 21:00 21.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/10/2023 Page 1/2 3S-23 Report Printed: 9/5/2023 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) 8/8/2023 12:00 8/8/2023 20:30 8.50 MIRU, MOVE MOB P Pull off 3S-22, set rig mats for pulling over 3S-23A. Spot pits and RU to take on fluids. 0.0 0.0 8/8/2023 20:30 8/8/2023 22:30 2.00 MIRU, WELCTL RURD P Take on 9.6 ppg NaCl to pits. Accept rig at 20:30 on 8/8/2023. 0.0 0.0 8/8/2023 22:30 8/9/2023 00:00 1.50 MIRU, WELCTL KLWL P Displace well to 9.6# brine 425 bbls = 125% well capacity 0.0 0.0 8/9/2023 00:00 8/9/2023 01:00 1.00 MIRU, WHDBOP OWFF P OWFF no flow 0.0 0.0 8/9/2023 01:00 8/9/2023 02:00 1.00 MIRU, WHDBOP MPSP P Set BPV and test dart // Test 1000 psi 10 min 0.0 0.0 8/9/2023 02:00 8/9/2023 04:00 2.00 MIRU, WHDBOP NUND P Nipple down production tree // Nipple up BOPs 0.0 0.0 8/9/2023 04:00 8/9/2023 04:30 0.50 MIRU, WHDBOP BOPE P Flood lines // Shell test BOPs 3500 psi 0.0 0.0 8/9/2023 04:30 8/9/2023 10:00 5.50 MIRU, WHDBOP BOPE P Test BOPE Test annular with 3 1/2" test joint to 250/3500 PSI F/5 min. All other test to 250/3000PSI F/5 min each, UVBR and LVBR 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 = 3000 PSI, after closure = 1500 PSI, 200 PSI attained = 13 sec, full recovery attained = 113 sec. UVBR = 5 sec, Annular = 25 sec, Simulated blinds = 5 sec, HCR choke/kill = 1 sec each, 5 back up nitrogen bottles average = 2000 PSI, Test gas detectors, PVT and flow show. AOGCC Rep. Brian Bixby witness waived. 0.0 0.0 8/9/2023 10:00 8/9/2023 11:00 1.00 MIRU, WHDBOP RURD P Rig down test equipment 0.0 0.0 8/9/2023 11:00 8/9/2023 11:30 0.50 COMPZN, RPCOMP MPSP P Pull BPV and test dart 0.0 0.0 8/9/2023 11:30 8/9/2023 12:30 1.00 COMPZN, RPCOMP THGR P Pick up landing joint make up to hanger // Set down 10K // BOLDS // Pull hanger to floor Pu wt. 130K 9,805.0 9,780.0 8/9/2023 12:30 8/9/2023 14:00 1.50 COMPZN, RPCOMP CIRC P Circulate B/U to clean up mud 9,780.0 9,780.0 8/9/2023 14:00 8/10/2023 00:00 10.00 COMPZN, RPCOMP PULL P Lay down hanger and landing jt // Pull and lay down 3.5" completion F9805' T/1572' 9,780.0 1,572.0 8/10/2023 00:00 8/10/2023 01:30 1.50 COMPZN, RPCOMP PULL P L/D Tubing from 1572' T/surface 1,572.0 0.0 8/10/2023 01:30 8/10/2023 02:15 0.75 COMPZN, WHDBOP RURD P R/D Tubing handdling EQ. R/U to perform BWM Install Tbg. hgr in wellhead secure. 0.0 0.0 8/10/2023 02:15 8/10/2023 02:30 0.25 COMPZN, WHDBOP SFTY P PJSM to start BWM 0.0 0.0 8/10/2023 02:30 8/10/2023 07:30 5.00 COMPZN, WHDBOP RURD P Start BWM. 0.0 0.0 8/10/2023 07:30 8/10/2023 10:30 3.00 COMPZN, WHDBOP NUND P Nipple down BOPs , nipple up 7" dry hole tree 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/24/2023 Page 2/2 3S-23 Report Printed: 9/5/2023 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) 8/10/2023 10:30 8/10/2023 11:30 1.00 COMPZN, WHDBOP PRTS P Rig up LRS // Test tree 1500 psi 30 min good test // Pull pits away from rig for move 0.0 0.0 8/10/2023 11:30 8/10/2023 12:00 0.50 COMPZN, WHDBOP SVRG P Replace hose on roughneck 0.0 0.0 8/10/2023 12:00 8/10/2023 18:00 6.00 DEMOB, MOVE DMOB P Clean under rig floor and steam tables, prep sub to move. Jack up sub, pull off well, relocate to end of well row. Clean around cellar and well location. Relocate rig mats spot sub base and move pits up to sub. Rig released at 1800. 0.0 0.0 8/17/2023 18:00 8/17/2023 18:30 0.50 DEMOB, MOVE SFTY P Cruz on location at 1730. safety meeting to move pit complex, shop and office. 8/17/2023 18:30 8/18/2023 00:00 5.50 DEMOB, MOVE MOB P Hook up to pit complex, shop and office complex. Mobilize Pit complex to 3G, Continue with office and shop to 2M. 8/18/2023 00:00 8/18/2023 10:30 10.50 DEMOB, MOVE MOB P Mobilize pits and stage at 3G spot in office complex and shop. Start sub base to 3G at 0830. Road blew out under 6" mats at tires of sub base at 1030. 8/18/2023 10:30 8/19/2023 00:00 13.50 DEMOB, MOVE MOB P Start working to get rig unstuck. ply wood under tires. Attempt to back rig out of hole using rig and weighted sow holes continued to grow in size. Staged more plywood under tires and reconfigure mats. stage dozer infront of rig called out 2 additional weighted sows to pull rig out of hole. 8/19/2023 00:00 8/20/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. 8/20/2023 00:00 8/21/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. soft road conditions sunk in road at 2100. Called Cruz at 10:00 PM mobilized sows to get out of hole. Cribbed under mats and built up to get mats back to grade. Worked rig free fell through 2 more times with sows attached and pulling rig. 8/21/2023 00:00 8/22/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. 8/22/2023 00:00 8/23/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. Rig became detained. Place dunnage and plywood, phone for Weighted SOW's to return. Hook up Weighted SOW's to the front of rig and pull forward. Continue Moving Rig towards 3G-pad 8/23/2023 00:00 8/24/2023 00:00 24.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. 8/24/2023 00:00 8/24/2023 21:00 21.00 DEMOB, MOVE MOB P Continue to move rig toward 3G pad exercising the rig mat shuffle technique. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 8/24/2023 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): 14144'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-23A 5900' 10048' 5802' 1440 10048' 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): 10270' MD and 5834' TVD 530' Md and 529' TVD Jill Simek STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544, ADL0380107 206-043 P.O. Box 100360, Anchorage, AK 99510 50-103-20453-01-00 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 10333' MD 108' 2606' 108' 4040' 5852'10472' 16" 9-5/8" 78' 4011' 10475-14091' 10443' 4-1/2" 5852-5901' 7" Perforation Depth TVD (ft): 8/1/2023 14144'3874' 3-1/2" 5900' Packer: HR ZXP Liner Top Packer SSSV: Camco DS Nipple w/ NoGo 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 11:03 am, Jul 21, 2023 323-416 Jill Simek Digitally signed by Jill Simek Date: 2023.07.20 16:01:40 -08'00' AOGCC inspection is required after cutoff and before any remedial cementing. X X VTL 7/24/2023 DSR-7/24/23 X 10-407 MDG 7/24/2023 GCW 07/24/2023JLC 7/24/2023 07/25/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.07.25 09:34:16 -08'00' RBDMS JSB 072523 3S-23A Plug and Abandon Procedure PTD #206-043 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 9,805ft KB. Well Type: Producer Scope of Work: Perform Plug and Abandonment of 3S-23A: 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 6,718ft 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 ~6,392ft 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-23A Plug and Abandon Procedure PTD #206-043 Page 2 of 2 Coil 17. MIRU. 18. Pump cement plug in production casing, from top of cement to surface. Job is planned for 245 bbls cement. 19. RDMO. Pumping 20. MIRU. 21. Perform OA down squeeze to place cement from surface to 4,040ft KB. Job is planned for 134 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-23A PTD #: 206-043 API #: 50-103-20453-01 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-23A P&A PTD #: 206-043 16” 62.5# H-40 Conductor @ 108' KB JS 7-20-2023 7" 26# L-80 Production Casing @ 10,412' KB 3-½” 9.3# L-80 Tubing @ 10,333' KB 9 5/8" 40# L-80 Surface Casing @ 4,040' KB Slots: 10,475' – 14,091' KB Calculated Top of Cement (7" x OH) = 9,471' KB Kuparuk Moraine 8,523' – 8,874' KB Coyote 6,642' – 7,519' KB Liner Top Packer = 10,290' KB Seal Assembly = 10,322' KB 4-½” 12.6# L-80 Liner @ 14,144' KB Tubing cut at 9,805ft KB TOC (tubing) at 10,085ft KB Cement retainer set at 10,315' KB CIBP @ ~6,718' KB Cement Plug (Production Casing x Open Hole Annulus) Approx. 6,542' – 6,692' KB Cement Plug (Production Casing) Approx. 6,718' KB to Surface Cement Plug (Production Casing x Surface Casing Annulus) 4,040' KB to Surface CIBP (IF REQUIRED) @ ~8,599' KB Moraine Cement Plug (IF REQUIRED) (Production Casing x Open Hole Annulus) Approx. 8,423' – 8,573' KB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:10,288.0 3S-23A 8/7/2006 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut at 9805' RKB (Welltec Mechanical) 3S-23A 5/15/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/27/2010 ninam 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 29.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 4,040.2 2,605.6 40.00 L-80 BTC PRODUCTION 7 6.28 28.7 10,471.8 5,851.7 26.00 L-80 BTCM LINER 4 1/2 3.96 10,269.9 14,143.6 5,900.4 12.60 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 26.5 Set Depth … 10,333.4 Set Depth … 5,840.1 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 26.5 26.5 0.00 HANGER 8.000 FMC GEN 5 TUBING HANGER 3.500 530.0 529.0 7.90 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.875" NO GO 2.875 3,828.6 2,508.7 62.22 GAS LIFT 5.390 CAMCO KBMG 2.920 5,982.4 3,704.3 54.99 GAS LIFT 5.390 CAMCO KBMG 2.920 7,542.4 4,618.6 53.37 GAS LIFT 5.390 CAMCO KBMG 2.920 8,568.8 5,209.9 57.20 GAS LIFT 5.390 CAMCO KBMG 2.920 9,408.5 5,612.5 64.94 GAS LIFT 5.968 CAMCO MMG 2.920 9,464.9 5,635.9 66.30 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.813" DS PROFILE 2.813 9,537.8 5,664.0 68.30 NIPPLE 4.520 CAMCO D NIPPLE w/ 2.75" NO GO 2.750 10,294.5 5,836.3 84.24 LOCATOR 5.000 BAKER LOCATOR 3.000 10,321.9 5,839.0 84.60 SEAL ASSY 3.750 BAKER BONDED SEAL ASSEMBLY w/ 15' STROKE 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) 9,805.0 5,747.9 74.55 CUT WELLTEC MECHANICAL TUBING CUT (TATTLE-TAIL INDICATED GREATED THAN 3.5" BLADE EXAPANSION) 5/15/2023 2.992 10,315.0 5,838.4 84.51 CEMENT RETAINER 2.725" FH CEMENT RETAINER 5/6/2023 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) 3,828.6 2,508.7 62.22 1 GAS LIFT DMY BK-5 1 0.0 5/14/2023 0.000 5,982.4 3,704.3 54.99 2 GAS LIFT DMY BK-5 1 0.0 6/3/2006 0.000 7,542.4 4,618.6 53.37 3 GAS LIFT DMY BK-5 1 0.0 5/13/2023 0.000 8,568.8 5,209.9 57.20 4 GAS LIFT DMY BK-5 1 0.0 6/3/2006 0.000 9,408.5 5,612.5 64.94 5 GAS LIFT OPEN 1 1/2 5/14/2023 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,269.9 5,833.8 83.85 PACKER 7.000 HR ZXP LINER TOP PACKER 3.958 10,290.2 5,835.9 84.19 NIPPLE 5.500 RS PACKOFF SEAL NIPPLE 3.958 10,321.4 5,839.0 84.59 BUSHING 5.580 TKC XO BUSHING 3.920 14,095.1 5,900.6 90.14 PACKOFF 5.200 BAKER PACKOFF & CROSSOVERS 2.390 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,475.0 14,091.0 5,852.0 5,900.6 C-4, 3S-23A 5/31/2006 32.0 SLOTS SLOTTED LINER Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,321.9 14,091.0 5,839.0 5,900.6 Cement Plug 80 BBL, 15.8 PPG, CLASS G, BELOW RETAINER 5/7/2023 10,048.0 10,321.9 5,802.5 5,839.0 Cement Plug 2.3 BBL, 15.8 PPG, CLASS G, ABOVE RETAINER 5/7/2023 Horizontal, 3S-23A, 7/18/2023 6:20:47 PM Vertical schematic (actual) LINER; 10,269.9-14,143.6 SLOTS; 10,475.0-14,091.0 PRODUCTION; 28.7-10,471.8 Cement Plug; 10,321.9 ftKB CEMENT RETAINER; 10,315.0 Cement Plug; 10,048.0 ftKB CUT; 9,805.0 GAS LIFT; 9,408.5 GAS LIFT; 8,568.8 GAS LIFT; 7,542.4 GAS LIFT; 5,982.4 SURFACE; 28.8-4,040.2 GAS LIFT; 3,828.6 NIPPLE; 530.0 CONDUCTOR; 29.0-108.0 KUP PROD KB-Grd (ft) 32.69 RR Date 4/20/2003 Other Elev… 3S-23A ... TD Act Btm (ftKB) 14,144.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045301 Wellbore Status PROD Max Angle & MD Incl (°) 92.85 MD (ftKB) 11,929.30 WELLNAME WELLBORE3S-23A Annotation Last WO: End DateH2S (ppm) 130 Date 11/3/2017 Comment SSSV: NIPPLE 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:14144 ft MD Lease No.:ADL 0380107 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 4040 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 10472 Feet Csg Cut@ Feet Liner:4-1/2"O.D. Shoe@ 14144 Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 10333 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Retainer 10315 ft 10048 ft 7.2 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1760 1710 1695 IA 500 500 500 OA 400 400 400 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Had a good solid tag with good cement sample from the bailer. Top of cement was supposed to be about 10085 ft MD; they tagged at 10048 ft MD. MIT-T passed (0.66 bbls in, 0.58 bbls back). May 12, 2023 Kam StJohn Well Bore Plug & Abandonment KRU 3S-23A CPAI PTD 2060430; Sundry 323-239 none Test Data: P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2023-0512_Plug_Verification_KRU_3S-23A_ksj 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" B 108' 9.625" L-80 2604' 7" L-80 5852' 4-1/2" L-80 5901' 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 10471' SIZE DEPTH SET (MD) 14144' 31' 5833' 62.5# 40# 108' 31' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 80 bbl 15.8 ppg Class G, below cmnt retainer 10048'-10315' 2.3 bbl 15.8 ppg Class G, above cmnt retainer Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 10315'-14091' SUSPENDED Slotted Liner: 10475-14093' MD and 5852-5900' TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 10269' MD/ 5834' TVD PACKER SET (MD/TVD) 42" 12-1/4" 65 bbls ArcticCRETE 31'616 sx AS Lite, 341 sx LiteCrete 12.6# 31' 10266' 4040'31' 31' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# WT. PER FT.GRADE CEMENTING RECORD 5990886 SETTING DEPTH TVD 5987322 TOP HOLE SIZE AMOUNT PULLED 468963 467913 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 1707' MD/ 1545' TVD N/A 2560' FNL, 1246' FEL, Sec. 18, T12N, R8E, UM 1435' FSL, 763' FWL, Sec. 24, T12N, R7E, UM P.O. Box 100360, Anchorage, AK 99510-0360 476013 5993856 276' FNL, 1800' FWL, Sec. 24, T12N, R7E, UM 10048' MD/ 5715' TVD 14144' MD/ 5901' TVD ADL0380107, ADL0025544, ADL0025551 ALK 2639, ALK2616 50-103-20453-01-00 KRU 3S-23A April 30, 2006 May 29, 2006 9. Ref Elevations: KB: 31' Kuparuk River Field/ Kuparuk River Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 5/12/2023 206-043/ 323-239 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, slotted liner (cemented)6.125" TUBING RECORD 217 sx Class G8-1/2" 10333' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 10:16 am, Jun 08, 2023 Suspended 5/12/2023 JSB RBDMS JSB 060823 57.6 xGDSR-6/12/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1707' 1545' 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 16:08:28 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:10,288.0 3S-23A 8/7/2006 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut at 9805' RKB (Welltec Mechanical) 3S-23A 5/15/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 12/27/2010 ninam General Notes: Last 3 entries Com Date Last Mod By TREE: GMC / GEN 5 / 5M TREE CAP CONNECTION: TOP 5.75"" ACME with 3.5"" EUE 8RD THREAD 5/11/2003 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 29.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 4,040.2 2,605.6 40.00 L-80 BTC PRODUCTION 7 6.28 28.7 10,471.8 5,851.7 26.00 L-80 BTCM LINER 4 1/2 3.96 10,269.9 14,143.6 5,900.4 12.60 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 26.5 Set Depth … 10,333.4 Set Depth … 5,840.1 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 26.5 26.5 0.00 HANGER 8.000 FMC GEN 5 TUBING HANGER 3.500 530.0 529.0 7.90 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.875" NO GO 2.875 3,828.6 2,508.7 62.22 GAS LIFT 5.390 CAMCO KBMG 2.920 5,982.4 3,704.3 54.99 GAS LIFT 5.390 CAMCO KBMG 2.920 7,542.4 4,618.6 53.37 GAS LIFT 5.390 CAMCO KBMG 2.920 8,568.8 5,209.9 57.20 GAS LIFT 5.390 CAMCO KBMG 2.920 9,408.5 5,612.5 64.94 GAS LIFT 5.968 CAMCO MMG 2.920 9,464.9 5,635.9 66.30 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE w/ CAMCO 2.813" DS PROFILE 2.813 9,537.8 5,664.0 68.30 NIPPLE 4.520 CAMCO D NIPPLE w/ 2.75" NO GO 2.750 10,294.5 5,836.3 84.24 LOCATOR 5.000 BAKER LOCATOR 3.000 10,321.9 5,839.0 84.60 SEAL ASSY 3.750 BAKER BONDED SEAL ASSEMBLY w/ 15' STROKE 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) 9,805.0 5,747.9 74.55 CUT WELLTEC MECHANICAL TUBING CUT (TATTLE-TAIL INDICATED GREATED THAN 3.5" BLADE EXAPANSION) 5/15/2023 2.992 10,315.0 5,838.4 84.51 CEMENT RETAINER 2.725" FH CEMENT RETAINER 5/6/2023 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) 3,828.6 2,508.7 62.22 1 GAS LIFT DMY BK-5 1 0.0 5/14/2023 0.000 5,982.4 3,704.3 54.99 2 GAS LIFT DMY BK-5 1 0.0 6/3/2006 0.000 7,542.4 4,618.6 53.37 3 GAS LIFT DMY BK-5 1 0.0 5/13/2023 0.000 8,568.8 5,209.9 57.20 4 GAS LIFT DMY BK-5 1 0.0 6/3/2006 0.000 9,408.5 5,612.5 64.94 5 GAS LIFT OPEN 1 1/2 5/14/2023 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,269.9 5,833.8 83.85 PACKER 7.000 HR ZXP LINER TOP PACKER 3.958 10,290.2 5,835.9 84.19 NIPPLE 5.500 RS PACKOFF SEAL NIPPLE 3.958 10,321.4 5,839.0 84.59 BUSHING 5.580 TKC XO BUSHING 3.920 14,095.1 5,900.6 90.14 PACKOFF 5.200 BAKER PACKOFF & CROSSOVERS 2.390 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,475.0 14,091.0 5,852.0 5,900.6 C-4, 3S-23A 5/31/2006 32.0 SLOTS SLOTTED LINER Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,321.9 14,091.0 5,839.0 5,900.6 Cement Plug 80 BBL, 15.8 PPG, CLASS G, BELOW RETAINER 5/7/2023 10,085.0 10,321.9 5,808.8 5,839.0 Cement Plug 2.3 BBL, 15.8 PPG, CLASS G, ABOVE RETAINER 5/7/2023 Horizontal, 3S-23A, 5/22/2023 11:47:16 AM Vertical schematic (actual) LINER; 10,269.9-14,143.6 SLOTS; 10,475.0-14,091.0 PRODUCTION; 28.7-10,471.8 Cement Plug; 10,321.9 ftKB CEMENT RETAINER; 10,315.0 Cement Plug; 10,085.0 ftKB CUT; 9,805.0 GAS LIFT; 9,408.5 GAS LIFT; 8,568.8 GAS LIFT; 7,542.4 GAS LIFT; 5,982.4 SURFACE; 28.8-4,040.2 GAS LIFT; 3,828.6 NIPPLE; 530.0 CONDUCTOR; 29.0-108.0 KUP PROD KB-Grd (ft) 32.69 RR Date 4/20/2003 Other Elev… 3S-23A ... TD Act Btm (ftKB) 14,144.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045301 Wellbore Status PROD Max Angle & MD Incl (°) 92.85 MD (ftKB) 11,929.30 WELLNAME WELLBORE3S-23A Annotation Last WO: End DateH2S (ppm) 130 Date 11/3/2017 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 4/30/2023 CHANGE WELL TYPE DRIFT W/ 8' x 2.125'' & 2.75'' DMY CA-2 PLUG (DMY CEMENT RETAINER ASSEMBLY) TO TAG D-NIP @ 9538' RKB (NO WEIGHT SWINGS OR OBSTRUCTIONS OBSERVED); LRS PERFORM STEP RATE INJECTIVITY TEST .5 BPM TO 3 BPM (SEE BODY); LRS ESTABLISH OA LLR OF 1.75 BPM @ 1300#. IN PROGRESS. 5/1/2023 CHANGE WELL TYPE DRIFT W/ 8' x 2.125'' STEM & 2.74'' x 3' (DMY CEMENT RETAINER) TO 10315' RKB (NO ANOMALIES). READY FOR COIL. 5/3/2023 ACQUIRE DATA (P&A) FUNCTION TEST ALL T & IC LDS/GN'S , T POT PASSED , T PPPOT PASSED , IC POT PASSED , IC PPPOT PASSED 5/6/2023 CHANGE WELL TYPE TAG NIPPLE AND PAINT FLAG AT 9512' CTMD (EOP= 9502', + 26' CORRECTION). RIH W / CEMENT RETAINER TIE INTO FLAG, CORRECT TO 9538'' RKB, SET REAINER @ 10315' RKB, PERFORM INJECTIVITY TEST @ 1 BPM 737 PSI, 1.5 BPM 1334 PSI, 2 BPM 2090 PSI, PUMPED 82.3 BBLS OF 15.8 CLASS G CEMENT, 80 BBLS BELOW RETAINER AND LAID IN 2.3 BBLS ON TOP OF RETAINER, CLEAN OFF CEMENT TOP TO 10,085' RKB, POOH AND RDMO. 5/9/2023 ACQUIRE DATA TAG TOC @ 10054' SLM, PERFORM MITT TO 1500 PSI (PASSED), READY FOR STATE WITNESS. 5/12/2023 ACQUIRE DATA STATE WITINESS (CAM ST.JOHN) TAG TOC @ 10048' SLM. PERFORM PASSING MIT-T TO 1500 PSI. CEMENT JOB COMPLETE, NEXT UP SLICKLINE PRE-RIG. 3S-23A Suspend 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): 14144'None Casing Collapse Structural Conductor Surface 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: 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 10475-14091' 10443' 4-1/2" 5852-5901' 14144'3874' 3-1/2" 5900' 7" 16" 9-5/8" 78' 4011' Perforation Depth MD (ft): MD 108' 2606' 108' 4040' 5852'10472' Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 5900'10288'5836'3385 None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544, ADL0025551, ADL0380107 206-043 P.O. Box 100360, Anchorage, AK 99510 50-103-20453-01-00 ConocoPhillips Alaska, Inc. KRU 3S-23A None/SuspendedKuparuk River Oil Pool Kuparuk River Field N/A Tubing Grade:Tubing MD (ft): Packer: 10270' MD/5834' TVD SSSV: None Perforation Depth TVD (ft):Tubing Size: L-80 10333' 6/18/2023 Packer: HR ZXP Liner 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 James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-1102 CTD Engineer P 66 t _ c Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Kayla Junke at 2:52 pm, May 01, 2023 323-263 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 13:56:26-08'00' Foxit PDF Editor Version: 12.0.1 James J. Ohlinger MDG 5/24/2023 X VTL 6/12/2023 BOP test to 3500 psig Annular preventer test to 2500 psig 10-407 DSR-5/2/23 X GCW 06/12/2023 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.12 16:10:08 -08'00' RBDMS JSB 061423 James J Ohlinger Staff Wells Engineer CPAI Drilling and Wells 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. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 1, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3S-23 (PTD# 206-043). Well 3S-23 was drilled and completed as a Kuparuk Producer in April 2003. The well has been slated to be P&A'd for development of the Coyote formation. Page 1 of 2 3S-23 RWO Procedure Kuparuk Producer Suspend PTD #206-043 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-23. (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 250/3,500 psi. Test annular 250/3,500 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. Page 2 of 2 3S-23 RWO Procedure Kuparuk Producer Suspend PTD #206-043 General Well info: Wellhead type/pressure rating:FMC Gen V Production Engineer:Brian Lewis Reservoir Development Engineer:Lynn Aleshire Estimated Start Date:06/18/2023 Workover Engineer:James Ohlinger (265-1102 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:3385 psi using 0.1 psi/ft gradient Static BHP: 3859 psi / 4744’ TVD measured on 2/11/2018. Rig work should be done over P&A’d well and not exposed to formation pressure during Rig portion of work. Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 29.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.835 Top (ftKB) 28.8 Set Depth (ftKB) 4,040.2 Set Depth (TVD) … 2,605.6 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 28.7 Set Depth (ftKB) 10,471.8 Set Depth (TVD) … 5,851.7 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 10,269.9 Set Depth (ftKB) 14,143.6 Set Depth (TVD) … 5,900.4 Wt/Len (l… 12.60 Grade L-80 Top Thread BTCM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,269.9 5,833.8 83.85 PACKER HR ZXP LINER TOP PACKER 3.958 10,290.2 5,835.9 84.19 NIPPLE RS PACKOFF SEAL NIPPLE 3.958 10,292.7 5,836.2 84.22 HANGER FLEXLOCK LINER HANGER 5.000 10,302.5 5,837.1 84.35 SBE 80-40 CASING SEAL BORE EXTENSION 4.000 10,321.4 5,839.0 84.59 BUSHING TKC XO BUSHING 3.920 14,095.1 5,900.6 90.14 PACKOFF BAKER PACKOFF & CROSSOVERS 2.390 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 26.5 Set Depth (ft… 10,333.4 Set Depth (TVD) (… 5,840.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.5 26.5 0.00 HANGER FMC GEN 5 TUBING HANGER 3.500 530.0 529.0 7.90 NIPPLE CAMCO DS NIPPLE w/ 2.875" NO GO 2.875 9,464.9 5,635.9 66.30 SLEEVE BAKER CMU SLIDING SLEEVE w/ CAMCO 2.813" DS PROFILE 2.813 9,537.8 5,664.0 68.30 NIPPLE CAMCO D NIPPLE w/ 2.75" NO GO 2.750 10,294.5 5,836.3 84.24 LOCATOR BAKER LOCATOR 3.000 10,321.9 5,839.0 84.60 SEAL ASSY BAKER BONDED SEAL ASSEMBLY w/ 15' STROKE 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/ft )Type Com 10,475.0 14,091.0 5,852.0 5,900.6 C-4, 3S-23A 5/31/2006 32.0 SLOTS SLOTTED LINER 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 3,828.6 2,508.7 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.156 1,864.0 11/17/2015 2 5,982.4 3,704.3 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2006 3 7,542.4 4,618.6 CAMCO KBMG 1 GAS LIFT OV BK-5 0.313 0.0 11/18/2015 4 8,568.8 5,209.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2006 5 9,408.5 5,612.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/17/2015 Notes: General & Safety End Date Annotation 12/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE Horizontal - 3S-23A, 2/7/2018 12:04:43 PM Vertical schematic (actual) LINER; 10,269.9-14,143.6 SLOTS; 10,475.0-14,091.0 PRODUCTION; 28.7-10,471.8 SEAL ASSY; 10,321.9 LOCATOR; 10,294.5 NIPPLE; 9,537.8 SLEEVE; 9,464.9 GAS LIFT; 9,408.5 GAS LIFT; 8,568.8 GAS LIFT; 7,542.4 GAS LIFT; 5,982.4 SURFACE; 28.8-4,040.2 GAS LIFT; 3,828.6 NIPPLE; 530.0 CONDUCTOR; 29.0-108.0 HANGER; 26.5 Last Tag Annotation Last Tag: Depth (ftKB) 10,288.0 End Date 8/7/2006 Last Mod By WV5.3 Conversion Last Rev Reason Annotation Rev Reason: H2S End Date 2/7/2018 Last Mod By pproven KUP PROD KB-Grd (ft) 32.69 Rig Release Date 4/20/2003 Annotation Last WO: End Date 3S-23A H2S (ppm) 130 Date 11/3/2017... TD Act Btm (ftKB) 14,144.0 Well Attributes Wellbore API/UWI 501032045301 Field Name KUPARUK RIVER UNIT Wellbore Status PROD Max Angle & MD Incl (°) 92.85 MD (ftKB) 11,929.30 3S-23A Existing Completion3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco DS-nipple @ 530' RKB (2.875" ID)3-1/2" Camco KBMG gas lift mandrels @ 3829', 5982', 7542', 8569', & 9409' RKBBaker CMU Sliding Sleave @ 9465' RKB (2.813" ID)3-1/2" Camco D nipple @ 9538' RKB (2.75" min ID)3-1/2" locator @ 10,295' RKBBaker SA @ 10,322' RKB (w/ 15' stroke)Liner topBaker HR ZXP liner top packer @ 10,270' RKBRS Packoff Seal Nipple @ 10,290' RKBBaker Flexlock liner hanger @ 10,293' RKBBaker 80-40 SBE (4.0" ID) @ 10,303' RKB7" 26# L-80 shoe @ 10,472' MD4-1/2" 12.6# L-80 shoe @ 14,144' RKBC4 Sand 10,475-14,091' RKB slotted liner9-5/8" 40# L-80 shoe @ 4040' MD3S-237" casing cut @ 4149' MDTagged cement @ 3696' MDSidetracked ~ 4040' 3-1/2" Tubing Cut ~ 9805' MD , 74.6° Inc.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): 14144'None Casing Collapse Structural Conductor Surface 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: 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 Jill Simek jill.simek@conocophillips.com (907) 263-4131 Staff Well Intervention Engineer Tubing Grade:Tubing MD (ft): Packer: 10270' MD/5834' TVD SSSV: None Perforation Depth TVD (ft):Tubing Size: L-80 10333' 5/1/2023 Packer: HR ZXP Liner Packer SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025544, ADL0025551, ADL0380107 206-043 P.O. Box 100360, Anchorage, AK 99510 50-103-20453-01-00 ConocoPhillips Alaska, Inc. KRU 3S-23A None/SuspendedKuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 5900'10288'5836'3723 None MD 108' 2606' 108' 4040' 5852'10472' 16" 9-5/8" 78' 4011' Perforation Depth MD (ft): 10475-14091' 10443' 4-1/2" 5852-5901' 14144'3874' 3-1/2" 5900' 7" P s 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-239 By Kayla Junke at 1:43 pm, Apr 19, 2023 Jill Simek Digitally signed by Jill Simek Date: 2023.04.19 09:29:24 -08'00' VTL 4/24/2023 DSR-4/20/23 10-407 X Suspension approved through 12/31/2023. P&A, including surface abandonment must be completed by 12/31/2023 10-407 SFD 4/21/2023 X JLC 4/26/2023 4/26/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.26 11:53:54 -08'00' RBDMS JSB 042723 JS 3S-23A SUSPEND Permit to Drill #: 206-043 Producer 3S-23A (PTD: 206-043) was drilled and completed in the Kuparuk C4 in 2006. In November 2022, the well was shut in for water handling and low production. At the time it was shut in, 3S-23A produced 35 BOPD, 3,800 BWPD and 590 MCFD. Subsequently, this well has been identified as a P&A candidate, to allow for slot recovery and slot optimization for Coyote Development. The well’s resource is recoverable by updip producer 3S-07. 3S-23A 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-23A 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 10,333ft KB and a Baker bonded seal assembly set at 10,322ft KB. A 4 ½” slotted liner was run from 10,270ft to 14,144ft KB. Slots are 10,475ft to 14,091ft KB. Surface casing is 9-5/8”, and production casing is 7”. Per this procedure, suspended operations will be performed by pumping 81 bbls of 15.8 ppg Class “G” cement through a cement retainer at approximately 10,315ft KB, then placing 2 bbls on top of the retainer. A tag and pressure test will confirm planned Top of Cement in tubing at ~10,085ft KB. Well Status/History: Last MITs: MIT-T passed to 2500psi on 11/6/2015; MIT-IA passed to 2500psi on 11/4/2015; MIT-OA failed 12/12/2005 SBHP = 4,343psi @ 6,200ft SS. (2/11/2018) Min ID = 2.75” @ 9,538ft KB (Camco D Nipple w/ 2.75” No-Go) Nipple is listed as “problematic” in AnnComm Last Tag: Tagged 10,288ft KB (8/7/2006) 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 10,315ft KB, or as far as possible. 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. JS Record Results. DISCUSS RESULTS WITH WELL INTERVENTIONS ENGINEER 5. Establish/confirm OA LLR for cement downsqueeze. 6. RDMO. Coiled Tubing / Cementing: Objective: Place a cement plug across the perforations and squeeze some cement into perforations. Cement Volume Calculations (TOC approximately 10,085ft KB in tubing): 4 ½ liner,100ft below bottom slots to bottom of seal assembly: (0.01522 bbl/ft) * (14,191ft – 10,333) = 58.7 bbls 3 ½” tubing, bottom of tubing/seal assembly to TOC: (0.008696 bbl/ft) * (10,333ft – 10,085ft) = 2.2 bbls Squeeze volume = 20.1 bbls Total volume = 58.7 + 2.2 + 20.1 = 81 bbls 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 81 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 2/7/2018 schematic and tubing details for depth correlation. Use Camco D-nipple at 9,537ft KB for correlation. 6. RIH and perform tie in pass (tag/flag nipple at 9,538ft KB). 7. RIH with cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 8. Set cement retainer at approximately 10,315ft KB (middle of tubing spacer, above seal assembly), or as deep as the retainer will safely drift. (Do not set retainer shallower than 9,975ft KB) 9. Close in the CT x tubing annulus, and line up to pump down the coil tubing. 10. Pump 20 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 11. Pump 10 bbls freshwater spacer 12. Pump 79 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. 13. Shut down, un-sting from retainer 14. Lay in remaining 2.0 bbls cement above retainer (equates to ~ 230’ of cement above the retainer, leaving TOC ~10,085ft KB) 15. POOH above TOC. Circulate CTU clean. 16. Wash up surface equipment. RDMO. JS Slickline / Little Red Objective: State witnessed tag of TOC, MIT-T 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 10,085ft KB. Record Results. TAG MUST BE AOGCC WITNESSED 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. Report issues and results to Well Interventions Engineer. 8. RDMO JS Schematic: JS Suspend Diagram: i 20 6043 WELL LOG 2 9 1 8 8 TRANSMITTAL AL PROACTIVE DiAgNosTic SERvicEs, Inc. To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 SCANNED Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: RitCEIVED ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C 2018 Anchorage, AK 99518 AOG CC Fax: (907)245-8952 1) Production Profile 05-Mar-18 3S-23A Color Log/CD 50-103-20453-01 2) Signed : I , Date :a( ?°/( ' ce Print Name: i PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(DMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\conocoPhillips_Transmit.docx • • RECEIVED OCT 232015 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 20, 2015 %WO) MAY 1 12016 0/-1.3 ab (^ .23 s _ a3A Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: 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. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, c_r_y (iti MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10/20/2015 3H,3J,3Q&3S Pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3H-26 501032020800 1940290 9" NA 9" NA 4.3 10/9/2015 3J-18 500292270100 1961470 12" NA 12" NA 8 10/3/2015 3J-19 500292270200 1961480 11" NA 11" NA 4.25 10/5/2015 30-21 500292263000 1951930 12" NA 12" NA 5.5 10/9/2015 3S-6A 501032045401 2030880 11" NA 11" NA 9.1 10/3/2015 r)3S-23A 501032045301 2060430 16" NA 16" NA 6.2 10/3/2015 3S-24A 501032045601 2040610 18" NA 18" NA 6.3 10/3/2015 3S-26 501032036101 2010400 9" NA 9" NA 3.8 10/3/2015 n ,,,:, ..... .. ,F.--— STATE OF ALASKA OCT 0 8 2015 ALQA OIL AND GAS CONSERVATION CONOSION REPORT OF SUNDRY WELL OPERATIONS = . G , 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing f- Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool Repair Well Re-enter Susp Well Other:Cond Extension 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J' Exploratory r 206-043 3.Address: 6.API Number: Stratigraphic r Service r P. 0. Box 100360,Anchorage,Alaska 99510 50-103-20453-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380107,ADL0025544,ADL0025551 KRU 3S-23A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 14144 feet Plugs(measured) None true vertical 5900 feet Junk(measured) None Effective Depth measured 10288 feet Packer(measured) 10322 true vertical 0 feet (true vertical) 5839 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108 108 1640 630 SURFACE 4011 9-5/8 4040 2606 5750 3090 PRODUCTION 10443 7 10472 5851 7240 5410 LINER 3874 4-1/2 14144 5900 8430 7500 Perforation depth: Measured depth: 10475'-14091' True Vertical Depth: 5852'-5901' CAS P 'AN2 2.016 Tubing(size,grade,MD,and TVD) 3.5, L-80, 10322 MD, 5839 TVD Packers&SSSV(type,MD,and TVD) PACKER= BAKER BONDED SEAL ASSEMBLY @ 10322 MD and 5839 TVD SSSV=CAMCO DS NIPPLE w/2.875"NO GO @ 530 MD and 529 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r,.' Gas r VVDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ 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: 315-431 Contact Martin Walters/MJ Loveland Email n1878Aconocophillips.com Printed Name Martin Walters Title Well Integrity Supervisor Signature �� �JC�"o-' Phone:659-7043 Date: 10/4/2015 VTL(/o//2//5- elz-fc RBDMS� DC T 12 2015 Form 10-404 Revised 5/2015 Submit Original Only * • • 3S-23A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/19/15 Welder welded 16"x 16" .375 62#conductor ext onto existing conductor. 10/03/15 Injected 6.2 gallons of RG2401 sealant into the conductor. •ti OF Ty 0)I//j�sN THE STATE Alaska Oil and Gas �� o T KA. Conservation Commission dAs sty== 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279.1433 ALAS* Fax 907.276 7542 www.aogcc.alaska.gov Martin Walters 4F1/4 D(,-3 Well Integrity Supervisor ' ' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-23A Sundry Number: 315-431 Dear Mr. Walters: 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, /D7?2•64 Cathy P. Foerster ,, - Chair DATED this ll� day of July, 2015 Encl. STATE OF ALASKA RECEIVED • ,.._,,SKA OIL AND GAS CONSERVATION COM.„.ISSION JUL ] 5 Z0 ) APPLICATION FOR SUNDRY APPROVALS s ? i x/ i(S 20 AAC 25.280 AOGCC CC 1.Type of Request Abandon r Rug Fbrforations r Fracture Stimulate r Pull Tubing r , l� Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing Id Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r- Re-enter Susp Well r Other Cond Extension r 2.Operator Name: 4.Current Well Class: 5 Permit to Drill Number. ConocoPhillips Alaska, Inc. Exploratory r Development r. 206-043 3.Address: Stratigraphic r Service r 6 API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20453-01 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes r No Pr' KRU 3S-23A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380107, ADL0025544, ADL0025551 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): 14144 5900 1li ILI ° 57o Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108' 108' 1640 630 SURFACE 4011 9-5/8 4040' 2606' 5750 3090 PRODUCTION 10443 7 10472' 5851' 7240 5410 LINER 3874 4-1/2 14144' 5900' 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft) Tubing Size. Tubing Grade. Tubing MD(ft): 10475-14091' 5852'-5901' 3.5 L-80 10322 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER= BAKER BONDED SEAL ASSEMBLY MD= 10322 TVD=5839 NIPPLE=CAMCO DS NIPPLE MD=530 TVD=529 12 Attachments: Description Summary of Proposal 7 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/15/2015 OIL WINJ r WDSPL r Suspended r 16.Verbal Approval Date: GAS r WAG r GSTOR r SPLUG E Commission Representative: GINJ r Op Shutdown r Abandoned r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Martin Walters/MJ Loveland Email: n1878@cop.com Printed Name Martin Walter Title: Well Integrity Supervisor Signature %71:2?"& Pti, ' lttf,f , Phone:659-7043 Date:07/12/15 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 31 5^ 1-13 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes 0 No V Subsequent Form Required /i ' — 4- d 4- APPROVED BY �Q Approved by: pIS ONER HFA �C(N I$5�I Date��2 �`3 n .r. gniRlicboi NITr months from tC PP Val• Submit Form and Form 10-403 Revised 5/2015 U -TM 'Z� 1 Attachmenin Duplicate vrL 7-/ e/'� x/2,41' RBDMS kt AUG - 2 2015 IUL 15 2015 ConocoPhillips Aoocc Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 12, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3S-23A, PTD 206-043 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, IC Martin Walters ConocoPhillips Well Integrity Projects Supervisor y/ ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 3S-23A (PTD 206-043) SUNDRY NOTICE 10-403 APPROVAL REQUEST July 12, 2015 This application for Sundry approval for Kuparuk well 3S-23A is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface. At some point during normal operations the conductor subsided about 16". 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 Projects Supervisor . KUP 3S-23A ConocoPhillips '"62 Well Attributes Max Angle&MD TD AI1Ska Ih0 Wellbore API/UWI Field Name Well Status Intl(°) MD(ftKB) Act Btrn(5/03) l«ac:9'hdl,pc..- 501032045301 KUPARUK RIVER UNIT PROD 92.85 11,929.30 14,144.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Wel Confi9:Ho,00nlal-3S-23A.3/1320129:0339 AM SSSV:NIPPLE 45 12/3/2011 Last WO: 32.69 4/20/2003 Schematic•Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 10,288.0 8/7/2006 Rev Reason:WELL REVIEW osborl 3/13/2012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd CONDUCTOR 16 15.062 29.0 108.0 108.0 62.50 H-40 WELDED HANGER.27 , Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TMD)...String WL..String...String Top Thrd SURFACE 95/8 8.835 28.8 4,040.2 2,605.5 40.00 L-80 BTC - $ - Cuing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 28.7 10,471.8 5,851.2 26.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER 41/2 3.958 10,269.9 14,143.6 5,900.4 12.60 L-80 BTCM CLiner Details CONDUCTOR. Top Depth 29.108 (ND) Top Incl Nomi... Top(11KB) (RKB) I°) Item Description Comment ID(in) NIPPLE.530 sir 10,269.9 5,833.8 83.85 PACKER HR ZXP LINER TOP PACKER 3.958 III 10,290.2 5,837.0 85.45 NIPPLE RS PACKOFF SEAL NIPPLE 3.958 I. 10,292.7 5,837.2 85.45 HANGER FLEXLOCK LINER HANGER 5.000 GAS UFT 10,302.5 5,837.9 85.43 SBE 80-40 CASING SEAL BORE EXTENSION 4.000 a; 10,321.4 5,839.4 85.40 BUSHING TKC XO BUSHING 3.920 am 14,095.1 5,900.6 90.14 PACKOFF BAKER PACKOFF&CROSSOVERS 2.390 [Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)... String Wt...String.. String Top Thrd TUBING 31/2 2.992 26.5 10,333.4 _ 5,840.3 - 9.30 L-80 J EUE8RDMOD , SURFACE, ' evietion Details 29-4,040_ Top Depth (TVD) Top Incl Nomi... Y Top(ftKB) OM) I") item Description Comment ID(in) 26.5 26.5 -0.05 HANGER FMC GEN 5 TUBING HANGER 3.500 GAS LIFT, 5,982 ' 530.0 528.9 7.56 NIPPLE CAMCO DS NIPPLE w/2.875"NO GO 2.875 9,464.9 5,635.6 66.30 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO 2.813"DS PROFILE 2.813 __ 9,537.8 5,663.8 69.38 NIPPLE CAMCO D NIPPLE w/2.75"NO GO 2.750 10,294.5 5,837.3 85.44 LOCATOR BAKER LOCATOR 3.000 10,321.9 5,839.4 85.40 SEAL ASSY BAKER BONDED SEAL ASSEMBLY w/15'STROKE 3.000 GAS LIFT, - 7,542 ilLz III Shot III Top(TMD) Bim(TVD) Dens IV Top(ftKB)She(ftKB) (15168) (18(B) Zone Date NIL- Type Comment 10,475.0 14,091.0 5,851.6 5,900.6 C-4,3S-23A 5/31/2006 32.0 SLOTS SLOTTED LINER GAS LIFT, _ 6'569 Notes:General&Safety End Date Annotation 12/2 7/2010 I NOTE:View Schematic w/Alaska Schematic9.0 MI GAS L,408IFT, 9 MI IIII UP SLEEVE,9.465 Ili NIPPLE.9538 I- .. LOCATOR. 19295 -.._ SEAL ASSY. ( 1 10,322 Mandrel Details ,111111 Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) II Make Model (in) Sery Type Type (in) (pal) Run Date Com... 1 3,828.6 2,508.7 62.15 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.06/3/2006 PRoOucnoN. 2 5,982.4 3,704.3 55.03 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2006 29-15.47z 3 7,542.4 4,618.6 53.37 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2006 alto 'IV! 4 8,568.8 5,209.9 57.20 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/3/2006 1, 5 9,408.5 5,612.4 64.82 CAMCO MMG 1 12 GAS LIFT OV RK 0.313 0.08/16/2007 SLOTS, in,r( 10,475-14,091 'i( i LINER, 10.270.1044 N II it TD(3S-23A), 14,144 Bettis, Patricia K (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Thursday, July 23, 2015 5:59 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3S-23A TD 14144 RKB, 5901 TVD Plug Back 14140 RKB, 5901 TVD MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,July 16, 2015 9:51 AM To: NSK Well Integrity Proj Subject: [EXTERNAL]KRU 3S-23A Good morning Martin, Please advise what the current plug back depth is for the KRU 3S-23A well, both MD and TVD. The information was missing from the sundry application. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue 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 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, July 16, 2015 9:51 AM To: NSK Well Integrity Proj (N1878@conocophillips.com) Subject: KRU 3S-23A Good morning Martin, Please advise what the current plug back depth is for the KRU 3S-23A well, both MD and TVD. The information was missing from the sundry application. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue 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 .~., ~; K ~.; ,~ ~ ' `y~, ~. '~ vs-.~~ ~ rtiR~ ~` _ ,, ,~~ ~ MICROFILMED 6/30/2010 DO NOT PLACE - ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • WELL LOG TRANSMITTAL To: State of Alaska July 14, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation L AK-MW-4333321 The technical data listed below is b g herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-23A 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-103-20453-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-103-20453-01 Digital Log Images ~~~.~~~~ AU ~ ~' ~ ~~~$ 1 CD Rom 50-103-20453-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services ~ ~~Co-b~-i3 ~ ~~~~ Attn: Rob Kalish 6900 Arctic Blvd. ?~nch~~~g?,: Alaska ~95i8 __ gn Date: Si ed• ogs 35-23~A, ein su miffed ~r ~w~ DATA SUBMITTAL COMPLIANCE REPORT 6/25/2008 Permit to Drill 2060430 Well Name/No. KUPARUK RIV UNIT 3S-23A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20453-01-00 MD 14144 TVD 5901 Completion Date 6/4/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~, DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ,fib D Asc Directional Survey C Lis 15442 `°Inctaetion/Resistivity ED D Li ' 13989 I /R d i i i i s { / . n uct on es st v ty ~ ~14 t `` 13989 LIS V ifi ti p ~- er on ca 15442 Induction/Resistivity 3987 14144 Open 8/22/2006 10291 14143 Open 9/28/2007 LIS Veri, GR, ROP, FET, DRHO, NPHI w/PDS and TIF graphics 3995 10491 Open 7/19/2006 LIS GR, EWR4, ROP, PWD 0 0 Open 7/19/2006 GR, EWR4, ROP, PWD 2 Blu 10491 14144 Open 9/28/2007 Vision Service Final Print Scale 1:600 29-May-2006 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~N Chips Received? ~1-~ Analysis ~L Received? Daily History Received? ~ N Formation Tops ~./ N Comments: Compliance Reviewed By: Date: ~7~~~~~~~~r~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ ~ ~ ~ . f ~ ~ "~ ~ ~ ~~~~,I~ N0.4418 ~~~ ',~,~ ;~g~~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 09/26/07 3S-23A 40013525 OH MWD EDIT VISION-SERVICE 05/29/06 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • 02-Aug-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3S-23A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 3,987.78' MD Window /Kickoff Survey: 14,083.40' MD (if applicable) Projected Survey: 14,144.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ ~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~'~`i3 ~- • ,~ C011000~'t1~~Ip5 Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 4951Q-Q360 August 7, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: _ / ~ ~ r WW3 s - ~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIJ). 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 of 2.5 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, M.J oveland 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 PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date RG2041 vol RG casing filler vol. Corrosion inhibitor/ sealant date ft bbls ft al al 8/5/2006 3S-03 2o3-os1 a' a.6 2' 2" 11/18/2003 5.7 7.1 8/5/2006 3S-06A 203-088 4' 4" 0-0 4' 4" 11/18/2003 %.5 18.1 8/5/2006 3S-o7 202-187 14' ~ 5 1' 11 " 11 /18/2003 5.7 5.7 8/5/2006 3S-oaB 2o3-oas ~~ 2" o 0 3' 2" 11/18/2003 18.7 0 8/5/2006 3S-09 202-205 16' 2.5 2' 11" 11!1$12003 5.7 11.5 8/5/2006 ~s-~o 2o2-2sz 12' ~ 5 1' 11" 11/18/2003 5 7 5.7 8/5/2006 3s-1a 202-221 9' 1.5 5' 4" 11/18!2003 8.5 23 8/5/2006 35-15 2o2-z5a s' o a 2' 2" 11/18/2003 5 7 7 1 8/5/2006 35-16 203-407 a' s" o.0 4' 8" 11/18/2003 8 19.5 814!2006 3s-1;A zo3-oso ia~ ~ ~ 2' 11f1812003 5.7 6.1 8/5/2006 35-18 2o2-20a 12' 1.1 1' 11" 11/18/2003 5.7 5.6 8/5/2006 3s-~g 2o~-a96 i i 2' 3" 11/18/2003 5.7 7.5 8/5/2006 3S-21 203-031 7' 0.5 2` 1" 11/18/2003 5.7 6.6. 8/5/2006 ss-22 203-0~ ~ ~~ 0 0 i ~ i o" 11/18/2003 5 ; 5.1 8/5/2006 3S-23A 206-043 4' 0.3 2' 2" 1 1 /18/2003 5.7 7.1 8/5/2006 3S-24A 204-061 1' 9" 0.0 1 ~ 9" 1 1/1812003 10.3 0 8/5/2006 35-26 201-440 1' a" o 0 1' 4" 11118/2003 7.8 0 8/5/2006 • ConocoPhillips July 12, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3S-23A Dear Commissioner: • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99590-0360 Phone: 907-265-6830 ~~~~~~~ JUL 1 8 2006 Alaska Oil ~ Cas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 3S-23A. If you have any questions regarding this matter, please contact me at 265-6830 or Jason Brink at 265-6419. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA • ALASKA OlL AND GAS CONSERVATION COMMISSION (~]]~~ FZE~~I`/~~J06 JULY 8 ZOQ6 ~'~^~mission WELL COMPLETION OR RECOMPLETION REP~~/4~L~~~~-ission 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: i1C Of~E Development ^/ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: June 4, 2006 12. Permit to Drill Number: 206-043 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 30, 2006 ~ 13. API Number: 50-103-20453-01 4a. Location of Well (Governmental Section): Surface: 2560' FNL, 1246' FEL, Sec. 18, T12N, R8E, UM ' 7. Date TD Reached: May 29, 2006 14. Well Name and Number: 3S-23A ` At Top Productive Horizon: 276' FNL, 1800' FWL, Sec. 24, T12N, R7E, UM 8. KB Elevation (ft): 31' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1435' FSL, 763' FWL, Sec. 24, T12N, R7E, UM 9. Plug Back Depth (MD + ND): 14140' MD / 5901' TVD Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476013 y- 5993856 Zone- 4 10. Total Depth (MD + ND): .14144' MD / 5901' ND 16. Property Designation: . ADL 25544 & 25551 • TPI: x- 468963 y- 5990886 Zone- 4 Total Depth: x- 467913 ' - 5987322 - Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 2639 & 2616 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: xx MD 21. Logs Run: KDp ~ /YJ~j ~ 2~0 Z7 ' T~ GR/Res, Dens/Neu 7.3(•O 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.6# B 31' 108' 31' 108' 42" 65 bbls ArcticCRETE 9.625" 40# L-80 31' 4040' 31' 2604' 12.25" 616 sx AS Lite, 341 sx LiteCrete 7" 26# L-80 31' 10471' 31' 5852' 8.5" 217 sx Class G 4.5" 12.6# L-80 10266' 14144' 5833' 5901' 6.125" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number, if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 10287' 10270' slotted liner from 10475'-14093' and 5852'-5900' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10096'-10244' and 32.5 bbls squeeze pill 26. PRODUCTION TEST Date First Production June 7, 2006 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Date of Test 6/11/2006 Hours Tested 20 hours Production for Test Period --> OIL-BBL 3516 GAS-MCF 1964 WATER-BBL 3145 CHOKE SIZE 40% GAS-OIL RaT10 559 Flow Tubing press. 398 psi Casing Pressure 1 ggg Calculated 24-Hour Rate -> OIL-BBL 3157 ' GAS-MCF 1346 WATER-BBL 2619 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". _ COMFLLTiON NONE RBDMS BFI ~u~ 2 ~ 2006 r~~ YE ED /~" I Form 10-407 Revised 12/2003 DR'I G'INA'L CONTINUED ON REVERSE ~'r~~~ r~ zs. zs. 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". 3S-23A Top Kuparuk C 10418' 5848' 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: Jason Brink @ 263-6419 Printed Na Rand Thomas Title: Greater Kuparuk Area Drilling Team Leader / ~ (f ~ ~~ 6 Signature - ne Date -z 6 S. Ez`' S r7 INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on ail types of sands 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 12/2003 ~onocoP`hii~ips Time Log Summary 4Vellview i'deb ReA~rtmg - - TimeLogs ___. __ - ---- - -- Date From To Dur S Depth E. De th Phase Code _ Subcode T_ COfv1 - -- - - - 04/16/2006 12:00 14:30 2.50 MIRU MOVE DMOB P Blew down rig, moved rock washer and re ared to move ri 14:30 15:45 1.25 MIRU MOVE DMOB P Held PJSM then moved rig off well, re ared ri for move 15:45 00:00 8.25 MIRU MOVE MOB P Bregan moving rig from 1H South (NEWS Ice Pad) to 3S Pad, have moved ri 12.4 miles of 25 04/17/2006 00:00 09:30 9.50 0 0 MIRU MOVE MOB P Fin moving Rig from NEWS Ice Pad to 3S Pad, moved rig 12.6 miles for a total of 25 miles. 09:30 18:00 8.50 0 0 MIRU MOVE MOB P Moved rig camp 25 miles to 3S Pad from 1 H South, shut down 2 hrs due to flat tire, aired up and fin moving to 3S pad, Crew set up pit liner on 3S pad and spotted rig for maintenance, Rig and Camp Move completed at 18:00 HRS. Rig Released for Top drive Installation. 04/24/2006 12:00 12:45 0.75 MIRU MOVE MOB P Moved rig 100' down 3S pad from where top drive was changed out and s otted over well 3S-23A. 00:45 04:00 3.25 MIRU MOVE RURD P Bermed around rig and set in rigs electric transformer and hooked up lines around rig. ACCEPTED RIG @ 16:00 H rs 4/24/06 04:00 06:30 2.50 COMPZ MOVE RURD P Set in rockwasher and centrifuge cuttings box and bermed same, RU circ lines in cellar preparing to circ out diesel. Ri on hi hline at 17:00 hrs 06:30 07:30 1.00 COMPZ WELCT EQRP P Checked wellhead pressures, SITP 150 psi, IA 150 psi, OA -0- psi, RU FMC lubricator and ulled BPV 07:30 08:30 1.00 COMPZ WELCT NUND P RU circulating hose to tree. Check lines w/ 120 si ri air. 08:30 09:00 0.50 COMPZ WELCT SFTY P PJSM with crew & mud engineer in doghouse. Prepare to circulate out diesel ca from tubin and annulus. 09:00 12:00 3.00 COMPZ WELCT CIRC P Reverse circulate seawater down annulus taking diesel returns from tubing thru choke until seawater returned. Switch lines and circulate seawater down tubing taking diesel returns from annulus thru choke until clean seawater returned. Displaced diesel cap from well. Monitor well, well dead. Start blowing down & rigging down circulatin lines. 04/25/2006 00:00 00:30 0.50 COMPZ WELCT OWFF P RD circulating hoses while monitoring well P~cJ€~ 1 of 29_, Time Logs _ - - - -- - .Date From To Dur _ _5. e th E. Depth Phase Code Su_bcode_ T LOM_ _ - -- - - - -- 04/25/2006 00:30 01:00 0.50 COMPZ WELCT OTHR P Set BPV 01:00 01:30 0.50 COMPZ WELCT NUND P ND 3-1/8" 5 Ksi tree and tubing head ada ter. 01:30 04:30 3.00 COMPZ WELCT NUND P Attempt to pull SBMS seal, lodged in neck of tubing hanger. Tie on with 60" pipe wrenches and bridge crane & pull SBMS seal 04:30 10:30 6.00 COMPZ WELCT NUND P NU 11" 5 Ksi BOPE. Change bottom rams to 7". 10:30 15:00 4.50 COMPZ WELCT BOPE P Test BOPE. Accumulator capacity test: 2900 psi initial manifold pressure, 1850 psi after all dosed, rebuilt 200 psi in 15 sec., full pressure in 1 min 28 sec. Blind rams, variable pipe rams, and annular to 300 psi & 3500 psi. (7" rams to be tested after decompletion.) Choke and kill lines and valves, choke manifold, floor safety valves, upper and lower kelly valves to 300 psi & 3500 psi. Witnessing of test waived by Chuck Scheve, AOGCC Field Ins ector. 15:00 16:30 1.50 COMPZ PLUG OTHR P Rack & tally 160 joints of 4" drillpipe. 16:30 17:00 0.50 COMPZ WELCT OTHR P Pull two way check. 17:00 17:30 0.50 COMPZ RPCOh PULD P MU landing joint. BOLDS. Pull tubing hanger to rig floor, 110 K# PU Wt. LD hanger and landing joint. RU to circulate. 17:30 1.8:30 1.00 COMPZ RPCOti CIRC P Circulate bottoms up, 6 BPM, 750 psi. 8.5 Seawater all around. 18:30 20:30 2.00 COMPZ RPCOh TRIP P POOH with 3-1/2" completion string, stand back 11 stands for cementing, later. 20:30 00:00 3.50 COMPZ RPCOti PULD P Continue POOH, laying down 3-1/2" tubing and jewelry. approximately 150 joints layed down, plus 33 in derrick at 2400 hrs. 04/26/2006 00:00 09:00 9.00 COMPZ RPCOh PULD P Continue POH LD 3-1/2" tubing & jewelry. Recovered entire string thru locator/seal assembly. Chemical cut was incomplete, left about 1-1/2" uncut. Recoverred 319 joints, DS Nipple, 5 GLM, CMU Sliding sleeve, Locator/Seal ass . 09:00 10:00 1.00 COMPZ RPCOti RURD P RD tubing equipment. RU 4" DP e ui ment. Han ton s. 10:00 12:00 2.00 COMPZ RPCON RURD P PU & MU 7" test joint to test plug to test 7" rams. Crossovers too tall to close rams on 7" test joint. RD hoses & LD test joint. Blow down water line, Plan to test 7" rams after setting bridge plug, with test joint made up on DP. ~~sgo 2 of~fl - _ _ - -- -- -- - -- -- I Time Logs Date From To__ Dur yepth, E. Depth Phase Code 5ubcode T COM _ ____ 04/26/2006 12:00 17:00 5.00 COMPZ RPCOh TRIP P MU old bit & 7" casing scraper. RIH PU 4" DP to 4508'. 17:00 17:30 0.50 COMPZ RPCOti CIRC P Circulate bottoms up, 7 BPM, 540 psi. 85K# PU, 65K# SO, 35K# Block Wt. 17:30 18:00 0.50 COMPZ RPCOh OTHR P Slowdown top drive. Monitor well, static. 18:00 18:30 0.50 COMPZ RIGMN SVRG P Service rig. 18:30 21:00 2.50 COMPZ RPCOh TRIP P POH. LD bit & scraper. 21:00 23:30 2.50 COMPZ RPCOh TRIP P MU Bsker 7" K-1 retainer and setting tool on DP. RIH to 4425' (15' above 7' coupling). 90K# PU, 70K# SO, 35K# Block Wt. Rotate 10 turns and set retainer, Pull 42K# over, set down 35K#, and repeat - retainer set.PU to 95K# (5K# overpull), rotate 10 turns to close ports and release setting tool. Brid a Plu set at 4425' MD. 23:30 00:00 0.50 COMPZ RPCOh CIRC P Break circulation and circulate sea water while preparing to displace to 8.9+ mud, 5 BPM, 260 si. 04/27/2006 00:00 01:30 1.50. COMPZ RPCOh CIRC P Pump 30 Bbl hi-visc pill, followed by 8.9+ ppg mud to displace seawater. 5 BPM, 300 si. 01:30 02:00 0.50 COMPZ RPCOti TRIP P POH 1 stand. Blow down top drive. 02:00 03:30 1.50 COMPZ RPCOh OTHR P PU & MU 7" test joint in 4" DP string. Close 7" pipe rams. Test rams, casing, & K-1 bridge plug to 300 psi for 10 min, and stage up to 3000 psi for 15 min, OK. 03:30. 04:00 0.50 COMPZ RPCOh RURD P Blow down & rig down test equipment. LD 7" test 'oint. 04:00 05:00 1.00 COMPZ RIGMN SVRG P Service rig. 05:00 07:00 2.00 COMPZ RPCOh TRIP P POH. LD Baker setting tool 07:00 08:00 1.00 COMPZ RPCOti RURD P Load 5" DC and Baker tools for cutting casin . 08:00 11:00 3.00 COMPZ RPCOh TRIP P MU casing cutter BHA. RIH to 4188'. MU top drive, circulate slow, & locate casing collar. Blow down top drive, stand back 1 stand. 11:00 12:00 1.00 COMPZ RIGMN OTHR T Trouble shoot top drive. 12:00 12:30 0.50 COMPZ RPCOti OTHR P Break circulation rotating w/ top drive and cut casing at 4214' MD. Good indications on um of cut. 12:30 13:30 1.00 COMPZ RPCOh CIRC P RU lines and attempt to circulate out 7" x 9-5/8"annulus. Pressured up, no o. 13:30 16:30 3.00 COMPZ RPCOh TRIP P POOH. Change knives in casing cutter. Old knives showed proper wear for a cut. ~~ ~~ge 3 Lf 2~ T~n~e Lis Date From To Dur e th E. Depth Phase Code Subcode T COM _ _ 04/27/2006 16:30 17:00 0.50 COMPZ RPCOh OTHR P Bring in casing handling tools. 17:00 18:30 1.50 COMPZ RPCOh TRIP P RIH with casing cutter. Locate coupling at 4151'. PU 2' and cut casing at 4149' MD. Good indications on um of cut. 18:30 20:00 .1.50 COMPZ RPCOh CIRC P Circulate in 7" casing while rigging up lines. Close bag and attempt to circulate out 7" x 9-5/8" annulus. Pump 1.1 BPM, 16 SPM, 1250 psi getting small stream of returns from OA. A rox 10% returns. 20:00 20:30 0.50 COMPZ RPCOh OWFF P Monitor well for flowback. 20:30 23:00 2.50 COMPZ RPCOh TRIP P POH. LD casing cutter assy. 23:00 00:00 1.00 COMPZ RPCOh TRIP P Bring in casing spear tools. MU 7" casin sear with ackoff. 04/28/2006 00:00 02:00 2.00 COMPZ RPCOh OTHR P Finish MU 7" casing spear assy on a joint of 4" DP. MU-head pin & hose. RIH & spear casing in first joint below casing hanger. BOLDS. Pull up in stages to 250K# and hold, got about 1-1/2" of stretch. Slack off to 150K# and break circulation, 1.5 BPM, 1200 psi. PU to 175k# and pipe pulled free, pressure dropped to 70 psi, full retums. Pull 7" hanger above rig floor, circulate at 3 BPM, 200 psi. 120K# PU, 75K# SO, 35K# Block Wt. 02:00 03:00 1.00 COMPZ RPCOh CIRC P CBU displacing diesel, water, and spoiled mud from annulus outside 7". Circulated another bottoms up to clean up hole. Worked casing ~5' a few times, movin (reel . 03:00 04:30 1.50 COMPZ RPCOh PULD P Break out & LD casing spear assy. Clean and remove Baker fishing tools. RU casin sli s & elevators. 04:30 09:30 5.00 COMPZ RPCOti PULD P PJSM with GBR. POH laying down 7" casin .Recovered 102 'oints. 09:30 11:30 2.00 COMPZ RPCOti RURD P RD GBR. Remove casing from pipe shed. Tally 3-1/2" tubing in derrick. RU tubin ton s. 11:30 13:30 2.00 COMPZ RPCOh TRIP P RIH with 11 stands of 3-1/2" tubing stin er. RIH with DP. 13:30 16:00 2.50 COMPZ RPCOh CIRC P RU to circulate, tag bridge plug at 4423'. Circulate to clean up hole for cementin , 6 BPM, 350 si. 16:00 17:00 1.00 COMPZ RPCOh OTHR P RU to cement. PJSM with Dowell and rig crew. Dowell pump 10 Bbls water ahead, followed by 43 Bbls of 17.0 ppg Class G Cement (+0.2% D46, 1.0% D65, 0.2% D167, 0.1% S002.), chase with 3 Bbls water. Switch to rig pump and pump 32 Bbls mud to spot balanced lu . Page ~, mf 29 Time Logs I Date From To Dur ~ e th E. De~th_ Phase Code__ Subcode T COM 04/28/2006 17:00 18:00 1.00 COMPZ RPCOti TRIP P POH 10 stands, slow. 18:00 19:00 1.00 COMPZ RPCOh CIRC P Circulate to clean out DP, stinger, and hole, 6 BPM, 330 si. 19:00 19:30 0.50 COMPZ RPCOh OTHR P Install Super Sliders on bottom of DP stands in derrick. 19:30 22:00 2.50 COMPZ RPCOh TRIP P POH installing a Super Slider near the bottom of each 'oint of DP. 22:00 00:00 2.00 COMPZ RPCOh PULD P RU tubing tongs. Continue POH LD 3-1/2" tubin stin er. 04/29/2006 00:00 07:00 7.00 COMPZ RPCOti NUND P Change lower pipe rams from 7" to 4". ND BOPE, install 2' drilling spool, NU BOPE. 07:00 10:00 3.00 COMPZ RPCOh OTHR P Load BHA & subs in pipe shed. Change liners in mud pumps from 5-1/2" to 5". 10:00 15:00 5.00 COMPZ RPCOh PULD P PU and stand back 4" DP. 15:00 19:00 4.00 COMPZ RPCOh OTHR P Rack & tally 7" casing in pipe shed. 19:00 22:30 3.50 COMPZ RPCOh OTHR P Test BOPE: Blind rams, upper and lower pipe rams, annular, spools to 300 psi & 3500 psi. Choke & kill lines and valves, choke manifold, floor safety valves, top drive valves to 300 psi & 3500 psi. Accumulator capacity test, OK. Witnessing of test waived by Lou Grimaldi, AOGCC Field Ins ector. 22:30 23:00 0.50 COMPZ RPCOI~ OTHR P Continue rack & tally 7" casing. 23:00 00:00 1.00 COMPZ RPCOh DHEQ P RU & test 9-5/8" surface casing against blind rams. 3000 psi for 30 minutes, lost 150 psi, good test. Continue rack & tally 7" casing while testin 04/30/2006 00:00 06:30 6.50 COMPZ RPCOh OTHR P Continue rack & tally 7" casing, drift same. 06:30 08:00 1.50 COMPZ RIGMN SVRG P Slip & cut 42' of drilling line. Check crown-o-matic. 08:00 15:00 7.00 COMPZ RPCOh PULD P PU & MU BHA. Download MWD tools and shallow test. 15:00 16:00 1.00 COMPZ RPCOh TRIP P RIH PU DP. 16:00 16:30 0.50 COMPZ RIGMN SVRG P Service rig. 16:30 18:30 2.00 COMPZ RPCOh TRIP P Continue RIH PU DP. 18:30 23:00 4.50 COMPZ RPCOti OTHR P Tag cement at 3696'. Clean out firm to hard cement to 9-5/8" shoe at 4040'. -- Pa~g~ ~ of 29 Time Logs __ _ ---- _ Date From To Dur e th E. De th Phase Code Subcode T CQM 04/30/2006 23:00 00:00 1.00 4,040 4,090 INTRM1 STK KOST P Drill. below shoe & orient motor to low side. Drill on low side to 4090' MD (2627' TVD) to start sidetrack. 110 K# \ ~ © ~ _~ P11, 62K# SO, 80K# Rot. Wt., 35K# ''~'~` Blocks. 8K# WOB, 133 Motor RPM, 165 SPM, 400 GPM, 5150 ft-Ib Torque 2~a~ ®~ on btm, 4800 ft-Ib Torque off btm, 1280 si on btm, 1180 si off btm. 05/01/2006 00:00 01:00 1.00 4,090 4,090 INTRM1 STK CIRC P . Circulate & condition mud and hole for LOT/FIT. Mud 9.0 in & out. 01:00 02:00 1.00 4,090 4,090 INTRM1 STK OTHR P Blow down top drive. Stand back 1 stand. RU lines to pump down DP & annulus. Close pipe rams. Pressure up at 6 SPM, 0.35 BPM and do Leak-Off Test. Formation leak-off at 640 psi w/ 9.0 ppg mud, 13.7 ppg EMW. Shoe at 4040' MD, 2606' TVD. 02:00 02:30 0.50 4,090 4,090 INTRM1 STK OTHR P Bleed off pressure. Open rams. Blow down & ri down hoses. 02:30 12:00 9.50 4,090 4,426 INTRM1 DRILL KOST P Orient motor down to low side and continue sliding from 4090' to 4155'. Continue drill & slide to 4426' MD, 2804' TVD. 12:00 00:00 12.00 4,426 5,318 INTRMI DRILL DDRL P Continue directionally drilling 8-112" hole to 5318' MD, 3321' TVD, and drilling ahead. Pump sweeps as needed to kee hole clean. 05/02/2006 00:00 12:00 12.00 5,318 5,757 INTRM1 DRILL DRLG P Cont directionally drilling 8 112" hole per directional plan from 5,318' MD to 5,757' MD/3,577' TVD (439'), ART 8.25 hrs, AST .50 hrs, ADT 8.75 hrs, 5-38K on bit, 80 rpm's, 210 spm, 514 gpm, off btm pressure 2,420 psi, on btm pressure 2,280 psi, off btm torque 5,775 ft/Ibs, on btm torque 7,300 ft/Ibs, rot wt 90K, up wt 150K, dwn wt 70K, g.2+ ppg LSND MW, ave ECD 10.3 12:00 00:00 12.00 5,757 6,463 INTRM1 DRILL DRLG P Cont directionally drilling 8 1/2" hole per directional plan from 5,757' MD to 6,463' MD/3,983' TVD (706'), ART 7.92 hrs, AST .86 hrs, ADT 8.78 hrs, 10K on bit, 80 rpm's, 210 spm, 510 gpm, off btm pressure 2,180 psi, on btm pressure 2,400 psi, off btm torque 8,600 ft/Ibs, on btm torque 8,300 ft/Ibs, rot wt 97K, up wt 165K, dwn wt 73K, 9.1+ppg LSND MW, ave ECD at 10.3 05/03/2006 00:00 01:00 1.00 6,463 6,518- INTRM1 DRILL DRLG P Directionally drill 8 1/2" hole from 6,463' MD to 6,518' MD/4,011' TVD 55' . 01:00 01:30 0.50 6,518 6,518 I NTRMI DRILL OTHR T Riser boot leaking. Worked pipe and Chan ed out to riser boot. Nos ills. - - -- P~ge ~ of 23 Time Logs Date From To Dur th E. Depth Phase Code Subcode 'OM 05/03/2006 01:30 12:00 10.50 6,518 7,343 INTRM1 DRILL DRLG P Cont directionally drilling 8 1/2" hole from 6,518' MD to 7,343' MD/4,499' TVD (825'), ART 7.27 hrs, AST .97 hrs, ADT 8.24 hrs, 5-22K on bit, 80 rpm's, 210 spm, 514 gpm, off btm pressure 2,160 psi, on btm pressure 2,320 psi, off btm torque 8,675 fUlbs, on btm torque 8,880 ft/Ibs, rot wt 103K, up wt 180K, dwn wt 78K, 9.1 ppg LSND MW, ave ECD at 10.3 12:00 14:00 2.00 7,343 7,470 INTRM1 DRILL DRLG P Directionally drill 8 1/2" hole from 7,343' MD to 7,470' MD/4,575 TVD 127' . 14:00 15:00 1.00 7,470 7,470 INTRM1 DRILL CIRC P Pump Hi-Wt Hi-Vis sweep and circ hole clean at 208 s m, 2,050 si. 15:00 19:00 4.00 7,470 4,040 INTRM1 DRILL WPRT P POOH from 7,470' to shoe at 4,040', wet on elevators with no roblem. 19:00 20:30 1.50 4,040 4,040 INTRM1 DRILL OTHR P Slip and cut drill line while monitoring hole. 20:30 22:00 1.50 4,040 7,470 INTRM1 DRILL WPRT P RIH from 4,040' to 7,470' with no roblem. 22:00 00:00 2.00 7,470 7,586 INTRM1 DRILL DRLG P Cont directionally drilling 8 1/2" hole from 7,470' MD to 7,586' MD/4,646' ND (116'), ART 1.67 hrs, AST .82 hrs, ADT 2.49 hrs, 20K on bit, 80 rpm's, 207 spm, 510 gpm, off btm pressure 2,220 psi, on btm pressure 2,460 psi, off btm torque 9,700 fUlbs, on btm torque 7,800 ft/Ibs, rot wt 107K, up wt 175K, dwn wt 80K, 9.2+ ppg LSND MW, ave ECD at 10.3 05/04/2006 00:00 12:00 12.00 7,586 8,264 INTRM1 DRILL DRLG P Cont directionally drilling 8 1/2" hole from 7,586' MD to 8,264' MD/5,038' TVD (678'), ART 5.56 hrs, AST 2.84 hrs, ADT 8.40 hrs, 20-34K on bit, 80 rpm's, 210 spm, 514 gpm, off btm pressure 2,430 psi, on btm pressure 2,790 psi, off btm torque 9,220 ft/Ibs, on btm torque 9,010 ft/Ibs, rot wt 113K, up wt 183K, dwn wt 83K, 9.2 LSND MW, ave ECD at 10.4 ppg, max as 40 units. 12:00 00:00 12.00 8,264 8,830 INTRMI DRILL DRLG P Cont directionally drilling 8 1/2" hole from 8,264' MD to 8,830' MD/5,345' TVD (566'), ART 3.92 hrs, AST 5.43 hrs, ADT 9.35 hrs, 15-20K on bit, 80 rpm's, 200 spm, 490 gpm, off btm pressure 3,300 psi, on btm pressure 3,230 psi, off btm torque 9,800 ft/Ibs, on btm torque 10,700 ft/Ibs, rot wt 107K, up wt 185K, dwn wt 83K, increased mud wt 1/10th per circ from 9.6 ppg to 10.3+, ave ECD at 11.2 max as 293 units. _.~ age 7 ~~ .'~. Time Logs ~ -~ Date From To Dur th E. De th Phase Code Subcode QM 05/05/2006 00:00 12:00 12.00 8,830 9,276 INTRM1 DRILL DRLG P Cont directionally drilling 8 1/2" hole from 8,830' MD to 9,276' MD/5,553' TVD (446'), ART 4.02 hrs, AST 4.84 hrs, ADT 8.86 hrs, 18-22K on bit, 80 rpm's, 196 spm, 480 gpm, off btm pressure 3,210 psi, on btm pressure 3,500 psi, off btm torque 7,580 ft/Ibs, on btm torque 9,224 ft/Ibs, rot wt 120K, up wt 185K, dwn wt 87K, 10.6 LSND MW, ave ECD at 11.3 ppg, max as 123 units. 12:00 19:00 7.00 9,276 9,477 INTRM1 DRILL DRLG P Directionally drill 8 1/2" hole from 9,276' MD 9,477' MD/5,642' TVD (201'), getting intermediate pulsing from MWD. 19:00 20:00 1.00 9,382 9,382. INTRMI DRILL CIRC P Rack back 1 stnd, pump 25 bbl Hi-Vis sweep, rot and recip pipe, tool pulsing normal after sweep cleared bit, RIH 1 stnd. 20:00 00:00 4.00 9,477 9,655 INTRM1 DRILL DRLG P Cont directionally drilling 8 1/2" hole from 9,477" MD to 9,655' MD/5,704' TVD (178'), ART 3.47 hrs, AST 4.04 hrs, ADT 7.51 hrs, 15-25K on bit, 80 rpm's, 196 spm, 480 gpm, off btm presure 3,140 psi, on btm pressure 3,340 psi, off btm torque 7.600 ft/Ibs, on btm torque 8,900 ft/Ibs, rot wt 110K, up wt 185K, dwn wt 85K, 10.6 LSND MW, ave ECD at 11.5 ppg, max as 223 units. 05/06/2006 00:00 12:00 12.00 10,062 10,347 INTRM1 DRILL DRLG P Cont directional drilling 8 1/2" hole from 10,062' MD to 10,347' MD/5,841' TVD (285'), ART 6.94 hrs, AST 2.90 hrs, ADT 9.84 hrs, 15-30K on bit, 80 rpm's, 200 spm, 485 gpm, off btm pressure 3,400 psi, on btm pressure 3,540 psi, off btm torque 8,600 ft/Ibs, on btm torque 9,500 ft/Ibs, rot wt 107K, up wt 190K, dwn wt 80K, 10.6 LSND MW, ave ECD at 11.3 ppg, max as 76 units. 12:00 00:00 12.00 9,655 10,062 INTRM1 DRILL DRLG P Cont directional drilling 8 1/2" hole from 9,655' MD to 10,062' MD/5,805' TVD (407'), ART 4.09 hrs, AST 4.78 hrs, ADT 8.87 hrs, 20-28K on bit, 80 rpm's, 196 spm, 484 gpm, off btm pressure 3,260 psi, on btm pressure 3,590 psi, off btm torque 8,230 ft/Ibs, on btm torque 9,990 ftnbs, rot wt 120K, up wt 187K, dwn wt 87K, 10.6 LSND MW, ave ECD at 11.5 ppg, max as 137 units. ~~ ~ ~ _.. ~ ~ P~~ f 9 ~ . e . Time dogs Date From To Dur th E. De th Phase Code Subcode OM ,_ 05/07/2006 00:00 03:45 3.75 10,347 10,491 INTRM1 DRILL DRLG P Cont directiinally drilling 8 1/2" hole from 10,347' MD to 10,491' MD/5,851' TVD (144'), ART 2.29 hrs, AST .42 hrs, ADT 2.71 hrs, 10-25K on bit, 80 rpm's, 188 spm, 465 gpm, off btm pressure 3,240 psi, on btm pressure 3,420 psi, off btm torque 9,500 ft/Ibs, on btm torque 11,200 ft/Ibs, rot wt 115K, up wt 187K, dwn wt 80K, 10.6 LSND MW, ave ECD at 11.4 ppg, max gas 286 units. 03:45 05:45 2.00 10,491 10,491 INTRM1 DRILL CIRC P Survey and pump 30 bbl Hi-Vis Super Sweep at 480 gpm, 3,525 psi, 95 rpm, CBU 2x, as dwn to 37 units. 05:45 06:00 0.25 10,491 10,491 INTRM1 DRILL OWFF P Blow dwn Top Drive and monitor well, well static. 06:00 10:00 4.00 10,491 7,349 INTRM1 DRILL WPRT P POH wet on elevators from 10,491' to 7,349' with no roblem. 10:00 11:30 1.50 7,349 10,491 INTRM1 DRILL WPRT P RIH from 7,349' to 10,491' with no roblem and no fill. 11:30 13:30 2.00 10,491 10,491 INTRM1 DRILL CIRC P Pump 30 bbl Super Sweep at 480 gpm, 3,370 psi, 95 rpm, CBU 2x, max as 25 units. 13:30 13:45 0.25 10,491 10,491 INTRMI DRILL OWFF P Blow dwn Top Drive and monitor well, well static. 13:45 23:00 9.25 10,491 43 INTRM1 DRILL TRIP P POOH wet on elevators with no roblem, hole takin ro er fill. 23:00 00:00 1.00 43 43 INTRM1 DRILL SRVY P RU and dwn load MWD. 05/08/2006 00:00 01:30 1.50 43 0 INTRM1 DRILL PULD P LD 8 1/2" Intermediate BHA. 01:30 02:00 0.50 0 0 INTRMI DRILL RURD P Drain stack, RU and pull wear ring. 02:00 03:30 1.50 0 0 INTRMI WELCT OTHR P Change out lower rams to 7". 03:30 04:30 1.00 0 0 INTRM1 WELCT BOPE P RU and test lower rams at 250 and 3,000 si. Test OK. 04:30 06:00 1.50 0 0 INTRM1 RIGMN SVRG P Slip and Cut drill line. 06:00 08:30 2.50 0 0 INTRM1 CASIN( RURD P Unload 8 1/2" BHA from pipeshed and RU to run 7" casin . 08:30 23:30 15.00 0 10,471 INTRM1 CASIN( RNCS P PU and RIH 260jnts 7" 26# BTC casing to set depth of 10,471' MD. CBU at 3,212' and 7,400' at 3 bpm and had full returns. No pr RiH; but tort mourns of pipe displacement at 8,400'. 23:30 00:00 0.50 10,471 10,471 INTRM1 CASIN( RURD P RD fill up tool, RU Dowell cement head. 05/09/2006 00:00 09:00 9.00 10,471 10,471 INTRM1 CEMEf~ CIRC P Circ and cond mud for cementing, mixed and pumped 100 bbl LCM pill. Circ at 1 bpm at 300 psi. Increased rate to 1.5 bpm at 480 psi, as return rate increased. Held PJSM with Dowell re 's and ri crew on cement 'ob. m ..._ ~~ ~~~ 9 r~fi 23 Time Logs f Date From To Dur . _ e th E. De th Phase Code Subcode T „OM 05/09/2006 09:00 09:45 0.75 10,471 10,471 INTRM1 CEMEI~ DISP P Turn over to Dowell and pumped 10 bbls CW100, tested lines to 3,500 psi, pumped an additional 20 bbls CW100 and 40 bbls MudPush at 12.5 ppg, dropped btm plug mixed and pumped 43 bbls (217 sx) 15.8 ppg, 1.16 yeild, Class "G" cement with 1/4 ppsx CelloFlake at an ave 4.7 bpm and ave 850 psi., L ire recip; wh+~ cite and cond mud, dr lu . 09:45 11:15 1.50 10,471 10,471 INTRM1 CEME~ DISP P Dowell pumped 20 bbls fw and turned over to rig. Rig pumped 377 bbls of 10.6 ppg LSND mud at an ave of 5 bpm ,initial pressure was 450 psi, pressure increased to 770 psi after 370 bbls with 31 % return flow, slowed pump to 2.5 bpm at 550 psi, pumped calculated stks plus 1/2 of shoe track and plug did not bump, shut down with CIP at 11:15, checked floats and floats holding. Cale TOC is at 9,471'r:he~t apprr~t.9Q-15°le~ dt~r~ cement job yr 32~ pai ' in pump resc~+~s ccrrrerrt 'ob 11:15 11:30 0.25 10,471 10,471 INTRM1 CEME~ OTHR P Monitored well and had slight breathing, gained 1.75 bbls in 10 min, shut in well. 11:30 16:00 4.50 10,471 10,471 INTRM1 CEMEf~ WOC P WOC with well shut in, press built to 60 psi and bled to zero after 3 hrs, finished rack and tally 4" DP in shed, RD kelly hose from goose neck on stnd i e for Anadril Perisco a sensor. 16:00 17:00 1.00 10,471 10,471 INTRM1 CEMEI~ RURD P RD cement head and open well at 16:30 with 0 psi and well static. LD landin 'nt and drained stack. 17:00 18:30 1.50 10,471 10,471 INTRM1 WELCT EQRP P Installed FMC 7" pack-off and tested seals to 5,000 si for 15 min, test OK. 18:30 21:00 2.50 10,471 10,471 INTRM1 DRILL RURD P Blow dwn cite lines, RU Periscope sensor on stand pipe and re-install kell hose. 21:00 23:00 2.00 10,471 10,471 INTRM1 DRILL PULD P RU handling equipment and spinners, LD 5 stnds 5" HWDP from derrick. 23:00 00:00 1.00 10,471 10,471 INTRM1 DRILL OTHR P Off load casing equipment, rack and tall 4" HWDP and 4 3/4" DC's. 05/10/2006 00:00 02:00 2.00 0 0 INTRM1 DRILL OTHR P Fin unloading 5" HWDP from pipeshed and loaded 6 1/8" BHA #2 into i eshed 02:00 03:00 1.00 0 0 INTRM1 WELCT EQRP P Changed out lower set of pipe rams from 7" cs back to 4" DP age 1~ ~t ~ ~~,. ~. .._ Time Logs Date From To Dur th E. De th .Phase Code Subcode OM 05/10/2006 03:00 08:00 5.00 0 0 INTRM1 WELCT BOPE P RU and tested BOPE, rams, valves and manifold to 250 psi low and 3,500 psi high including annular preventer. Performed Koomey test, initial pressure 3,000 psi, after closure pressure was down to 1,900 psi, took 18 seconds to achieve 200 psi, full pressure attained in 1 min 24 seconds, 4 nitrogen bottles ave 1,900 psi. NOTE: Jeff Jones with AOGCC waived witnessin of test. 08:00 09:00 1.00 0 0 INTRM1 DRILL OTHR P Pulled test plug and installed wear bushin 09:00 11:00 2.00 0 0 INTRM1 RIGMN SVRG P Changed out 4" XT-39 saver sub on top drive and serviced same, calibrated top drive and block height for Schlumber er MWD 11:00 11:15 0.25 0 0 INTRM1 DRILL SFTY P Held PJSM with Schlumberger MWD, directional driller and rig crew on picking up and making up of 6 1/8" Perisco a BHA #2 11:15 15:30 4.25 0 243 INTRM1 DRILL PULD P MU 6 1/8" Periscope BHA #2, shallow test MWD, MU nuke subs and install sources, PU NM flex collars, jars and test MWD connection. 15:30 17:30 2.00 243 1,300 INTRM1 DRILL PULD P PU 4" DP from pipeshed and RIH to to 1, 300' 17:30 18:00 0.50 1,300 1,300 INTRM1 DRILL DHEO P MU Top Drive and test MWD tools, blow dwn To Drive. 18:00 22:00 4.00 1,300 4,670 INTRM1 DRILL PULD P Cont PU 4" DP from pipeshed and RIH to 4,670' 22:00 23:00 1.00 4,670 5,800 INTRM1 DRILL TRIP P Cont RIH with 4" DP from derrick to 5.800' 23:00 23:30 0.50 5,800 5,800 INTRM1 DRILL CIRC P RU and fill pipe, 68 spm, 690 psi 23:30 00:00 0.50 5,800 7,236 INTRM1 DRILL TRIP P Cont RIH with 4" Dp from derrick to 7,236', u wt 160K, dwn wt 70K 05/11/2006 00:00 01:30 1.50 7,236 8,852 INTRM1 DRILL TRIP P Cont RIH with 6 1/8" BHA #2 with DP out of derrick from 7,236' to 8,852' 01:30 05:30 4.00 8,852 8,852 INTRM1 DRILL PULD P PU &RIH with 21 jts (7 stds) of 4" HWDP, Then PU &RIH with 7 stds of hybrid push pipe, (2-4 3/4" DC's & 1 HWDP POOH and stood back same 05:30 07:00 1.50 8,852 10,322 INTRM1 DRILL TRIP P Cont RIH with BHA #2 from 8,852 and tagged cement at 10,322' (Flt Collar 10,385' 07:00 08:30 1.50 10,322 10,322 INTRM1 DRILL CIRC P Circ hole evening MW in and out at 10.6 ppg for csg test, circ at 101 spm, 200 gpm at 1,600 psi, st wt up 215K, do wt 80K. 08:30 09:30 1.00 10,322 10,322 INTRM1 CASIN( DHEQ P RU and tested 7" csg at 10,322' to 3,500 si for 15 min and ck ok. ® ~ ~ ~ ®. ~ _-~___...~ ~ .~ ._._ .~. ~~g~ 11 of ~~ Time Logs ~ ~~ Date From To Dur ~~th E. De th Phase Code Subcode T OM 05/11/2006 09:30 11:45 2.25 10,322 10,365 INTRM1 CEMEt~ COCF P Drilled out cement from 10,322' to 10,365' (20' above FC @ 10,385') Drilled with 10-12K wob, 80 rpm's, circ at 220 gpm at 1,750 psi, rot wt 110K, up wt 215K, do wt 80K, off btm torque 11,000 ft-Ibs, on btm 11,980 ft-Ibs. 11:45 12:30 0.75 10,365 10,365 INTRM1 CASIN( CIRC P Circ btms up at 10,365' for csg test, circ at 110 spm, 220 gpm at 1,750 psi with 10.5 MW in and out. 12:30 14:30 2.00 10,365 10,365 INTRM1 CASIN( DHEO P Stood back 1 std then RU and tested 7" csg at 10,365' to 3,500 psi for 30 min, ood test. 14:30 20:00 5.50 10,365 10,511 INTRM1 CEME~ DRLG P Drilled out plugs, float collar at 10,385', shoe track and float shoe at 10,471', then cleaned out 20' to btm at 10,491'. Then drilled 20' of new formation to 10,511' MD/5,852' TVD, drilled out cmt at 10K wob, 80 rpm's, 122 spm, 240 m at 2,170 si 20:00 00:00 4.00 10,511 10,511 INTRM1 CEME~ CIRC P Circ hole clean at 10,511', pumped 30 bbl low dens sweep followed by 30 bbl 12.5 ppg weighted sweep, circ hole clean and pumped a 30 bbl water spacer followed by a 30 bbl Hi-Vis Flo-Pro spacer, displaced hole over to 10.5 ppg, Naar Flo-Pro mud at 257 gpm, 2,290 psi, ADT .77 hrs, up wt 230K, dwn wt 70K, rot wt 110K. 05/12/2006 00:00 09:00 9.00 10,511 10,511 PROD1 DRILL OTHR P Cleaned out trip tank, flowline, shakers, mud pits and mud pump suctions preparing to take on Naar Flo Pro mud 09:00 12:00 3.00 10,511 10,511 PROD1 DRILL CIRC P Took on 125 bbls of new 10.4 ppg Naar Flow Pro mud and circ thru hole to shear same, added Lubetex for 1 1/2 to 2% lubricant into mud while circ hole, circ at 121 spm, 240 gpm 2,100 si, ECD while circ hole 11.6 12:00 13:00 1.00 10,511 10,511 PROD1 DRILL LOT P RU and performed LOT to 13.6 ppg EMW, began leaking off at 960 psi, at 5,850' TVD with 10.4 ppg MW, did not um 3 bbls after leak off. 13:00 15:30 2.50 10,511 10,511 PROD1 DRILL WOEQ NP Cont to circ hole shearing new mud while waiting on additional mud to arrive rig, Schlumberger est flow rates for rotary steerable tool and est clean hole ECD with 10.4 ppg Flo-Pro at 11.85 ppg at 80 and 120 rpm's at 250 m, took SPR's. m~ ~e ~1~ cif .~ _ _. ~ ~~ . ~.m ~_ e ~ Time Logs _ Date From To Dur th E. De th Phase Code Subcode OM 05/12/2006 15:30 00:00 8.50 10,511 10,786 PROD1 DRILL DDRL P Directionally drilled 6 1/8" hole with Schlumberger rotary steerable and Periscope drilling system, drilled from 10,511' MD to 10,786' MD/5,862' TVD (275'), ADT 6.12 hrs, 10K wob, 100 rpm's, 124 spm, 250 gpm, off btm pressure 2,300 psi, on btm pressure 2,320 psi, off btm torque 7,800 fUlbs, on btm torque 10,000 ft/Ibs, rot wt 110K, up wt 150K, dwn wt 83K, 10.5 ppg Naar Flo-Pro MW, ave ECD at 11.8 ppg with 2.5% Lubetex, ave 150 units and max as 350 units. 05/13/2006 00:00 12:00 12.00 10,786 11,213 PROD1 DRILL DDRL P Directionally drilled 6 1/8" hole with Schlumberger rotary steerable and Periscope drilling system, drilled from 10,786' to 11,213' MD/5,860' TVD (427'), ADT 8.35 hrs, 5-15K wob, 100 rpm's, 125 spm, 248 gpm, off btm pressure 2,400 psi, on btm pressure 2,423 psi, off btm torque 10,500 ft/Ibs, on btm torque 12,900 ft/Ibs, rot wt 110K, up wt 160K, dwn wt 75K, 10.6 ppg Naar Flo-Pro MW, ave ECD at 12.3 ppg with 2.5% Lubetex, ave BGG 200 units and max gas 766 units. Drlg thru numerous Sidetrite stringers. Sim-Ops: Flushed 7" x 9 5/8" Annulus with 200 bbls fresh water and freeze rotected with 60 bbls diesel. 12:00 00:00 12.00 11,213 11,455 PROD1 DRILL DDRL P Directionally drilled 6 1/8" hole with Schlumberger rotary steerable and Periscope drilling system, drilled from 11,213' to 11,455' MD/5,850' TVD (242'), ADT 10.87 hrs, 10-15K wob, 100 rpm's, 125 spm, 250 gpm, off btm pressure 2,350 psi, on btm pressure 2,380 psi, off btm torque 10,800 ft/Ibs, on btm torque 13,800 ft/Ibs, rot wt 105K, up wt 155K, dwn wt 75K, 10.6 ppg Naar Flo-Pro MW, ave ECD at 12.8 ppg, increasing lubricants to 3% (Lubetex), ave BGG 200 units and max gas 632 units. Cont drlg through Sidetrite stringers, crossed fault at 11,395' MD with no fluid loss. _ ~ ~~®m ~~~ge 1~ oaf Time Logs -~ ,~ Date From To Dur mss; th E. De th Phase Code Subcode UM 05/14/2006 00:00 12:00 12.00 11,455 11,660 PROD1 DRILL DDRL P Directionally drilled 6 1/8" hole with Schlumberger rotary steerable and Periscope drilling system, drilled from 11,455' to 11,660' MD/5,857' TVD (205'), ADT 8.95 hrs, 10-15K wob, 100 rpm's, 124 spm, 246 gpm, off btm pressure 2,370 psi, on btm pressure 2,400 psi, off btm torque 7,850 ft/Ibs, on btm torque 11,760 ft/Ibs, rot wt 107K, up wt 157K, do wt 77K, 10.7 ppg Naar Flo-Pro MW, ave ECD at 12.73 ppg, 3% Lubricants (Lubetex), ave BGG 50 units and max gas 800 units. P-rate slow while drlg, seeing some siderite stringers but P-rate down from previous stringers, ave 18'/hr ast few hrs 12:00 12:45 0.75 11,660 11,660 PROD1 DRILL CIRC NP Circ btms up during crew change and while preparing pipe rack for trip out, circ at 250 gpm, 2,480 psi and 100 r ms with 8,000 ft-Ibs off btm for ue 12:45 15:00 2.25 11,660 10,471 PROD1 DRILL REAM NP Monitored well-static, backreamed out of hole from 11,660' to 7" csg shoe at 10,471 with no problems, BROOH at 90 r m's, 240 mat 2,100 si 15:00 16:00 1.00 10,471 10,471 PROD1 DRILL CIRC NP Circ btms up at 10,741, circ at 124 spm, 247 gpm at 2,140 psi, 40 rpm's 6,100 ft-Ibs torque, rot wt 110K, up wt 150K, do wt 85K, 10.7 ppg MW, ECD was 12.1 16:00 16:15 0.25 10,471 10,471 PROD1 DRILL OWFF NP Monitored well-Static 16:15 22:15 6.00 10,471 243 PROD1 DRILL TRIP NP POOH from 10,471' to BHA @ 243', taking up/down wts every 10 stnds, Calc hole fill was 59 bbls, actual fill was 74 bbls, hole took 13 bbls over calculated fill. 22:15 00:00 1.75 243 0 PROD1 DRILL PULD NP LD jars, stnd back flex collars, PJSM and remove nukes, LD bit. 05/15/2006 00:00 04:00 4.00 0 245 PROD1 DRILL PULD NP MU 6 1/8" BHA #3 RIH to 245', changed out rotary steerable assembly, MU new bit #3 and surface tested RSS, MU ADN, held PJSM then loaded radioactive sources, RIH with NMFDC's and jars RIH to 245' Installed corrosion rin 04:00 09:00 5.00 245 10,439 PROD1 DRILL TRIP NP RIH with BHA #3 from 245' to above 7" csg shoe to 10,439', st wt up 163K, do 87K 09:00 11:45 2.75 10,439 10,439 PROD1 RIGMN SVRG P Slip and cut 47' of drlg line, serviced to drive 11:45 12:00 0.25 10,439 10,960 PROD1 DRILL TRIP NP RIH from 10,439' and sat down at 10,960' 12:00 12:30 0.50 10,960 11,290 PROD1 DRILL REAM NP Washed down thru spot at 10,960', then RIH 2 stds and set down again 11,290' ~m Te ~ ~~ ~ # ~~ Time Lo s Date .From To Dur th E. De th Phase Code Subcode OM 05/15/2006 12:30 13:30 1.00 11,290 11,515 PROD1 DRILL REAM NP Washed down from 11,290'to 11,515' when washing down at 200 gpm, 1800 psi and prior to getting a btms up, the ECD's began climbed to 13.4 ppg, slowed pump rate to 105 gpm at 730 psi, had large amount of CaCo going over shakers, appeared CaCo had greased out with the Lubetex and ran over the shakers, screened down and cunt to circ hole and monitored returns, staged pump rate up to 190 gpm at 1,570 psi and ECD's were down to 12.04 ppg, MW in and out at 10.5 with full returns. 13:30 14:45 1.25 11,515 11,660 PROD1 DRILL REAM P Cont to wash down from 11,515'to btm at 11,660' with no problems, washed down at 105 gpm at 700 psi and 70 rpm's, staged pump rate up to 190 gpm at 1,600 psi, and had a 12.08 ppg ECD, increased pump rate to 250 gpm at 2,370 psi with a ECD of 12.41 ppg and no losses, rot wt 105K, up wt 150K, do wt 75K, 80 rpm's with 8,900 ft-Ibs off btm for ue, took SPR's. 14:45 00:00 9.25 11,660 11,854 PROD1 DRILL DRLG P Cont directionally drilling 6 1/8" hole with Schlumberger rotary steerable and Periscope system from 11,660' MD to 11,854' MD/5,861' TVD (194'), ART 5.65 hrs, 5-12K wob, 100 rpm's, 125 spm, 250 gpm, off btm pressure 2,250 psi, on btm pressure 2,350 psi, off btm torque 9,800 ft/Ibs, on btm torque 12,000 ft/Ibs, rot wt 107K, up wt 155K, dwn wt 75K, 10.6+ Naar Flo-Pro MW, ave ECD at 12.6 ppg, 2.5% Lubricants (Lubetex) ave BGG 40 units, max gas 997 units. Note drilled out base of sand from 11,730' to 11, 780' 05/16/2006 00:00 12:00 12.00 11,854 11,992 PROD1 DRILL DDRL P Cont to directionally drill 6 1/8" hole with Schlumberger rotary steerable and Periscope system from 11,854' to 11,992' MD/5,857' TVD (138'), ADT 8.77 hrs, 10-15K wob, 96 rpm's, 127 spm, 252 gpm, off btm pressure 2,550 psi, on btm pressure 2,620 psi, off btm torque 10,000 ft/Ibs, on btm torque 12,900 ft/Ibs, rot wt 97K, up wt 160K, dwn wt 65K, 10.6 Naar Flo-Pro MW, ave ECD at 12.85 ppg, 3% Lubricants (Lubetex) ave BGG 30 units, max gas 667 units. Note: Made 9 downlinks to RSS takin a rox 2 hrs ~~ _. ...,.._ _ _ --~ ~P~ 9 o"~ Time Logs Date From To Dur th E. De th Phase Code Subcode QM _ 05!16/2006 12:00 16:45 4.75 11,992 12,017 PROD1 DRILL DDRL P Cont to directionally drill 6 1/8" hole with Schlumberger rotary steerable and Periscope system from 11,992' to 12,017 MD/5,855' TVD (25'), ADT 3.08 hrs, 10-15K wob, 96 rpm's, 125 spm, 250 gpm, off btm pressure 2,550 psi, on btm pressure 2,620 psi, off btm torque 10,000 ft/Ibs, on btm torque 12,900 ft/Ibs, rot wt 97K, up wt 160K, dwn wt 65K, 10.6 Naar Flo-Pro MW, ave ECD at 12.7 ppg, 3% Lubricants (Lubetex) ave BGG 15 units, max gas 120 units. Note: After building angle to 90 deg's, attempted to hold angle and assembly cont to build to 92.5 deg's, attempted to drop angle by downlinking tool and it would not drop, time drilled 2.25 hrs for 17 'and still would not dro an le. 16:45 20:00 3.25 12,017 10,471 PROD1 DRILL REAM T Monitored well-static, backreamed out of hole from 12,017' to 7" csg shoe at 10,471' with no problems, BROOH at 95 r m's, 240 mat 2200 si. 20:00 21:30 1.50 10,471 10,471 PROD1 DRILL CIRC T Circulate 2 bottoms up to condition mud and hole for trip out. 250 GPM, 2260 psi, 10.6+ ppg mud in & out. 145K# PU, 80K# SO, 110K# Rot. Wt. Monitor well, static. Blow down top drive. 21:30 00:00 2.50 10,471 5,619 PROD1 DRILL TRIP T POOH wet from 10,471' to 5,619' 05/17/2006 00:00 02:30 2.50 5,619 243 PROD1 DRILL TRIP T Cont POOH from 5,619' to BHA at 243' 02:30 07:15 4.75 243 0 PROD1 DRILL PULD T Heid PJSM, LD jars and stood back NMFDC's, removed radioactive sources and downloaded MWD, Fin LD BHA #3 and cleared rig floor. Calc fill on trip out of hole 59 bbls, Actual fill 72 bbls 07:15 08:45 1.50 0 0 PROD1 RIGMN SVRG P Serviced top drive, drawworks, blocks and crown 08:45 12:00 3.25 0 233 PROD1 DRILL PULD T MU 6 1/8" BHA #4 with Bit #4 ona 1.5 deg bend mud motor with Persicope logging tools, loaded radioactive sources and RIH with NMFDC's and jars to 233', shallow tested tools and ck ok 12:00 17:00 5.00 233 10,491 PROD1 DRILL TRIP T RIH with BHA #4 from 233' to 10,491', filled i e eve 25 stds. 17:00 18:00 1.00 10,491 10,491 PROD1 DRILL CIRC T Oriented motor to high side and Circ btms up at 10,491' (20' below 7" shoe) circ at 200 gpm at 2,200 psi, at 35 bbls from btms up saw greasing effect with the mud, circ till cleaned up, st wt up 170K, do wt 80K, no gas at btms u. Time Logs Date From To Dur ~ a th E. De th Phase Code Subcode OM 05/17/2006 18:00 19:30 1.50 10,491 12,017 PROD1 DRILL TRIP T Cont RIH from 10,491' to bottom at 12,017'. Washed thru spots at 10,900', 11,150' and 11,400', no other problems RIH, washed 30' to btm. WWT Rep Inspected super sliders on tri in and ck ok 19:30 00:00 4.50 12,017 12,036 PROD1 DRILL DDRL P Circulate open hole clean & survey. Orient to low side and slide to drop angle. Picking up frequently due to motor stalling from stick and slip of drillpipe. Stalling tendency decreasing as bit and motor work into their own hole. Slide from 12017' to 12036' MD, 5855' TVD. AST & ADT 0.87 hrs, 5K# WOB, 250 Motor RPM @ 240 GPM, 120 SPM, 2280 psi off btm, 2450 psi on btm, 175K# PU, 75K# SO, 107K# Rot. Wt., 9000 ft-Ib Torque off btm. 10.6 ppg Flo-Pro in & out, 3% lubricant, 12.7 ppg clean hole ECD. 125 units maximum gas at bottoms up after tri . 05/18/2006 00:00 12:00 12.00 12,036 12,156 PROD1 DRILL DDRL P Drill, Slde and survey 6 1/8" hole per directional plan and geology using Schlumbergers Periscope tool. Drilled from 12,036' to 12,156' MD/ 5,859' TVD ( 120') ART 1.68 hrs, AST 2.57 hrs, 10-15K wob, 40 rpm's, 120 spm, 240 gpm, off btm pressure 2,150 psi, on btm 2,460 psi, off btm torque 8,800 ft-Ibs, on btm 9,200 ft-Ibs, rot wt 105K, up wt 185K, do wt 70K, 10.6 ppg Naar Flo-Pro mud, ave ECD 12.9 ppg, ave BGG 20 units, max gas 223 units. Note: After sliding we are having to make a MADD pass with Periscope tool. 12:00 00:00 12.00 12,156 12,296 PROD1 DRILL DDRL P Continue drill, slide, & survey to 12,296' MD, 5861' TVD (140'). ART 0.27 hrs, AST 5.67 hrs, 10K wob, 260 RPM Motor, 40 RPM rotary, 125 spm, 250 gpm, off btm pressure 2,400 psi, on btm 2,500 psi, off btm torque 7,800 ft-Ibs, on btm 10,000 ft-Ibs, rot wt 105K, up wt 175K, do wt 70K, 10.6 ppg Naar Flo-Pro mud, ave ECD 12.9 ppg, ave BGG 35 units, max gas 400 units. Note: After sliding we are having to make a MADD pass with Periscope tool. e~~ e_ €~~~ ~ f Time Logs Date From To Dur th E. De th Phase Code Subcode T~ OM 05/19/2006 00:00 12:00 12.00 12,296 12,431 PROD1 DRILL DDRL P Continue to drill, slide, & survey 6 1/8" hole from 12,296' to 12,431' MD, 5881' TVD (135'). ART 3.23 hrs, AST 4.15 hrs, 10-15K wob, 250 RPM's Motor, 40 RPM's rotary, 121 spm, 240 gpm, off btm pressure 2,350 psi, on btm 2,460 psi, off btm torque 8,500 ft-Ibs, on btm 11,000 ft-Ibs, rot wt 105K, up wt 175K, do wt 70K, 10.6 ppg Naar Flo-Pro mud, ave ECD 12.8 ppg, ave BGG 25 units, max gas 243 units. Note: Cont to make a MADD pass with Periscope tool after slidin . 12:00 16:30 4.50 12,431 12,472 PROD1 DRILL DDRL P Continue to drill, slide, & survey 6 1/8" hole from 12,431' to 12,472' MD, 5877' TVD (41'). ART 1.47 hrs, AST 0.87 hrs, 10-15K wob, 260 RPM's Motor, 40 RPM's rotary, 125 spm, 250 gpm, off btm pressure 2,400 psi, on btm 2,650 psi, off btm torque 8,300 ft-Ibs, on btm 10,400 ft-Ibs, rot wt 105K, up wt 175K, do wt 70K, 10.6 ppg Naar Flo-Pro mud, ave ECD 12.8 ppg, ave BGG 25 units, max gas 150 units. Note: Cont to make a MADD pass with Periscope tool after sliding. Having trouble sliding and projecting angle at bit due to formation hardness and di . 16:30 20:00 3.50 12,472 10,471 PROD1 DRILL REAM P Monitored well-static, circ hole to clear BHA then backreamed out of hole from 12,472' to shoe at 10,471' with no problems, BROOH at 80 rpm's, 240 m at 2,300 si. 20:00 21:30 1.50 10,471 10,471 PROD1 DRILL CIRC P Circulate 2 bottoms up to clean hole and condition mud, 120 SPM, 240 GPM, 2100 psi. Rotate & reciprocate slowly keeping bit below shoe, 175K# Up, 80K# Dn, 110K# Rot Wt. 10.6+ ppg MW in & out. Monitor well, static. Blow down to drive. 21:30 00:00 2.50 10,471 5,132 PROD1 DRILL TRIP P POOH for rotary steerable BHA from 10,471' to 5132' at 2400 hrs. 05/20/2006 00:00 02:30 2.50 5,132 233 PROD1 DRILL TRIP P Cont to POOH from 5,132' to BHA at 233' 02:30 06:30 4.00 233 0 PROD1 DRILL PULD P LD the Jars and stood back NMFDC's, held PJSM and removed radioactivice sources, downloaded MWd and fin LD BHA #4 and cleared ri floor 06:30 07:00 0.50 0 0 PROD1 DRILL PULD P Pulled wear bushing ~ m~ .~ ~'ag~ r~~ cat ~ ~ Time Logs _ Date From To Dur ~ .. th E. De th Phase Code Subcode OM 05/20!2006 07:00 13:30 6.50 0 0 PROD1 WELCT BOPE P tnstaiied test plug, RU and tested BOP's, tested rams,valves and manifold to 250 psi low and 3,500 psi high including annular and 3 1/2" for completion. Tested Koomey, Koomey pressure before 2,850 psi, after functioning 1,950 psi, took 19 seconds to build 200 psi and 1 min 15 seconds for full recovery, have 4-nitrogen bottles ave 1,900 psi. NOTE: John Crisp with AOGCC waived witnessin of test. 13:30 14:30 1.00 0 0 PROD1 DRILL PULD P Rig down test equipment and re-installed riser. 14:30 17:00 2.50 0 230 PROD1 DRILL PULD P MU 6 1/8" BHA #5 with Bit #5 on a Schlumberger Powerdrive RSS with Persicope logging tools, loaded radioactive sources and RIH with NMFDC's and jars to 230', surface tested tools and ck ok 17:00 18:00 1.00 230 1,200 PROD1 DRILL TRIP P RIH to 1200'. Shallow test MWD tools, OK. 18:00 22:30 4.50 1,200 10,471 PROD1 DRILL TRIP P Blow down top drive. RIH to shoe at 10471', fill DP eve 25 stands. 22:30 00:00 1.50 10,471 10,471 PROD1 DRILL CIRC P MU top drive & break circulation. Rotate and reciprocate pipe keeping bit below shoe. Circulate to condition mud in casing and pits, 100 SPM to 106 SPM, 200 GPM to 212 GPM, 1800 psi to 1600 psi. Initial returns 10.4+ ppg, 12.2 ppg at bottoms up, with some CaCO3 sag evident at bottoms up. 13.0 ppg Max ECD, 11.8 ppg ECD after bottoms up. 25 units Max. Gas. Continue circulating to even out mud in hole and pits. 190K# U , 75K# - 80K# Dn, 105K# Rot Wt. 05/21/2006 00:00 03:00 3.00 10,471 10,471 PROD1 DRILL CIRC P Fin circ and cond mud at the 7" csg shoe, 10471', circ till 10.6 ppg MW in and out, circ at 212 gpm at 1,800 psi, rot wt 105K, u wt 190K, do wt 78K 03:00 05:00 2.00 10,471 10,471 PROD1 RIGMN SVRG P Slip and cut 50' of drlg line, serviced to drive, blocks and drawworks 05:00 06:00 1.00 10,471 12,356 PROD1 DRILL TRIP P RIH from 10,471' to 12,356' with np roblems 06:00 07:45 1.75 12,356 12,472 PROD1 DRILL CIRC P Washed down from 12,356' to btm at 12,472' with no problems, staged pump rate up to 180 gpm at 1600 psi, circ btms up while lowering ECD from 13.35 to 12.95 ppg with 10.6 ppg Naar Flo-Pro mud. 135 K# Up, 70K-75K# Dn Wt. a ~®. _ ~~ ~... ._ e ~ P~g~ 1'~ of 29 ~ Time Logs Date From To Dur .. th E. De th Phase Code Subcode DM 05/21/2006 07:45 14:30 6.75 12,472 12,700 PROD1 DRILL DDRL P Directionally drilled 6 1/8" hole with Schlumbergers Powerdrive RSS and Periscope tool from 12,472' to 12,700' MD/ 5,881' TVD, (228') ADT 3.81 hrs, 2-10K wob, 96 rpm's, 128 spm, 252 gpm, off btm pressure 2,530 psi, on btm 2,560 psi, off btm torque 11,000 ft-Ibs torque, on btm torque 12,400 ft-Ibs, rot wt 105K, up wt 185K, do wt 70K, 10.6 ppg Naar Flo-Pro mud ave ECD 12.9 to 13.0 ppg, ave BGG 50 units, max gas 625 units, NOTE: Began to see an ave of 20 bph mud losses after drlg below 12,555' to 12,690' 93% returns, noticed a decrease inflow out and pump pressure while drlg from 12,690' to 12,700', same as seen at 12,555'., 14:30 15:30 1.00 12,700 12,700 PROD1 DRILL CIRC T Pumped and spotted 25 bbl, 40 ppb LCM pill outdside of bit, pumped down at 180 gpm at 1,800 psi, slowed pump rate to 1.5 bpm at 630 psi, in the 1 hr pumping and spotting pill lost 26 bbls, as of 16:00 hrs had lost approx 155 bbls in 6 hrs, ave 25.8 bph. 40 ppb LCM pill. consisted of 12 ppb DynaRedF, 12 ppb SafeCarb250, 8 b NutPlu F and 8 b G-Seal 15:30 16:15 0.75 12,700 12,700 PROD1 DRILL CIRC T Circ hole at a reduced rate monitoring for losses, circ hole at 3 bpm at 1,000 psi, after 30 min had lost 23 bbls for 75% returns at 1/2 the drlg rate, mixed 2nd 40 b LCM ill 16:15 17:30 1.25 12,700 12,700 PROD1 DRILL CIRC T Pumped and spotted 2nd 25 bbl. 40 ppb LCM pill outside of bit, spotted pill at 3 b mat 1,000 si 17:30 19:00 1.50 12,700 11,785 PROD1 DRILL TRIP T POOH slow 10 stds from 12,700' to 11,785', hole began to swab, pumped out at 1 /2 bpm to keep hole full, st wt up w/o the pump was 215K, with pump 155K, talc top of 25 bbl pill est at 12,000'. 19:00 00:00 5.00 11,785 11,785 PROD1 DRILL CIRC T Circ hole at 3 bpm at 920 psi while adding 8 ppb LCM to mud system, in addition to 37 ppb CaCO allready in system while drilling, ave 4 bph losses while circ hole at 3 bpm and adding LCM, staged pump rate up to 70 SPM, 1050 psi; 80 SPM, 1200 psi, losses stayed in 3 to 6 BPH range. Total mud lost today 227 bbls. Continue staging rate up and monitoriring losses, while maintaining LCM concentration and mud ro erties. ~ _ A._,. ~ _ m ___ fi'~~e €~ €~f 9 Time Lo s Date From To Dur e th E. De th Phase Code Subcode OM 05/22/2006 00:00 05:30 5.50 11,785 11,785 PROD1 DRILL CIRC T Cont to cir hole adding an additional 8 ppb LCM to mud, circ at 3bpm at 920 psi, ave loss at 3bpm was 4-5 bph, increased pum rate to 200 gpm and losses ave 20 bph and at 220 gpm losses ave 30 bph, slowed back down to 3 bph, observed slight breathing with pump off, 10.6 ppg MW in and out with no as. 05:30 08:15 2.75 11,785 12,700 PROD1 DRILL TRIP T Washed down slow from 11,785' at 3bpm at 1,100 psi and 40 rpm's with 9,500 ft-Ibs torque, TIH ave 4-5 bph loss 08:15 08:45 0.50 12,700 12,700 PROD1 DRILL CIRC T Staged pump rate up at 12,700' from 3 bpm at 1,200 psi and 60 rpm's to 200 gpm at 1,850 psi and 100 rpm's and monitored well for losses, in 15 min hole losses were 22 bbls for a calculated 88 bph loss of 70% returns, slowed um rate to 3 b m. 08:45 17:00 8.25 12,700 12,700 PROD1 DRILL CIRC T Circ hole monitoring for losses, at 3 bpm at 1,050 psi, ave 4 bph for the 1st 4 hrs, while circ, lowered MW to 10.5 ppg and losses slowed to an ave of 2 bph, cleaned out pill pit while pilot testing Form-A-squeeze pill and working up squeeze procedure, cont to circ hole, pumped at 4 bpm at 1,270 psi for 1 hr and had a 12 bbl loss, slowed to 3bpm at 1,050 psi while mixin Form-A-S eeze ill. 17:00 18:00 1.00 12,700 12,700 PROD1 DRILL CIRC T Pumped and spotted 32.5 bbls of 11.1 ppg MI's Form-A-Sgeeze pill, spotted to balance at 130 gpm, 1,000 psi at 40 rpm's with 11,800 ft-Ibs torque, rot wt 115K, up wt 140K, do wt 88K rotating, up wt w/o pump 200K. displaced pill leaving 11 bbls inside DP, est top of plug at 11,807' (893') with 1st potential loss zone at 12,557'. 18:00 21:00 3.00 12,700 10,471 PROD1 DRILL TRIP T Pumped out of hole spotting pill from 12,700' to 11,875', pulled pipe at 30'/min and pumped at .25 bpm to spot remaining pill, cont to pump out of hole from 11,875' to the shoe at 10,471', pumped out at 0.75 bpm, monitored well on connection and well-static ~ _~_ _ m ~ Pie ~~ ~f 2~ ~ ~_ ~., Time Logs Date From To Dur pth E. De th Phase Code Subcode OM 05/22/2006 21:00 23:00 2.00 10,471 10,471 PROD1 DRILL OTHR T PJSM. Close pipe rams, line up to pump down kill line and DP. Pressure up and squeeze Form-A-Squeeze pill as per plan. Pressure up to 100 psi, shut in for 30 minutes, ISIP 70 psi, 10 psi at 30 min. Pressure up to 200 psi, shut in for 30 minutes, ISIP 140 psi, 20 psi at 30 min. Pressure up to 300 psi, shut in for 30 minutes, ISIP 240 psi, 40 psi at 30 min. Bleed off remaining pressure, open rams. Monitor well, very slight to no flow back. Break circulation and bring pump rate up to 200 GPM, 1400 psi, and verify proper o eration of SWS tools. 23:00 23:30 0.50 10,471 11,785 PROD1 DRILL TRIP T RIH to 11785'. had correct pipe dis lacement while RIH. 23:30 00:00 0.50 11,785 11,785 PROD1 DRILL CIRC T Break circulation, rotate and reciprocate pipe while reducing mud weight from 10.5 ppg to 10.4 ppg and conditioning mud. Circulate 70 SPM, 140 GPM, 1050 psi while watering back and treating mud. 180K# PU, 75K# SO, 105K# Rot Wt., 50 RPM. Mud lost last 24 hrs 135 bbls, Total mud lost 362 bbls. 05/23/2006 00:00 06:30 6.50 11,785 11,785 PROD1 DRILL CIRC T Continue circulating, reduce MW, 10.4 ppg in, 10.4+ ppg to 10.5 ppg out. Rotate and work pipe while circulating. Stage pump rates up from 70 SPM, 140 GPM, 1100 psi, to drilling rate at 120 SPM, 240 GPM, 2250 psi, after lower MW returned. Losing 3 to 5 BPH while circulating, only a small increase at higher pump rate. 180K# PU, 75K# SO, 105K# Rot Wt., 50 RPM. 06:30 08:30 2.00 11,785 12,700 PROD1 DRILL TRIP T Wash & ream in hole to bottom at 12700' MD, 60 SPM, 120 GPM, 900 si, 40 RPM. No solid fill. 08:30 11:00 2.50 12,700 12,700 PROD1 DRILL CIRC T Circulate to condition mud and hole, continue reducing mud weight, 10.3 ppg in, 10.4 ppg out. Stage pumps up to drilling rate, 120 SPM, 240 GPM, 2250 si, loss rate 4 to 8 BPH. i .~.~. ~_ ~_ ~g~ ~2 rzf Time Los Date From To Dur th E. De th Phase Code Subcode OM 05/23/2006 11:00 00:00 13.00 12,700 13,050 PROD1 DRILL DDRL P Drill with RSS, from 12700' to 13050' MD, 5889' TVD, down link to tools as needed for directional control. 5K-10K# WOB, 95 RPM, 135 SPM, 270 GPM, 2600 psi, 13400 ft-Ib Torque on btm, 12800 ft-Ib Torque off btm, 180K# PU, 60K# SO, 95K# Rot Wt. 7.67 hrs ART. Reducing MW while drilling, 10.1+ ppg in & out at 2400 hrs, 12.84 Max ECD. Max gas 600 Units, Avg gas approx. 75 Units, cuttings gas. Losing 15 to 20 BPH while drillin . 05/24/2006 00:00 14:00 14.00 13,050 13,564 PROD1 DRILL DDRL P Continue drilling from 13050' to 13564' MD, 5909' TVD. RSS tools not responding as expected and needed. 95 RPM, 5K-10K# WOB, 205K# PU, 50K# SO, 95K# Rot Wt., 146 SPM, 272 gpm, 2930 psi, 13K ft-Ib Tq on btm, 12.8K ft-Ib Tq off btm, 10.0 ppg MW, 12.63 ECD. 14:00 16:30 2.50 13,564 13,564 PROD1 DRILL CIRC T Circulate hole clean & condition mud, 125 SPM, 250 GPM, 2400 psi, Work pipe & rotate 95 RPM while circulating. Spot 35 Bbl pill with 60 ppb LCM on bottom. 16:30 22:00 5.50 13,564 10,450 PROD1 DRILL REAM T Attempt to POH, hole swabbing. Backream out of hole into casing to 10450', circulating slowly to keep hole full and leave LCM pill on bottom. Hole takin fill lus slow loss. 22:00 23:00 1.00 10,450 10,450 PROD1 DRILL CIRC T Attempt to POH, still trying to swab. Circulate bottoms up 135 SPM, 270 GPM, 2200 psi, work and rotate pipe 40 RPM. 23:00 00:00 1.00 10,450 10,167 PROD1 DRILL TRIP T Monitor well, slow flow fell off to zero. Pull 3 stands slow, swabbing slightly, pulling mud out of DP. Monitor hole, static to losing slowly. RU to circulate. 05/25/2006 00:00 01:00 1.00 10,167 10,167 PROD1 DRILL CIRC T Circulate once around, 125 SPM, 250 GPM, 2000 psi. Work pipe and rotate 40 to 95 RPM, 185K# PU, 75K# SO, 107K# Rot Wt. 01:00 06:30 5.50 10,167 6,177 PROD1 DRILL TRIP T Blow down top drive, stand back stand. POH 10 stands, slow. Hole trying to swab, fill DP and get proper hole fill. Pump out 25 stands, hole fill OK. Pull 5 stands on elevators, fill DP to et ro er hole fill. 06:30 07:30 1.00 6,177 6,177 PROD1 DRILL CIRC T Circulate, work and rotate pipe to clean hole, 115 SPM, 230 GPM, 1270 si, 40 to 95 RPM. 07:30 13:30 6.00 6,177 107 PROD1 DRILL TRIP T Pull 10 stands, fill each 5 thru DP. Pump out 10 more. Continue POH, filling every 5 stands thru drillpipe. LD Jars. Stand back non-ma flex DC. ~_.® ~~ ~®~ v .® -- a .-s I~~~ ~~ cif Time Logs :Date From To Dur th E. Depth Phase Code Subcode OM 05/25/2006 13:30 14:00 0.50 107 0 PROD1 DRILL PULD T PJSM. Remove RA sources. LD LWD tools. Pull bit to floor. 14:00 14:30 0.50 0 0 PROD1 DRILL OTHR T Inspect rotary steerable tools and flow test in rotary table. Found one pad on PD Bias Unit was in extended position. Flow test showed no flow to that pad and restricted flow to the other two ads. 14:30 15:30. 1.00 0 107 PROD1 DRILL PULD T LD bit #5 and RSS tools. MU new bit, RSS tools, &LWD Periscope tools, test same. 15:30 16:30 1.00 107 107 PROD1 DRILL PULD T Download LWD tools. 16:30 21:30 5.00 107 10,450 PROD1 DRILL TRIP T RIH with non-mag Flex DC, PU jars. RIH, shallow test tools at 1000'. RIH to 10450'. 21:30 23:00 1.50 10,450 10,450 PROD1 RIGMN SVRG P Slip & cut 48' off drilling line. Service to drive. 23:00 00:00 1.00 10,450 10,450 PROD1 DRILL CIRC NP Circulate to condition mud, stage rate up from 60 SPM, 120 GPM, to 106 SPM, 212 GPM, 1700 psi. Work pipe & rotate 50 RPM while circulating. 450 units gas, peaked at 1250 units at bottoms up. 10.0 ppg MW in. Returns 9.6+ ppg minimum, 11.0 ppg max, 10.1+ ppg at 2400 hrs. ECD 11.9 to 12.2 05/26/2006 00:00 01:30 1.50 10,450 10,450 PROD1 DRILL CIRC NP Circulate to condition mud at 10450', inside shoe. Work and rotate full stand while circulating, 50 RPM. 106 SPM, 212 GPM, 1700 psi. Slowed rate to 90 SPM, 180 GPM, 1200 psi last 30 minutes. 1250 Unit gas peak at bottoms up, 200 Units after 15 min., 2 Units after 30 min. 190K# PU, 80K# SO, 112K# Rot Wt. Blow down top drive. 01:30 02:30 1.00 10,450 13,010 PROD1 DRILL TRIP NP RIH, tag up at 13010'. 02:30 04:30 2.00 13,010 13,564 PROD1 DRILL REAM NP MU top drive. Break circulation slowly. Wash & ream thru spot at 13010'. W & R stand 2 or 3 times, 12925' to 13020', 126 SPM, 250 GPM, 2400 psi. Wash & ream stands to bottom at 13564', no significant tight spots or fill. 50 RPM, 119 SPM, 238 GPM, 2350 si 04:30 05:00 0.50 13,564 13,564 PROD1 DRILL CIRC NP Circulate bottoms up, 129 SPM, 258 GPM, 2550 psi. Work & rotate pipe, 50 RPM. Had 200 - 300 Units Gas while circulating, with a peak at 914 Units. ~. F~~a~ ~~ ~t 2~ Time Logs Date From To Dur ~ th E. De th Phase Code Subcode CM _ 05/26/2006 05:00 12:00 7.00 13,564 13,597 PROD1 DRILL DDRL P Drill from 13564' to 13597' MD (5911' TVD). 12K-18K# WOB, 96 RPM, 129 SPM, 256 GPM, 2650 psi. 205K# PU, 55K# SO, 100K# Rot Wt, 13K ft-Ib Torque on btm, 11 K ft-Ib Torque off btm. 5.19 hr ART, 6.3 Avg ROP. Pumped a 30 Bbl sweep with 30 ppb LCM @ 0845, losses decreased from 40-50 BPH to --20 BPH and slowly decreased to about 5 BPH. 12:00 00:00 12.00 13,597 13,676 PROD1 DRILL DDRL P Drill from 13597' to 13676' MD (5912' TVD). 22K-24K# WOB, 96 RPM, 136 SPM, 270 GPM, 2800 psi. 205K# PU, 55K# SO, 100K# Rot Wt, 13K ft-Ib TQ on btm, 11 K ft-Ib TQ off btm. 10.92 hr ART, 5 to 14 ROP. 12 Units Avg Gas, 50 Units Max. Gas. Pumped a 20 Bbl sweep with 20 ppb fine nut plug and 1% Screenkleen about 1230 hrs, no chan a in ROP, losses at 3 to 5 BPH. 05/27/2006 00:00 12:00 12.00 13,676 13,782 PROD1 DRILL DDRL P Drill from 13676' to 13782' MD (5907' TVD). 20K-25K# WOB, 96 RPM, 131 SPM, 262 GPM, 2770 psi. 180K# PU, 67K# SO, 105K# Rot Wt, 14.5K ft-Ib TO on btm, 10K ft-Ib TQ off btm. 9.34 hr ART, 8 to 20 ROP. 25 to 50 Units as, 440 Units max. after connection. 12:00 00:00 12.00 13,740 13,906 PROD1 DRILL DDRL P Drill to 13906' MD (5903' TVD). 18K-20K# WOB, 96 RPM, 132 SPM, 264 GPM, 2860 psi. 165K# PU, 65K# SO, 95K# Rot Wt, 13K ft-Ib TQ on btm, 12K ft-Ib TQ off btm. 10.67 hr ART, 5 to 15 ROP. 25 to 75 Units as, 390 Units max. after connection. 05/28/2006 00:00 05:30 5.50 13,906 14,023 PROD1 DRILL DDRL P Drill from 13906' to 14023' MD (5899' TVD). 20K# WOB, 96 RPM, 132 SPM, 262 GPM, 2810 psi. 175K# PU, 70K# SO, 107K# Rot Wt, 12.3K ft-Ib TO on btm, 9.5K ft-Ib TQ off btm. 3.13 hr ART, drilling break at 13927' - ROP went from about 12 FPH up to 40 to 70 FPH, back in C4 sand. 620 U Max as from drillin sand. 05:30 06:30 1.00 14,023 14,023 PROD1 DRILL CIRC T Circulate and cycle pumps attempting to downlink to RSS tools, no success. Started dropping angle drilling sand and a eared to lose steerin control. 06:30 07:30 1.00 14,023 14,023 PROD1 DRILL CIRC T Circulate hole clean, work and rotate pipe. Spotted LCM pill in open hole. 134 SPM, 268 GPM, 2750 psi. Cuttings gas decreased from 450 U to 60 U. 07:30 11:00 3.50 14,023 11,880 PROD1 DRILL REAM T POH to 13590', saw a couple tight spots pulling thru Miluveach shale, and light swabbing. MU top drive and backream out to 11880', 40 RPM, 67 SPM, 134 GPM, 800 si. ~_ ~ .___-...~ .~ _ ~s 2 ~sf 2~ Time Logs ~ ~ --- Date From To Dur e th E. Depth Phase Code Subcode Tom. T - C M O 05/28/2006 11:00 12:30 1.50 11,880 11,880 PROD1 DRILL CIRC T CBU, work and rotate pipe, 40 RPM, 130 SPM, 260 GPM, 2250 psi. 800 U Max ass ike, back to 10 U. 12:30 14:30 2.00 11,880 10,450 PROD1 DRILL REAM T Backream out of hole to 11307', 40 RPM, 104 SPM, 208 GPM, 900 psi. POH to 10450', inside shoe, on elevators, started to swab. 14:30 17:30 3.00 10,450 10,450 PROD1 DRILL CIRC T Monitor well 30 minutes, static. Circulate and increase MW to 10.2 ppg, 125 SPM, 250 GPM, 1950 psi. 50 U Max gas, back to 2 U. Monitor well 30 minutes, static. 17:30 00:00 6.50 10,450 300 PROD1 DRILL TRIP T Continue POH on elevators to 300'. Hole took proper fill. Prepare to LD BHA. 05/29/2006 00:00 01:30 1.50 300 0 PROD1 DRILL PULD T Finish POH. Check RSS tools. Bias pads appeared to be functioning, no apparent seal leaks. Pumping tests indicated possible tool problems, but showed proper cycling of flow to pads. LD bit and RSS tools. 01:30 06:30 5.00 0 0 PROD1 WELCT BOPS P Pull wear bushing. Set test plug. Test BOPE: all rams, annular, choke & kill lines, choke manifold, floor safety valves, upper and lower kelly cocks to 250 psi & 3500 psi. Accumulator capacity test, OK. Witnessing of test waived by Jeff Jones, AOGCC Field Ins ector. 06:30 07:00 0.50 0 0 PROD1 WELCT BOPE P Pull test plug. Set wear bushing. 07:00 08:00 1.00 0 0 PROD1 RIGMN SVRG P Service blocks, top drive, & drawworks. 08:00 10:30 2.50 0 230 PROD1 DRILL PULD T MU new bit &RSS tools. PJSM. PU MWD tools & load RA sources. RIH non-ma flex DC, MU 'ars. 10:30 15:00 4.50 230 10,450 PROD1 DRILL TRIP T RIH, shallow test tools at 1000'. RIH to 10450', inside shoe. 15:00 16:00 1.00 10,450 10,450 PROD1 RIGMN SVRG P Slip & cut 48' of drilling line. 16:00 17:30 1.50 10,450 10,450 PROD1 DRILL CIRC T Circulate & condition mud, 85 SPM, 168 GPM, 1100 si. 17:30 18:30 1.00 10,450 13,595 PROD1 DRILL TRIP T RIH, tag spot at 13595'. 18:30 20:00 1.50 13,595 14,023 PROD1 DRILL REAM T Wash and ream thru tight spots in Miluveach shale to bottom at 14023'. Started losing mud while reaming to bottom. 20:00 20:30 0.50 14,023 14,023 PROD1 DRILL CIRC T Circulate and downlink to RSS tools. Bottoms up gas peaked at 1300 Units, down to 550 Units and decreasing. Mud loss continuing. Approximately 175 Bbls lost in 2 hrs. Pumped 40 Bbl LCM swee w/ 30 b LCM. i~_ - - - ...,_,_ ~~~ ~ t~f 2~ Time Logs Date From To Dur e th E. De th Phase Code Subcode OM 05/29/2006 20:30 23:30 3.00 14,023 14,144 PROD1 DRILL DDRL P Drill from 14023' to 14144' MD (5901' TVD). Drilling break at 14095', ROP went from 50 FPH to 75-100 FPH. Control drilled rest of stand down at 50 FPH. Losses increased at drilling break. Pumped 80 Bbls LCM sweep w/ 30 ppb LCM at 14121'. Hole dropping angle after drilling break, reduced pump from 260 GPM to 225 GPM for losses (14115' to 14131'), but angle drop increased, resumed 260 GPM for rest of stand down. 23:30 00:00 0.50 14,144 14,144 PROD1 DRILL CIRC T Reduce circulating rate to 75 SPM, 150 GPM and finish pumping LCM sweep. Work and rotate pipe. Loss rate 150 to 170 BPH after drilling break. 05/30/2006 00:00 07:00 7.p0 14,051 14,051 PROD1 DRILL CIRC T Cont pumping LCM pill at 3 bpm, 900 psi, reduced pump rate in stages to 1.9 bpm, 650 psi, fluid loss at 130 bph, up wt 145K, dwn wt 105K while um in . 07:00 07:30 0.50 14,051 14,051 PROD1 DRILL OWFF T Monitor well on trip tank while slowly recip drill pipe, static loss at 4 bph, up wt 220K, dwn wt 77K. 07:30 07:45 0.25 14,051 14,144 PROD1 DRILL TRIP T RIH from 14,051' to14,144'. 07:45 08:30 0.75 14,144 14,144 PROD1 DRILL CIRC T Pump and spot Forma Squeeze Pill. 08:30 13:30 5.00 14,144 10,450 PROD1 DRILL REAM T Back ream OOH from 14,144' MD to 10,450' MD, for ue at 9,430 ft/Ibs. 13:30 15:30 2.00 10,450 10,450 PROD1 DRILL OTHR T RU and squeeze Forma Squeeze Pill at 30 min intervals, 140 psi bled to 30 psi, 250 psi bled to 50 psi and 400 psi bled to 110 si, RD. 15:30 17:30 2.00 10,450 14,144 PROD1 DRILL TRIP T RIH from 10,450' to 13,700', tight hole at 13,700', KU and reamed through with no pump, cunt ream to btm at 14,144'. 17:30 18:30 1.00 14,144 14,144 PROD1 DRILL CIRC T Circ at 2 bpm, 600 psi, rot and recip at 40 r m. 18:30 19:00 0.50 14,144 14,144 PROD1 DRILL OWFF T Monitor well on trip tank, static loss at 2 b h, callin TD at 14,144' MD. 19:00 21:00 2.00 14,144 14,144 PROD1 DRILL WPRT P Short trip from 14,144' to 13,200' and back to btm. 21:00 00:00 3.00 14,144 14,144 PROD1 DRILL CIRC P CBU at 4.5 bpm, 1,750 psi, 22% return flow, max gas 500 units, 75 rpm's, followed b a 130 bbl tube-tex ill. 05/31/2006 00:00 00:30 0.50 14,144 14,144 PROD1 DRILL OWFF P Monitor well on trip tank. 00:30 06:30 6.00 14,144 9,695 PROD1 DRILL TRIP P POOH from 14,144' to 9,695', pipe ulled d and had no hole fill at 9,695'. 06:30 07:15 0.75 9,695 9,695 PROD1 DRILL CIRC P CBU at 100 spm, 1,350 psi, rot and reci at 20 r m's, max as 50 units. 07:15 07:30 0.25 9,695 9,695 PROD1 DRILL OWFF P Monitor well on trip tank, with no loss or ain. ~.. e~_ e - - ~ ~ ~~ 7 ~fi Time Logs Date From To Dur ., e th E. De th Phase Code Subcode OM _ 05/31/2006 07:30 13:30 6.00 9,695 230 PROD1 DRILL TRIP P Cont POOH from 9,695' to 230'. 13:30 15:00 1.50 230 0 PROD1 DRILL PULD P PJSM removed nuke sources, LD BHA #7. 15:00 17:00 2.00 0 0 PROD1 DRILL RURD P PJSM, RU to run 4 1/2" 12.6# BTC Slotted Liner. 17:00 23:00 6.00 0 3,868 PROD1 CASIN( RUNL P PU RIH with 89 jnts slotted liner, 6 jnts blank i e, MU han er assembl . 23:00 00:00 1.00 3,868 6,214 PROD1 CASIN( RUNL P Cont RIH with liner assembly on 4" DP from 3,868' to 6,214'. 06/01/2006 00:00 04:45 4.75 6,214 14,140 PROD1 CASIN( RUNL P Cont PU and RIH with 4 1/2" Liner . assembly on 4" drill pipe, from 6,214' to 14,140', u wt 190K, dwn wt 80K. 04:45 06:15 1.50 14,140 14,140 PROD1 CASIN( OTHR P Drop ball and pump dwn at 3 bpm, 520 si to seat. 06:15 06:45 0.50 14,140 14,140 PROD1 CASIN( OTHR P Stage pump pressure up and set packer at 10,266' as per Baker Rep, RU and test annulus/packer at 3,000 si for 30 min, test OK. 06:45 07:30 0.75 14,140 10,225 PROD1 CASIN( OTHR P Unsting running tool from packer assembl and LD 2 'nts DP. 07:30 09:00 1.50 10,225 10,225 PROD1 RIGMN SVRG P Slip and cut drill line. 09:00 09:30 0.50 10,266 10,070 PROD1 DRILL PULD P PJSM and POOH LD 4" DP from 10,225' to 10,070', hole not taking ro er fill. 09:30 09:45 0.25 10,070 10,070 PROD1 DRILL OWFF P Monitor well for 15 min with no loss or ain. 09:45 13:00 3.25 10,070 10,070 PROD1 DRILL CIRC P CBU at 100 spm, 750 psi to cond mud. 13:00 00:00 11.00 10,070 200 PROD1 DRILL PULD P Cont POOH LD 4" DP from 10,070' to 200' with no hole fill roblems. 06/02/2006 00:00 01:30 1.50 200 0 PROD1 DRILL PULD P Cont LD 4" DP and liner running tool from 200'. 01:30 06:30 5.00 0 5,757 PROD1 DRILL PULD P RIH from derrick with hybrid pipe, HWDP and remaing 4" DP, removing su er sliders. 06:30 14:00 7.50 5,757 0 PROD1 DRILL PULD P POOH LD 4" DP, HWDP and hybrid i e. 14:00 18:30 4.50 0 0 PROD1 DRILL PULD P Off load Dp from pipeshed, rack and tall 82 'nts 3 1/2" tubin and 'ewel 18:30 00:00 5.50 0 5,237 COMPZ RPCOti RCST P PJSM, PU RIH with 3 1/2" completion . strin from i e shed to 5,237'. 06/03/2006 00:00 06:00 6.00 5,237 10,303 COMPZ RPCOh RCST P Cont PU RIH with 3 1/2" completion strin from 5,237' to 10, 303'. 06:00 07:00 1.00 10,303 10,303 COMPZ RPCOh DHEQ P Test seals to 1,000 psi and MU han er. 07:00 09:30 2.50 10,303 10,268 COMPZ RPCOh CIRC P Pull out of seal bore recep and dis lace well to 10.2 brine. 09:30 10:00 0.50 10,268 10,314 COMPZ RPCOh HOSO P Land hanger and RILD's, up wt 118K, ' dwn wt 65K. 10:00 10:15 0.25 10,314 10,314 COMPZ RPCOh DHEQ P RU and test 3 1/2" x 7" at 1,000 psi, test OK. 10:15 11:00 0.75 10,314 10,314 COMPZ RPCOh RURD P LD landing jnt and install TWC. ~ ~'~~ ~3 t~f ~9~ ~~ ._..~ ~ ._.. ~ ..~ ..~ Time Logs Date From To Dur th E. Depth Phase Code Subcode Tt OM__ 06/03/2006 11:00 14:30 3.50 10,314 10,314 COMPZ RPCOh NUND P ND 11" BOP. 14:30 19:00 4.50 10,314 10,314 COMPZ RPCOti NUND P NU adaptor flange and tree, test pack-off to 5,000 psi, test tree at 250 and 5,000 si. 19:00 20:00 1.00 10,314 10,314 COMPZ RPCOCV RURD P RU lubricator and pull TWC. 20:00 23:30 3.50 10,314 10,314 COMPZ RPCOh FRZP P Filled tubing, RU and attempted to perform MITIA on 3 1/2" x 7". DCR-1 valve sheared at 2,400 psi, Little Red pumped 120 bbls diesel dwn backside at 4 bpm,1,150 psi, lined up and e ualized tubin and annulus. 23:30 00:00 0.50 10,314 10,314 COMPZ RPCOh RURD P Blew dwn lines, RD all circ lines. 06/04/2006 00:00 01:00 1.00 10,314 10,314 COMPZ RPCOh RURD P PJSM, blow dwn and RD circ lines in cellar. SITP 300 psi, IA 300 psi, OA 50 si. 01:00 02:00 1.00 10,314 10,314 COMPZ RPCOA OTHR P RU and install FMC lubricator, install BPV. 02:00 06:00 4.00 10,314 10,314 COMPZ RPCOCv OTHR P Clean pits and surface equipment, clean out cellar box and rock washer. ~~ ~~ ~®~~~ ~9 t~f ~9~ ~~ a • Halliburton Company. Survey Report Company: ConocoPhillipsAlaska Inc. Date: 6/13/2006 Time: 08:54:01 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3S-23, True N orth Site: Kuparuk 3S Pad Vertical (TVD) Refer ence: 3S-23A 57.6 Well: 35-23 5ectioir (VS) Reference: .Well (OAON,O.OOE,200.OOAzi) WeIlpaCh: 3S-23A Survey Calculation M ethod: Minimum Curvature Db: Orade Field: Kuparuk River Unit ~ North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 ~~ ', Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre j ~' Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 - J - Well: 3S-23 Slot Name: Well Position: +N/-S 11.68 ft Northing : 5993856.07 ft Latitude: 70 23 39.634 N +E/-W -441.97 ft Fasting : 476013.11 ft Longitude: 150 11 42.590 W Position Uncertainty: 0.00 ft L-- -._._... Wellpath: 3S-23A Drilled From: 3S-23 501032045301 Tie-on Depth: 3987.78 ft '~ Current Datum: 3S-23A Height 57.65 ft Above System Datum: Mean Sea Level i, Magnetic Data: 4/16/2006 Declination: 23.83 deg Field Strength: 57544 nT Mag Dip Angle: 80.79 deg ~! Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ' ft ft ft deg 29.95 0.00 0.00 200.00 Survey Program for Definitive Wellpath ~ Date: 6/7/2006 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft ', 88.45 264.45 3S-23 Gyro (88.45-264.45) (0) CB-GYRO-SS Camera based gyro single shot 392.31 3987.78 3S-23 IIFR (3 92.31-10451.02) ( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC j 4077.88 10451.57 3S-23A (4077.88-10451 .57) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10501.88 14083.40 3S-23A Anad rill (10501. 88-1408 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __ ill) lncl Azim "IT'D SysTVD N/S FJW f11apN iVtapE i'ooI ft deg deg - ft ft -- __ ft ft ft ft 29.95 0.00 0.00 29.95 -27.70 0.00 0.00 5993856.07 ~ 476013.11 • TIE LINE 88.45 0.90 96.00 88.45 30.80 -0.05 0.46 5993856.02 476013.57 CB-GYRO-SS 175.28 0.55 64.00 175.27 117.62 0.06 1.51 5993856.13 476014.62 CB-GYRO-SS ' 264.45 1.40 316.00 264.43 206.78 1.03 1.14 5993857.10 476014.25 CB-GYRO-SS 392.31 4.73 308.39 392.09 334.44 5.43 -4.08 5993861.52 476009.05 MWD+IFR-AK-CAZ-SC i 482.55 6.49 312.60 481.90 424.25 11.20 -10.75 5993867.30 476002.40 MWD+IFR-AK-CAZ-SC 567.81 9.02 307.77 566.37 508.72 18.55 -19.58 5993874.68 475993.59 MWD+IFR-AK-CAZ-SC 661.88 12.64 301.22 658.75 601.10 28.41 -34.22 5993884.58 475978.99 MWD+IFR-AK-CAZ-SC ~, 752.96 16.00 294.86 747.00 689.35 38.85 -54.14 5993895.09 475959.10 MWD+IFR-AK-CAZ-SC 841.13 18.51 290.03 831.20 773.55 48.76 -78.32 5993905.07 475934.96 MWD+IFR-AK-CAZ-SC li 935.62 21.23 284.41 920.06 862.41 58.16 -108.99 5993914.57 475904.32 MWD+IFR-AK-CAZ-SC '' 1032.71 24.03 278.41 1009.68 952.03 65.42 -145.58 5993921.95 475867.75 MWD+IFR-AK-CAZ-SC' 1121.05 27.68 276.22 1089.16 1031.51 70.28 -183.79 5993926.93 475829.57 MWD+IFR-AK-CAZ-SC 1217.02 30.87 270.88 1172.88 1115.23 73.07 -230.58 5993929.88 475782.79 MWD+IFR-AK-CAZ-SC 1313.55 33.70 264.82 1254.50 1196.85 71.04 -282.04 5993928.00 475731.33 MWD+IFR-AK-CAZ-SC '' 1403.82 36.81 259.87 1328.22 1270.57 64.01 -333.62 5993921.15 475679.73 MWD+IFR-AK-CAZ-SC 'i 1496.59 41.44 255.38 1400.18 1342.53 51.37 -390.73 5993908.69 475622.58 MWD+IFR-AK-CAZ-SC 1592.56 46.19 252.49 1469.42 1411.77 32.92 -454.53 5993890.45 475558.74 MWD+IFR-AK-CAZ-SC II 1687.20 49.16 248.67 1533.15 1475.50 9.62 -520.47 5993867.35 475492.73 MWD+IFR-AK-CAZ-SC ~i 1780.25 54.18 246.53 1590.84 1533.19 -18.23 -587.91 5993839.73 475425.20 MWD+IFR-AK-CAZ-SC 1873.13 59.27 244.24 1641.79 1584.14 -50.60 -658.45 5993807.59 475354.56 MWD+IFR-AK-CAZ-SC 1967.57 60.25 244.60 1689.35 1631.70 -85.83 -732.05 5993772.60 475280.87 MWD+IFR-AK-CAZ-SC ', 2062.44 59.31 241.98 1737.11 1679.46 -122.66 -805.27 5993736.00 475207.53 MWD+IFR-AK-CAZ-SC 2157.79 59.80 238.14 1785.44 1727.79 -163.68 -876.48 5993695.22 475136.20 MWD+IFR-AK-CAZ-SC 2251.34 60.88 236.13 1831.73 1774.08 -207.80 -944.75 5993651.32 475067.79 MWD+IFR-AK-CAZ-SC ' I, 2346.01 63.74 229.39 1875.76 1818.11 -258.53 -1011.38 5993600.81 475001.00 MWD+IFR-AK-CAZ-SC ', ' 2440.25 63.90 227.94 1917.34 1859.69 -314.39 -1074.88 5993545.16 474937.33 MWD+IFR-AK-CAZ-SC ', • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 3S Pad Well: 3S-23 ~i'cllpath: 3S-23A Sun°c~° h1D lncl .azim TVD ft deg deg ft 2535.05 64.06 228. 79 1958. 93 2579.61 66.87 228. 20 1977. 43 2628.52 67.95 227. 81 1996. 22 2724.33 70.41 230. 21 2030. 27 2819.52 68.45 231. 39 2063. 72 2913.90 65.16 237. 04 2100. 91 3005.24 62.64 242. 26 2141. 12 3099.18 61.98 247. 63 2184. 79 3191 .50 64. 57 253.00 2226. 33 3287 .06 65. 49 254.21 2266. 67 3380. 80 65. 46 255.05 2305. 58 3477 .04 62. 50 252.51 2347. 80 3570 .56 62. 87 252.95 2390. 72 3664 .45 63. 68 253.75 2432. 94 3757. 76 61. 99 253.18 2475. 54 3850. 72 62. 29 253.51 2518. 98 3943. 76 62. 89 252.90 2561. 81 3987. 73 62. 96 253.31 2581. 83 ~ 4077 .88 63. 52 250.17 2622. 43 4099. 88 62. 78 250.83 2632. 36 4198. 47 58. 82 250.34 2680. 45 I, 4294. 00 57. 67 250.20 2730. 73 4387. I 70 55. 22 250.98 2782. 51 4482. 76 52. 42 255.02 2838. 64 4579. 13 52. 88 257.69 2897. 11 4673. 29 54. 22 258.80 2953. 05 4767. 82 55. 56 260.72 3007. 43 4863. 11 56. 24 260.21 3060. 85 4958. 78 55. 63 260.03 3114. 44 5053. 23 54. 70 260.26 3168. 39 5148. 63 54. 00 259.41 3223. 99 5243. 24 55. 04 260.42 3278. 90 ~i 5338. 73 54. 46 259.67 3334. 01 i' 5434. 11 53. 99 259.93 3389. 77 5528. 55 55. 50 259.61 3444. 29 5623. 84 54. 77 259.11 3498. 76 5719. 51 54. 80 259.35 3553. 92 5813. 89 55. 11 259.45 3608. 12 Date: 6/13/2006 'time: 08:54:01 Page: 2 Co-ordinatc(NE) Reference: Well: 3S-23, True North Ve~~ticai (TVD) Reference: 3S-23A 57.6 tiection (~'S) Reference: Well (O.OON,O.OOE,200.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle __ Sys TVD it/S E/1i~ >V1apN ft ft ft ft 1901.28 -370.99 -1138.55 5993488.78 1919.78 -397.85 -1168.91 5993462.01 1938.57 -428.06 -1202.47 5993431.91 1972.62 -486.78 -1270.06 5993373.41 2006.07 -543.11 -1339.12 5993317.31 2043.26 -593.84 -1409.41 5993266.81 2083.47 -635.30 -1480.14 5993225.58 2127.14 -670.52 -1555.45 5993190.61 2168.68 -698.24 -1633.06 5993163.14 2209.02 -722.69 -1716.16 5993138.97 2247.93 -745.29 -1798.39 5993116.63 2290.15 -769.42 -1881.42 5993092.77 2333.07 -794.09 -1960.77 5993068.36 2375.29 -818.11 -2041.11 5993044.59 2417.89 -841.73 -2120.69 5993021.23 2461.33 -865.29 -2199.43 5992997.93 2504.16 -889.16 -2278.50 5992974.32 2524.18 -900.53 -2315.96 5992963.06 2564.78 -925.76 -2392.39 5992938.09 2574.71 -932.31 -2410.89 5992931.59 2622.80 -960.90 -2492.04 5992903.26 2673.08 -988.32 -2568.50 5992876.09 2724.86 -1014.28 -2642.14 5992850.37 2780.99 -1036.75 2839.46 -1054.81 2895.40 -1070.24 2949.78 -1083.97 3003.20 -1097.04 3056.79 -1110.64 3110.74 -1123.91 3166.34 -1137.59 3221.25 -1151.08 3276.36 -1164.55 3332.12 -1178.26 3386.64 -1191.96 3441.11 -1206.39 3496.27 -1221.00 3550.47 -1235.21 -2715.47 -2789.91 -2864.06 -2940.15 -3017.96 -3096.04 -3172.42 -3248.72 -3324.57 -3401.38 -3477.54 -3553.43 -3630.27 -3707.06 -3783.01 5992828.14 5992810.32 5992795.13 5992781.65 5992768.82 5992755.48 5992742.46 5992729.02 5992715.78 5992702.55 5992689.09 5992675.64 5992661.45 5992647.10 5992633.13 5908.19 55. 32 258. 93 3661. 92 3604. 27 -1249 .74 -3859. 08 5992618. 85 6003. 78 54. 89 258. 88 3716. 60 3658. 95 -1264 .82 -3936. 02 5992604. 01 6098. 24 54. 27 258. 03 3771. 35 3713. 70 -1280 .23 -4011. 44 5992588. 85 6193. 46 53. 79 257. 75 3827. 28 3769. 63 -1296 .39 -4086. 79 5992572. 92 6288. 69 53. 09 257. 26 3884. 00 3826. 35 -1312 .94 -4161. 47 5992556. 62 6383. 87 55. 62 258. 52 3939. 47 3881. 82 -1329 .15 -4237. 09 5992540. 65 6478. 98 55. 13 258. 12 3993. 51 3935. 86 -1345 .00 -4313. 73 5992525. 05 6573. 82 54. 71 258. 24 4048. 01 3990. 36 -1360 .89 -4389. 70 5992509. 40 6670. 09 54. 29 257. 42 4103. 92 4046. 27 -1377 .42 -4466. 31 5992493. 13 6762. 70 53. 53 257. 44 4158. 47 4100. 82 -1393 .70 -4539. 35 5992477. 08 6858. 76 53. 25 257. 17 4215. 76 4158. 11 -1410 .65 -4614. 58 5992460. 38 6954. 45 54. 98 256. 24 4271. 85 4214. 20 -1428 .48 -4690. 02 5992442. 79 7049. 46 54. 12 256. 23 4326. 95 4269. 30 -1446 .90 -4765. 19 5992424. 61 7142. 56 54. 79 258. 00 4381. 08 4323. 43 -1463 .78 -48:9. 03 5992407. 97 7240. 30 53. 92 257. 74 4438. 03 4380. 38 -1480 .47 -4916. 69 5992391. 53 1~1apE _ _ Tool ft 474873.49 MWD+IFR-AK-CAZ-SC f 474843.05 MWD+IFR-AK-CAZ-SC 474809.40 MWD+IFR-AK-CAZ-SC I 474741.62 MWD+IFR-AK-CAZ-SC I 474672.39 MWD+IFR-AK-CAZ-SC 474601.94 MWD+IFR-AK-CAZ-SC 474531.09 MWD+IFR-AK-CAZ-SC 474455.67 MWD+IFR-AK-CAZ-SC ', 474377.98 MWD+IFR-AK-CAZ-SC 474294.81 MWD+IFR-AK-CAZ-SC 474212.52 MWD+IFR-AK-CAZ-SC '' 474129.42 MWD+IFR-AK-CAZ-SC 474050.00 MWD+IFR-AK-CAZ-SC ' 473969.59 MWD+IFR-AK-CAZ-SC '. 473889.94 MWD+IFR-AK-CAZ-SC , 473811.13 MWD+IFR-AK-CAZ-SC ' 473732.00 MWD+IFR-AK-CAZ-SC 473694.50 MWD+IFR-AK-CAZ-SC 473618.00 MWD+IFR-AK-CAZ-SC 473599.48 MWD+IFR-AK-CAZ-SC '. 473518.24 MWD+IFR-AK-CAZ-SC 473441.70 MWD+IFR-AK-CAZ-SC 473367.99 MWD+IFR-AK-CAZ-SC '. 473294.60 MWD+IFR-AK-CAZ-SC 473220.11 MWD+IFR-AK-CAZ-SC 473145.92 MWD+IFR-AK-CAZ-SC 473069.79 MWD+IFR-AK-CAZ-SC '' 472991.94 MWD+IFR-AK-CAZ-SC I 472913.83 MWD+IFR-AK-CAZ-SC I'I 472837.42 MWD+IFR-AK-CAZ-SC 472761.08 MWD+IFR-AK-CAZ-SC 472685.19 MWD+IFR-AK-CAZ-SC 472608.35 MWD+IFR-AK-CAZ-SC 472532.15 MWD+IFR-AK-CAZ-SC 472456.23 MWD+IFR-AK-CAZ-SC 472379.35 MWD+IFR-AK-CAZ-SC 472302.52 MWD+IFR-AK-CAZ-SC 472226.54 MWD+IFR-AK-CAZ-SC 472150.42 MWD+IFR-AK-CAZ-SC 472073.45 MWD+IFR-AK-CAZ-SC 471997.98 MWD+IFR-AK-CAZ-SC 471922.59 MWD+IFR-AK-CAZ-SC 471847.87 MWD+IFR-AK-CAZ-SC 471772.20 MWD+IFR-AK-CAZ-SC 471695.52 MWD+IFR-AK-CAZ-SC 471619.51 MWD+IFR-AK-CAZ-SC 471542.85 MWD+IFR-AK-CAZ-SC 471469.76 MWD+IFR-AK-CAZ-SC 471394.49 MWD+IFR-AK-CAZ-SC 471319.00 MWD+IFR-AK-CAZ-SC 471243.77 MWD+IFR-AK-CAZ-SC 471169.89 MWD+IFR-AK-CAZ-SC ~~ 471092.19 MWD+IFR-AK-CAZ-SC ~i Halliburton Company Survey Report Company: ConocoPhilkips Alaska Inc. Date: 6/13/2006 Time: 08:54:01 Page: 3 Field: Kuparuk River Unit Co-ordinate(NF),Reference: Well: 3S-23, True'North Site: Kuparuk 3S Pad Vertical (TVDpReference: 3S-23A 57.6 Well: 35-23 Section (VS) Reference: Well (O.OON,O.OOE,200.OOAzi)- Wellpath: 3S-23A Survey Calculation 1Vlethod: Minimum Curvature Db: Oracle Survey - 111D Incl _ _ Azim TVD S_ys'Iti'D _ _ __ ___ N/S E/~V MapA NIapE Tool ft deg deg ft ft ft ft ft ft 7335.53 52.95 257.82 4494.77 4437.12 -1496.66 -4991.44 5992375.58 471017.39 MWD+IFR-AK-CAZ-SC i 7430.88 53.51 257.33 4551.84 4494.19 -1513.10 -5066.03 5992359.38 470942.76 MWD+IFR-AK-CAZ-SC 7526.79 53.00 257.05 4609.22 4551.57 -1530.14 -5140.97 5992342.59 470867.77 MWD+IFR-AK-CAZ-SC 7619.83 55.20 257.33 4663.77 4606.12 -1546.84 -5214.46 5992326.12 470794.24 MWD+IFR-AK-CAZ-SC 7715.73 54.46 256.95 4719.01 4661.36 -1564.29 -5290.88 5992308.92 470717.76 MWD+IFR-AK-CAZ-SC 7810.43 53.53 257.16 4774.68 4717.03 -1581.45 -5365.54 5992292.00 470643.05 MWD+IFR-AK-CAZ-SC 7905.51 54.67 258.18 4830.43 4772.78 -1597.89 -5440.78 5992275.80 470567.77 MWD+IFR-AK-CAZ-SC !. ~' 8000.19 54.06 257.43 4885.60 4827.95 -1614.15 -5516.00 5992259.79 470492.51 MWD+IFR-AK-CAZ-SC '; 8095.44 55.48 257.43 4940.54 4882.89 -1631.08 -5591.93 5992243.10 470416.53 MWD+IFR-AK-CAZ-SC ' 8190.13 54.44 257.10 4994.91 4937.26 -1648.17 -5667.55 5992226.26 470340.86 MWD+IFR-AK-CAZ-SC 8286.37 54.62 256.35 5050.75 4993.10 -1666.17 -5743.84 5992208.51 470264.53 MWD+IFR-AK-CAZ-SC 8381.60 55.17 255.24 5105.52 5047.87 -1685.29 -5819.36 5992189.63 470188.95 MWD+IFR-AK-CAZ-SC 8476.31 56.04 250.82 5159.04 5101.39 -1708.10 -5894.07 5992167.06 470114.17 MWD+IFR-AK-CAZ-SC ~'i 8570.49 57.22 248.63 5210.84 5153.19 -1735.36 -5967.84 5992140.04 470040.32 MWD+IFR-AK-CAZ-SC ', II 8666.47 57.93 246.15 5262.31 5204.66 -1766.51 -6042.62 5992109.13 469965.46 MWD+IFR-AK-CAZ-SC 8761.11 59.95 243.12 5311.15 5253.50 -1801.25 -6115.85 5992074.63 469892.12 MWD+IFR-AK-CAZ-SC ', 8855.93 60.96 240.53 5357.91 5300.26 -1840.21 -6188.55 5992035.91 469819.30 MWD+IFR-AK-CAZ-SC ~, 8950.47 61.97 237.28 5403.08 5345.43 -1883.10 -6259.65 5991993.25 469748.07 MWD+IFR-AK-CAZ-SC 9047.13 62.20 233.48 5448.34 5390.69 -1931.62 -6329.92 5991944.96 469677.65 MWD+IFR-AK-CAZ-SC 9142.39 62.63 230.90 5492.46 5434.81 -1983.37 -6396.61 5991893.43 469610.80 MWD+IFR-AK-CAZ-SC 9237.83 62.53 227.42 5536.42 5478.77 -2038.76 -6460.69 5991838.25 469546.55 MWD+IFR-AK-CAZ-SC ~ 9332.80 63.44 225.00 5579.57 5521.92 -2097.31 -6521.76 5991779.90 469485.31 MWD+IFR-AK-CAZ-SC 'I 9427.05 65.31 222.16 5620.33 5562.68 -2158.87 -6580.32 5991718.54 469426.55 MWD+IFR-AK-CAZ-SC ', i 9521.92 67.79 218.88 5658.09 5600.44 -2225.03 -6636.83 5991652.57 469369.83 MWD+IFR-AK-CAZ-SC I, ~I 9617.13 70.83 215.23 5691.74 5634.09 -2296.11 -6690.46 5991581.67 469315.98 MWD+IFR-AK-CAZ-SC '- I 9710.36 72.53 214.67 5721.04 5663.39 -2368.65 -6741.16 5991509.30 469265.05 MWD+IFR-AK-CAZ-SC 9806.27 74.58 210.62 5748.20 5690.55 -2446.09 -6790.75 5991432.02 469215.22 MWD+IFR-AK-CAZ-SC 9901.60 76.38 208.35 5772.10 5714.45 -2526.42 -6836.16 5991351.85 469169.56 MWD+IFR-AK-CAZ-SC ~ 9998.40 78.46 207.15 5793.19 5735.54 -2610.02 -6880.14 5991268.39 469125.31 MWD+IFR-AK-CAZ-SC 10093.06 81.03 205.34 5810.04 5752.39 -2693.56 -6921.33 5991185.00 469083.87 MWD+IFR-AK-CAZ-SC ~ 10187.70 82.22 203.40 5823.82 5766.17 -2778.84 -6959.95 5991099.85 469044.97 MWD+IFR-AK-CAZ-SC ~I 10281.81 84.08 199.44 5835.05 5777.40 -2865.81 -6994.06 5991013.00 469010.58 MWD+IFR-AK-CAZ-SC 10377.06 85.31 200.99 5843.86 5786.21 -2954.80 -7026.84 5990924.12 468977.53 MWD+IFR-AK-CAZ-SC 10451.57 85.19 200.47 5850.03 5792.38 -3024.25 -7053.12 5990854.77 468951.02 MWD+IFR-AK-CAZ-SC ' 10501.88 85.53 202.09 5854.10 5796.45 -3070.98 -7071.32 5990808.10 468932.68 MWD+IFR-AK-CAZ-SC 10515.34 85.98 201.74 5855.10 5797.45 -3083.43 -7076.33 5990795.67 468927.63 MWD+IFR-AK-CAZ-SC ', 10597.68 89.41 199.92 5858.41 5800.76 -3160.31 -7105.58 5990718.89 468898.14 MWD+IFR-AK-CAZ-SC 'I 10625.55 89.21 199.83 5858.74 5801.09 -3186.52 -7115.05 5990692.71 468888.58 MWD+IFR-AK-CAZ-SC ', 10692.08 88.73 199.11 5859.94 5802.29 -3249.23 -7137.22 5990630.08 468866.21 MWD+IFR-AK-CAZ-SC 10786.93 89.21 200.03 5861.64 5803.99 -3338.59 -7168.99 5990540.83 468834.16 MWD+IFR-AK-CAZ-SC 'i 10817.06 89.17 199.37 5862.07 5804.42 -3366.95 -7179.14 5990512.50 468823.91 MWD+IFR-AK-CAZ-SC ! ', 10882.27 90.41 200.30 5862.31 5804.66 -3428.29 -7201.27 5990451.24 468801.59 MWD+IFR-AK-CAZ-SC 10977.23 91.06 201.21 5861.09 5803.44 -3517.08 -7234.92 5990362.57 468767.66 MWD+IFR-AK-CAZ-SC '~ 10991.46 90.82 200.65 5860.86 5803.21 -3530.37 -7240.00 5990349.30 468762.54 MWD+IFR-AK-CAZ-SC i 11073.21 89.89 200.63 5860.35 5802.70 -3606.87 -7268.82 5990272.90 468733.48 MWD+IFR-AK-CAZ-SC 11105.62 89.96 200.18 5860.39 5802.74 -3637.25 -7280.11 5990242.56 468722.09 MWD+IFR-AK-CAZ-SC i 11135.30 90.24 201.01 5860.34 5802.69 -3665.03 -7290.56 5990214.82 468711.56 MWD+IFR-AK-CAZ-SC I 11148.13 91.23 200.91 5860.18 5802.53 -3677.01 -7295.14 5990202.85 468706.93 MWD+IFR-AK-CAZ-SC ', 11167.26 91.74 200.78 5859.68 5802.03 -3694.88 -7301.95 5990185.00 468700.07 MWD+IFR-AK-CAZ-SC ~', ', 11264.07 90.13 201.82 5858.10 5800.45 -3785.06 -7337.11 5990094.95 468664.62 MWD+IFR-AK-CAZ-SC '' 11355.04 92.84 199.78 5855.67 5798.02 -3872.86 -7370.46 5990007.26 468630.99 MWD+IFR-AK-CAZ-SC !L _11452.64 91.88 200.69 5851.77 5794.12 -3961 _55 -7403.15 5989918.69 468598.02 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 6/13/2006 Time: 08:54:01 Page: d ~' Field: Kuparuk River Unit Co-ordinate(tiE) Reference: WeIL 35-23, True North Site: Kuparuk 3S Pad Vertical (TVD) Reference: 3S-23A 57.6 Well: 3S-23 Section (VSO Reference: Well (O.OON,O.OOE,200.OOAzi) Wellpath: 3S-23A Survey Calculation Method: Minimum Curvature Db: Oracle Survc~ __ _ Sys TVD _ ~{S __ E/W JIapN _MapF, _ - .Tool __ <V1D lncl _Azim TVD ft deg deg ft ft ft ft ft ft __ _- __- 11488.22 90.13 200.95 5851.15 5793.50 -3994.80 -7415.80 5989885.48 468585.27 MWD+IFR-AK-CAZ-SC 11547.76 87.63 198.00 5852.31 5794.66 -4050.91 -7435.64 5989829.44 468565.25 MWD+IFR-AK-CAZ-SC it 11598.12 87.05 199.22 5854.65 5797.00 -4098.58 -7451.70 5989781.82 468549.04 MWD+IFR-AK-CAZ-SC I 11644.42 86.02 194.24 5857.45 5799.80 -4142.83 -7465.00 5989737.63 468535.60 MWD+IFR-AK-CAZ-SC i 11737.95 87.91 194.28 5862.40 5804.75 -4233.35 -7488.00 5989647.19 468512.31 MWD+IFR-AK-CAZ-SC 11773.69 91.58 195.27 5862.56 5804.91 -4267.90 -7497.11 5989612.67 468503.09 MWD+IFR-AK-CAZ-SC 11816.83 92.40 193.31 5861.06 5803.41 -4309.67 -7507.76 5989570.93 468492.31 MWD+IFR-AK-CAZ-SC 11832.68 91.65 192.32 5860.50 5802.85 -4325.12 -7511.27 5989555.50 468488.75 MWD+IFR-AK-CAZ-SC 11859.77 90.31 191.91 5860.04 5802.39 -4351.60 -7516.95 5989529.04 468482.98 MWD+IFR-AK-CAZ-SC 11883.47 90.31 191.29 5859.91 5802.26 -4374.82 -7521.72 5989505.84 468478.14 MWD+IFR-AK-CAZ-SC 11929.31 92.85 192.78 5858.64 5800.99 -4419.63 -7531.27 5989461.07 468468.45 MWD+IFR-AK-CAZ-SC 11950.40 91.93 192.54 5857.77 5800.12 -4440.19 -7535.89 5989440.53 468463.76 MWD+IFR-AK-CAZ-SC ~, 11977.57 92.17 192.18 5856.79 5799.14 -4466.71 -7541.70 5989414.02 468457.87 MWD+IFR-AK-CAZ-SC 11992.00 92.30 192.56 5856.23 5798.58 -4480.79 -7544.79 5989399.95 468454.73 MWD+IFR-AK-CAZ-SC li 12017.22 91.10 192.83 5855.48 5797.83 -4505.39 -7550.33 5989375.38 468449.11 MWD+IFR-AK-CAZ-SC ~ 12042.35 89.08 192.63 5855.44 5797.79 -4529.90 -7555.87 5989350.89 468443.50 MWD+IFR-AK-CAZ-SC ' 12073.87 88.05 192.99 5856.23 5798.58 -4560.62 -7562.85 5989320.19 468436.41 MWD+IFR-AK-CAZ-SC '. 12104.30 87.88 194.54 5857.31 5799.66 -4590.16 -7570.09 5989290.68 468429.08 MWD+IFR-AK-CAZ-SC 12137.19 89.73 195.28 5858.00 5800.35 -4621.93 -7578.55 5989258.94 468420.52 MWD+IFR-AK-CAZ-SC 12175.22 89.01 196.45 5858.42 5800.77 -4658.51 -7588.95 5989222.39 468410.01 MWD+IFR-AK-CAZ-SC ~' 12198.19 88.50 197.01 5858.92 5801.27 -4680.50 -7595.56 5989200.43 468403.33 MWD+IFR-AK-CAZ-SC ',' 12233.67 85.41 197.95 5860.80 5803.15 -4714.29 -7606.20 5989166.67 468392.58 MWD+IFR-AK-CAZ-SC '~ 12268.85 81.75 199.16 5864.73 5807.08 -4747.43 -7617.32 5989133.58 468381.36 MWD+IFR-AK-CAZ-SC II 12294.89 80.74 198.95 5868.70 5811.05 -4771.76 -7625.72 5989109.28 468372.88 MWD+IFR-AK-CAZ-SC 12329.86 83.44 198.00 5873.51 5815.86 -4804.60 -7636.69 5989076.47 468361.80 MWD+IFR-AK-CAZ-SC j 12361.35 86.34 198.20 5876.31 5818.66 -4834.41 -7646.44 5989046.69 468351.96 MWD+IFR-AK-CAZ-SC 12389.41 89.11 196.49 5877.43 5819.78 -4861.17 -7654.79 5989019.96 468343.52 MWD+IFR-AK-CAZ-SC Iii 12403.57 89.94 195.76 5877.55 5819.90 -4874.78 -7658.73 5989006.38 468339.54 MWD+IFR-AK-CAZ-SC 12412.18 90.07 195.89 5877.54 5819.89 -4883.06 -7661.08 5988998.10 468337.17 MWD+IFR-AK-CAZ-SC 'I 12485.17 90.24 194.93 5877.35 5819.70 -4953.42 -7680.47 5988927.81 468317.55 MWD+IFR-AK-CAZ-SC 12518.43 89.45 193.69 5877.44 5819.79 -4985.65 -7688.69 5988895.61 468309.23 MWD+IFR-AK-CAZ-SC 12548.64 89.90 193.53 5877.61 5819.96 -5015.01 -7695.80 5988866.27 468302.02 MWD+IFR-AK-CAZ-SC 12580.26 88.77 193.49 5877.98 5820.33 -5045.76 -7703.19 5988835.56 468294.54 MWD+IFR-AK-CAZ-SC, 12615.81 88.52 192.14 5878.82 5821.17 -5080.41 -7711.07 5988800.93 468286.55 MWD+IFR-AK-CAZ-SC 12644.19 88.77 192.83 5879.49 5821.84 -5108.11 -7717.20 5988773.25 468280.33 MWD+IFR-AK-CAZ-SC 12675.61 89.62 192.62 5879.93 5822.28 -5138.76 -7724.12 5988742.63 468273.31 MWD+IFR-AK-CAZ-SC 12707.75 88.73 192.67 5880.39 5822.74 -5170.11 -7731.16 5988711.30 468266.17 MWD+IFR-AK-CAZ-SC i 12739.51 89.38 191.66 5880.91 5823.26 -5201.15 -7737.85 5988680.29 468259.38 MWD+IFR-AK-CAZ-SC ~' li I 12769.77 89.38 192.62 5881.24 5823.59 -5230.74 -7744.21 5988650.73 468252.92 MWD+IFR-AK-CAZ-SC ' 12803.61 89.80 192.98 5881.48 5823.83 -5263.73 -7751.71 5988617.76 468245.32 MWD+IFR-AK-CAZ-SC ~' 12835.73 89.59 192.68 5881.66 5824.01 -5295.05 -7758.84 5988586.47 468238.09 MWD+IFR-AK-CAZ-SC ' ~, 12864.98 87.95 193.62 5882.28 5824.63 -5323.53 -7765.49 5988558.02 468231.35 MWD+IFR-AK-CAZ-SC ', 12879.27 87.16 194.00 5882.89 5825.24 -5337.39 -7768.90 5988544.16 468227.89 MWD+IFR-AK-CAZ-SC i 12886.93 87.15 194.24 5883.27 5825.62 -5344.81 -7770.77 5988536.75 468226.00 MWD+IFR-AK-CAZ-SC i 12926.70 86.61 194.73 5885.44 5827.79 -5383.26 -7780.70 5988498.34 468215.95 MWD+IFR-AK-CAZ-SC 12959.95 86.64 195.93 5887.40 5829.75 -5415.27 -7789.48 5988466.36 468207.07 MWD+IFR-AK-CAZ-SC 12991.77 86.61 196.71 5889.27 5831.62 -5445.75 -7798.40 5988435.91 468198.05 MWD+IFR-AK-CAZ-SC 13023.66 87.19 196.81 5890.99 5833.34 -5476.24 -7807.58 5988405.45 468188.77 MWD+IFR-AK-CAZ-SC 13054.49 87.60 195.90 5892.39 5834.74 -5505.80 -7816.26 5988375.93 468180.00 MWD+IFR-AK-CAZ-SC 13087.47 88.32 196.74 5893.57 5835.92 -5537.43 -7825.52 5988344.33 468170.64 MWD+IFR-AK-CAZ-SC ~ 13119.27 88.53 195.82 5894.44 5836.79 -5567.94 -7834.43 5988313.85 468161.63 MWD+IFR-AK-CAZ-SC i 13150.22 89.01 196.64 5895.11 5837.46 -5597.65 -7843.08 5988284.17 468152.89 MWD+IFR-AK-CAZ-SC 13182.98 89.35 196.20 5895.58 5837.93 -5629.07 -7852.34 5988252.78 468143.53 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 6/13/2006 Time: 08:54:01 Page: 5 Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 35-23, True North ' Site: Kuparuk 3S Pad Vertical (TVD) Reference: 3S-23A 57.6 Well: 3S-23 Section (VS) Reference: Well (O.OON,O.OOE,200.OOAzi) 1Vellpath: 3S-23A Survey Calculation S7ethod: Minimum Curvature Db: Oraale Survey NID Incl Azim TVD Sys 71'D N/S E/~V MapN MapE Tool ft deg deg ft ft ft ft ft ft 13214.83 89.56 196.30 5895.88 5838.23 -5659.65 -7861.25 5988222.24 468134.52 MWD+IFR-AK-CAZ-SC 13244.81 90.38 196.84 5895.89 5838.24 -5688.38 -7869.80 5988193.53 468125.88 MWD+IFR-AK-CAZ-SC 13278.01 88.97 195.39 5896.08 5838.43 -5720.27 -7879.01 5988161.67 468116.57 MWD+IFR-AK-CAZ-SC ', 13308.74 88.25 195.21 5896.83 5839.18 -5749.91 -7887.12 5988132.07 468108.37 MWD+IFR-AK-CAZ-SC '~. 'I 13338.09 87.36 194.01 5897.95 5840.30 -5778.28 -7894.52 5988103.72 468100.88 MWD+IFR-AK-CAZ-SC ~I 13374.73 86.64 194.46 5899.87 5842.22 -5813.75 -7903.51 5988068.29 468091.77 MWD+IFR-AK-CAZ-SC 13408.52 86.64 192.94 5901.85 5844.20 -5846.52 -7911.50 5988035.54 468083.67 MWD+IFR-AK-CAZ-SC ~~, 13435.70 86.33 192.13 5903.52 5845.87 -5873.00 -7917.39 5988009.08 468077.70 MWD+IFR-AK-CAZ-SC 13468.88 87.19 192.92 5905.39 5847.74 -5905.34 -7924.58 5987976.77 468070.42 MWD+IFR-AK-CAZ-SC i 13501.04 87.50 192.93 5906.88 5849.23 -5936.65 -7931.76 5987945.49 468063.13 MWD+IFR-AK-CAZ-SC 13529.46 87.53 192.82 5908.11 5850.46 -5964.33 -7938.09 5987917.83 468056.72 MWD+IFR-AK-CAZ-SC 13565.10 87.60 193.30 5909.63 5851.98 -5999.02 -7946.13 5987883.17 468048.56 MWD+IFR-AK-CAZ-SC 13600.83 88.83 193.19 5910.74 5853.09 -6033.78 -7954.32 5987848.44 468040.27 MWD+IFR-AK-CAZ-SC i 13623.42 90.10 193.30 5910.95 5853.30 -6055.77 -7959.49 5987826.47 468035.02 MWD+IFR-AK-CAZ-SC 13654.25 91.51 193.43 5910.52 5852.87 -6085.76 -7966.62 5987796.51 468027.80 MWD+IFR-AK-CAZ-SC 13687.17 91.61 193.80 5909.62 5851.97 -6117.74 -7974.36 5987764.55 468019.95 MWD+IFR-AK-CAZ-SC ~' 13715.86 91.37 194.64 5908.88 5851.23 -6145.54 -7981.41 5987736.78 468012.82 MWD+IFR-AK-CAZ-SC 13738.26 91.47 195.14 5908.32 5850.67 -6167.19 -7987.16 5987715.16 468006.99 MWD+IFR-AK-CAZ-SC 13779.73 91.71 195.43 5907.17 5849.52 -6207.17 -7998.09 5987675.21 467995.94 MWD+IFR-AK-CAZ-SC 13806.75 91.72 195.49 5906.36 5848.71 -6233.20 -8005.29 5987649.20 467988.66 MWD+IFR-AK-CAZ-SC I 13838.37 91.96 195.80 5905.35 5847.70 -6263.64 -8013.81 5987618.80 467980.04 MWD+IFR-AK-CAZ-SC 13871.23 92.33 196.33 5904.12 5846.47 -6295.19 -8022.90 5987587.28 467970.85 MWD+IFR-AK-CAZ-SC i 13897.99 91.99 195.91 5903.11 5845.46 -6320.88 -8030.32 5987561.62 467963.34 MWD+IFR-AK-CAZ-SC ~ 13930.70 91.85 196.14 5902.01 5844.36 -6352.30 -8039.35 5987530.23 467954.22 MWD+IFR-AK-CAZ-SC ' 13958.17 91.65 195.16 5901.17 5843.52 -6378.74 -8046.76 5987503.81 467946.73 MWD+IFR-AK-CAZ-SC '' 13985.16 90.82 192.78 5900.59 5842.94 -6404.92 -8053.27 5987477.65 467940.13 MWD+IFR-AK-CAZ-SC !, 14025.81 89.75 190.49 5900.39 5842.74 -6444.74 -8061.47 5987437.87 467931.81 MWD+IFR-AK-CAZ-SC ii ', 14056.04 89.66 190.13 5900.55 5842.90 -6474.48 -8066.88 5987408.15 467926.30 MWD+IFR-AK-CAZ-SC 14083.40 90.14 188.51 5900.59 5842.94 -6501.47 -8071.31 5987381.17 467921.79 MWD+IFR-AK-CAZ-SC !' 14144A0 ~ 90.14 188.51 5900.45 5842.80 -6561.41 -8080.28 5987321.27 467912.63 PROJECTED to TD I~ • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 3S-23A, June 26, 2006 AK-MW-4333321 1 LDWG formatted Disc with verification listing. API#: 50-103-2045 3-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~Dlo - b ~3 Signed: '~ 13`~~g STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: aim re~~~~adrr:in.statc-.ak.u~• ~ogc:: prudr,oe ~r:v(~ad:~;n.s~ta.e.ak.us b+~l €eckensten~:n3adrr:i:~.stUte.a>~.i~.s Contractor: Nordic Rig No.: 3 DATE: 5/29/2006 Rig Rep.: Shane McGeehan Rig Phone: 659-7438 Rig Fax: 659-7566 Operator: Conoco/Phillips Alaska Op. Phone: 659-7446 Op. Fax: 659-7566 Rep.: Dink Heim Field/Unit & Well No.: 3S-23A PTD #A430 Operation: Drlg: X Workover: Explor.: _ Test: Initial: Weekly: Bi-Weekly x Test Pressure: Rams: 250/3500psi Annular: 250/3500ps Valves: 2 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 11" P Pipe Rams 1 2 7/8" by 5" P Lower Pipe Rams 1 4" P Blind Rams 1 P Choke Ln. Valves 1 3 1/8" P HCR Valves 1 3 1/8" P Kill Line Valves 2 3 1/8" P Check Valve 1 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Quantity Test Resu Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test R No. Valves 12 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3000 Pressure After Closure 1850 200 psi Attained 15sec. Full Pressure Attained 1 min. 18sec. Blind Switch Covers: All stations P Nitgn. Bottles (avg): 1900psi Test Results Number of Failures: 0 Test Time: 4 Hours Components tested ', Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ~ir:~3 re~~;~adrr:in.state.~a>~.~~s• Remarks: 24 HOUR NOTICE GIVEN YES X NO Date 05/28/06 Time Test start 2:30 Finish 12:45 Waived By Witness Jeff Jones Ben Weden BOP Test (for rigs) BFL 11/09/04 Nordic 3 05-29-06.x1s Ite: 3S-23A (206-043) BOP 7" ram exceptiorl# • Subject: Re: 3S-23A (206-043) BOP 7" ram exception From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Fri, 21 Apr 2006 13:16:19 -0800 To: "Brink, Jason A" <Tason.Brink@conocophillips.com> CC: AOGCC North Slope Office <aogcc~rudhoe_bay@admin.state.ak.us> Jason, Your proposal is acceptable. The key point is that the pathway to the reservoir has been eliminated by the pre-rig squeeze. Call or message with any questions. A copy of this message should be available at the rig with the approved work programs. Tom Maunder, PE AOGCC Brink, Jason A wrote, On 4/21/2006 11:13 AM: Tom Per our telephone conversation, this is a follow up in writing for the 7" ram test exception. The following is an estimated order of operations: Fin spotting rig over well after Top drive Install & Rig up Load 4" DP into pipe shed and check wellhead pressures Pull BPV thru lub. and Circ out freeze protect diesel to rock washer, -250 bbls Set BPV ND tree and adapter, Install blanking plug NU BOP stack Test BOP's 250!3500 psi for 1 week test Pull blanking plug &BPV, Unland Hanger with Jt of tbg Stand back 1,000' of tbg F/Cmt Stinger & LD remaining-9,000' of tbg RU & test 7" csg rams MU CIBP & RIH on 4" DP, Setting same at 4,440' BOP configuration will be as follows: • Annular • Blind ram • 7" ram Current status of the well is as follows: • Perforations have been squeezed with cement through retainer • Cement spotted over cement retainer • CMIT passed • 3-1/2" tbg has been chemically cut The bottom 7" ram cannot be tested with BPV and test plug installed. It is requested that the 7" ram be tested after the tubing is pulled. Please verify the 7" ram test exception is acceptable. 4/24/2006 8:42 AM i ~~ n ~' 33 ~~ (t ~ S ~ i ~ at a id ~ d 4 9 ~.. ALASSA OIL C011i5ERQATIOI~T C01-IDII Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk Oil Pool, 3S-23A ConocoPhillips Alaska, Inc. Permit No: 206-043 Surface Location: 2560' FNL, 1246' FEL, SEC. 18, T12N, R8E, UM Bottomhole Location: 192' FNL, 38' FEL, SEC. 26, T12N, 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 an approval 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 file NPrrrlit 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of April, 2006 ~~ ~ ~ ~',~' ~. ( ' ~ ~ ~ ~~ ° r -~ FRANK H. MURKOWSKI, GOVERNOR .. /~'-r1~ ~~ ~~+ t][va ~~ 333 W. 7TM AVENUE, SUITE 100 SIOr1T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 S FAX (907) 276-7542 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~ ~ ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.I.thomas@conocophillips.com March 27, 2006 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 3S-23A Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 3S-23A, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). The expected spud date is April 20, 2006. If you have any questions or require any further information, please contact Jason Brink at 265-6419. Sincerely, Randy Thomas GKA Drilling Team Leader • STATE OF ALASKA r~ws ~~CEIVEC}' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~k ^ ~ 0 2006 :~ ~„ ~~~~ta f3s1 ~ has C~fls. COmmis~0tr, 1a. Type of Work: 1 b. Current Well Class: Exploratory Development Oil Q 1c. Specify if well is proposed for: Drill ^ Re-drill ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone ^ Single Zone ^ Shale Gas ^ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180' 3S-23A 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15947" TVD: 5919' ~ Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2560' FNL, 1246' FEL, Sec. 18, T12N, R8E, UM ' ADL 25544 8~ 25551 Kuparuk Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 245' FNL, 3452' FEL, Sec. 24, T12N, R7E, UM ALK 2639 & 2616 4!20/2006 Total Depth: 9. Acres in Property: 14. Distance to ,.../,~: 192' FNL, 38' FEL, Sec. 26, T12N, R7E, UM 2560 Nearest Property: ~aailes ~f,'1,o6 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Barest i 3S-Z ....~g~p aw~~'( Surface: x- 476013 ~ y- 5993856 ~ Zone- 4 (Height above GL): 30' RKB feet Well within Pool: 3S-23 , 192' @ 1 Q227 16. Deviated wells: Kickoff depth: 4150 ~ ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.8° deg Downhole: 3433 psig Surface: 2782 psig 1 S. Casing Program ifi ti S Setting Depth Quantity of Cement pec ca ons B tt T Size om op o c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8.5" 7" 26# L-80 BTCM 10431' 30' 30' 10431' 5859' 210 sx Class G 6.125" 4.5" 12.6# L-80 BTC 5716' 10231' 5845' 15947' 5919' Slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 10535' 6130' 10236' 5873' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 65 bbls ArcticCrete 108' 108' Surface 4020' 9-5/8" 6 6 sx ite 341 sx 4040' 2604' LiteCrete Intermediate 10499' 7" 256 sx Class G 10519' 6116' Production Liner Perforation Depth MD (ft): Perforation Depth TVD (tt): 10217'-10244' 5857'-5880' 20. Attachments: Filing Fee ^/ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program 0 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact JaSOrI Brink @ 263-6419 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~'~'`~ Phone 2G5 6 8 3a Date '~ /Z7 /p (, _ P r n A/ D Commission Use Only Permit to Drill API Number: Permit Approval See cover letter / Number. .~,~p "a~3 ' / 50- ~D3 ~' ~-+~ Y S~ ~ ~ t Date: . ~ . for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed met ane, gas hydrates, or gas contained in shales: Samples req'd: Yes N Mud log req'd: Yes ^ No [yY Other: ~~~ ~ c~`~ ~~,~` MV ~"L~~ ~~ H2S measure Ye ^ Directional svy req'd: Yes ~ No ^ . ~~ V, APPROVED BY THE COMMISSION ~ ,COMMISSIONER DATE: E vie , ,/, ,/ »/_ ~ mi n up i e ~/• ~/- v - - - ,a.y , ,.-- ~~ y~y~~ A~tion for Permit to Drill, Well 3S-23A Revision No.O Saved: 17-Mar-O6 .~ ~~~a Permit It - Kuparuk Well 3S-23A • ~ ~•, ~k App/ication for Permit to Dril/ Document '•~ 11~1~~cWll M p x i m i z E well Value Table of Contents 1. Well Name .................................................................................................................2 Requirements of 20 AAC 25.005 (f) ........................................................................................................ 2 2. Location Summary ................................................................................................... 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. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 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 Condition Analysis ..................................................................................... 6 Re uirements of 20 AAC 25.005 c 11 ................... q ()( ) ............................................................................. 6 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 3S-23A PERMIT lT Page 1 of 6 Printed: 17-Mar-06 O~~GINAL • A~tion for Permit to Drill, Well 3S-23A Revision No.O Saved: 17-Mar-06 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. Attachments :...........................................................................................................6 Attachment 1 Drilling Program Attachment 2 Directional Plan Attachment 3 Well Schematic Attachment 4 Cementing Details Attachment 5 Drilling Hazards Summary 1. Well Name Requirements of 20 AAC 25.005 (f) f«acfT avelf must be identified by a uniq~ac; Hanle cfesiarated Ly the operator and a unique API nutrrf~er assigned try the cornnTissron trnrfer 2(7 AAC'?S.l1~tJ(bj. f=ur a ~relf ~J~t:ff tnuftfpfe evelf Branches each firanch rrnrst.~inr<Iarly fie identified Ley a ut~igcte tTame and API ntrnr~er b¢~ addirxi a suffix to the name designated l;~ar the vreli ~;~ the operator atTd tG the t~~>ntJ~er assrgne;~' t:~ the !~~eif Lay the con~n~issfon. The well for which this application is submitted will be designated as 3S-23A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) AfT ap,GllCatlGrl fGr c? PC'rn7it tG J7rt/f f71UStJE? aCG't}fn,C%8nlcd f?¢` cc~CfJ Ctf t}7C fC1//GV`/inC-/' l~cTn5, L'XCept f:7r an It£'iTt df!"es7dy Gn ~fC #~sJ~fJ tf7e cotnrnrs~ion and identified in the ~vpfication: (2) a pfr7t identit~~ing the prG,t~ert}F and the property's G.F~ners atTd shG~vtnQ (AJtfTe coGrdinatRs ~f tf~e pror7GSed kx~~tfon Gf the ivRtf at the surface, at the top Gf ear fT ot~jecti~~e fGrrnation, rand af' trtai depth, rRf:RrerlCed tG gGVerntnentaf ser7-irn fines (C3) ft~e ~:GOrdinates Gf the propnsed focatiGri of the yvelf at file surface, referenced tG rile state pfane coGrdin~te system for' tfrr5 state as nTaintained by t/Te NatiorTaf Geodetic StErve}~ irr tfre IYativria! tlLeat;~ic arTd Attrosphetrc AclrTtrnrstration, (C; tfTa prc?,oGSed depth of the well at ttTe fap ufeac:ft c~L?ective fGtrrratiorT and at total depttt,• Location at Surface 2560' FNL 1246' FEL, Sec 18, T12N, R8E, UM US State Plane 1927, NAD 27, Alaska Zone 04 RKB E/ovation 57.7' AMSL Northings; 5,993,856.07 Eastings: 476,013.11 Pad Elevation 27.7' AMSL Location at Top of Productive Interval Ku aruk C-4 Sand 245' FNL and 3452' FEL, Sec. 24, T12N R7E, UM US State Plane 1927, N.40 27, Alaska Zone 04 Measured De th, RKB: 10 381' Northings; 5,990,916.95 Eastings: 468,990.77 Total ~ertica/De th RKB.• 5854' Total t/ertica/ De th SS.• 5797' Location at Total De th 192' FNL, 38 FEL, Sec. 26, T12N, R7E, UM US State Plane 1927, NAD 27, Alaska Zone 04 MeaSUred De th, RKB: 15 94T ' Northings: 5,985,698.78 Eastings: 467,106.36 Total t/erticalDe th RKB: 5919' - Tota/ ~ertica/ De th SS.- 5861' ai7d (r7) otfler ;i~fortrlatiGn require d Ly 2l1 AAC 25. f35t1(6); Requirements of 20 AAC 25.050(b) If a sv~gfi i.S tG be %Ttentinnalfy de~faterl, the a,Gplication fi?r a Permit to L3r iff F,~t; n 1 CT- 4071;' tncrst (t j inc7c~de a f~laf; dr<~;vt~ to a ,sui/f~hfe sCatR ,sflndvin,~ tfre J~ath of tf~e ,r~rnf~nsed vreflL~Grc; rndu,Ifttq a:7 adjacent feel,<f~nrus ~vitfTin 11111 feet of any portiGn of the f~rop~ced ~r•R1f; 3S-23A PERMIT IT Page 2 of 6 Printed: 17-Mar-06 ORIGINAL • ~tion for Permit to Drili, Well 3S-23A Revision No.O Saved: 17-Mar-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) Arr avpricatiota for a Permit to Brill rrrust Lae accompanied by each of the fcl/o~rif~g i(en7s; except fvr arr rt~-rn already ct ~ llfe Witt, tare cc>r~7n~isslot~ arrd ider~tifred rr~ the atop/l<_:atic~r;: (5) a descriptfcata of the procedure for cnndtrctirg f^rrnation integrity tests; as reagt>irert under Zt7 AAC 25. f1~f1(t~,, A procedure is on file with the commission for performing LOT's. For 3S-23A the procedure will be followed. If a 16.0 ppg EMW or the maximum EMW specified in the wellplan is reached without indication of leak- off, then this becomes the data for a formation integrity test (FIT) instead of a leak off test (LOT). 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An appiicatlon frr a Permit to frill Irrust be accvinpanied by each of the foiiov~it7g items, except for an itetta already on fife With thc> CCl17fI?aiSSiC3t1 and ,"."/E'P7tif~Ec7 it t}7C,' c?,IJpflCc7ti'CJt7.` ~6j a c ;~trrn, l„te proposed cr3srt ~g ar~d cerrrer~trt7G7 pr~gratn as regctired by Zt1,4AC ~~: £~3L1, ~~t~d a drvsc;riptiotl of airy slotted iir,,:r, pre petfcrated finer, nr sereen to fie ittstallerl Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weight Length MDlTVD MD/TVD OD in in Ib/ft Grade Connection ft ft ft Cement Pro ram 7" 8-1/2 26 L-80 BTC-Mod 10431 surface 10431/5859 Planned TOC = 9432' MD, 949' above top of Reservoir 4-1/2" 6-1/8" 12.6# L-80 CSG BTC 5716 10231/5845 15947/5919 slotted liner pattern: 2" Liner x .1875", 12 slots/ft 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) Ara ~~fapficati!;ra fnr a I'ert7tft tca Llriff n?ust fle accnmparied fy each of the f~tlov ing Items, ,~xcect f~;r ara it.;m airea~a'V ara file v/ith the corntnC~ican a~~d identified lri fire appii ~~tlora,° (%J a diagr atn attd de_s; ripfi;;r~ rf tft;~ divertr~r systetr~ as recicrired h,€~ Ztd DIAL" <?5, f~35; unless this reciuiretnet~t t"s Waived try tf~e corrrrrxissiL~an under ?_CI AAL' <)5: tI,35'(h)!Z,),` No diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) Aft applic;atl;ar~ for <, Petrrr.:t to f7riil Inust!~e accafnpahied fay each of tl?e folio~:jing items, except for t`an item already cn ftl.~ Witit the coinrnission and ldenti~ed ir, tf;,=. ~.np/Ic<~fiora.° (b'j a ~f~:zllfr?g dui<l,c~r agratr, h~cludinax <~ diagram and description of the drilling fluid sysL rn, as reg~~irecl ~~y ~`1,QAC: 25: (1.33; Intermediate Drilling will be done with an LSND type mud system and the production hole with adrill-in mud system. Drilling will be done having the following approximate properties over the listed intervals: 3S-23A PERMIT lT Page 4 of 6 R Printed: 17-Mar-06 t ~~ ~~ ~~ 8-1/2" Hole mud properties ~ation for Permit to Drill, Well 3S-23A Revision No.O Saved: 17-Mar-06 INTERVAL MUD PROPERTIES __ API Fluid Depth MD Mud Wt. Yield Point Loss (ft) (ppg) (Ib/100ft2) (ml/30min) Solids (%) pH Initial 8.8 - 9.0 14 -18 < 8 6 - 10 9.0 - 9.5 4,500'- 5,500' 90-9.4 18-20 <6 6-10 9.0-9.5 5,500'- 6,500' 94-9.7 20-22 <5 7-12 9.0-9.5 6'500'- 7,500' 9.7-9.9 21 -28 <5 7-12 9.0-9.5 7,500'- 8,500' 9g_10.2 21 -28 <4 8-14 9.0-9.5 8,500'- TD 10.2-10.5 21 -28 <4 10-15 9.0-9.5 6-1/8" Hole mud properties INTERVAL MUD PROPERTIES API Fluid Depth MD Mud Wt. Yield Point Loss (ft) (ppg) (Ib/100ft2) (ml/30min) Solids (%) pH 10,432' 15,497' g4-11.6 ~ 17-25 <4 6-10 9.0-9.5 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25..033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Nordic Calista Rig #3. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) Ar, applic~~tior, tear ~ Permit to L3rilf n?~rst be accon;parriccf fey each ofthe :¢olfo~rG~r~ iten7s; ;:xcel.,r far ar; if~rn atrra~'y on fi/e ~ittt tt~e ;:GCT1rrTlS.51L>t7 anr~ ftfr'.ntlflel~ IfI tfte dp~L3~'(;r3tiC?IJ; {~`-~l f01 r?f1 ~vXl7/Urc'~"Or/ ~/" SfI"c7~"If,~;'"s?f?~71v`' t,;:s'f ;~`dEf'~~ c3 C`:3~3Ufc3~"IL3f7 _SP.tClll~ !iCtt` ~17~ f7`r',I7tf1S Gf•~.11"Ff~tt:~"£'Cf dfiPi;7f717r31~}~ LJe'!i-j?f`L'S5Uri-'CI` S~f~~~c7 d,S r:'C/utr!'c~ l1y <?tl AAC°?5. (J.i3(fJ; N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) Arf application far a Pefnit tf~ 1~frt! rfrust ae acc:arfapaniecf 6y eacf; of tf~e foI/o~/in~ sterns; ~.~Lc~t for Cff rta;nr alr~~c.~`y vf~ ~t~ ~~rtt; lf~e ce~rr~n~ission af~cl ider7tlfieo'~, tl~e application. (I t1~ fcr ar, exptorator;/ or sfratiyrap/sic test ~v~~l a s~~isn~ic f c>fiaetion of " ! c~fie-ctivf~ ~rraly~~is ~~s rc~~fil elf 6y ~'fJ AAC ~.~, tT~Z; a~,~ N/A -Application is not for an exploratory or stratigraphic test well. 3S-23A PERMIT !T Page 5 of 6 Printed: 17-Mar-06 ®~~~1,~~~tif`~~ ~tion for Permit to Drill, Well 3S-23A Revision No.O Saved: 17-Mar-06 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(i 1) Ar; applicatirrr fvr a Permit to Llrill most he accrrnpanied Ley each rf the folr~~rr"rry iterrrs; except f.~r ar; item already vr; fi!e s e itt; tf.=e corrrrnis~irn and identified ir; the application: (11J far a well drirled frnm an offshore piatforn, n;rf;ile t~o?tnrn-fronded stroctcrr~ jack-up rir~, rr orating drilling vessel, an anafrsis ofse<~Led crrr:litirns as required by 2f1 AAC 25, t161(L),• N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application frr a Permit to Qriil must ehe accornpartied ley eacf, rf the fotirvru;g item except frr an iterrr already on hle ~vrtti the ~c~rrtrr;;ssirrt and identifed in tt;e a~a~/icatiun: (1 )) evidence shr~ing that the requireir;ents c~f2t1 AAC` 25 g25 {Brndinq}have been nret,• Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) ,4n applicati!;n fcr a Penr;it tr f)rill must be accompanied by each of the following items, except frr an item alrea:~y on hIe .s~ith the rcmmissron artd identified in the <~pc~liraticrr,° Please see Attachment: Drilling program. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application fc~r a Per-rrtii tr l7rill rrxrstc be accorrapanied by earth of tt;e frlio~~~ing items axcept frr an item already rn frle with the ccmrnission and identified in the application.• (~`li a general description ofPrcw the operator plans tr disprse rf drillinr~ rncrd and cuttings and a statement of whether the rperator ir;t:=nc~s tr request ar~thorization under 211 AAC° 2S t180 for oat annular disposal rireratinn in tltt: wetl.,• Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well or by injection into a permitted annulus on 3S pad. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage there and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 3S-23A for annular disposal of fluids occurring as a result of future drilling operations on 3S pad. 15. Attachments Attachment 1 Drilling Program Attachment 2 Directional Plan Attachment 3 Well Schematic Attachment 4 Cementing Details Attachment 5 Drilling Hazards Summary 3S-23A PERMIT IT Page 6 of 6 Printed: 17-Mar-06 nn~~~~nt n L. 3S-23A Drilling Program Pre-Rig Well Work: 1. Test wellhead Packoffs and lock down screws. (12/12/05.• POT & PPPOT-T & IC -PASSED, FUNCTION TEST LDS's -ALL PASSED ) 2. Set 3.5" cement retainer in tubing tail at 10135' and .Circulate tbg/IA to brine thru open GLM @9996' md. 3. Perform combo MIT. 4. RU CTU and sting into cement retainer. Sqz cement away. Un-sting and leave 60' of cement above retainer. 5. Tag and pressure test the cement plug. (AOGCC witness needed) 6. Chemical cut 3.5" tubing at 10,020' 7. Set BPV and prep wellhead for rig arrival. Rig Work: 1. Move in and rig up Nordic 3. Remove BPV and install and test two way check. 2. Nipple down tree and tubing head adapter. 3. NU and test the 11" x 5K BOPE to 250 PSI / 3500 PSI. 4. Pull two way check. 5. Pull and lay down the tubing hanger. Stand back 1000' of 3-1/2" tubing and lay down the remainder. 6. Set wear bushing. 7. Rig up E-Line. Make up 7" cast iron bridge plug and set inside 7" casing at 4440' MD. 8. Chemically cut 7" casing at 4240' MD which is 200' below the 9-5/8"surface casing shoe. 9. Pull wear bushing. Make up 7" landing joint (spear if necessary) with J latch running tool and pull 9-5/8" x 7" packoff. MAKE UP 7" landing joint with 8-1/2" left hand Acme running tool and pull hanger and casing. 10. Ensure 7" casing is free and circulate hole to 9.2 PPG LSND. 11. Pull and lay down 7" casing. Test all casing for NORM. 12. Install wear bushing. Make up 3-1/2" mule shoe, 1,000' of 3-1/2" tubing stinger, 4"drill pipe and RIH to plug back total depth at 4440' MD 13. Spot a 700' balanced cement plug on top of cast iron bridge plug with the top of cement inside 9-5/8" casing shoe at approximately 3740' MD. POOH 3 stands above the top of cement and circulate above cement plug. ~i~~'~Nj `~ 14. Pull out of hole and lay down 3-1/2" tubing stinger. ~c^~~ =}~s~- ~~~~ r~~`C ~,.~ C~.~./~ 15. Pick up drilling BHA, 4"drill pipe, and run in hole to top of cement and tag for cement hardness. Test 9-5/8"using to 3000 PSI for 30 minutes and record on chart. -Start of Drilling operations for New Well 3S-23A 16. Drill to kickoff point and drill out 20' to 50' of new hole. Perform LOT. Minimum 12.5 PPG EMW LOT required based on kick tolerance. Expect 14.1 PPG LOT based on old wellbore. OR161NAL 17. Directionally drill 8-1/2" interme a hole section through the top of the Kup c C sand landing at approximately 10,431' MD and 85 degrees deviation. 18. Run and cement 7" casing as per program bringing the top of the cement back to 9432' MD. Land 7" casing and hanger. Install packoff. Flush 9-5/8" x 7" casing annulus with seawater then freeze protect casing annulus with diesel. 19. Install wear bushing. Make up 6-1/8" drilling assembly. Clean out to float collar and perform 30 minute casing test to 3,000 psi. Drill out 20 to 50 feet of new hole and perform LOT. Minimum LOT is 13.4 PPG EMW to compensate for expected ECD in this hole section. 20. Circulate hole from LSND to drill-in fluid. 21. Drill 6-1/8" horizontal section to well TD at 15,947. 22. Circulate the hole clean and pull out of hole. 23. Run 4-1/2" slotted liner and liner hanger. 24. Set liner hanger and liner top packer. Test annulus to confirm set of liner top packer. Release hanger running tool. POOH. 25. POOH, laying down drill pipe as required. 26. Run 3-~/z, 9.3#, L-80 tubing with profile nipple, gas lift mandrels and stinger assembly to depth. 27. Circulate corrosion inhibited fluid into the 3-1/2" x 7"annulus. 28. Sting in, space out and land hanger. Run in lock down screws. Pressure test the inner annulus. 29. Install two way check. Nipple down BOP. Nipple up adapter, tree and test to 5000 PSI. Pull two way check. 30. Pressure annulus and shear valve in gas lift mandrel. Freeze protect the tubing and IA with diesel. 31. Set BPV. 32. Move rig off. Post Rig Procedure 1. Rig up slickline and install gas lift design. 2. Flowback well to tanks to clean up returns before diverting into production facility. 3. Put well on production. ORIGINAL Conoco hillips Alaska ConocoPhillips Alaska (Kuparuk) K~par~~k 12ivpr l,~nit Kuparuk 3S Pad 3S-23 Plan 3S-23A Plan: 3S-23A (wp07) Proposal Report 22 February, 2006 • HALLIBtJRT01"~ Sperry Drilling Ser~rices ORIGINAL O d ~~ w ~ ~N c J " 0 J W Z Q U oZ M ~~ N ~ ~p pi ~ ~ J M ~ N ~ y ~ J p~~ M O C N J O lL p W ~ r CO Z <n O O N O Z4 +o ~~ N N_ ~ ~ ~ ti ~ d U ~~ N Z~n~ ~~0~0 CV •- f~ O ~ 07 ~ O to ~nM(~O O ~ ~ N t~ ~ O Z ~ N M Q I II I u FT' I I i ~ °a C I II 3 I II o ~ I II ~ ~ I II I II o ~ I II H ~ I Ii ~ 3 ~' - - _ - i I I M ~ ~ -__--_- a I II ` ,_,- _ Q ~ --- ~ II , ~~ .-. N - ,, I III ~~ ro ~ ---J I`I I -~~ ~ m M J = I n I II _- ~ ~ N a m 111 I II ,-' -'~ ~ M ; ~ I I II - ~- N N I II I II , - p ~ ~") ~ I 11 ' ~ n 3 ti t i t ' r I 11 - " 3 J M .. ~ i II I II I I I ~ N rn "'~ n ° 3 M ~ ~ ~ I t l LL ' r ~' O I II J ~ 111 ~ N C ~ N I II n M o N V -~ N 1 II I II n ' ~ d ' M I II , - v C G L ~ F ~ Q N ~ III ..-~ _ fA I ~~ o O d I II `I I 3 ~ I - d ~ 1 __________________ r ~ ~ \ ~ ~ I I N N a+ + I I o M ~ ~ ~ ~ C O ~,, Yom'! ' ~ I I ~ ~ I , a 3 ~. \ U ~ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ N C ,I 1 ~ II H Q \ ~ I r~ N (~, v ~ _ _ _ _ _ _ _ _ _ I _ I N -------- - _ _ - ~ r ~ - 3 N N M O r ~ ~( v ~ ~N V _ _ _ _ II - - - ~~ .c a T 8 u o ~, V \\ - - \ ~, ~~ ... .C ~~ Q^ N~ N~ fl. R'M~''~M Sti x Y N ~ ... ~c~ ma ~(OM~.N X a M Y~ ~ .. W ~ C o~ ~°- d ti ~' 0 I I I II - ~- I;I~ Q I uI III 1 II I I ly I~ 1 1 I II III 1 ~ ,1 1 U i ~ It II' ~ ~~ I 4 II II ~~ i it III ~ ~` II II I I r ~~ II II ~ 1 r I I i t I I I ( ~ I I I I ~ l r ~ I I II I I \ I I I I I I I II p'il ~ i t 1 1 l I `y1Q , I I I II II 1 3P` r I ' I II , I n~' L ~ I I I I I ~ Q I I I i I II I r I ~ I I I II I ti r r ~ ~ ~ ' I II I~ I ~ I I II I i ~ ~ ~ r ~ C1 I ~ i I I 11 I I I I I II Q ~ r ~ ~ i I II II U ' I II I ~ h ~ p rL III I o I II >Z I ~ ~ n i I II ~ I II x C O P 111 Q i I II ~ ~ C I I II Y i II 3 ~~-. C o ~ ~ I I I R I II J ~ Y I n °~.~ ~ R rn ~ I u I I I a j f u I II ~ I II '~ m I I I In N M 0 n °o N 0 °o 0 O Oni 0 rn 0 o ~ h O O Lf') o° `-' ~ o O o N N ~ ~ C O o° ~ N ~ > M O C7 N O r u o o ~ ~ if ~~ N O ~ ~ N O ~ N M M 7 ~ ~ ~ (~!M 0051) U;daa !e~!~an anal c S ~ Z "' a N ~ 0 ~ O s N N M ~(/y~ .1C Y C ~ 2 2 ~o~ g a ~ ~ d°~ N N~ r a~ ~ O N N a ~~ ~ M ~ fn ~ h at ~ .W~ Y YM ~M W J ~ H ~'` .~-/ o l„) ;L d y (~ J Q d V ~ o ~ 'sN~~a I ~ ~~°°'+. ~ ~Z ° a o ZooF~v a N _~ S~~ ' 1f! 00 O ~ c'~ O J ;~ u~1 ~ B' h' '~ ~ Z a ~ J > or o ~~ 0L ! LL (~ ~ f0 ~ ~ e- ~ ~ _ M fA tY O ~ Q r r V ~ I~~, M t~D, ~ ~ FQ- ~ w ~ c~~ ~~N rn o w e ~ ~ o o ~ L OU 9~ ~ ~ N ~ u~'J co 60 ~ ~ W i ~ i r '• C N ~ ~ ~ ~ 01 oM P CO ~ Of ~ ® ~ ~ T O Z-NM o '~ Zo~i ~ 3o ~ o O O ~ ~ ~ ~ w C + ~ ~ Ui ~ ~ :S ` ° I ~ I Q N tD ' r ~ ` I ~ I ~ 7 ~ d (' O O N 0 i ~ ` C i ~ I m d 3 O c' _ C O ' ~ ~ I i I tl! i fb V ~ 7 C C C ~ p p lO r ~ ' ~ ' ~ i 'O` ~ U ~ V O ~ I v + ~ ~ I I I ~ ` h ~ 0 ~ ~ ~ ' ' ~ 8° , ' I I I , ' . I I I ~ o ~ W '~ ~ ' ~ / MN ~ I I I I i ~ ~ ~ c~ ~F-o~oo ~ ~ ILNrN~ ~ ~ .:.. ~ / / ` I ~ ~ _ ~ V R ~ \ o L Q ~ ~ ~ ~ ~Op, l I I I II I I I i ~ ~ ~ 4- O ~~ ~„m O z ~L-~Q N N L C d~~ 0 ~ o N ~ 4 1 Q ~ E O V 7= ~ ~ ~N ` ` i ~ ` ° ~ ~~ ~' Y ~ ti i ~ ~ N `" ~ I I ~ ~ i ~ ~ N rn O ° ~ ~~ G J N ~ g G ~ ~ / ~ ~ D ~ i ~ i ~ II I I II i I ~ ~ I ! ~ ~ ~ F ~ ~ 0 ~ ~' ~ O d Y N ~ t~D ` O O I ~ ~ i r li u ° , I ~ ~~ ~ LLY , ~ ~ N ~ ~ ~ rn aa,, ~ 2 c A o v o ~ '~ ~ ~ ,~ ~~ ~ ~ m ~ 'a ~ L ~`' o ~ ~ ,, ; ' ` I ~~ ~ p _ , •. i ~ i O r i ~ i ~ ° i i ~ I i I ' 1~ ` '7 I II N r ~ ~ N 3 H 4 i i r n ~~ ~ ` ` I - i ~ o' i `~ ~ i O V V °g ~ „Q ~ a 3 . . R ; v a N 3 I I ~ I ~ j. o o0 C ~ ~ 4 FM- ~ ~ ~ ~ 3 i0 ' ~ ~ ~ w N J N N LL N a ~; p H ; p O ~ d ~c O U3 U) a, cn n M N `" ..J en M _ ¢ r- 3 a ~ ~ O u~ ~~~~~ ~ O ~ M i+) N N ~. ~ ~ N M ~ A Q I-- ~ S M~` V ~ in M eh N N N Q ~ M N ~ O I- ~ O O U 3 m N N M V N ~u!/u 0090 ~+)4UON/~-)4}nog o 0 N p O O O O O O O O O O O O ~ ~ ~ ~ ~ r ~ O N M M ~ ~ ~ ~ ~ ~ ~ 61 • Halliburton Energy Services ConocoPh~llips Alaska Planning Report -Geographic 'abase: EDM 2003.11 Single User Db Local Co-ordinate Reference: W pany: ConocoPhillips Alaska (Kuparuk) TVD Reference: 3: )ect: Kuparuk River Unit MD Reference: ' 3£ Kuparuk 3S Pad North Reference: i ~ Tr I: 3S-23 Survey Calculation Method: ~ I Mi lbore: Plan 3S-23A ' ign: 3S-23A (wp07) ~. ,~ ~.-: - .. • HALLIBURTON Ku aruk River Unit North Slo a Alaska United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 3S-23 Well Position +N/-S 0.00 ft Northing: 5,993,856.07 ft Latitude: 70° 23' 39.634" ~ +E/-W 0.00 ft Easting: 476,013.11 ft ~ Longitude: 150° 11' 42.590" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Plah 3S-23A .. d Strength (nT) BGGM2005 12/7/2005 23.96 80.78 57,541 3S-23A w 07 Audit Notes: Version: Phase: PLAN Tie On Depth: 4,150.00 1'SQCtion; Depth From (TVD) +N/-S +El-W Direction (ft) (ft) (ft1 (°) 30.00 0.00 0.00 200.00 2/22/2006 3:47:49PM ORIGINAL COMPASS 2003.11 Build 50 • n Halliburton Energy Services ConocoPhillip~s Planning Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: W Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 3E Project: Kuparuk River Unit MD Reference: 3; Site: Kuparuk 3S Pad North Reference: Ti Well: 3S-23 Survey Calculation Method: M Wellbore: Plan 3S-23A 3S-23A w 07 a=~ x.,;~,x~;=~,,. .sc~.•Aydm~~:,ax~.~d Design: (P ) ~'nionm~®~ n Summar y __ _- easured Vertical Dogleg Rate Build Rato Turn. Rate TFQ "Depth Inclination Azimuth ° Depth +NI-S +E/-W f (°I100ft) (°/100ft) (°f100ft) (°) ::* (ft) (°) ( ) (ft) (ft) ( t) 4,150.00 62.53 251.14 2,655.88 -944.93 -2,453.31 0.00 0.00 0.00 0.00 4,250.00 58.53 251.14 2,705.06 -973.07 -2,535.68 4.00 -4.00 0.00 180.00 4,432.63 54.27 258.27 2,806.19 -1,013.38 -2,682.17 4.00 -2.33 3.90 127.58 8,970,32 54.?7 258.27 5,047.07 -1,646.95 -5,732.55 0.00 0.00 0.00 0.00 10,427.23 85.00 196.00 5,858.98 -3,005.27 -7,026.44 3.00 1.42 -2.89 -77.22 10,527.23 85.00 196.00 5,867.70 -3,101.03 -7,053.90 0.00 0.00 0.00 0.00 10,725.14 91.83 204.48 5,873.18 -3,286.35 -7,122.26 5.50 3.45 4.29 51.32 10,798.32 91.83 204.48 5,870.84 -3,352.92 -7,152.57 0.00 0.00 0.00 0.00 11,010.31 90.24 194.00 5,866.99 -3,552.76 -7,222.32 5.00 -0.75 -4.94 -98.52 11,080.31 90.24 194.00 5,866.70 -3,620.68 -7,239.25 0.00 0.00 0.00 0.00 11,156.54 89.55 196.18 5,866.84 -3,694.26 -7,259.09 3.00 -0.90 2.86 107.45 11,653.20 89.55 196.18 5,870.70 -4,171.24 -7,397.50 0.00 0.00 0.00 0.00 11,684.76 88.64 195.94 5,871.20 -4,201.56 -7,406.23 3.00 -2.90 -0.77 -165.10 12,211.37 88.64 195.94 5,883.70 -4,707.79 -7,550.79 0.00 0.00 0.00 0.00 12,378.41 87.77 191.00 5,888.94 -4,870.10 -7,589.67 3.00 -0.52 -2.96 -100.07 12,629.22 87.77 191.00 5,898.70 -5,116.11 -7,637.49 0.00 0.00 0.00 0.00 13,232.34 91.25 205.67 5,903.89 -5,686.93 -7,826.71 2.50 0.58 2.43 76.79 13,424.48 91.25 205.67 5,899.70 -5,860.06 -7,909.93 0.00 0.00 0.00 0.00 13,754.91 88.14 199.84 5,901.45 -6,164.59 -8,037.68 2.00 -0.94 -1.77 -118.03 14,194.66 88.14 199.84 5,915.70 -6,578.02 -8,186.86 0.00 0.00 0.00 0.00 14,394.68 89.88 203.44 5,919.15 -6,763.88 -8,260.61 2.00 0.87 1.80 64.30 15,137.43 89.88 203.44 5,920.70 -7,445.30 -8,556.12 0.00 0.00 0.00 0.00 15,153.16 90.08 203.69 5,920.71 -7,459.72 -8,562.41 2.00 1.24 1.57 51.73 15,918.31 90.08 203.69 5,919.70 -8,160.38 -8,869.85 0.00 0.00 0.00 0.00 15,921.14 90.08 203.75 5,919.70 -8,162.97 -8,870.99 2.00 0.17 1.99 85.18 15,947.00 ~ 90.08 203.75 5,919.66 ~ -8,186.65 -8,881.41 0.00 0.00 0.00 0.00 2/22/2006 3:47:49PM Page 3 of 9 COMPASS 2003.11 Build 50 JRIGINAL HALLIBUATON ~p~rry ~Ir111ing 3~rrvic~s • Halliburton Energy Services . ConocoPhill>Ips Planning Report -Geographic tabase: EDM 2003.11 Single User Db Local Co-ordinate Reference: ~ W grpany: ConocoPhillips Alaska (Kuparuk) TVD Reference: ~ 3E jest; Kuparuk River Unit MD Reference: 13, T Kuparuk 3S Pad North Reference: i ! ` 3S-23 Survey Calculation Method: ` M 1'borsa: Plan 3S-23A ' ,_~ qn: 3S-23A (wp07) ,. _.. ,, ,.,: ,. , W•° • HAL.LIBURTON Sperry C)ri~~iing Serv~e~~t _._ ;II 3S-23 -23 L1 Pian @ 57.70ft (Nordic 3 (30+27.7)) -23 L1 Pian @ 57.70ft (Nordic 3 (30+27.7)) ie iimum Curvature 3S=23A (wp07) Map Map MD inclination (ft} (°) Azimuth (°) TVD {ft) SSTVD (ft) +N/-S (ft) +E/-W (ft) Northing (ft) Easting (ft) DLSEV (°/100ft) VertSectio ~' (ft)` 4,042.50 62.98 252.38 2,606.74 2,549.04 -914.91 -2,362.54 5,992,948.83 473,647.89 0.00 1,667.77 9 5/8" Csg Pt. 4,150.00 62.53 251.14 2,655.88 2,598.18 -944.93 -2,453.31 5,992,919.11 473,557.02 1.11 1,727.02 Planned KOP - Lowside Kick-off Drop @ 4°/100ft, 4150ft MD, 2656ft TVD ' e~Onnn 80 g3 251,1a 9,679,71 2;fi22.01 -959.14 -2,494.90 5,992,905.04 473,515.39 4.00 1,754.60 4,250.00 58.53 251.14 2,705.06 2,647.36 -973.07 -2,535.68 5,992,891.24 473,474.57 4.00 1,781.64 Continue Dir @ 4°l100ft, 4250ft M D, 2705ft TVD 4,300.00 57.33 253.02 2,731.61 2,673.91 -986.11 -2,575.99 5,992,878.33 473,434.22 4.00 1,807.68 4,400.00 55.00 256.94 2,787.30 2,729.60 -1,007.67 -2,656.18 5,992,857.03 473,353.98 4.00 1,855.37 4,432.63 54.27 258.27 2,806.19 2,748.49 -1,013.38 -2,682.17 5,992,851.40 473,327.97 4.00 1,869.62 Sail @ 54°Inc & 258°Azi : 4432ft MD, 2806ft TVD 4,500.00 54.27 258.27 2,845.53 2,787.83 -1,024.51 -2,735.72 5,992,840.45 473,274.39 0.00 1,898.39 4,600.00 54.27 258.27 2,903.92 2,846.22 -1,041.01 -2,815.20 5,992,824.20 473,194.86 0.00 1,941.09 4,700.00 54.27 258.27 2,962.31 2,904.61 -1,057.52 -2,894.69 5,992,807.94 473,115.33 0.00 1,983.79 4,800.00 54.27 258.27 3,020.70 2,963.00 -1,074.03 -2,974.17 5,992,791.69 473,035.80 0.00 2,026.49 4,900.00 54.27 258.27 3,079.09 3,021.39 -1,090.54 -3,053.66 5,992,775.44 472,956.27 0.00 2,069.19 5,000.00 54.27 258.27 3,137.48 3,079.78 -1,107.05 -3,133.14 5,992,759.19 472,876.74 0.00 2,111.88 100.00 5 54.27 258.27 3,195.88 3,138.18 -1,123.56 -3,212.63 5,992,742.94 472,797.22 0.00 2,154.58 , 5,200.00 54.27 258.27 3,254.27 3,196.57 -1,140.07 -3,292.11 5,992,726.68 472,717.69 0.00 2,197.28 5,300.00 54.27 258.27 3,312.66 3,254.96 -1,156.58 -3,371.60 5,992,710.43 472,638.16 0.00 2,239.98 400.00 5 54.27 258.27 3,371.05 3,313.35 -1,173.09 -3,451.08 5,992,694.18 472,558.63 0.00 2,282.68 , 5,500.00 54.27 258.27 3,429.44 3,371.74 -1,189.60 -3,530.57 5,992,677.93 472,479.10 0.00 2,325.38 600.00 5 54.27 258.27 3,487.83 3,430.13 -1,206.11 -3,610.05 5,992,661.67 472,399.57 0.00 2,368.08 , 5,700.00 54.27 258.27 3,546.23 3,488.53 -1,222.61 -3,689.54 5,992,645.42 472,320.04 0.00 2,410.78 5,800.00 54.27 258.27 3,604.62 3,546.92 -1,239.12 -3,769.02 5,992,629.17 472,240.51 0.00 2,453.48 5,900.00 54.27 258.27 3,663.01 3,605.31 -1,255.63 -3,848.51 5,992,612.92 472,160.98 0.00 2,496.18 6,000.00 54.27 258.27 3,721.40 3,663.70 -1,272.14 -3,927.99 5,992,596.66 472,081.45 0.00 2,538.87 6,100.00 54.27 258.27 3,779.79 3,722.09 -1,288.65 -4,007.48 5,992,580.41 472,001.92 0.00 2,581.57 200.00 6 54.27 258.27 3,838.18 3,780.48 -1,305.16 -4,086.96 5,992,564.16 471,922.39 0.00 2,624.27 , 300.00 6 54.27 258.27 3,896.58 3,838.88 -1,321.67 -4,166.45 5,992,547.91 471,842.86 0.00 2,666.97 , 6,400.00 54.27 258.27 3,954.97 3,897.27 -1,338.18 -4,245.93 5,992,531.66 471,763.33 0.00 2,709.67 500.00 6 54.27 258.27 4,013.36 3,955.66 -1,354.69 -4,325.42 5,992,515.40 471,683.80 0.00 2,752.37 , 6,600.00 54.27 258.27 4,071.75 4,014.05 -1,371.20 -4,404.90 5,992,499.15 471,604.27 0.00 2,795.07 6,700.00 54.27 258.27 4,130.14 4,072.44 -1,387,71 -4,484.39 5,992,482.90 471,524.74 0.00 2,837.77 800.00 6 54.27 258.27 4,188.53 4,130.83 -1,404.21 -4,563.87 5,992,466.65 471,445.21 0.00 2,880.47 , 900.00 6 54.27 258.27 4,246.92 4,189.22 -1,420.72 -4,643.36 5,992,450.39 471,365.68 0.00 2,923.16 , 7,000.00 54.27 258.27 4,305.32 4,247.62 -1,437.23 -4,722.84 5,992,434.14 471,286.15 0.00 2,965.86 100.00 7 54.27 258.27 4,363.71 4,306.01 -1,453.74 -4,802.33 5,992,417.89 471,206.62 0.00 3,008.56 , 7 200.00 54.27 258.27 4,422.10 4,364.40 -1,470.25 -4,881.81 5,992,401.64 471,127.09 0.00 3,051.26 , 300.00 7 54.27 258.27 4,480.49 4,422.79 -1,486.76 -4,961.30 5,992,385.38 471,047.56 0.00 3,093.96 , 400.00 7 54.27 258.27 4,538.88 4,481.18 -1,503.27 -5,040.78 5,992,369.13 470,968.03 0.00 3,136.66 , 500.00 7 54.27 258.27 4,597.27 4,539.57 -1,519.78 -5,120.27 5,992,352.88 470,888.50 0.00 3,179.36 , 7,600.00 54.27 258.27 4,655.67 4,597.97 -1,536.29 -5,199.75 5,992,336.63 470,808.97 0.00 3,222.06 700.00 7 54.27 258.27 4,714.06 4,656.36 -1,552.80 -5,279.24 5,992,320.37 470,729.44 0.00 3,264.76 , 7,800.00 54.27 258.27 4,772.45 4,714.75 -1,569.30 -5,358.72 5,992,304.12 470,649.91 0.00 3,307.46 900.00 7 54.27 258.27 4,830.84 4,773.14 -1,585.81 -5,438.21 5,992,287.87 470,570.38 0.00 3,350.15 , D00.00 S 54.27 258.27 4,889.23 4,831.53 -1,602.32 -5,517.69 5,992,271.62 470,490.85 0.00 3,392.85 , 8,100.00 54.27 258.27 4,947.62 4,889.92 -1,618.83 -5,597.18 5,992,255.37 470,411.32 0.00 3,435.55 2/22/2006 3:47:49PM Page 4 of 9 COMPASS 2003.11 Build 50 ORIGINAL • ~' Halliburton Energy Services ConoeoPhill>Ip~S Planning Report -Geographic •- Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: W Company: ConocoPhillips Alaska (Kuparuk) > TVD Reference: ' 3~ Project: Kuparuk River Unit 'MD Reference: 9,1 3: Site: Kuparuk 3S Pad ~. rth Reference: , Tr Well: 3S-23 rvey Calculation Method. Mi Wellbore: Plan 3S-23A ' Design: 3S-23A (wp07) ~.,.,., FiN~A~i iV~ `~ HALLlBIJRTON Spsrry Dr1111nS Sarvlc+>}s 3S-23 !3 L1 Plan @ 57.70ft (Nordic 3 (30+27.7)) !3 L1 Plan @ 57.70ft (Nordim3 (30+27.7)) mum Curvature ~:::' 3S-23A (wp07) Map Map MD Inclination Azimuth TVD SSTVD (ft) (°) (°) Ift) (ft) +N(-S (ft) +FJ-W (ft) Northing (ft) Easting (ft) 8,200.00 54.27 258.27 5,006.01 4,948.31 8 270 32 54.27 258.27 5,047.07 4,989.37 -1,635.34 -1,646.95 -5,676.66 -5,732.55 5,992,239.11 5,992,227.68 470,331.79 470,275.87 Build @ 3°/100ft to 85° Inc - 8271ft MD, 5047ft TVD DLSEV Vert Section (°/100ft) (ft) 0.00 3,478.25 0.00 3,508.28 8,300.00 54.47 257.20 5,064.36 5,006.66 -1,652.08 -5,756.13 5,992,222.63 470,252.28 3.00 3,521.16 8,400.00 55.22 253.65 5,121.95 5,064.25 -1,672.66 -5,835.24 5,992,202.31 470,173.12 3.00 3,567.56 8,500.00 56.07 250.16 5,178.39 5,120.69 -1,698.31 -5,9is.69 5,992,176.91 470,C94S9 3.00 3,618.49 600.00 8 57.02 246.75 5,233.53 5,175.83 -1,728.96 -5,991.26 5,992,146.52 470,016.93 3.00 3,673.82 , 8,700.00 58.05 243.41 5,287.22 5,229.52 -1,764.51 -6,067.75 5,992,111.21 469,940.33 3.00 3,733.39 800.00 8 59.17 240.15 5,339.31 5,281.61 -1,804.88 -6,142.95 5,992,071.09 469,865.01 3.00 3,797.05 , 8,900.00 60.37 236.97 5,389.66 5,331.96 -1,849.96 -6,216.64 5,992,026.25 469,791.18 3.00 3,864.61 9,000.00 61.65 233.86 5,438.14 5,380.44 -1,899.61 -6,288.64 5,991,976.84 469,719.04 3.00 3,935.89 9,100.00 62.99 230.83 5,484.60 5,426.90 -1,953.71 -6,358.73 5,991,922.97 469,648.78 3.00 4,010.69 200.00 9 64.40 227.88 5,528.92 5,471.22 -2,012.10 -6,426.72 5,991,864.80 469,580.60 3.00 4,088.82 , 9,300.00 65.86 224.99 5,570.98 5,513.28 -2,074.62 -6,492.44 5,991,802.49 469,514.69 3.00 4,170.05 9,400.00 67.38 222.17 5,610.66 5,552.96 -2,141.11 -6,555.70 5,991,736.21 469,451.22 3.00 4,254.17 500.00 9 68.95 219.42 5,647.86 5,590.16 -2,211.39 -6,616.33 5,991,666.14 469,390.38 3.00 4,340.94 , 9,600.00 70.56 216.72 5,682.48 5,624.78 -2,285.25 -6,674.16 5,991,592.48 469,332.32 3.00 4,430.13 9,606.69 70.66 216.54 5,684.70 5,627.00 -2,290.31 -6,677.92 5,991,587.43 469,328.54 3.02 4,436.17 Upper Kalubik 9,700.00 72.20 214.07 5,714.41 5,656.71 -2,362.49 -6,729.03 5,991,515.41 469,277.20 3.00 4,521.48 9,800.00 73.89 211.48 5,743.58 5,685.88 -2,442.92 -6,780.79 5,991,435.17 469,225.19 3.00 4,614.76 900.00 9 75.60 208.92 5,769.89 5,712.19 -2,526.29 -6,829.31 5,991,351.95 469,176.41 3.00 4,709.70 , 10,000.00 77.34 206.41 5,793.29 5,735.59 -2,612.39 -6,874.44 5,991,266.01 469,131.01 3.00 4,806.04 10,029.88 77.87 205.67 5,799.70 5,742.00 -2,638.62 -6,887.25 5,991,239.82 469,118.11 3.00 4,835.07 Lower Kalubik 10,100.00 79.11 203.93 5,813.69 5,755.99 -2,700.99 -6,916.07 5,991,177.56 469,089.10 3.00 4,903.53 10 200.00 80.89 201.48 5,831.06 5,773.36 -2,791.82 -6,954.07 5,991,086.85 469,050.81 3.00 5,001.89 , 10,300.00 82.69 199.06 5,845.34 5,787.64 -2,884.66 -6,988.35 5,990,994.13 469,016.23 3.00 5,100.85 10,381.82 84.17 197.09 5,854.70 5,797.00 -2,961.92 -7,013.56 5,990,916.96 468,990.78 3.00 5,182.08 Top of C4 10,400.00 84.50 196.65 5,856.49 5,798.79 -2,979.24 -7,018.82 5,990,899.66 468,985.47 2.99 5,200.15 10,427.23 85.00 196.00 5,858.98 5,801.28 -3,005.27 -7,026.44 5,990,873.66 468,977.76 3.00 5,227.21 Sail @ 85° Inc : 10427ft MD, 5859ft TVD 10,431.82 85.00 196.00 5,859.38 5,801.68 -3,009.66 -7,027.70 5,990,869.27 468,976.49 0.00 5,231.77 7" Casing @ 10432ft MD, 5859ft TVD - 293ft FNL 8 3466ft FEL -Sec 24 - T12N - R07E - 7" 500.00 10 85.00 196.00 5,865.33 5,807.63 -3,074.95 -7,046.42 5,990,804.05 468,957.56 0.00 5,299.52 , 10,527.23 85.00 196.00 5,867.70 5,810.00 -3,101.03 -7,053.90 5,990,778.00 468,950.00 0.00 5,326.59 Continue Build @ 5.5°/100ft to 91 .8°, 10527ft M D, 5868ft TVD - 3S-23A T1 (wp07) 10,567.12 86.37 197.72 5,870.70 5,813.00 -3,139.09 -7,065.43 5,990,739.98 468,938.35 5.50 5,366.30 10,600.00 87.51 199.12 5,872.46 5,814.76 -3,170.24 -7,075.81 5,990,708.87 468,927.87 5.49 5,399.12 10 700.00 90.96 203.40 5,873.79 5,816.09 -3,263.38 -7,112.06 5,990,615.85 468,891.32 5.50 5,499.05 , 725.14 10 91.83 204.48 5,873.18 5,815.48 -3,286.35 -7,122.26 5,990,592.91 468,881.05 5.51 5,524.12 , 10,798.32 91.83 204.48 5,870.84 5,813.14 -3,352.92 -7,152.57 5,990,526.45 468,850.53 0.00 5,597.03 Continue GeoSteer in C4 10798ft MD, 5871ft TVD 10,800.00 91.82 204.40 5,870.78 5,813.08 -3,354.45 -7,153.27 5,990,524.92 468,849.83 4.87 5,598.71 ORIGINAL A y Halliburton Energy Services ConocoPhillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co.ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Projoct: Kuparuk River Unit MD Reference: Site: Kuparuk 3S Pad North Reference: Well: 3S-23 Survey Calculation Method: Wellborn: Plan 3S-23A Design: 3S-23A (wp07) ~,. ~..```~ ~r "-~ ,°'- • HALLIBURTON SpQrry 17rllling 3ervlcas W e113S-23 3S-23 L1 Plan @ 57.70ft (Nordic 3 (30+27;7)) 3S-23 L1 Plan @ 57:70ft (Nordic 3 (30+27.7)) True Minimum Curvature Planned Surv ey 3S-23A (wp07) ,. ..,. f Map MaP ~ MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing (ft) Easting (ft) DLSEV (°/100ft) Vert Sectio (ft) (ft) (°) (°) (ft) (ft) (ft) (ft) 900.00 10 91.07 199.46 5,868.26 5,810.56 -3,447.16 -7,190.58 5,990,432.34 468,812.22 5.00 5,698.59 , 11 000.00 90.32 194.51 5,867.04 5,809.34 -3,542.76 -7,219.78 5,990,336.85 468,782.72 5.00 5,798.41 , 010.31 11 90.24 194.00 5,866.99 5,809.29 -3,552.76 -7,222.32 5,990,326.86 468,780.15 5.02 5,808.68 , 11,080.31 90.24 194.00 5,866.70 5,809.00 -3,620.68 -7,239.25 5,990,259.00 468,763.00 0.00 5,878.29 3S-23A T2 (wp07) 100.00 11 90.06 194.5b' 5,866.65 5,808.95 -3,639.75 -7,244.11 5,990,239.94 468,758.08 2.9Q 5,897.88 , 156.54 11 89.55 196.18 5,866.84 5,809.14 -3,694.26 -7,259.09 5,990,185.48 468,742.92 3.00 5,954.23 , 11,200.00 89.55 196.18 5,867.17 5,809.47 -3,736.00 -7,271.20 5,990,143.79 468,730.68 0.00 5,997.59 300.00 11 89.55 196.18 5,867.95 5,810.25 -3,832.04 -7,299.07 5,990,047.85 468,702.51 0.00 6,097.37 , 400.00 11 89.55 196.18 5,868.73 5,811.03 -3,928.08 -7,326.94 5,989,951.91 468,674.33 0.00 6,197.14 , 500.00 11 89.55 196.18 5,869.51 5,811.81 -4,024.11 -7,354.81 5,989,855.98 468,646.16 0.00 6,296.92 , 600.00 11 89.55 196.18 5,870.29 5,812.59 -4,120.15 -7,382.67 5,989,760.04 468,617.99 0.00 6,396.69 , 11,653.20 89.55 196.18 5,870.70 5,813.00 -4,171.24 -7,397.50 5,989,709.00 468,603.00 0.00 6,449.78 3S-23A T3 (wp07) 684.76 11 88.64 195.94 5,871.20 5,813.50 -4,201.56 -7,406.23 5,989,678.71 468,594.18 3.00 6,481.25 , 700.00 11 88.64 195.94 5,871.56 5,813.86 -4,216.21 -7,410.41 5,989,664.08 468,589.94 0.00 6,496.45 , 11,800.00 88.64 195.94 5,873.93 5,816.23 -4,312.34 -7,437.86 5,989,568.04 468,562.19 0.00 6,596.17 900.00 11 88.64 195.94 5,876.31 5,818.61 -4,408.47 -7,465.32 5,989,472.01 468,534.43 0.00 6,695.89 , 000.00 12 88.64 195.94 5,878.68 5,820.98 -4,504.60 -7,492.77 5,989,375.98 468,506.67 0.00 6,795.62 , 100.00 12 88.64 195.94 5,881.06 5,823.36 -4,600.73 -7,520.22 5,989,279.95 468,478.91 0.00 6,895.34 , 200.00 12 88.64 195.94 5,883.43 5,825.73 -4,696.86 -7,547.67 5,989,183.92 468,451.16 0.00 6,995.06 , 12,211.37 88.64 195.94 5,883.70 5,826.00 -4,707.79 -7,550.79 5,989,173.00 468,448.00 0.00 7,006.40 3S-23A T4 (wp07) 12,250.54 88.43 194.78 5,884.70 5,827.00 x,745.54 -7,561.16 5,989,135.28 468,437.51 3.00 7,045.42 300.00 12 88.18 193.32 5,886.16 5,828.46 -4,793.50 -7,573.17 5,989,087.37 468,425.35 3.00 7,094.59 , 378.41 12 87.77 191.00 5,888.94 5,831.24 -4,870.10 -7,589.67 5,989,010.83 468,408.61 3.00 7,172.22 , 400.00 12 87.77 191.00 5,889.78 5,832.08 -4,891.28 -7,593.79 5,988,989.67 468,404.42 0.00 7,193.52 , 500.00 12 87.77 191.00 5,893.67 5,835.97 -4,989.36 -7,612.86 5,988,891.65 468,385.04 0.00 7,292.22 , 600.00 12 87.77 191.00 5,897.56 5,839.86 -5,087.45 -7,631.92 5,988,793.64 468,365.66 0.00 7,390.91 , 12,629.22 87.77 191.00 5,898.70 5,841.00 -5,116.11 -7,637.49 5,988,765.00 468,360.00 0.00 7,419.75 3S-23A TS (wp07) 700.00 12 88.17 192.72 5,901.21 5,843.51 -5,185.34 -7,652.03 5,988,695.83 468,345.24 2.50 7,489.77 , 800.00 12 88.75 195.16 5,903.89 5,846.19 -5,282.35 -7,676.12 5,988,598.90 468,320.85 2.50 7,589.17 , 900.00 12 89.33 197.59 5,905.57 5,847.87 -5,378.27 -7,704.30 5,988,503.08 468,292.36 2.50 7,688.95 , 000.00 13 89.91 200.02 5,906.24 5,848.54 -5,472.92 -7,736.54 5,988,408.54 468,259.82 2.50 7,788.92 , 100.00 13 90.48 202.45 5,905.90 5,848.20 -5,566.12 -7,772.76 5,988,315.47 468,223.31 2.50 7,888.88 , 200.00 13 91.06 204.89 5,904.54 5,846.84 -5,657.69 -7,812.90 5,988,224.04 468,182.87 2.50 7,988.66 , 232.34 13 91.25 205.67 5,903.89 5,846.19 -5,686.93 -7,826.71 5,988,194.84 468,168.97 2.50 8,020.86 , 300.00 13 91.25 205.67 5,902.42 5,844.72 -5,747.90 -7,856.01 5,988,133.98 468,139.47 0.00 8,088.17 , 400.00 13 91.25 205.67 5,90C.23 5,842.53 -5,838.00 -7,899.33 5,988,044.02 468,095.87 0.00 8,187.66 , 13,424.48 91.25 205.67 5,899.70 5,842.00 -5,860.06 -7,909.93 5,988,022.00 468,085.20 0.00 8,212.01 3S-23A T6 (wp07) 500.00 13 90.54 204.34 5,898.52 5,840.82 -5,928.49 -7,941.85 5,987,953.68 468,053.06 2.00 8,287.23 , 600.00 13 89.60 202.58 5,898.40 5,840.70 -6,020.22 -7,981.66 5,987,862.09 468,012.97 2.00 8,387.04 , 700.00 13 88.66 200.81 5,899.92 5,842.22 -6,113.12 -8,018.62 5,987,769.32 467,975.72 2.00 8,486.98 , 13,754.91 88.14 199.84 5,901.45 5,843.75 -6,164.59 -8,037.68 5,987,717.91 467,956.49 2.00 8,541.87 2/22/2006 3:47:49PM Page 6 of 9 COMPASS 2003.11 Build 50 • y' Halliburton Energy Services HALLIBURTON ConocoP hillips Planning Report -Geographic ~~~~ ~~~~~~~ ~~~~~~ Alaska --_ -__ Database: _. EDM 2003.11 Single User Db Local Co-ordinate Reference: Well 3S-23 Company: CohocoPhillips Alaska (Kuparuk) • -VD Reference: 3S-23 L1 Plan @ 57.70ft (Nordic 3 (30+27.7)) Project: Kuparuk River Unit Reference: 3S-23 L1 Plan @ 57.70ft (Nordic 3 (30+27.7)) Site: Kuparuk 3S Pad h Reference: True !~: 3S-23 S4~rvey Calculation Method: Minimum Curvature bore: ` .Plan 3S-23A 07 3S 23A ~ - ~~ ' n. g (wp ) - rn,~.~ri,wrA..e ~, _.,~ ~.v5t~is~tagaq'= :~ , 3S-23A (wp07) ._ ~, ,~ ,. _ Map Map MD (ft) Inclination (°) Azimuth (°) TVD (ft) SSTVD (ft) +N/-S (ft) +EI-W Northing (ft} (ft) Fasting (ft) DLSEV (°/100ft) Vert Section (ft) 800.00 13 88.14 199.84 5,902.91 5,845.21 -6,206.98 -8,052.98 5,987,675.57 467,941.06 0.00 8,586.94 , 900.00 13 88.14 199.84 5,906.15 5,848.45 -6,301.00 -8,086.90 5,987,581.68 467,906.84 0.00 8,686.88 , 000.00 14 88.14 199.84 5,909.39 5,851.69 -6,395.01 -8,120.82 5,987,487.78 467,872.62 0.00 8,786.83 , 100.00 14 88.14 199.84 5,912.63 5,854.93 -6,489.03 -8,154.75 5,987,393.89 467,838.39 0.00 8,886.78 , 14,194.66 88.14 199.84 5,915.70 5,858.00 -6,578.02 -8,186.86 5,987,305.00 467,806.00 0.00 8,981.39 200.00 14 88.19 199.94 5,915.87 5,858.17 -6,583.04 -8,188.67 5,987,299.99 467,804.17 1.98 8,986.73 , 14 300.00 89.06 201.74 5,918.27 5,860.57 -6,676.47 -8,224.23 5,987,206.69 467,768.31 2.00 9,086.68 , 394.68 14 89.88 203.44 5,919.15 5,861.45 -6,763.88 -8,260.61 5,987,119.41 467,731.67 2.00 9,181.26 , 400.00 14 89.88 203.44 5,919.16 5,861.46 -6,768.75 -8,262.72 5,987,114.53 467,729.53 0.00 9,186.57 , 500.00 14 89.88 203.44 5,919.37 5,861.67 -6,860.50 -8,302.51 5,987,022.93 467,689.46 0.00 9,286.38 , 600.00 14 89.88 203.44 5,919.58 5,861.88 -6,952.24 -8,342.29 5,986,931.32 467,649.38 0.00 9,386.20 , 700.00 14 89.88 203.44 5,919.79 5,862.09 -7,043.99 -8,382.08 5,986,839.71 467,609.31 0.00 9,486.02 , 800.00 14 89.88 203.44 5,920.00 5,862.30 -7,135.73 -8,421.87 5,986,748.11 467,569.23 0.00 9,585.84 , 900.00 14 89.88 203.44 5,920.20 5,862.50 -7,227.48 -8,461.65 5,986,656.50 467,529.15 0.00 9,685.66 , 000.00 15 89.88 203.44 5,920.41 5,862.71 -7,319.22 -8,501.44 5,986,564.89 467,489.08 0.00 9,785.48 , 100.00 15 89.88 203.44 5,920.62 5,862.92 -7,410.96 -8,541.23 5,986,473.28 467,449.00 0.00 9,885.30 , 15,137.43 89.88 203.44 5,920.70 5,863.00 -7,445.30 -8,556.12 5,986,439.00 467,434.00 0.00 9,922.66 3S-23A T8 (wp07) 153.16 15 90.08 203.69 5,920.71 5,863.01 -7,459.72 -8,562.41 5,986,424.60 467,427.66 2.00 9,938.36 , 200.00 15 90.08 203.69 5,920.64 5,862.94 -7,502.61 -8,581.23 5,986,381.77 467,408.71 0.00 9,985.10 , 300.00 15 90.08 203.69 5,920.51 5,862.81 -7,594.19 -8,621.41 5,986,290.34 467,368.24 0.00 10,084.90 , 400.00 15 90.08 203.69 5,920.38 5,862.68 -7,685.76 -8,661.59 5,986,198.91 467,327.76 0.00 10,184.69 , 500.00 15 90.08 203.69 5,920.25 5,862.55 -7,777.33 -8,701.77 5,986,107.47 467,287.29 0.00 10,284.48 , 600.00 15 90.08 203.69 5,920.12 5,862.42 -7,868.90 -8,741.95 5,986,016.04 467,246.82 0.00 10,384.27 , 700.00 15 90.08 203.69 5,919.99 5,862.29 -7,960.47 -8,782.14 5,985,924.61 467,206.35 0.00 10,484.07 , 800.00 15 90.08 203.69 5,919.86 5,862.16 -8,052.05 -8,822.32 5,985,833.17 467,165.88 0.00 10,583.86 , 900.00 15 90.08 203.69 5,919.72 5,862.02 -8,143.62 -8,862.50 5,985,741.74 467,125.41 0.00 10,683.65 , 15,918.31 90.08 203.69 5,919.70 5,862.00 -8,160.38 -8,869.85 5,985,725.00 467,118.00 0.00 10,701.92 3S-23A T9 (wp07) 921.14 15 90.08 203.75 5,919.70 5,862.00 -8,162.97 -8,870.99 5,985,722.41 467,116.85 2.00 10,704.74 , 15,947.00 90.08 203.75 5,919.66 5,861.96 -8,186.65 -8,881.41 5,985,698.77 467,106.36 0.00 10,730.56 BHL @ 15947ft MD. 59 20ft TVD , 192ft FNL 8 38ft FEL -Sec 26 - T12N - R 07E - 4 1/2" - 3S-23A T10 (wp 07) 2/22/2006 3:47:49PM Page 7 of 9 COMPASS 2003.11 Build 50 ORIGINAL ~ ~ / Halliburton Energy Services HALLIBURTON ConocoPhill>Ips Planning Report -Geographic ~~~ Dr1l~tng ~~,~~~ Alaska Database: Company: Protect; Site: WeII; Wailbore: Design: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well 3S-23 ConocoPhillips Alaska (Kuparuk)._: TVD Reference: 3S-23 L1 Plan @ 57:70ft (Nordic 3 (30+27.7)) Kuparuk River Unit MD Reference: 3S-23 L1 Plan @ 57.70ft (Nordic 3 (30+27.7)) Kuparuk 3S Pad North Reference: True 3S-23 - Survey Calculation Method: Minimum Curvature Plan 3S-23A 3S-23A (wp07) _ , ,..., _.. '~?, - =.~~. .: TVD Targat,Mame +N/-S +E/-W Northing Easting (ft) • Shape ft ft (ft) {ft) 5,9 i 5.70 3S 23A T7 (v>p07) -6,578.n2 -8,186.86 5,987,305.00 467,806.00 - Point 5,919.70 3S-23A T9 (wp07) -8,160.38 -8,869.85 5,985,725.00 467,118.00 - Point 5,883.70 3S-23A T4 (wp07) -4,707.79 -7,550.79 5,589,173.00 468,448.C0 - Point 5,920.70 3S-23A TS (wp07) -7,445.30 -8,556.12 5,986,439.00 467,434.00 - Point 5,867.70 3S-23AT1 (wp07) -3,101.03 -7,053.90 5,990,778.00 468,950.00 - Point 5,870.70 3S-23A T3 (wp07) -4,171.24 -7,397.50 5,989,709.00 468,603.00 - Point 5,898.70 3S-23A TS (wp07) -5,116.11 -7,637.49 5,988,765.00 468,360.00 - Point 5,866.70 3S-23A T2 (wp07) -3,620.68 -7,239.25 5,990,259.00 468,763.00 - Point 5,884.70 3S-23 L1 Fault 2 -4,746.90 -7,583.67 5,989,134.00 468,415.00 - Point 5,899.70 3S-23A T6 (wp07) -5,860.06 -7,909.93 5,988,022.00 468,085.20 - Point 5,919.66 3S-23AT10(wp07) -8,186.65 -8,881.41 5,985,698.77 467,106.36 - Point 5,870.70 3S-23 L1 Fault 1 -4,364.61 -7,505.89 5,989,516.00 468,494.00 - Point - - :.. s. ~ Prognosod Casing Points . , Measured Vertical Casing Hoie ~ '' ~ ' Depth Depth Diameter Diameter " (ft) Ift) („) ( ) 4,042.50 2,606.74 9-518 12-1 /4 10,431.82 5,859.38 7 8-112 15,947.00 5,919.66 4-1/2 6-118 2/22/2006 3:47:49PM Page 8 of 9 COMPASS 2003.11 Build 50 • • Halliburton Energy Services HALLIBUATON . ConocoPhiil~ps Planning Report -Geographic Sp+srry Drilling Servic+as Alaska _ ___ _ - __.~~ _._.--__ i~ base: __ .........~~....-..~..~ EDM 2003.11 Single User Db ._._m__. Local Co-ordinate Reference: VJell 3S-23 pany: ConocoPhillips Alaska (Kuparuk) TVD Reference: 3S-23 L1 Plah @ 57.70ft (Nordic 3 (30+27.7)) ect: Kuparuk River Unit MD Reference: 3S-23 L1 Plan @ 57.70ft (Nordic 3 (30+27.7)) Kuparuk 35 Pad North Reference: True 3S-23 Survey Calculation Method: Minimum Curvature bore: .Plan 3S-23A 07 - ~ i n: g ) 3S-23A(wp ~~„~a~,.xxti ;. ,fM >t,?~.~~:: onnosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +Nl-E +Ef-W „ ,;~y_~ (ft) (°) (°) (~) (ft) Ift) 9,606.69 70.66 216.54 5,684.70 -2,290.31 -6,677.92 Tipper t<aiuh;k 10,029.88 77.87 205.67 5,799.70 -2,638.62 -6,887.25 Lower Kal~bik 10,381.82 84.17 197.09 5,854.70 -2,961.92 -7,013.56 Top of C4 2/22/2006 3:47:49PM Page 9 of 9 COMPASS 2003.11 Build 50 ORIGIN/~L ConocoPhillips ~as~ ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 3S Pad 3S-23 Plan 3S-23A Anticollision Summary 22 February, 2006 • HALLIBURTOIr~I ~p~~rry Drilling Sier~ri~e~s ORIGINAL SUAV6Y pNOGRAM NAD 27 ASP Zone 4: WELL DETAILS: 35.23 ConorwPhillips Alaska (Kuparuk) Datr. 2006-02-20I'00:00:00 Valtdatrd:Yn Vmioe: ~~rn~ Ground Level: 0.00 Drilling d Wells kitarpolation 6tedtoa: MD krtervai: SOStatbns +NI-S +EI-VI Northing Fasting Vathtude Longitude Slot West Sak Deptk Frain Deptk To Sarvey/Plea Toel Dapth Rarge From: 6000 To 19947.0042298251 0.00 0.00 5993858.07 476017.11 70°23~'39.6YfN 150°71'4259W '8150 24950 CB(°l'R0 .4 Mnfinum Ranpe;1791.7p042296254 CaleuWgon Method: Minimum CurvaWre 39236 4158.00 MIVDHFII~AK-CA7 SC Rakranca; pbn: 3S-23A (wpOT) Error System: ISCWSA 4158A0 15947.00 3S-23A (wp07) MWD+iFR-wK-CwZSC Sran MNhod: Trav. Cylinder NOrth Error Surface: Elliptical Conic blaming McMod: Rules Based 0 0 90 270 90 rrom colour to mu 4150 9000 9250 9500 9750 10000 180 10250 10500 10750 Travelling Cylinder Azimuth (TFO+AZI) [°J vs Centre to Centre Separation [I50 ft/in] 11000 11250 11500 11750 12000 REFERENCE INFORMATION Coordinate (WE) Reference: Well SS-21, True North Verlicel (ND) Reference: 9S-23 L1 Plan @ 57.708 (Nordic 9 (30+27.7)) Section (VS) Reference: Slo[ - (O.OON, O.OOE) Measured Dep[h Reference: 35-23 L1 Plan @ 57.700 (Nordic 1(30+27.7)) Calculation Method: Minimum Curvature 9000 9250 9500 9750 10000 10250 10500 10750 11000 11zso 11500 11750 12000 15947 180 Trrvelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [15 NiD] SECTION DETAILS Sec MD Inc Azi TVD +NlS tE(-W DLeg TFace VSec Target 1 41150.00 62.53 251.14 2655.88 A44.9S -2453.11 0.00 0.00 1727.02 2 4:!50.00 56.53 251.14 2705.06 573.07 -2535.68 4.00 180.00 1781.51 S 4432.65 54.27 258.27 2806.19 -1013.38 -268217 4.00 127.58 1869.62 4 6:!70.32 54.27 258.27 5047.07 -1646.95 5732.55 0.00 0.00 3506.28 5 10427.23 85.00 196.00 5858.98 -3005.27 -7026.44 3.00 -77.22 5227.21 6 t0:i2711 85.00 196.00 5867.70 3101.03 -7053.90 0.00 0.00 5326.59 SS-23A T7 (wp07) 7 t0i'25.14 97.89 204.48 5873.18 .9286.35 -772216 5.50 51.32 5524.12 8 t0i'98.32 91.83 204.48 5870.84 3352.92 -7152.57 0.00 0.00 5597.03 9 111110.31 90.24 194.00 5666.99 3552.76 -7222.32 5.00 A8.52 5808.68 10 1u1so.31 9o.za 19a.oo 5666.70 36z9se azs9.zs o.oo o.o0 5678.2s ss-z1Arz(wpo7> 11 11'156.54 89.55 196.18 5666.84 9694.26 -7259.09 9.00 107.45 5954.25 12 111L59.20 89.55 196.18 5870.70 417114 -7397.50 0.00 0.00 6449.78 33-23A TS (wp07) 11 11684.76 88.64 195.94 587110 -4201.56 -7406.25 9.00 -165.10 6481.25 14 12211.37 88.64 195.94 5883.70 -0707.79 -7`•~•~ 0.00 0.00 7006.40 9S•23A T4 (wp07) 15 12178.41 87.77 191.00 5888.94 -4870.10 -7589.67 3.00 •100.07 7172.22 16 121129.22 87.77 191.00 5898.70 -5116.11 -7637.49 0.00 0.00 7419.75 SS-23A T5 (wp07) 17 13.432.34 91.25 205.67 5903.89 5686.93 -7826.71 2.50 76.79 6020.66 18 13424.48 91.25 205.67 5899.70 5660.06 -7909.93 0.00 0.00 8212.01 >5-23A T6 (wp07) 19 191154.91 88.14 199.84 5901.45 -6164.59 -0037.68 200 •116.03 6541.67 2014194.66 88.14 199.84 5915.70 -0576.02 -0186.86 0.00 0.00 6981.39 SS-23A T7 (wp07) 21 14394.68 89.88 203.44 5919.15 5763.68 -0260.61 200 64.10 9181.26 2215137.41 69.88 203.44 5920.70 -7445.30 -8558.12 0.00 0.00 9922.66 3S-23A T8 (wp07) 2S 15153.16 90.08 209.69 5920.71 •7459.72 -0562.41 2.00 51.73 9938.96 2415918.11 90.08 203.69 5919.70 -6160.98 5869,85 0.00 0.0010701.92 SS-27A T8 (wpOT) 25 15921.14 90.08 203.75 5919.70 -0162.97 5870.99 2.00 85.18 10704.74 26 151#7.00 90.08 203.75 5919.66 -0186.65 3881.41 0.00 0.00 10730.56 9S-29A T10 - Tce (wp07) • • ~' Halliburton Energy Services HgLL~g~JgTON ConoeoPlvllips Anticollision Report i ces Sperry Drilling Serv Alaska - _- Company: __ ConocoPhillips Alaska (Kuparuk). Local Co-ordinate Reference: Well 3S-23 Project: Kuparuk River Unit TVD Reference: 3S-23 L1 Plan @ 57.70ft (Nordic 3 (30+27.7)) :Reference Sito: Kuparuk 3S Pad MD Reference: 3S-23 L1 Plan @ 57.70ft (Nordic 3 (30+27.7))- e Error: S O.OOft North Reference: True , forence Well: 3S-23 Survey Calculation Method: Minimum Curvature ,`.11 Error: O.OOft ?Output errors are at 2.00 sigma ~(erence Wellbore; Plan 3S-23A Database: EDM 2003.11 Single User Db 'rence Design: 3S-23A (wp07) Offset TVD Reference: Offset Datum. Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval SO.OOft Error Model: Depth Range: 6,000.00 to 15,947.OOft Scan Method: Results Limited by: Maximum center-center distance of 1,791.70ft Error Surface: Warning Levels evaluated at: 0.00 Sigma ISCW SA Trav. Cylinder North Elliptical Conic `,ey Tool Program Date 2/22/2006 F.n Tn (ft) (ft) Survey {Wetlbore) Tool Name Description 88.50 264.50 3S-23 Gyro (3S-23) CB-GYRO-SS Camera based gyro single shot 392.36 4,150.00 3S-2311FR (3S-23) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,150.00 15,947.00 3S-23A (wp07) (Plan 3S-23A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Offset Well - Wellhore -Design Depth Depth Distance (ft) from Plan (ft) (ft) (ft) lft) Kuparuk 3S Pad 3S-17 - 3S-17 - 3S-17 Out of range 3S-17 - 3S-17A - 3S-17A Out of range 3S-19 - 3S-19 - 3S-19 6,002.07 6,100.00 1,561.26 172.02 1,390.67 Pass -Major Risk 3S-21 - 3S-21 - 3S-21 Out of range 3S-22 - 3S-22 - 3S-22 6,024.23 6,100.00 1,238.93 160.91 1,116.39 Pass -Major Risk 3S-23 - 3S-23 - 3S-23 10,227.65 10,100.00 191.82 188.27 12.22 Pass -Major Risk 3S-24 - 3S-24 - 3S-24 15,932.94 13,450.00 1,656.02 - 323.48 1,333.29 Pass -Major Risk 3S-24 - 3S-24A - 3S-24A Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/22/2006 4:20:55PM Page 2 of 2 COMPASS 2003.11 Build 50 ORIGINAL KRU - 3S-23 Pr~ucer Single Completion w/ Jet Pump Contingency ~ - ConocoPhillips 16" insulated conductor @ 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" +/-108' MD 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" TAM 9-5/8" Po Collar Stnd 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 490' MD. Grade BTC Threads (+!- Use of port collar at the discretion of the drilling team. 1000' MD/TVD) Surtace csg. 9-5/8"40# L-80 BTC (4040' MD / 2604' TVD) Casing point GLM Placement: 100' above the C80 sand Mandrel #1-4: 3-''/i' x 1" KBUG Manrel #5: 3-1/2" x 1-1/2" 'MMG' TVD MD 2544' 3907' 3744' 6475' 4592' 8269' 5221' 9383' 5673' 9996' 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 10,048' MD / 5716' TVD: 3-1/2" Baker'CMU' sliding sleeve w/ 2.813" Camco 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 3-112" 'SAB-3' Permanent Packer set +/- 100' MD above top planned pert. Minimum ID through the packer 3.00". 6' Pup Joint 3-1l2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco'D' nipple w/ 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 w/shear out sub. Tubing tail 50' above top planned perforation. C Sand Perfs ~ 10217'-10244' Production csg. ~ ~ : Ceirieiit 7" 26# L-80 TD @ 10535' MD BTCM (10519' MD, 6116' TVD) ORIGINAL • KRU - 3S-23 Producer P&A'd Pre-Rig Pre-Rig P&A 16" insulated conductor @ +/- 108' MD TAM 9-5/8" P Collar Stnd Grade BT Threads (+ 1000' MD/TV Surface cs 9-5/8"40# L- BTC (4040' 2604' TVD Casing poi 100'abovet C80 sand Tubing chemi 10,020' MD Top of cem tbg 10,075' Cement Reta +/- 10,135' M C Sand Pe 10217'-1024 Production 7" 26# L-80 BTCM (10519' MD, 6116' TVD) 0 C /- D) 9~ 80 MD/ nt he cal cut @ ent inside MD finer set @ D rfs ............ . csg :~:Ceiner~t;:;:; Conoco~illips 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1 /2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 490' MD. Use of port collar at the discretion of the drilling team. GLM Placement: Mandrel #1-4: 3-'/~' x 1" KBUG Manrel #5: 3-1 /2" x 1-1/2" 'MMG' TVD MD 2544' 3907' 3744' 6475' 4592' 8269' 5221' 9383' 5673' 9996' Pre-Rig Well Work: 1. Test wellhead Packoffs. 2. Set 3.5" cement retainer in tubing tail at 10135' and . Circulate tbg/IA to brine thru open GLM @9996' md. 3. Perform combo MIT. 4. RU CTU and sting into cement retainer. Sqz cement away. Un- sung and leave b0' of cement above retainer. 5. Tag and pressure test the cement plug. (AOGCC witness needed) 6. Chemical cut 3.5" tubing at 10,020' 7. Set BPV and prep wellhead for rig arrival. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 10,048' MD / 5716' TVD: 3-1/2" Baker'CMU' sliding sleeve w/ 2.813" Camco 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. 10,111' MD: Baker 7" x 3-1/2"'SAB-3' Permanent Packer set +/-100' MD above top planned pert. 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 w/ 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 w/shear out sub. Tubing tail 50' above top planned perforation. TD @ 10535' MD ORIGINAL • 3S-23 A Producer (PROPOSED SIDETRACK) Cut and Pull 7" below Surf Csg. Sidetrack 8-~/2" oaen hole 16" 62.5# H-40 -108' 2.875" DS nipple -i 9-5/8" 40# L-80 BTCM 4040' MD / 2604' ND 3'/~' 9.3IppfIL-80~EU~ 8rd Tubing GL '„J ~LM Camco 3-12" x 1 " KBMG w/ DV and latch Camco 3-12" x 1" KBMG w! DV and latch GL-1 I r~LM Camco 3-12" x 1" KBMG w/ DV and latch Camco 3-1/2" x 1"KBMG w/ DV and latch \~ Top of cement 9432' MD / 5610' TVD Sper'~}/ ~rxn iiata Plan 07 Tubing Jewelry: 2.875" DS nipple 490' MD # TVD MD OD Type Company 1 2500 3809 1.00 Bellows Camco 2 3700 5963 1.00 Bellows Camco 3 4600 7505 1.00 Bellows Camco 4 5200 8561 1.00 Bellows Camco 5 5610 9400 1.00 Orifice Camco CMU Sliding Sleeve w/ 2.813" DS profile 9450' MD 275" D nionle w nn no ID(<70 dea_l 9500' MD FMC Gen V tubing Hanger and pup jt. 31/2" 9.2 # L-80 EUE Tubing TUblllg COnlp~etlOn: 3-1/2" 9.2 # L-80 Eue pup joints for space out as needed 3-12" 9.2 # L-80 EUE Tubing 2.875" Camco DS landing nipple 31/2" EUE box x pin 3-12" 9.2 # L-80 EUE Tubing 3-12" Tubing Pup jt. 9.2 # L-80 EUE GLM Camco 31/2" x 1" KBMG w/ DV and latch 31/2" Tubing Pup jt. 9.2 # L-80 EUE 3-12" 9.2 # L-80 EUE Tubing 31/2" Tubing Pup jt. 9.2 # L-80 EUE GLM Camw 3-1 /2" x 1" KBMG w/ DV and latch 31/2" Tubing Pup jt. 9.2 # L-60 EUE 3-1/2" 9.2 # L-80 EUE Tubing 3-1/2" Tubing Pupjt. 9.2 # L-80 EUE GLM Camco 3-12" x i" KBMG w/ DV and latch 3-12" Tubing Pupjt. 9.2 # L-80 EUE 3-12" 9.2 # L-80 EUE Tubing 3-12" Tubing Pup jt. 9.2 # L-80 EUE GLM Camco 312" x 1" KBMG w/ DV and latch 312" Tubing Pup jt. 9.2 # L-80 EUE 312" 9.2 # L-80 EUE Tubing 31/2" Tubing Pup jt. 9.2 # L-80 EUE GLM Camco 31/2" x 1-1/2" MMG w/ 1-%" DCR-1 shear valve and latch 31/2" Tubing Pup jt. 9.2 # L-80 EUE 3-1/2" 9.2 # L-80 EUE Tubing 3-1/2" Tubing Pup jt. 9.2 # L-80 EUE Baker CMU Sliding Sleeve w/ 2.813" DS Profle 3-12" Tubing Pup jt. 9.2 # L-80 EUE Camco D Nipple w2.750 no-go I.D. 3-12" EUE box x pin 3-12" Tubing Pup jt. 9.2 # L-80 EUE 3-12" 9.2 # L-80 EUE Tubing 3-1/2" Tubing Pup jt. 9.2 # L-80 EUE Baker 80-40 GBH-22 Locator Sub w/ 3-1/2" EUE box ,Length = 1.00' Baker seal assembly w/ 15' sVOke and 1/2 mule shoe ,Length = 17.00' Lltl@r COn'1pIG'tIOD: "~"~. co~oiorrs~~~ z: ,cxtrra~, Camco 3-12" x 1-12" MMG w/ 1-%" DCR-1 shear valve and latch sliding sleeve w/ 2.813" DS profile ~ 2.75 D nipple w/ no-go ID .~ Top Reservoir at +/- Kuparuk 10381' MD / 5854' TVD 7" 26 ppf L-80 BTC Mod 10431' MD, 5859' TVD 8-'/i' hole GLD: Circulate corrosion inhibitor before setting packer after tubing is spaced out and landed. , :, 2~r i,. TD 6-1/8" hole ---- - --- ----- -- ----- - - - - 15947 MD / 5919' TVD ~ 4-/" 12.6#/ft L-80 BTC Slotted liner Pattern: 12 slots/ft, .1875" X 2" slots ORIGINAL • Rig: Nordic 3 Location: Palm Client: ConocoPhillips Alaska, Inc. Revision Date: 3/9/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 2634207 Mobile: (907) 748-6900 email: martinl3@slb.com Previous Csg. < 9 5/8", 40.0# casing at 4,040' MD < Top of Tail at 9,432' MD < 7", 26.0# casing in 8 1/2" OH TD at 10,432' MD (5,859' TVD) CemCADE Preliminary Job Design 7" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Schlumberger Volume Calculations and Cement Systems Volumes are based on 75% excess. Tail slurry is designed for 1000' MD annular length Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.08%6155, 0.4% D167 - 1.16 ft3/sk 0.1268 ft3/ft x 1000' x 1.75 (75% excess) = 221.9 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3 221.9 ft3 + 17.2 ft3 = 239.1 ft3 239.1 ft3/ 1.16 ft3/sk = 206.1 sks Round up to 210 sks BHST = 143°F, Estimated BHCT = 111°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 20.0 4.0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 MUDPUSH II 6.0 40.0 6.7 27.7 Tail Slurry 6.0 42.6 7.1 34.8 Drop top plug 0.0 0.0 5.0 39.8 Water 5.0 20.0 4.0 43.8 Switch to rig 0.0 0.0 5.0 48.8 Mud 6.0 350.0 58.3 107.1 Slow - 12.5 ECD 4.0 20.1 5.0 112.1 Slow & bump plug 2.0 6.0 3.0 115.1 MUD REMOVAL Recommended Mud Properties: 10.5 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH" II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement and 2 per joint on shoe track. ORIGINAL ~ • Schlumberger CemCADE*well cementing recommendation for 7" Intermediate Casing Operator : CAPI Well 3S-23A Country Field Palm State :Alaska Prepared for :Jason Brink Location Proposal No. : V3 (WP-O7) Service Point Prudhoe Bay Date Prepared :March 09, 2006 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by :Mike Martin Phone (907) 263-4207 E-Mail Address martinl3c slb.com 5~~~ ~~ Q~ C7 C ~G 9~VAT E 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 [o 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 maybe 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. Aciual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumber er or others is not to be inferred. * Mark of Schlumberger ORIGINAL • Client CAPI Well 35-23 L1 String 7lntermediate District Prudhoe Bay Country Loadcase XS Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :10432.0 ft BHST :140 degF Bit Size : 8 1/2 in Previous String MD OD Weight ID (ft) (in) (Ib/ft (in) 4040.0 9 5/8 40.0 8.835 Landing Collar MD :10352.0 ft Casing/liner Shoe MD :10432.0 ft • Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 10432.0 7 40.0 26.0 6.276 N80 5410 7240 8RD 3 s-23 Side Track.cfw ; 03-09-2006 ; Loadcase XS ; Version wcs~cem45_89 Page 2 ORIGINAL • • Client CAPI Well 35-23 L1 String 7lntermediate District Prudhoe Bay Country Loadcase XS Mean OH Diameter :8.500 in Mean Annular Excess :75.0 Mean OH Equivalent Diameter: 9.470 in Total OH Volume :556.9 bbl (including excess) Max. Deviation Angle : 85 deg Max. DLS :6.989 deg/100ft Directional Survey Data AAD TVD Deviation Azimuth Dogleg $ev. 88.5 88.5 0.9 96.0 -1.017 175.3 175.3 0.6 64.0 -0.602 264.5 264.5 1.4 316.0 -1.856 392.4 392.1 4.7 308.4 2.618 482.6 481.9 6.5 312.6 2.002 567.9 566.4 9.0 307.8 3.062 661.9 658.8 12.6 301.2 4.058 753.0 747.0 16.0 294.9 4.068 841.2 831.2 18.5 290.0 3.276 935.7 920.1 21.2 284.4 3.515 1032.8 1009.7 24.0 278.4 3.734 1121.1 1089.2 27.7 276.2 4.270 1217.1 1172.9 30.9 270.9 4.293 1313.6 1254.5 33.7 264.8 4.451 1403.9 1328.2 36.8 259.9 4.676 1496.6 1400.1 41.4 255.4 5.848 1592.6 1469.4 46.2 252.5 5.370 1687.3 1533.1 49.2 248.7 4.330 1780.3 1590.8 54.2 246.5 5.688 1873.2 1641.7 59.3 244.2 5.854 1967.6 1689.3 60.3 244.6 1.089 2062.5 1737.0 59.3 242.0 -2.584 2157.8 1785.3 59.8 238.1 3.510 2251.4 1831.6 60.9 236.1 2.195 2346.1 1875.6 63.7 229.4 6.989 2440.3 1917.2 63.9 227.9 1.391 2535.1 1958.8 64.1 228.8 0.823 2579.7 1977.3 66.9 228.2 6.420 2628.6 1996.1 67.9 227.8 2.328 2724.4 2030.1 70.4 230.2 3.475 2819.6 2063.6 68.4 231.4 -2.364 2913.9 2100.7 65.2 237.0 -6.513 3005.3 2140.9 62.6 242.3 -5.826 3099.2 2184.6 62.0 247.6 -5.110 3191.6 2226.1 64.6 253.0 5.903 3287.1 2266.4 65.5 254.2 1.498 3380.9 2305.3 65.5 255.1 -0.816 3477.1 2347.5 62.5 252.5 -3.884 3570.6 2390.5 62.9 252.9 0.576 3664.5 2432.7 63.7 253.8 1.150 3757.8 2475.3 62.0 253.2 -1.891 3850.8 2518,7 62.3 253.5 0.450 3943.8 2561.6 62.9 252.9 0.869 3987.8 2581.6 63.0 253.3 0.845 4042.5 2606.4 63.0 252.4 1.514 4061.7 2615.2 63.0 252.0 1.531 3 s23 Side Track.cfw ; 03-~-2006 ; Loadcase XS ;Version wcscem45_89 Page 3 ORIGINAL • • Client CAPI ~r 3I~m~r Well 35-23 L1 g String 7lntermediate District Prudhoe Bay Country Loadcase XS Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. 4200.0 2679.4 60.5 251.1 -4.002 4250.0 2704.8 58.5 251.1 -3.998 4300.0 2731.3 57.3 253.0 -3.990 4400.0 2787.0 55.0 256.9 -4.003 4432.6 2805.9 54.3 258.3 -4.004 4500.0 2845.2 54.3 258.3 0.000 4600.0 2903.6 54.3 258.3 0.000 4700.0 2962.0 54.3 258.3 0.000 4800.0 3020.4 54.3 258.3 0.000 4900.0 3078.8 54.3 258.3 0.000 SUUU.O 3137.2 54.3 258.3 ^v.000 5100.0 3195.6 54.3 258.3 0.000 5200.0 3254.0 54.3 258.3 0.000 5300.0 3312.4 54.3 258.3 0.000 5400.0 3370.8 54.3 258.3 0.000 5500.0 3429.2 54.3 258.3 0.000 5600.0 3487.6 54.3 258.3 0.000 5700.0 3546.0 54.3 258.3 0.000 5800.0 3604.4 54.3 258.3 0.000 5900.0 3662.8 54.3 258.3 0.000 6000.0 3721.1 54.3 258.3 0.000 6100.0 3779.5 54.3 258.3 0.000 6200.0 3837.9 54.3 258.3 0.000 6300.0 3896.3 54.3 258.3 0.000 6400.0 3954.7 54.3 258.3 0.000 6500.0 4013.1 54.3 258.3 0.000 6600.0 4071.5 54.3 258.3 0.000 6700.0 4129.9 54.3 258.3 0.000 6800.0 4188.3 54.3 258.3 0.000 6900.0 4246.7 54.3 258.3 0.000 7000.0 4305.1 54.3 258.3 0.000 7100.0 4363.5 54.3 258.3 0.000 7200.0 4421.9 54.3 258.3 0.000 7300.0 4480.3 54.3 258.3 0.000 7400.0 4538.7 54.3 258.3 0.000 7500.0 4597.1 54.3 258.3 0.000 7600.0 4655.5 54.3 258.3 0.000 7700.0 4713.9 54.3 258.3 0.000 7800.0 4772.3 54.3 258.3 0.000 7900.0 4830.7 54.3 258.3 0.000 8000.0 4889.1 54.3 258.3 0.000 8100.0 4947.5 54.3 258.3 0.000 8200.0 5005.9 54.3 258.3 0.000 8270.3 5047.0 54.3 258.3 0.000 8300.0 5064.2 54.5 257.2 3.010 8400.0 5121.8 55.2 253.7 2.998 8500.0 5178.2 56.1 250.2 3.004 8600.0 5233.4 57.0 246.8 2.999 8700.0 5287.0 58.0 243.4 3.000 8800.0 5339.1 59.2 240.1 3.000 8900.0 5389.5 60.4 237.0 2.998 9000.0 5437.9 61.6 233.9 3.006 9100.0 5484.4 63.0 230.8 2.999 9200.0 5528.7 64.4 227.9 2.997 3s-23 Side Track.cfw; 03-09-2006 ; Loadcase X5: Version wcs<em45_89 Page 4 ORIGINAL • • Client CAPI Well 35-23 L1 String 7lntermediate District Prudhoe Bay Country Loadcase XS MD ft) Directional Survey Data TVD Deviation Azimuth (ft) de) de Dogleg Sev. de /100ft 9300.0 5570.8 65.9 225.0 3.001 9400.0 5610.4 67.4 222.2 3.002 9500.0 5647.6 68.9 219.4 2.997 9600.0 5682.2 70.6 216.7 3.001 9606.7 5684.5 70.7 216.5 2.928 9700.0 5714.2 72.2 214.1 3.005 9800.0 5743.3 73.9 2 i 1.5 2.999 9900.0 5769.6 75.6 208.9 3.004 10000.0 5793.0 77.3 206.4 2.997 10029.9 5799.5 77.9 205.7 2.995 10100.0 5813.4 79.1 203.9 3.008 10200.0 5830.8 80.9 20 i .5 2.998 10300.0 5845.1 82.7 199.1 2.996 10381.8 5854.4 84.2 197.1 2.997 10400.0 5856.2 84.5 196.6 3.023 10427.2 5858.7 85.0 196.0 2.999 10432.0 5859.1 85.0 196.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (Iblgal) (Ib/gal) 9607.0 14.00 9.70 Kalubik Shale 10380.0 14.00 9.70 kalubik Shale 10382.0 12.50 9.42 Top C4 Sandstone 10432.0 12.50 9.42 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 25 0.0 1710.0 1548.6 28 0.2 4040.0 2610.0 56 1.2 10432.0 5859.1 140 2.0 Sc~~m~r~~r Page 5 3 s23 Side Track.cfw ; 03-09-2000: Loadcase XS ;Version wcs-cem45_69 ~:,.«. • • Client CAPI SI~~rg~r Well 35-23 L1 String 7lntermediate District Prudhoe Bay Country Loadcase XS Section 2: centralizer placement Top of centralization :9432.0 ft Bottom Cent. MD :10422.0 ft Casing Shoe :10432.0 ft NB of Cent. Used :27 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 10352.0 23 1/1 51102570-7-4-25 (3116")A 40.5 9452.0 10432.0 4 2/1 S1102570-7-4-25 (3/16")A 92.7 10432.0 Centralizer Description Centralizer Tests Name Code Casing Cent Max. Min. OD Rigid Origin Hole Size Running Restoring . OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) S1102570-7-425 7 9.874 8.000 No Houma 8.500 415.90 2891.04 (3/16")A (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 6 3s-23 Side Track.cfw ; 03-09-2006 ; L°adCase XS ; Version wcs~cem45_69 • • Client CAPI Well 35-23 L1 String 7lntermediate District Prudhoe Bay Country Loadcase XS Section 3: fluid description Mud DESIGN Fluid No:1 Density : 10.501b/gal Job volume :376.1 bbl CW100 DESIGN Fluid No:2 Density : 8.32 Ib/gal Job volume :30.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 12.50 Ib/gal Job volume :40.0 bbl Water Fluid No: S Density : 8.32 Ib/gal Job volume :20.0 bbl Tail Slurry DESIGN Fluid No:6 Density Rheo. Model : HERSCHEL_B. k At temp. : 115 degF n Tv Get Strength SI~~rg~r 15.80 Ib/gal 4.94E-3 Ibf.s^n/ft2 0.870 :3.24 Ibf/100ft2 (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid :5.093 gal/sk Job volume :42.6 bbl Dry Density : 199.77 Ib/ft3 Yield : 1.16 ft3/sk Quantity : 205.83 sk Sack Weight : 94 Ib Porosity :58.6 % Solid Fraction :41.4 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Base Fluid :5.093 gal/sk Additives Code Conc. Function D167 0.400 %BWOC FLUID LOSS D065 0.300 %BWOC DISPERSANT D046 0.200 %BWOC ANTIFOAM 8155 0.080 %BWOC RETARDER Page 7 3s-23SideTrack.cfw;03-09-2006; LoadCaseXS;Versionwcs/j~~\em45_89 '•,..f' a 1 ~ ~ ~ • • • Client CAPI Well 35-23 L1 String 7lntermediate District Prudhoe Bay Country Loadcase XS ~~ ~~I~~rg~r section 4: riuia se uence Original fluid Mud 10.50 Ib/gal k : 1.32E-2 Ibf.s^n/ft2 n :0.563 Tv :5.36 Ibf/100ft2 Displacement Volume 396.1 bbl Total Volume 508.7 bbl TOC 9432.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) CW100 30.0 759.0 7661.0 8.32 viscosity:5.000 cP MUDPUSH II 40.0 1012.0 8420.0 12.50 k:8.59E-2 Ibf.s^n/ft2 n:0.279 Tv:11.82 Ibf/100ft2 Tail Slurntr 42.6 1000.0 0432,0 15,RQ k;4.94E-3 Ibf-s^n/ft2 n:0.870 Tv:3.24 Ibf/100ft2 Water 20.0 9829.3 8.32 k:3.05E-31bf.s^n/ft2 n:0.411 Tv:0.211bf/100ft2 Mud 376.1 0.0 10.50 k:1.32E-21bf.s^n/ft2 n:0.563 Tv:5.361bf/100ft2 Static Security Checks Frac 472 psi at 4040.0 ft pore 111 psi at 4040.0 ft Collapse 5006 psi at 10352.0 ft Burst 7190 psi at 8420.0 ft Csg.Pump out 63 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. (degF) Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW100 5.0 20.0 4.0 30.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 6.0 40.0 6.7 40.0 80 Tail Slurry 6.0 42.6 7.1 42.6 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to rig Mud 6.0 350.0 58.3 350.0 80 Mud 4.0 20.1 5.0 370.1 80 Slow rate ECD Mud 2.0 6.0 3.0 376.1 80 Slow & bump plug Total 01:55 508.7 bbl hr:mn Dynamic Security Checks Frac 1 psi at 10432.0 ft Pore 109 psi at 4040.0 ft Collapse 4950 psi at 8206.3 ft Burst 6440 psi at 0.0 ft Page s 3s-23 Side Track.cfw; 03-09-2006 ; ~oadCase KS ;Version wcs-cem45_89 ORIGINAL C] Client CAPI Well 3S-23 L1 String 7lntermediate District Prudhoe Bay Country Loadcase XS Section 6: WELLCLEAN II Simulator ft 0 o.: . a tti . 0 o. 0 ~'. o' 0 o' rn. ci- 0 Q' O' O O p: T.' Cement Coverage 9580- 9600- 9700- 9800- -, 9900- r 10000- ° 10:04 10240• 10340- 10440• Fluids. Concentrations E x° `9500 9400 9700 9800 _ 9900 ~- L 10004.;, a°. 1-0:f 00 6 10204 10300 ~ .Mud ®MUDPUSH II ~ Water. ~ CW100 ® Tail Slurry 9600 970Q _ 9$00 9500 a 1.0000 ~ 10140 10200 10300 10400 5409 9?DO 9840 9900 ~- r 1.0400 :aa, 0 10100 10204 70344 +odoo ~ .High ®Low ® Medium ®Norie Page y 3623 Side Track.cfw ; 03-09-2006: Loadcase XS ; Versim /w/c~s\-cem45_89 }C1~i l~ ~~IImM~rg~r Risk-Mud on the Wall x° • pro • • Client CAPI Well 3S-23 L1 String 7lntermediate District Prudhoe Bay Country Loadcase XS ft o] rn O O O ~ 1 o I r ' Fluid Sequence i Y- i ri t~l 1 ~ I r._. r._-T._-~.. _.7. __y.._._I I I I I I I I I t I 1 I i I I 1 t I 1 Dynamic Well Security ~ !----`-----°i -- - --' i - .N ~ n - - --- - ---- - --- - -.__,--i j I f 7 1 I -I l i. = O O > _ __.._.... J.__.___..-_-_____; M -_--- '-- -_._, i i_,.. - - -~--- -----. _.1 --- i~ i 0 100 200 Time (min) o Depth = 10432 ft --•---• --- C N ~ r AnnularVeloaty ; I ! ! i t li I ' 1 ~Q 11! I11: ~! ! -i Y ! ! ~ ~ I I I I I Y "' 0l 1 I 1 Y !I! 111[ -I Y ili Il!I ! I 1 i "~1" i I I' Y ii i Y lil It I ~ Q Y l~l U i j ._. _.-. i. .-. 0 100 200 Time (min) Depth = 10432 ft _„ .~-- I_._r_._.r._..._._i___.T..__r_._.r._._r___.r._.~._._r_._._._._~_._.r._._r_.__r. _.l-_. _.r._._.___7_. _ _._. Frac t.-.~.__Y._._.r._.y._._~_.-.Y._._,_-__r-_._,_.__r__.y.___r___y...._~_J.r. _i_I___.~._. y.___.i.. _. y-___ _~ ___- H dro static r. _._~._ . _ _ , _ ~ ~ ~ ~ I _I_: I ~._._._._ ~ N - -' ~Yn$min 1F 1__. J._. 1r1~• •~_~1_._11._._i_-__1. _._t_._-L._. J._._J_. _.~__._1_. ~.L-_.'_t._. _- J_, J._._ I F. _., I l'-- .1 I I yr1._. i I J. _._1___. I ~-_. J.___. N 1 ; I t j 1 I 1 i 1 ~ ~ - l r r _.~-___-r._.i._-'r-_--r--_:.___-r c' -'r' -I "'Y'.r, .-r - ( ~~ r r - 0 25 50 75 Time (min) Fluids at 10.432 ft _ _. I. _.=.-O Out , h_.-.t._.1 ~'- .'-._f- ''" t ~ --r-- - t -' ~ r i I ~ _J, - Q In I 1 I -~ i - -= S I T I ~ I ~ ~-i-~~.~ -a_~ -'i_. _r i._ t ..._ _¢._ J~i- ~i - ~ - ~ r~ -- , I r I I L~' -_ .O J _._r1 _. T._ ~i' 1 II ' f r _I._. 1 Y _ m I•-' i .-i tJ-'-'r"~- ',~ 1 . .1'_.ii ~ 1 i i ~.-` ~._ _ 1--, i ~ r t ~ f ~ ~ -~._ ~ Ind- ~ •-i-'~-'-~r '-1 ZI_.1 i I I I r I _ ._ N L.ti I . _._ - - - - Y~_ _. F r J 1_ I 1 l~. L J_ IL ~t i t 11 _ J 1 l L J J_ I L 1 _ I J L J ._ LL Y r ,_ I A J ~.. -a ._ V~_.~ -i~7 j 1 -J 1 l- I- d, -' - _ _ - , 1, _ IY _I 1- J - -- o fa.~._._._~-._,_._.i._.T._.~_.-J.._.J.__~~T._._._._.-._ -._._._ _..~.-__._.-. _. _._._.s._._._i ._.F.-._._.-.-._ _._._ 0 25 50 75 100 12 Time (min) Nage fu 3s-23 Side Track.cfw; 03-(/3-2006 ; Loadcase XS ;Version wcs-cem45_89 Ib/gal 12 • • 3S-23A Drilling Hazards Summary 8-1/2" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Shale stability in HRZ, K-1, and Low Control with higher MW and proper drilling Miluveach radices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on tri s as a last resort. Barite Sa Low Good drillin radices as documented in well Ian. Differential Sticking Moderate Periodic wiper trips. Do not leave pipe static for extended eriod of time. Abnormal Reservoir Pressure Moderate 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 rior to drillin a interval. Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-1/8" Hole / 4-1/2" Slotted liner Interval Event Risk Level Miti ation Strate High ECD and swabbing with High Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling pay interval. Pump and rotate out on tri s as a last resort. Abnormal Reservoir Pressure High Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Monitor PVT equipment. Kee hole full. Trouble Steering High Use Rotary Steerable assembly with Periscope. Use maximum volume of Super Sliders, torque/drag will be monitored to pro-actively identify a need for friction reduction devices to revent wei ht transfer roblems. Differential Sticking Moderate Periodic wiper trips. Do not leave pipe static for extended eriod of time. Sto losses with LC decision tree. Lost Circulation High Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, pre-treat with LCM prior to drilling fault crossings. Use LC decision tree designed for production laterals. Well Control Moderate Reservoir pressure is modeled to increase as the well is drilled to the toe. Highest expected reservoir pressure is expected to be 11.2 ppg based on model data. Close observations of flow checks while making connections near the bottom of the well and before tripping will be erformed. Siderite Noodules causing high High Near bit inclination will be first indicator that a dog leg doglegs problem has developed. Watch for hard drilling and keep deflection low in hi h Siderite areas. i 3S-23A Drilling Hazards Summary Page 1 of 1 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 • 6000000 5950000 5900000 5850000 ~-- 400000 a~ x"`17 500000 600000 700000 800000 • • • SHARON K. ALLSUP-DRAKE 1141 CONOCOPHILLIPS ATO 1530 ~- 700 G ST. l G~/Cl2 ~ / ~ ~~~ ~' ANCHORAGE AK 99501 DarE ss-X551/aai s', '~ PAY TO THE ~! ~ ~G~ 1~~~~ ~U" ` ~Li I / f (/l: I ~~ ~ /C/D- fj ~ J F ORDER OF .. ~~ - ( C~ ~' a ~/ ,(,Cil~~"7-~~ ~ yi ~'--~ ~~ DOLLARS L~J o~ JPMorganChase~ ~ Valid Up To 5000 Dollars ,~ JPMorgan Chase Bank, N.A. Columbus, OH ~~ fi~ MEMO -----_.._---.- _ ~~ r ~:044~155LL~:52874?L90792711'LL4~ .. __ _._ .~. • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~/~GC- 3~ f ~~' ` PTD# ~~ ~ - ~ 7 " Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and (ogs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception, assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (,Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist • ~ ^^ , , N O- ~ ~ ~ ~ ~ y y N ~ ~ ~ ~ ~ ~ ~ Y o o, ~; . ~ ~ ~ , 3. s 3. a ~ , O m. • ~ °, a° o- a , o, . n m , ~ a- o Q ~, ~ u-, _ ~ , O ~ ~ d ;, m o, ~ p , m O x m ~ ~ ~, , 0 ~ ~ 0~ i a ~ Ci ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Y, ~' C. ~ ~, 0 p, T ~, ; Z, ~ a o. a m -a ~ ° ar ° N 3, ° ~ p 3, ~ a. p, • N' ' a' c o ~ 3 ~, o ~ Q Q. _ v. ~, ~ ~ C, O• O~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ p ~ O. ~~ `~ N .O, _ ~ O. f0. ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ f6• O ~ p. - c _ m p N N m ~ c6, d c Q M ~ N, ~ G tt~ d ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Ul, y ~ a, ~ .M •Q G W O, ~ • 7~ _ N, ~, , ~, ~ ~ ~ -O C fA a p' ~ J '~ E O' ~ ~ . ~ 14 O U r 4 Z ~ m ~' S W E. y M d ~, ~~ ~ N ~ ~ ~ ~ ~ ~ ~ ~ ~~ d ~ C' rn ~ ~Op ~ C~ N. Vl, a' 7. rn a d ~ ~ U ~ O. ^, Q ~ ~ ~ U1 C ~ ~ ~ ~ ~ , O m, O W O O r ~ ~ N O Y ~ , . L' , «~. ~ c, f/? p, y, Y ~ ~ M. Q. 3~ °' ~ ~ C U O ~ f0 ~ O ~ C N N ~ ~ Q ~ ~ J. ~ d ~~ ~ ~ t ~ Y N ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ , , M. ~, a. N. a. 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To improve the readability of the Well History file and to simplify finding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically . organize this category of information. ~o~ - bY3 ¢ /3~~ Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 29 08:21:26 2006 Reel Header Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date...... ...............06/06/29 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 W-0004333321 E. QUAM D. HIEM • Scientific Technical Services Scientific Technical Services 3S-23A 501032045301 ConocoPhillips Alaska Inc. Sperry Drilling Services 23-JUN-06 SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 18 12N 8E 2560 1246 57.65 27.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4040.0 REMARKS: • • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL SEGMENT REPRESENTS THE INTERMEDIATE SECTION ONLY OF 3S-23A. IT EXITED THE 3S-23 WELLBORE AT 4040'MD (THE 9.625" CASING SHOE) BY MEANS OF A CEMENT PLUG (AFTER 300' OF 7" CASING HAD BEEN REMOVED). THE PRODUCTION SECTION WAS DRILLED AND LOGGED BY OTHERS. 4. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL AUTHORIZATION FROM THE GKA GEOSCIENCE GROUP. 6. MWD RUN 1 REPRESENTS A PART OF WELL 3S-23A WITH API#: 50-103-20453-01. THIS SECTION REACHED A TOTAL DEPTH (TD) OF 10491'MD/5853'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 (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped DEPTH INCREMENT: .5000 FILE SUMMARY curves; all bit runs merged. PBU TOOL CODE START DEPTH GR 3995.5 RPD 4020.0 RPM 4020.0 RPS 4020.0 RPX 4020.0 FET 4020.0 STOP DEPTH 10446.0 10438.0 10438.0 10438.0 10438.0 10438.0 ROP 4040. .10491.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3995.5 10491 7243.25 12992 3995.5 10491 RPD MWD OHMM 0.14 2000 15.6448 12837 4020 10438 RPM MWD OHMM 0.14 2000 8.56789 12837 4020. 10438 RPS MWD OHMM 0.15 2000 5.13613 12837 4020 10438 RPX MWD OHMM 0.2 1983.18 4.63005 12837 4020 10438 FET MWD HOUR 0.31 8.69 1.22958 12837 4020 10438 GR MWD API 49.85 424.72 124.593 12902 3995.5 10446 ROP MWD FT/H 0.91 242.97 92.347 12902 4040.5 10491 First Reading For Entire File..........3995.5 Last Reading For Entire File...........10491 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 BIT RUN NO MERGE TOP MERGE BASE 1 3995.5 10491.0 Physical EOF • • File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3995.5 10446.0 RPD 4020.0 10438.0 RPM 4020.0 10438.0 RPS 4020.0 10438.0 RPX 4020.0 10438.0 FET 4020.0 10438.0 ROP 4040.5 10491.0 LOG HEADER DATA DATE LOGGED: 07-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10491.0 TOP LOG INTERVAL (FT) 4040.0 BOTTOM LOG INTERVAL (FT) 10491.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 52.4 MAXIMUM ANGLE: 85.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 4040.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 10.60 MUD VISCOSITY (S) 51.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.020 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .490 156.2 MUD FILTRATE AT MT: .760 72.0 MUD CAKE AT MT: 1.200 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 :API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3995.5 10491 7243.25 12992 3995.5 10491 RPD MWDO10 OHMM 0.14 2000 15.6448 12837 4020 10438 RPM MWDO10 OHMM 0.14 2000 8.56789 12837 4020 10438 RPS MWDO10 OHMM 0.15 2000 5.13613 12837 4020 10438 RPX MWDO10 OHMM 0.2 1983.18 4.63005 12837 4020 10438 FET MWD010 HOUR 0.31 8.69 1.22958 12837 4020 10438 GR MWDO10 API 49.85 424.72 124.593 12902 3995.5 10446 ROP MWD010 FT/H 0.91 242.97 92.347 12902 4040.5 10491 First Reading For Entire File..........3995.5 Last Reading For Entire File...........10491 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Tape Name ................UNKNOWN Continuation Number.... Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF Writing Library • Scientific Technical Services Scientific Technical Services End Of LIS File
