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198-213
Originated: Delivered to:12-Nov-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1D-30 50-029-22965-00 910358412 Kuparuk River Leak Detect Log Field- Final 14-Oct-25 0 12 1D-30 50-029-22965-00 910358412 Kuparuk River Multi Finger Caliper Field & Processed 15-Oct-25 0 13 1D-30 50-029-22965-00 910390851 Kuparuk River Packer Setting Record Field- Final 31-Oct-25 0 14 1E-02 50-029-20472-00 910390619 Kuparuk RiverMulti Finger CaliperField & Processed 28-Oct-25 0 15 1E-36 50-029-22927-00 910357198 Kuparuk River Tubing Cut Record Field- Final 19-Oct-25 0 16 2U-06 50-029-21282-00 910390614 Kuparuk River Multi Finger Caliper Field & Processed 19-Oct-25 0 17 3K-20 50-029-23019-00 910390195 Kuparuk River Packer Setting Record Field- Final 22-Oct-25 0 18 3R-17 50-029-22242-00 910433126 Kuparuk River Packer Setting Record Field- Final 11-Nov-25 0 1910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:200-104180-050198-213185-019201-088192-005T41088T41088T41088T41089T41090T41091T41092T41093Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.12 11:46:38 -09'00'51E-3650-029-22927-00 910357198Kuparuk RiverTubing Cut RecordField- Final19-Oct-2501198-213 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: Replace Tubing 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?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12005'2425 None Casing Collapse Conductor Surface Tie-Back 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: 907-265-6049 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 CTD/RWO Engineer Subsequent Form Required: Suspension Expiration Date: L-80 L-80 PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 7" Tubing Grade: Tubing MD (ft): Authorized Name and Digital Signature with Date: Tubing Size: Cy Eller cy.eller@conocophillips.com Current Pools: MPSP (psi): Plugs (MD): 198-213 11181' 11515' 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Proposed Pools: 11597' Burst 6290' ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY 11124'MD/5717' TVD 11408'MD/5842'TVD 11394' 11440' 9-5/8" 80' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025660 6193' P.O. Box 100360, Anchorage, AK 99510 50-029-22927-00-00 10/20/2025 12004'596' 3-1/2" 4" 6193' BluePack Max RH BAKER ZXP SSSV: None Perforation Depth MD (ft): 11720-11740' 11760-11780' 11795-11815' 6037'11754' KRU 1E-36 3996' 121'121' 6331' 16" 11559' 4-1/2" 6017-6029' 6041-6053' 6063-6075' 7" 3979'6246' 6283' 5944' m n P 1 6 5 6 t g N 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 9:36 am, Oct 22, 2025 9:37 am, Oct 22, 2025 325-643 10-404 J.Lau 10/22/25 X DSR-10/22/25 AOGCC witnessed BOP and annular test to 3000 psi. Operate well per the attached risk assessed mitigations table. SFD 10/22/2025 Jack Lau 10/21/25 10/23/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 21, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Cy Eller CTD/RWO Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1E-36 (PTD# 198-213). Well 1E-36 was worked over by Nabors 7ES from 9/27/25 - 10/14/25 where a cemented 7" tie-back (subsidence style) repair was installed to remediate a PC leak that was identified above the surface casing shoe. After running a new 3-1/2" completion with stacked packer, a passing IA pressure test was not achieved. 7ES moved off of the well and completed a workover on 1E-11 while a plug was set on 1E-36 and further pressure testing was completed. Post-rig attempts to prove IA integrity were also unsuccessful so 7ES has moved back to 1E-36. If you have any questions or require any further information, please contact me at +1-907-265-6049. This application is intended to replace the Sundry that was submitted on 10/17/2025. Under the previous Sundry, the tubing has been pulled and PC leak depth diagnostics have been started. A 5-1/2" tie-back with 3-1/2" completion will be installed once the PC leak depth has been identified. 1E-36 RWO Procedure KUPARUK RIVER UNIT Producer PTD #198-213 Page 1 of 3 General Well info Wellhead type/pressure rating: FMC Gen IV Production Engineer: Banabas Dogah Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: 10/20/25 Workover Engineer: James J Ohlinger (+1-907-265-1102/ James.J.Ohlinger@conocophillips.com) On-Call Engineer: Cy Eller (907-265-6049) Current Operations: Tubing has been pulled from a pre-rig cut at 11098 RKB, and the PC leak depth is currently being identified using a test packer following the Sundry submitted for the 2nd workover that was verbally approved by Jack Lau on 10/18/2025. Well Type: Producer Scope of Work: Continue leak hunting. If PC leak is identified near the surface casing shoe (6200 6350), then a 5-1/2 tie-back liner and 3-1/2 gas lifted completion will be installed. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / Drilling Spools Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed on rig MIT-IA Failed; 100 psi in 15 minutes MIT-OA Cemented to surface during previous subsidence workover IC POT Passed on rig IC PPPOT Passed on rig MPSP: 2425 psi using 0.1 psi/ft gradient Static BHP: 3028 psi / 6029 TVD measured on 4/28/25 Pre-Rig Work Completed 1. Failed IA tests post circ-out, decision made to workover and diagnose PC leak depth. 2. Set plug in X-Nipple @ 11,181 RKB 3. Tubing Cut @ 11098 RKB 1E-36 RWO Procedure KUPARUK RIVER UNIT Producer PTD #198-213 Page 2 of 3 Rig Work MIRU - Completed 1. MIRU Nabors 7es on 1E-36. (No BPV will be installed due to risk assessment done for MIRU/RDMO on 7es w/o BPV.) 2. Circulate well to SW. Record shut-in pressures on the T & IA. If pressure is observed, bleed off pressure and complete 30-minute NFT. KWF will be used as needed if mechanical barrier does not pass 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve Tubing - Completed 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2 tubing down to pre-rig cut (if conducted) a. If not, RU Eline for Welltech Cutter Diagnose PC Leak Depth Current work in progress 6. RIH with test packer BHA first run yielded inconclusive results. Upper VBRs (2-7/8 x 5) compromised while testing. 7. Replace 2-7/8 x 5 VBRs and test on 3-1/2 test joint to 250/3000 psi. Test annular and lower VBRs (3-1/2 x 5- 1/2) on 5-1/2 test joint to 250/3000 psi for upcoming 5-1/2 liner install. 8. RIH with test packer BHA. Set at 6200, test above and below. RIH to 6350, set and test above and below. a. If test packer runs at shallow depth pass, continue in hole and test for leaking packer and continue with plan outlined in original Sundry. b. If test packer runs identify PC leak near shoe (6200 6350 RKB), POOH LD drillpipe and continue with steps below to install 5-1/2 tie-back. Wellhead Swap 9. RIH and set RBP/storm packer. PT to confirm as a barrier. 10. ND BOPs, ND tubing head, NU new 5-1/2 casing spool. NU BOPs and test breaks. 11. RIH and pull RBP/storm packer. Install 5-½ Tie-Back 12. MU and RIH with non-sealing overshot, nipple profile, 3-1/2 x 7 packer, GLM, sealbore, and 5-1/2 casing. 13. Once on depth, circulate CI and space out, drop ball and rod and pressure up to set packer. 14. RU Slickline, pull ball and rod, RD Slickline. 15. Pressure test 5-1/2 casing string and 3-1/2 x 7 packer from below to 2500 psi. 16. RIH and set RBP in 5-1/2 casing at ~100. PT to confirm as barrier. 17. ND BOPs, land 5-1/2 casing in slips and install packoffs. NU new tubing head and BOPs and test breaks Install 3-½ Completion 18. MU and RIH with seal assembly, nipple profile, GLMs and 3-1/2 tubing. 19. Once on depth, space out and land seals and tubing hanger. 20. Pressure test tubing to 3000 psi for 30 minutes. 21. Pressure test IA to 2500 psi for 30 minutes. ND BOP, NU Tree 22. Confirm pressure tests, then shear out SOV with pressure differential. 23. Install BPV. 24. ND BOPE. NU tree. PT tree. 25. Pull BPV, freeze protect well at opportune time, and set BPV if necessary. 26. RDMO. 1E-36 RWO Procedure KUPARUK RIVER UNIT Producer PTD #198-213 Page 3 of 3 Post-Rig Work 27. Install GLD. 28. Pull all plugs, X-lock and Hex. 29. Turn over to operations. Post-RWO, 1E-36 will be operated following the risk assessment table below: Note: The OOA is cemented to surface but will still have a pressure transmitter installed. 325-325 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:SLM 11,745.0 1E-36 1/5/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set XX Plug, Set Catcher, Pull DV, Cut Tbg 1E-36 10/19/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 9/8/2010 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 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 40.6 6,330.5 3,995.7 40.00 L-80 ABM-BTC Tie-Back String 7 6.28 37.0 6,283.2 3,979.0 26.00 L-80 Hyd 563 PRODUCTION 7 6.28 6,280.0 11,597.0 5,944.1 26.00 L-80 BTC-MOD LINER 4 1/2 3.96 11,408.1 12,004.0 6,192.8 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 11,098.0 Set Depth 11,394.0 String Max No 3 1/2 Set Depth 5,835.1 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M ID (in) 2.92 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) 11,124.0 5,716.9 67.61 Packer 6.276 3 1/2" x 7" Bludpack Max RH Packer SLB Bluepac k Max 2.885 11,180.8 5,739.3 66.03 Nipple - X 3.943 3 1/2" x 2.813 X nipple HES X Nipple 2.813 11,387.5 5,831.9 60.59 Overshot 5.900 3 1/2" x 7" PBOS. (1.96' from fully located) Norther Solution s Poor Boy Oversho t 3.960 Top (ftKB) 11,391.0 Set Depth 11,439.9 String Max No 4 Set Depth 5,858.1 Tubing Description Tubing Completion Lower Wt (lb/ft) Grade Top Connection ID (in) 3.00 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,413.6 5,844.9 59.97 LOCATOR 5.125 BAKER LOCATOR 3.000 11,414.9 5,845.5 59.94 SEAL ASSY 4.000 BAKER EXT TUBES & 9.97' SEAL ASSEMBLY 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) 37.0 37.0 0.00 EMERGENCY SLIPS C-21. 11" x 7" Emergency slips. 10/9/2025 7.000 11,098.0 5,707.2 68.34 CUT HES MECHANICAL TBG CUT AT 11,098' RKB 10/19/2025 2.992 11,177.1 5,737.8 66.13 CATCHER 2.72" AVA CATCHER, OAL 44" 10/17/2025 0.000 11,180.8 5,739.3 66.03 TUBING PLUG 2.81" XX PLUG w/ FILL EXT (OAL= 48") FN 2.31", EQ WATERMELON 1.62" 10/17/2025 0.000 11,710.0 6,010.7 52.92 CATCHER 2.71" x 8' CATCHER 9/8/2025 0.000 11,718.0 6,015.5 52.78 PLUG 230-450 INTERWELL HEX PLUG, MOE = 11,520' RKB, OAL = 8.43', FN = 2.5" GS ***CATCHER/PLUG MOVED DOWNHOLE ~200' TO ~11,710' RKB*** INTERW ELL HEX 25023 2 9/8/2025 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) 6,236.6 3,962.8 69.73 Collar - Stage 8.300 7" Innovus Multicycle Frac Sleeve Innovus Frac Sleeve 6.276 6,254.7 3,969.1 69.67 Packer 8.681 7" ICP Innovex Casing Packer Innovex ICP 6.276 11,408.1 5,842.1 60.10 PACKER 4.500 BAKER ZXP LINER PACKER & TIEBACK SLEEVE (LOCATOR @ 11415.38') 3.958 11,939.3 6,152.0 51.01 LANDING COLLAR 4.500 BAKER LANDING COLLAR 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,720.0 11,735.0 6,016.7 6,025.8 C-4, 1E-36 3/4/1999 4.0 APERF 150 deg. phase; 2.5" HC,DP 11,720.0 11,740.0 6,016.7 6,028.8 C-4, 1E-36 10/11/1999 4.0 RPERF 2.5" HC, DP chgs; 180 deg phasing 11,760.0 11,780.0 6,041.1 6,053.3 C-4, 1E-36 10/11/1999 4.0 RPERF 2.5" HC, DP chgs; 180 deg phasing 11,760.0 11,780.0 6,041.1 6,053.3 C-4, 1E-36 12/31/1998 4.0 APERF 180 Deg phasing; 2.5" HC 11,795.0 11,815.0 6,062.5 6,074.8 C-4, C-3, 1E-36 11/23/1998 4.0 IPERF 0 Deg phase +/- 90 deg. from low side; 2.5" HC Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date Surface String Cement 1E-36, 10/21/2025 1:59:52 PM Vertical schematic (actual) LINER; 11,408.1-12,004.0 IPERF; 11,795.0-11,815.0 APERF; 11,760.0-11,780.0 RPERF; 11,760.0-11,780.0 Primary Full Bore; 11,485.0 ftKB RPERF; 11,720.0-11,740.0 APERF; 11,720.0-11,735.0 PLUG; 11,718.0 CATCHER; 11,710.0 PRODUCTION; 6,280.0- 11,597.0 Primary Full Bore; 10,942.0 ftKB TUBING PLUG; 11,180.8 Nipple - X; 11,180.8 CATCHER; 11,177.1 Packer; 11,124.0 CUT; 11,098.0 SURFACE; 40.6-6,330.5 Tie-Back String; 37.0-6,283.2 Primary Full Bore; 3,786.0 ftKB Primary Full Bore; 47.5 ftKB Intermediate String 1 Cement; 37.0 ftKB CONDUCTOR; 41.0-121.0 EMERGENCY SLIPS; 37.0 KUP PROD KB-Grd (ft) 47.51 RR Date 11/13/199 8 Other Elev 1E-36 ... TD Act Btm (ftKB) 12,005.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292292700 Wellbore Status PROD Max Angle & MD Incl (°) 70.59 MD (ftKB) 9,221.62 WELLNAME WELLBORE1E-36 Annotation Last WO: End DateH2S (ppm) 320 Date 8/12/2016 Comment SSSV: NONE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 47.5 6,330.0 47.5 3,995.6 Primary Full Bore Lead 349 bbl 10.5 ppg Arctic Set III + Tail 10 bbl Cement... Stage #2: Circ out cmt contaminated mud - Cond mud for Stage #2 - Pump 30 bbl FW. Mix & pump AS III, followed by 10 bbl Tail. Displ w/rig pumps. Close stage tool w/1300 psi - Had approx 100 bbl cmt returns to surface. ^^Csg OD=9.625 3,786.0 6,330.0 2,951.4 3,995.6 Primary Full Bore Lead 130 bbl 10.5 ppg Arctic Set III + Tail 175 bbl 15.8 ppg Class G... Stage #1: RIH w/9-5/8" csg - Circ 1X csg volume @ 2000' and 3900'. MU hanger and land csg @ 6330' - Circ & cond mud @ 10 BPM, Total vol circ = 870 bbl. PT lines to 3500 psi. Pump 20 bbl wash, 40 bbl Spacer. Mix & pump AS III Lead, followed by Class G Tail. Displ w/rig pumps. Bump plug - Load top plug - Open stage tool w/2990 psi. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 10,942.0 11,597.0 5,650.8 5,944.1 Primary Full Bore Single Stage 35 bbl 15.8 ppg Class G ... RIH w/7" csg - PT cmt lines to 3500 psi - Pump 20 bbl ARCO wash + 40 bbl ARCO spacer. Mix & pump 35 bbl Class G. Displ w/mud using rig pumps. Bump plug - Floats held. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=7 11,485.0 12,004.0 5,881.6 6,192.8 Primary Full Bore Single Stage 21 bbl 15.8 ppg GasBlok-G ... Run 4- 1/2" liner - Circ & cond mud/hole for cmt @ 40 SPM, 3.4 BPM, 1700 psi while recip pipe - Circ volume total = 1063 bbl - Dowell flush lines w/5 bbl H2O, PT lines to 4500 psi. Pump 10 bbl ARCO wash @ 3.2 BPM, 1500 psi. Pump 30 bbl ARCO Spacer @ 13.5 ppg, 2.9 BPM, 1300 psi. Pump batch mixed Class G GasBlok cmt @ 15.8 ppg, 3.0 BPM, 1100 psi. Flush lines w/5 bbl H2O. Displ w/mud. Bump plug w/3200 psi. - Floats held. CIP @ 02:30 11/11/98. Had full returns - Recip'd pipe until preflush & spacer neared shoe. Circ out ~44 bbl preflush, spacer, & excess cmt. ^^Csg OD=4.5 37.0 6,254.7 37.0 3,969.1 Intermediate String 1 Cement Flood lines w/ 5 Bbls fresh water. PT lines. Pump 40 Bbls 11.0 PPG Tuned spacer w/ red die @ 4.2 BPM, 780 PSI. Pump 260 Bbls 15.3 PPG Primary cement @ 3.5 BPM, 1945 PSI. Pump 10 Bbls fresh water @ 3.3 BPM, 1692 PSI. Displace w/ rig 28.3 Bbls 10,.2 Brine @ 3.5 BPM, 2250 PSI. 50 Bbls 15.3 PPG cement returned to surface. Shift NCS sleeve closed. Bleed off no flow. Cement in place @ 13:49 Hrs. 10/10/2025 1E-36, 10/21/2025 1:59:52 PM Vertical schematic (actual) LINER; 11,408.1-12,004.0 IPERF; 11,795.0-11,815.0 APERF; 11,760.0-11,780.0 RPERF; 11,760.0-11,780.0 Primary Full Bore; 11,485.0 ftKB RPERF; 11,720.0-11,740.0 APERF; 11,720.0-11,735.0 PLUG; 11,718.0 CATCHER; 11,710.0 PRODUCTION; 6,280.0- 11,597.0 Primary Full Bore; 10,942.0 ftKB TUBING PLUG; 11,180.8 Nipple - X; 11,180.8 CATCHER; 11,177.1 Packer; 11,124.0 CUT; 11,098.0 SURFACE; 40.6-6,330.5 Tie-Back String; 37.0-6,283.2 Primary Full Bore; 3,786.0 ftKB Primary Full Bore; 47.5 ftKB Intermediate String 1 Cement; 37.0 ftKB CONDUCTOR; 41.0-121.0 EMERGENCY SLIPS; 37.0 KUP PROD 1E-36 ... WELLNAME WELLBORE1E-36 1E-36 Proposed Completion Producer COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121 121 16 15.06 62.58 H-40 WELDED WELDED Surface 6330.5 3995.7 9.625 8.83 40 L-80 ABM-BTC ABM-BTC Production Tie-Back 6279 3978 7 6.28 26 L-80 Hyd563 Hyd563 Production 11597 5944.1 7 6.28 26 L-80 BTC-MOD BTC-MOD Proposed Tie-Back ~11098 ~5707 5.5 4.95 15.5 L-80 Hyd563 Hyd563 Proposed Tubing ~10935 ~5648 3.5 2.992 9.3 L-80 EUE-M EUE-M Tubing 11440 5858 3.5 2.992 9.3 L-80 EUE EUE Liner 12004 6192.8 4.5 3.96 12.6 L-80 NSCT NSCT 449 Proposed 5-1/2" Tie-Back 5-1/2" 15.5# L80 HYD563 Casing to Surface PBR 3-1/2" x 1-1/2" Gas Lift Mandrel 3-1/2" x 7" Packer @ ~10,980' RKB 3-1/2" x 2.813" X Nipple Profile 3-1/2" Poor-Boy Overshot @ ~11,098' RKB Proposed Completion 3-1/2" 9.3# L80 EUEM Tubing to Surface 3-1/2" x 1" Gas Lift Mandrels @ TBD 3-1/2" x 2.813" X Nipple Profile 80-40 Locator Seal Assembly Existing 7" Subsidence Repair 7" 26# L80 HYD563 Casing to Surface 7" NCS Cementer @ 6,237' RKB 7" x 9-5/8" External Casing Packer @ 6,254' RKB 7" Sealing Overshot Casing Patch @ 6,279' RKB Existing Completion Left in Hole Tubing Cut @11,098' RKB 3-1/2" x 7" SLB BluePack Packer @ 11,124' RKB 3-1/2" Camco X-landing nipple @ 11,181' (2.813" min ID) Poor-boy Overshot @ 11,387' RKB Tubing Cut @ 11,391' RKB Surface Casing 6331' RKB Production Casing 11597' C-Sand Perfs Conductor ZXP Liner Packer 11,408' RKB TOC 10,942' RKB HC Zone ~3600'-5450' MD Ugnu Schrader Bluff West Sak Kalubik 11,498'-11,715' HRZ 10,937'-11,498' TOC 11,485' RKB Stage C. @ 2411'TOC 3786' RKB HEX Plug w/ Catcher 11,515' RKB - 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: Replace Tubing 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?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12005'2425 None Casing Collapse 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: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4529 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 11720-11740' 11760-11780' 11795-11815' 11559' 4-1/2" 6017-6029' 6041-6053' 6063-6075' 6193'11515'6037'11754' KRU 1E-36 3996' 10/7/2025 Date: 12004'596' 3-1/2" 6123' BAKER ZXP SSSV: None Perforation Depth MD (ft): 121'121' 6331' 5944' 16" 9-5/8" 80' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025660 198-213 P.O. Box 100360, Anchorage, AK 99510 50-029-22927-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 11408'MD/5842'TVD 11440' 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. Proposed Pools: 11597' Burst 6290' Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 7" Adam Klem adam.klem@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: L-80 m n P s 1 6 5 6 t g N 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 10:06 am, Oct 07, 2025 Digitally signed by Adam KlemDN: CN=Adam Klem, E=adam.klem@conocophillips.com , C=US Reason: I am approving this document Location: Date: 2025.10.07 09:43:03-08'00' Foxit PDF Editor Version: 13.1.6 Adam Klem 325-609 BJM 10/7/25 Conditions of approval on sundry 325-504 still apply. Include in the 10-404 a corrected wellbore diagram with both stages of surface casing cement indicated and second stage cement top to surface. A.Dewhurst 07OCT25 Yes 10/6/25 Bryan McLellan 10-404 DSR-10/10/25 10/13/25 1E-36 RWO Procedure KUPARUK RIVER UNIT Producer PTD #198-213 Page 1 of 4 General Well info Wellhead type/pressure rating: FMC Gen IV Production Engineer: Banabas Dogah Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: 09/24/25 Workover Engineer: James J Ohlinger (+1-907-265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in; 4/21/25 Well Type: Producer Scope of Work: Pull the existing 3-1/2 completion down to a pre-rig tubing cut, ~11,391 MD. A test packer run will be conducted to confirm the 7 production casing leak intervals, and the remaining casing condition. To isolate the leaks from any hydrocarbon bearing zones, new 3-1/2 tubing with a stack packer and seal assembly, or dual packers to straddle the leaks will be run. The surface casing has a minimal subsidence of 27, and the recent tubing caliper shows no tubing anomalies or restrictions indicating that a subsidence like repair is required. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / Drilling Spools Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 4/30/25 MIT-OA Open shoe IC POT Failed 4/21/25 IC PPPOT Passed 4/21/25 TIFL Failed 4/21/25 SCLD Complete 11/18/21 CMIT TxIAxOA (1000 psi) Inconclusive 5/18/25 MPSP: 2425 psi using 0.1 psi/ft gradient Static BHP: 3028 psi / 6029 TVD measured on 4/28/25 Pre-Rig Work 1. Pull CA-2 plug, set HEX plug in liner (below packer) 2. MIT-T 3. Open lowest GLM in upper completion. Dummy off other GLMs. 4. Pack-off Tests 5. Function Test LDS/GNS 6. Tubing Cut ~11,391 RKB 7. Prepare well within 48 hrs of rig arrival. 1E-36 RWO Procedure KUPARUK RIVER UNIT Producer PTD #198-213 Rig Work MIRU 1. MIRU Nabors 7es on 1E-36. (No BPV will be installed due to risk assessment done for MIRU/RDMO on 7es w/o 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; a HEX plug was set ~11,500 MD. Circulate KWF if the downhole barrier cannot be verified. 3. Set BPV and confirm as barrier, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2 tubing down to pre-rig cut (~11,391 RKB). Production Casing Testing 6. RIH w/ test packer and confirm the production casing leak depths a. Top of cement ~10,942 RKB START OF CAP Current Well Status: Tubing stub at 11,391 MD Plug set in 7 casing at 11,348 MD and pressure tested to 2000psi Known leak from 5,704-6,244MD Casing from top of plug at 11,348 to 6,244 MD pressure tested to 2000psi with 10.2# brine Pull 7.0 Casing from below known leak 7. Set plug in 7 casing @ ~6500 MD and PT. Dump sand on top of plug 8. Bleed OA to O psi and monitor for no flow for 30 minutes 9. ND BOPE. 10. Grow/stretch and cut (if needed) 7 casing at surface 11. ND old tubing spool. NU DSA and BOPE. a. Cant test flange break with test-joint since packoffs are removed and 7 is above flange. Test 11 3k flange break to 3000 psig at earliest opportunity. 12. Cut 7.0 casing with cutter at ~6,250 MD 13. Pull 7.0 casing down to cut (~2500). 14. Test 11 3k flange to 3000 psig once casing is out of hole Bore out 9-5/8 and run 7.0 Tie-Back 12.PU mills and bore out 9-5/8 as necessary to obtain drift for new 7.0 tie-back. 13.Run new 7.0 tie-back casing with sealing overshot. 14.Pressure up to set ECP 15.Test casing to 2500 psig. 16.Rig up cementers. Open cement sleeve. 17.Cement OA to surface. 18.Perform 30 minute no flow test, split stack and land slips, cut excess casing and install IC packoffs. Installed Tie- back spool and terminate 7.0. Land stack and MU to casing flange. a.Test flange break to BOPE test pressure. 19.Circulate out sand on shallow RBP. Pull RBP 20.Pull deep RBP Run new 3.5 Completion Page 2 of 4 Fluid inside 7" casing and in OA is 10.2 ppg, per Adam Klem phone call 10/6/25 OA surface shoe is open. -bjm 1E-36 RWO Procedure KUPARUK RIVER UNIT Producer PTD #198-213 Page 3 of 4 21. MU 3.5 completion with poor boy overshot, nipple, production packer, GLMs. RIH with completion 22. Once on depth, space out as needed, land hanger, RILDS, 23. Install BPV, PT from below. ND BOP, NU tree. PT tree 24. Pull BPV 25. Circulate out the 10.2ppg brine with lighter weight corrosion inhibited seawater to surface 26. Once well has been displaced to a lighter fluid, freeze protect well 27. Drop ball and rod. Pressure up to set packer 28. PT tubing to 3000psi 29. PT IA to 2500psi 30. RDMO. Post-Rig Work 15. Install GLD. 16. Pull HEX plug ~11,500 MD in well. 17. Turn over to operations. Superseded by revised schematic. -A.Dewhurst 09OCT25 1E-36 RWO Procedure KUPARUK RIVER UNIT Producer PTD #198-213 Page 4 of 4 Superseded by revised schematic. -A.Dewhurst 09OCT25 1 Dewhurst, Andrew D (OGC) From:Klem, Adam <Adam.Klem@conocophillips.com> Sent:Wednesday, 8 October, 2025 09:28 To:Dewhurst, Andrew D (OGC) Cc:McLellan, Bryan J (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]KRU 1E-36 Repair Well Sundry 325-609 Lead 130 bbl 10.5 ppg Arctic Set III + Tail 175 bbl 15.8 ppg Class G... Stage #1: RIH w/9-5/8" csg - Circ 1X csg volume @ 2000' and 3900'. MU hanger and land csg @ 6330' - Circ & cond mud @ 10 BPM, Total vol circ = 870 bbl. PT lines to 3500 psi. Pump 20 bbl wash, 40 bbl Spacer. Mix & pump AS III Lead, followed by Class G Tail. Displ w/rig pumps. Bump plug - Load top plug - Open stage tool w/2990 psi. **TOC calculated from annulus volume based on hole diameter + 20% enlargement ^^Csg OD=9.625 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, October 8, 2025 9:27 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 1E-36 Repair Well Sundry 325-609 Adam, Thanks. So, TOC for the rst stage did not reach the depth of the stage tool? Where does the 3,786 MD depth come from; is there a CBL? Andy From: Klem, Adam <Adam.Klem@conocophillips.com> Sent: Wednesday, 8 October, 2025 09:20 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 1E-36 Repair Well Sundry 325-609 Apologies, apparently the surface casing stage collar was noticed after the schematic was created. The Surface casing had a two stage cement job and did have cement to surface. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 3 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, October 8, 2025 9:03 AM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]KRU 1E-36 Repair Well Sundry 325-609 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Adam, 4 The current status schematic for KRU 1E-36 shows TOC in the surface hole at 3,786 KB. Is the surface hole not fully cemented? From the well le, the original cementing report shows cement returns to surface. Do you know why it is being depicted as it is shown? If the schematic is not accurate, would you please provide a revised version? 5 Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 Originated: Delivered to:8-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-06 50-029-20603-00 910356999 Kuparuk River Multi Finger Caliper Field & Processed 6-Oct-25 0 12 1B-06 50-029-20603-00 910356999 Kuparuk River Packer Setting Record Field- Final 7-Oct-25 0 13 1B-10 50-029-20656-00 910292758 Kuparuk River Leak Detect Log Field- Final 5-Sep-25 0 14 1B-10 50-029-20656-00 910292758 Kuparuk RiverMulti Finger CaliperField & Processed 1-Sep-25 0 15 1B-10 50-029-20656-00 910292758 Kuparuk River Plug Setting Record Field- Final 2-Sep-25 0 16 1E-36 50-029-22927-00 910357582 Kuparuk River Multi Finger Caliper Field & Processed 4-Oct-25 0 17 1E-36 50-029-22927-00 910293121 Kuparuk River Plug Setting Record Field- Final 8-Sep-25 0 18 1H-116 50-029-23594-00 910313707 Kuparuk River Multi Finger Caliper Field & Processed 22-Sep-25 0 19 1R-35 50-029-23050-00 910312848 Kuparuk River Leak Detect Log Field- Final 19-Sep-25 0 110 1R-35 50-029-23050-00 910312848 Kuparuk River Multi Finger Caliper Field & Processed 18-Sep-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:181-075181-135198-213218-012201-210T40969T40969T40970T40970T40970T40971T40971T49072T40973T490731E-3650-029-22927-00910357582Kuparuk RiverMulti Finger CaliperField & Processed4-Oct-250171E-3650-029-22927-00910293121Kuparuk RiverPlug Setting RecordField- Final8-Sep-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 12:57:29 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 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?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12005'2425 None Casing Collapse 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: 907-265-1102 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 James Ohlinger james.j.ohlinger@conocophillips.com CTD Engineer Subsequent Form Required: Suspension Expiration Date: L-80 Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 7" 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. Proposed Pools: 11597' Burst 6290' AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 11408'MD/5842'TVD 1823'MD/1632'TVD 11440' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025660 198-213 P.O. Box 100360, Anchorage, AK 99510 50-029-22927-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? 121'121' 6331' 5944' 16" 9-5/8" 80' 3996' 9/24/2025 12004'596' 3-1/2" 6123' BAKER ZXP SSSV: CAMCO TRDP Perforation Depth MD (ft): 6193'11375'5826'11375' KRU 1E-36 11720-11740' 11760-11780' 11795-11815' 11559' 4-1/2" 6017-6029' 6041-6053' 6063-6075' m n P 1 6 5 6 t g N 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 11:20 am, Aug 22, 2025 Digitally signed by James J. Ohlinger DN: CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2025.08.22 10:39:03-08'00'Foxit PDF Editor Version: 13.1.6 James J. Ohlinger 325-504 JJL 9/5/25 10-404 DSR-9/10/25A.Dewhurst 10SEP25 X AOGCC witnessed BOP and Annular test to 3000 psi. Stacker packers to be set below production casing TOC. JLC 9/10/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.11 08:48:22 -08'00' 09/11/25 RBDMS JSB 091125 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 22, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J Ohlinger CTD/RWO Staff Engineer ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1E-36 (PTD# 198-213). Well 1E-36 was originally spud in 10/26/98 and rig released 11/13/98. The well has primarily been a Kuparuk C-sand Producer. The well has developed AnnComm issues that moved it to being a RWO candidate due to leaks in the production casing. If you have any questions or require any further information, please contact me at +1-907-229-3338. Leaks were recently bracketed between 11,225' and 11,285' MD via WFL in the 7" production casing. The leaks are within the HRZ, with the top of the HRZ at 10,937' MD (109' TVD difference). The next hydrocarbon bearing zone is in the Ugnu, Schrader Bluff, and West Sak intervals from ~3600' to 5450' MD, 1966' TVD above the top of the HRZ. New 3-1/2” tubing with a stack packer and seal assembly, or dual packers to straddle and isolate the production casing leaks will be run. The 7" casing has a minimal amount of subsidence of 27" and shows no sign of impeding the tubing. A caliper of the tubing shows no tight sports or anomalies indicating that a subsidence like repair is not required.. The tubing will be pulled from the pre-rig cut at 11,391' MD. General Well info Wellhead type/pressure rating: FMC Gen IV Production Engineer: Banabas Dogah Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: 09/24/25 Workover Engineer: James J Ohlinger (+1-907-265-1102/ James.J.Ohlinger@conocophillips.com) Current Operations: This well is currently shut in; 4/21/25 Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to a pre-rig tubing cut, ~11,391’ MD. A test packer run will be conducted to confirm the 7” production casing leak intervals, and the remaining casing condition. To isolate the leaks from any hydrocarbon bearing zones, new 3-1/2” tubing with a stack packer and seal assembly, or dual packers to straddle the leaks will be run. The surface casing has a minimal subsidence of 27”, and the recent tubing caliper shows no tubing anomalies or restrictions indicating that a subsidence like repair is required. BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / Drilling Spools Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 4/30/25 MIT-OA Open shoe IC POT Failed 4/21/25 IC PPPOT Passed 4/21/25 TIFL Failed 4/21/25 SCLD Complete 11/18/21 CMIT TxIAxOA (1000 psi) Inconclusive 5/18/25 MPSP: 2425 psi using 0.1 psi/ft gradient Static BHP: 3028 psi / 6029’ TVD measured on 4/28/25 !"" # $ %& ' ( '')*%& + " , - "&(./%0. 1 " 2#34567 8 *+9*: ! !5;08#1 07< == '= !5;/5( $8 / 7< 5 =* *">! !* =! =/ = ' #?' 0-" <) ==@ 2,??4 ( 6A-*= * := # .7<= '0("0;7$=,?/#??? " ,?/#??? " #$ % + 7< ; =B=7$&(. , #/C = 2#34567 " %&'( % (" % 1 5! / = '*= =* = * ,49,4567 " '2?3+4567 %("')) %*+& ,-)" % 8 ;#DC ' * =%& 5! * ' 9 $ =* ! == =*5!&(.=7>5= 3 #???#?' = * ? ,??#?' * . / ' ** .$< * = ! 7< # 0(7$ 0; " + 7<E '=7< ) , 5( $ (" 1 ! %&( 8 2,??4 ( 9 " : 1E-36 Existing Completion Producer COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Conductor 121 121 16 15.06 62.58 H-40 WELDED Surface 6330.5 3995.7 9.625 8.83 40 L-80 ABM-BTC Production 11597 5944.1 7 6.28 26 L-80 BTC-MOD Tubing 11440 5858 3.5 2.992 9.3 L-80 EUE Liner 12004 6192.8 4.5 3.96 12.6 L-80 NSCT ! " #$! %%&'( %%&)% PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface Camco TRDP-4E SSSV @ 1823' rkb (5.25" OD) 3-1/2" x 1-1/2" Gas Lift Mandrels @ TBD 3-1/2" Camco D-landing nipple @ 11,375 (2.75" min ID) ZXP Liner Packer @ ~11,408' RKB Surface Casing 6331' RKB Production Casing 11597' C-Sand Perfs Conductor *+ ,-.$-! %%& ( /" 0 $++ %%& ) /" 1 2- 34 ) /" ('' /" 5*% &'2 /" 5#$ %%& '% /" .! %%&22 %%&2( /" 5* )( /" 5*%%&( /" Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:SLM 11,745.0 1E-36 1/5/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set plug & catcher. Pulled sta #6 leaving open pocket 1E-36 5/1/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 9/8/2010 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 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 40.6 6,330.5 3,995.7 40.00 L-80 ABM-BTC PRODUCTION 7 6.28 38.3 11,597.0 5,944.1 26.00 L-80 BTC-MOD LINER 4 1/2 3.96 11,408.1 12,004.0 6,192.8 12.60 L-80 NSCT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.0 Set Depth … 11,439.9 Set Depth … 5,858.2 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.0 36.0 0.00 HANGER 8.000 FMC GEN IV HANGER 3.500 1,822.7 1,631.5 49.12 SAFETY VLV 5.250 CAMCO TRDP-4E SAFETY VALVE, S/N HGS-1378 2.812 3,260.4 2,610.9 46.68 GAS LIFT 5.500 CAMCO KBMM 2.920 5,487.5 3,696.3 68.80 GAS LIFT 5.500 CAMCO KBMM 2.920 7,430.0 4,400.8 68.53 GAS LIFT 5.500 CAMCO KBMM 2.920 8,959.3 4,950.5 68.15 GAS LIFT 5.500 CAMCO KBMM 2.920 10,362.9 5,446.1 69.64 GAS LIFT 5.500 CAMCO KBMM 2.920 11,328.9 5,803.8 62.16 GAS LIFT 6.018 CAMCO MMM 2.920 11,375.0 5,825.8 60.88 NIPPLE 4.470 CAMCO D NIPPLE 2.750 11,413.6 5,844.9 59.97 LOCATOR 5.125 BAKER LOCATOR 3.000 11,414.9 5,845.5 59.94 SEAL ASSY 4.000 BAKER EXT TUBES & 9.97' SEAL ASSEMBLY 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) 11,369.5 5,823.1 61.01 CATCHER 2.78" AVA Catcher set on top of CA-2 plug (OAL = 68") 4/30/2025 0.000 11,375.0 5,825.8 60.88 TUBING PLUG 2.75" CA-2 Plug (NO-GO = 2.79") (OAL = 29") 4/30/2025 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) 3,260.4 2,610.9 46.68 1 GAS LIFT GLV BK 1 1,260.0 11/12/2021 0.188 5,487.5 3,696.3 68.80 2 GAS LIFT OV BK-5 1 0.0 9/7/2004 0.250 7,430.0 4,400.8 68.53 3 GAS LIFT DMY BK-5 1 0.0 9/7/2004 0.000 8,959.3 4,950.5 68.15 4 GAS LIFT DMY BK-5 1 0.0 11/13/1998 0.000 10,362.9 5,446.1 69.64 5 GAS LIFT DMY BK-5 1 0.0 11/1/1998 0.000 11,328.9 5,803.8 62.16 6 GAS LIFT OPEN 1 1/2 5/1/2025 Open Pocke t 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) 11,408.1 5,842.1 60.10 PACKER 4.500 BAKER ZXP LINER PACKER & TIEBACK SLEEVE (LOCATOR @ 11415.38') 3.958 11,939.3 6,152.0 51.01 LANDING COLLAR 4.500 BAKER LANDING COLLAR 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,720.0 11,735.0 6,016.7 6,025.8 C-4, 1E-36 3/4/1999 4.0 APERF 150 deg. phase; 2.5" HC,DP 11,720.0 11,740.0 6,016.7 6,028.8 C-4, 1E-36 10/11/1999 4.0 RPERF 2.5" HC, DP chgs; 180 deg phasing 11,760.0 11,780.0 6,041.1 6,053.3 C-4, 1E-36 10/11/1999 4.0 RPERF 2.5" HC, DP chgs; 180 deg phasing 11,760.0 11,780.0 6,041.1 6,053.3 C-4, 1E-36 12/31/1998 4.0 APERF 180 Deg phasing; 2.5" HC 11,795.0 11,815.0 6,062.5 6,074.8 C-4, C-3, 1E-36 11/23/1998 4.0 IPERF 0 Deg phase +/- 90 deg. from low side; 2.5" HC 1E-36, 5/2/2025 5:42:29 AM Vertical schematic (actual) LINER; 11,408.1-12,004.0 IPERF; 11,795.0-11,815.0 RPERF; 11,760.0-11,780.0 APERF; 11,760.0-11,780.0 RPERF; 11,720.0-11,740.0 APERF; 11,720.0-11,735.0 PRODUCTION; 38.3-11,597.0 TUBING PLUG; 11,375.0 CATCHER; 11,369.5 GAS LIFT; 11,328.9 GAS LIFT; 10,362.9 GAS LIFT; 8,959.3 GAS LIFT; 7,430.0 SURFACE; 40.6-6,330.5 GAS LIFT; 5,487.4 GAS LIFT; 3,260.4 SAFETY VLV; 1,822.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) 47.51 RR Date 11/13/199 8 Other Elev… 1E-36 ... TD Act Btm (ftKB) 12,005.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292292700 Wellbore Status PROD Max Angle & MD Incl (°) 70.59 MD (ftKB) 9,221.62 WELLNAME WELLBORE1E-36 Annotation Last WO: End DateH2S (ppm) 320 Date 8/12/2016 Comment SSSV: TRDP Originated: Delivered to:2-Sep-25Alaska Oil & Gas Conservation Commiss02Sep25-NR ! "# $$%$ !&$$'($)*%+ ($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDCD4-24 50-103-20602-00-00 209-097 Colville River WL RBP FINAL FIELD 3-Aug-251E-36 50-029-22927-00-00 198-213 Kuparuk River WL WFL FINAL FIELD 5-Aug-252F-18 50-029-22720-00-00 196-178 Kuparuk River WL SCMT FINAL FIELD 6-Aug-251E-36 50-029-22927-00-00 198-213 Kuparuk River WL RST FINAL FIELD 7-Aug-251C-121 50-029-23015-00-00 201-080 Kuparuk River WL IPROF FINAL FIELD 8-Aug-252V-16 50-029-21296-00-00 185-033 Kuparuk River WL PPROF FINAL FIELD 9-Aug-252X-01 50-029-20963-00-00 183-084 Kuparuk River WL HEX-PLUG FINAL FIELD 10-Aug-251R-22A 50-029-22206-01-00 199-049 Kuparuk River WL PPROF FINAL FIELD 11-Aug-251C-121 50-029-23015-00-00 201-080 Kuparuk River WL IPROF FINAL FIELD 13-Aug-251B-08A 50-029-20635-01-00 197-112 Kuparuk River WL IPROF FINAL FIELD 22-Aug-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8 " ! - +" 8 # !(3 . 8 ) "3 8 # !9 3 : 8" +8 6 8 8 " 8 # !;" " 3 - 3 " 3 ""+ 3 + < +3!% T40840T40841T40842T40841T40843T40844T40845T40846T40843T408471E-3650-029-22927-00-00198-213Kuparuk RiverWLWFLFINAL FIELD5-Aug-251E-3650-029-22927-00-00198-213Kuparuk RiverWLRSTFINAL FIELD7-Aug-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.09.03 08:58:49 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\NPKVI7IS\2025-06-08_16036_KRU_1E-36_VividLeakDetectLog_FinalReport_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16036 KRU 1E-36 50-029-22927-00 VIVID Leak Detect Log 08-Jun-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC ***I have added a final report to the original upload dated 10-Jun-25*** Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 198-213 T40627 7/1/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.01 11:15:45 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\5NH9KXKT\2025-06-08_16036_KRU_1E-36_VIVIDLeakDetectLog_Partner_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16036 KRU 1E-36 50-029-22927-00 VIVID Leak Detect Log 08-Jun-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 198-213 T40538 6/10/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.10 15:18:02 -08'00' Originated: Delivered to:7-May-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1E-04 50-103-21852-00 910026680 Kuparuk River Leak Detect Log Field- Final 4-May-25 0 12 1E-11 50-029-20787-00 910026795 Kuparuk River Leak Detect Log Field- Final 3-May-25 0 13 1E-11 50-029-20787-00 910026795 Kuparuk River Plug Setting Record Field- Final 3-May-25 0 14 1E-36 50-029-22927-00 910026794 Kuparuk River Multi Finger Caliper Field & Processed 29-Apr-25 0 15 2F-12 50-029-21097-00 909990397 Kuparuk River Radial Bond Record Field- Final 16-Apr-25 0 16 3M-19 50-029-21737-00 909953646 Kuparuk River Leak Detect Log Field- Final 27-Apr-25 0 178910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40363T40364T40364T40365T40366T40367180-057182-051198-213184-043187-0645/8/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.05.08 10:12:05 -08'00'41E-3650-029-22927-00 910026794Kuparuk RiverMulti Finger CaliperField & Processed29-Apr-2501198-213 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~'~,"-. 1~ I ~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Dareth~ Lowell Date: ~-.//q /si ~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ ~~ • • ConocoPh ~ I I ~ ps Alaska ~ ~~ Y~~ s. P.0. BOX 100360 ~`' ~ ``~ ; ANCHORAGE, ALASKA 99510-0360 a+ a ~ ~ '' .ai. _ *~ ~ ~, March 14, 2008 ~ ;; .~ ~" ;- Mr. Tom Maunder ~ 3 Alaska Oil & Gas Commission n ~ •~ 333 West 7~' Avenue, Suite 100 4 Anchorage, AK 99501 V~1~ MAR ~ ~00~ Dear Mr. Maunder: Enclosed please. find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 17, 2008 and the corrosion inhibitor/sealant was pumped on February 2, and March 8, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling,. and volumes used on each conductor. Please call me or Perry Klein at 907-659-7043, if you have any questions.- Sincerely, `~, M.J. veland 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 n~to 3/14/2008 Well Name PTD # Initial top of cement . Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 H-04 182-103 23" NA 23" NA 4.5 2/2/2008 1 H-06 182-068 28' 3.2 5" 1 /17/2008 5.5 2/2/2008 1H-07 182-084 9' 3" 1 11" 1/17/2008 7 2/2/2008 1 H-08 182-093 SF NA SF NA 4 2/2/2008 1 E-31 .197-138 4'10" NA 4'10" NA 21 3/8/2008 1 E-32 197-132 8" NA 8" NA 3.5 3/8/2008 1 E-35 198-195 12" NA 12" NA 2 3/8/2008 1 E-36 -198-213 20" NA 20" NA 4.5 3/8/2008 02/21/06 Schlumberger NO. 3691 Schlumberger -DCS 'L-"~h ~ j 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 FEB 22 2006 Attn: Helen Warman A TTN: Beth F 333 West 7th Ave, Suite 100 .,,-,,,, "",iI,>. ",U¡WIHSSIQi, Anchorage, AK 99501 ?·.;'l(;oorage Field: Kuparuk e Well Job # Log Description Date BL Color CD 1 B-17 /q4 - 045" 11216283 SBHP SURVEY 02/18/06 1 1 E-36 1'I8-';¡1.~ 11216282 SBHP SURVEY 02/18/06 1 3H-07 /917-()7Q 11217023 LDL 02/11/06 1 3H·07 " /, 11166757 STATIC SURVEY 01/20/06 1 2A-09 /(J)/o-ml 11154126 PRODUCTION PROFILE 02/09/06 1 1A-10 /(:1/- ///}{J 11213710 INJECTION PROFILE 02/08/06 1 2M-14 ¡q,¡; - /J/n; 11154127 INJECTION PROFILE 02/10/06 1 1E-05 19Í"';-()6~ 11166747 PRODUCTION PROFILE WIDEFT 12/25/05 1 2H-12 /PIS-:Jft¡ 11154128 PRODUCTION PROFILE WIDEFT 02/11/06 1 1 C-21 11154131 PRODUCTION PROFILE WIDEFT/GHOST 02/14/06 1 3G-18 /q()- /,:)5 11154129 PRODUCTION PROFILE WIDEFT 02/12/06 1 1 E-119 11217025 INJECTION PROFILE 02/13/06 1 2U-13 JB4-~f{p 11166753 PRODUCTION PROFILE 01/14/06 1 1Y-09 /8-~- ~ 11213128 INJECTION PROFILE 02/06/06 1 1E-105 11162832 MEMORY INJECTION PROFILE 01/28/06 1 e 2C-08 /'Ö3-C)qs 11141255 INJECTION PROFILE 01/28/06 1 2C-02 1~7¡- f'R3 11213129 INJECTION PROFILE 02/07/06 1 1C-25 /QQ-031 11144074 GLS 02/02/06 1 2C-14 /f34 - n rD 11166759 PRODUCTION PROFILE 01/25/06 1 2C-10 /£3 -1-:" It 11144067 PRODUCTION PROFILE 01/26/06 1 1A-18 /CJo- F.~ 11144070 PRODUCTION PROFILE 01/29/06 1 2C-01 /8~-6~ 11213709 INJECTION PROFILE 02/07/06 1 1O-32/)()D-/7.^, 11141252 LEAK DETECTION LOG 01/25/06 1 2C-12 /B1-X;(o 11141260 PRODUCTION PROFILE 02/02/06 1 2C-15 /84 - /)6;;, 11141254 PRODUCTION PROFILE 01/27/06 1 1J-154 N/A PRODUCTION LOG WITRACTOR 02/05/06 1 1E-104 11217024 INJECTION PROFILE 02/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to'(907) 561-8317. Thank you. ·~UOJ ( ~. (fL¡ i::1"i:: rþ~'l ~'.'[J \"-¡:::¡. \. '" ;, i ,,) \ ~ II I' " ., ¡ \ I.. ¡ ~ ; "'''.. C~l) \J l./:\:l U L[~ (1;:,.'-1' Ir~ [-.:.:;;! If! ;, 'I ¡ \. .., t ¡ I ~., ¡ i I I i \.~: LI r~~-"\ f" 'j ! ._;"- ~ ...~.:.~ '\ ,< P\ \ \ ¡ ! f\ \ ~ t, L..I 1\ .' I '1 \ I ¡ !,' \ ....,\\ ! 1 / ;~... \ 't l ~, \ -; '1 1 :- .. LJ 1..J L.~ U lJ (,2::./ FRANK H. MURKOWSKI, GOVERNOR AT1A~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. rm AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 22,2004 Randy Thomas Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit We1l1E-36 Permit No: 198-213 Approval No. 304-213 Dear Mr. Thomas: Your request for approval of annular disposal in Kuparuk River Unit well 1E-36 (PTD 198-213) has been denied. This letter is provided to explain the basis for denying your request. When a well is proposed for annular disposal, all wells within ~ mile radius of the surface casing shoe of the candidate well are reviewed to determine that the wellbores are satisfactorily sealed in the earth and are not likely to provide a potential leak path to shallower depths. In this case, 2 "older" Kuparuk wells (1 E-04 and 1 E-28) are within 200 - 500' of 1E-36. The surface casing on both of the these older wells was set above the West Sak sands and the production wellbore sections were not cemented in the intervals below their surface casing shoes. Given the proximity of these uncemented wellbore sections, in particular 1E-04, to the surface casing shoe of 1E-36 it is not possible to assure that the drilling wastes will be confined as required by 20 AAC 25.080(c)(1). Please contact me if you would like to discuss this matter further. Sincerely, k~ 1r2 ,,".,.j 9- Thomas E. Maund[r~ '-V" - ¡ Sr. Petroleum Engineer cc: Steve Shultz, CPAI jjc/Enclosures ~,l ~ (~~ ~(. STATE OF ALASKA ~ R:FrE.'VED~\ ALASKA OIL AND GAS CONSERVATION COMMISSIO~'} h... ...', ¡ ANNULAR DISPOSAL APPLICATION JUN 032004 20 MC 25.080 (' 1 . Operator Name: ConocoPhillips Alaska t~ ¡ .-:j ,I"',~! ,..\ - ~ 3. Permit to Drill' 'F ~:~~ IjJrlS. CO~ìlj8s:or p", ", ,"0 ~ " r 198-213 r ¡"t:u ~ge Number: 4. API Number: 50-029-22927 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska 1 E-36 ~ 7. Publicly recorded wells 1 ,,8. Str~graPhiC description: a) All wells within one-quarter mile: a) Inte exposed to open annulus: 4 wells: 1 E-26, 1 E-28, 1 E-04, 1 E-31 (see summary) J \ interbedded claystone, siltstone and shale , tV \ N \0\ \ 6. Field: Kuparuk River Unit none c) Confinement: Shales beow . le W ~ Sak, Shales above the Kuparuk b) water wells within one mile: 9. Depth to base of permafrost: 1595' MD/150~ "- ) 1 o. Hy<\>carbon zones above waste receiving zone: West Sak 11. Previous volume disposed in annulus and date: 2. . ::sti:§ted~IU density: 13. Maximum anticipated pressure at shoe: None t ~ 10.0 ppg 2211 psi 14. Estimated volume to be disposed with t~ requt . 5. '~IUi\s to isposed: 35,000 bbls. \ Ty¡:es o~aste can be drilling mud, drill cuttings, cement-contaminated \w ~rill mL d, completion fluids, diesel, formation fluids associated with the act of 16. Estimated start date: ~ ~ \~. . :Jrillirg a well, :Jomestic waste water, and any water needed to facilitate June 15, 2004 \ I \ ~ pumping of drilling mud or drilling cuttings. 17. Attachments: /' Q. 'k\-/ Well Schematic (Include M~nd - VJ2 Q Cemer: Bond Log (if required) D FIT Records wlLOT Graph 0 ~\ er 0 y knowledge. 18. I hereby certify that the foregolg is t~le-éJll1d correct to the best of Signature: ~ r' - Printed Name: "" Randy Thomas Conditions of approval: ~ Subsequent form required: Title: \') f'o lù ~.... -. Lc.._.I Phone Number: Commission Use Only 265-6830 Date: 6 (j(<jr LOT review and approval: Approval number: .30 - d-/3 Approved by: COMMISSIONER BY ORDER OF THE COMMISSION Date: Form 10-403AD Rev. 9/2003 ('~"'¡ ¡-"'¡, I:, C''',, Ii 1\,,! A I ) r(~\ (~~J ~ ~\h INSTRUCTIONS ON REVERSE ,.JS B~FP BFM sJIß~' in2>uf!ic.~ IMa! 8' It Y ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve Shultz Phone (907) 263-4620 Fax: (907) 265-1535 Email: steven.m.Shultz(f.~!.conocophillips.com May 28 ,2004 Alaska Oil and Gas Conservation Commission 222 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on WelllE-36 Dear Sir: ConocoPhillips Alaska, Inc. hereby requests that 1 E-36 be peI1TIitted for annular pumping of fluids occurring as a result: of drilling operation, per regulation 20 ACC 25.080. It is intended to be used for annular disposal operations on E-pad when needed on the drilling program presently in e:IJect . Please see the attached. fonll 10-403 and other pertinent information as follows: 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Annular Disposal Transmittal Form Pressure Calculations for Annular Disposal Surface Casing Description \ Surface Casing Cementing Report and Daily Drilling Reports during cement ops Casing and Formation Integrity Report (LOT at surface casing shoe) Production Casing Description Production Casing Cementing Report and Daily Drilling Report during cement ops Plan View o:fExisting Adjacent Wells Plan View of Existing and Planned AdjacentW ells Pressure Integrity Test If you have any questions or require further information, please contact Steve Shultz at 263- 4620 in the Conoco/Phillips office. Sin, ce, r~ZIY', " """ (,,~~,ì ') hi. ., I i{!J'" , .~-' " /l /' / // .. ¿ll ~/ ,,// vv'- i ~/J U &~Ve Shultz Drilling Consultant ( Annular Disposal Transmittal Form-WelllE-36 A. B. Designation of well to receive drilling wastes: The depth to the base of freshwater aquifers and permafrost, if present. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. C. D. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: G. H. 1 E-36 No Aquifers/Base of Permafrost=:!:: 1595' MDI1500'TVD From the 9 5/8" shoe to the Cement top all that is open is interbedded claystone, siltstone and shale with occasional minor non- hydrocarbon bearing sands. See attached horizontal plane clearance report and plot indicating that there are four wells within a quarter of a mile in the same horizontal plane as the 9 5/8" surface casing shoe. All have been arctic packed with the exception of 1E-35. They are: 1E-26 (11/8/82, 41 bb1s cement, 102 bbls arctic pack), 1E-28 (10/5/82,41 bbls of cement and 98 bbls of arctic pack), 1E-4 (7/21/80, 41 bbls of cement, 120 bbls of arctic pack), 1E-31 was drilled in July of 1997 and had losses on the surface casing cementing operations and ended up doing a top job (morning reports attached with directional), but the well is 1017' distant from 1E-36) Types of waste can be drilling mud, drilling cuttings, cement -contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated differential pressure at casing shoe during disposal operation is 2211 psi. See attached calculation page. See Attached: cementing reports, LOT /FIT reports and casing reports. See attached casing summary sheet and calculation pages. 6347' MD 3989' TVD 11677' MD 5996' TVD Well: lE-36 Kuparuk tlùducer Date 5/28/2004 ~ --------- -------. u ~ 9 5/8" Surface Csg ~ Estimated TOC 10000'MD 5288'TVD T' Production Csg Assumptions Maximum surface pressure of 1,450 psi, 12.0 ppg fluid being injected Column of gas to bottom GLM w/ no gas lift pressure (if producer) Column of diesel to shoe of 7"csg (if injector) Gas down to lower GLM and no header pressure (if producer) Maximum Differential Pressure at Surface Shoe Maximum Disposal MW Maximum Differential Pressure @ 9 5/8" Shoe (Max Diff Prcss=Max Disposal Press +(Max Disposal MW) (.052)(TVD)-(Fluid Wt on Backside)(.052)(TVD) LOT on 9 5/8" Shoe 12.0ppg 2211 psi 1525psi 14.2 ppg MWE Production Casine: Size Weight Grade Collapse @ 100% Collapse @ 85% Gas Depth (TVD of GLM(producer) or T' TOC (injector» T' X 9 5/8" Annulus fluid weight Max Disposal Pressure Allowed for 9 5/8"for burst Maximum allowable surface pressure for T' collapse Criteria for Producer Criteria for Injector No Header Pressure Column of Diesel to top of T' cement Column of gas to last GLM No 4 Y2" X 7" surface pressure No cement outside T' to GLM 12.0 ppg mud in 9 5/8" annulus 12.0ppg mud in 9 5/8" annulus Water from 95/8" shoe to GLM CPC=7" Collapse Press.-(Max Mud wt.)!.052)(TVD of 9 S/S")-S.33!.052)(TVD of GLM- TVD of 9 S/S")+( gas gradient)(TVD of bottom GLM) TVD(.052) 8.33 inch 26 ppf L-80 5410 psi 4599psi 5850' TVD 2.3ppg (0.11 psi/ft) 4126psi 1648psi Surface Casine: Size Weight Grade Burst @100% Burst @ 85% Fluid Weight on Backside Maximum Disposal Pressure Maximum Differential Pressure @ 95/8" Shoe . 12.0ppg Mud Weight . Maximum surface pressure of 1500 psi . MDP=-(Fluid wt. backside)(.052)(TVD)+MW(.052)(TVD shoe)+Max Surface Pressure 9 5/8 inch 40# L-80 5750 psi 4888 psi 8.33 ppg 1,450 psi 2211 psi Maximum Mud Weight . To burst 9 5/8"casing with 1500 psi 19.4 ppg MMW=Pb @ 85% +(Fluid Weight on Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) -.~ --~ 5000 4000 - (1) ... ::s t/) t/) (1) ... 0.. Co E ::s 0.. 3000 - 2000 8 Maximum Pressure for Burst - T 1- ~. 9 10 11 Mud Weight 12 13 14 ~ 3000 2500 - ._~ 2000 - Q) '- :J ~ 1500- Q) '- a. 1 000 - 500 - Max Pressure for Collapse with Associated Mud Weight 0 8 9 10 11 Mud Weight 12 13 14 ( ~ ¥ CooocoPhillips ConocoPhillips Alaska, Inc. MWD <0 -12005'>,36 slot #36, Pad 1 E CLEARANCE LISTING Page 1 Date Printed: 12-May-2004 Kuparuk River Unit, North Slope, Alaska r'¡. BAKER HUGHES INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and Maqnetic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of ft/1 OOOft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Horizontal Plane clearance calculation for all minima Hole size/Casinqs are NOT included Hole size/Casinqs are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.58standard deviations. Closinq Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation Well bore Name 36 I Created 19-5ep-2003 I Last Revised 12-May-2004 Well Name 36 I Government ID I Last Revised 24-Feb-2004 Installation Name Pad 1 E 1 Eastinq 550528.1946 I Northinq 5959591.1090 I Coord System Name 'I North Aliqnment AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name Kuparuk River Unit I Eastinq 487754.6208 1 Northinq " 5948985.8206 1 Coord System Name 1 North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True Clearance Su~rnmary Offset Offset Offset Offset Minimum MD[ft] Diverging Ellipse Ellipse Clearance Clearance WellName \,IVe II bore Slot Structure Distance From[ft] Separation MD[ft] Factor MD[ft] rftl rftl 4 4 slot #4 Pad 1 E 410.14 6332.02 6332.02 28 28 slot #28 Pad 1 F 434.48 6330.00 6330.00 31 31 slot #31 Pad 1 E 1017.08 6332.02 6332.02 31PB1 31 PH "I slot #~1 Pad 1 E 1017.08 6332.02 6332.02 26A 26A slot #26 Pad 1 E 1194.43 6332.02 6332.02 30 30 slot #30 Pad 1 E 1354.32 6330.00 6330,00 17 17 slot #17 Pad 1 E 1560.83 6330,00 6330.00 Reference\l'~lre¡llbore Survey ToolProQram Survev Name, IMDrftl Mwrj, <0' - 12005'> 12005.00 1 Survey Tool ISCWSA MWD 1 Error Model Basic MWD - ISCWSA - 28 JAN 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated y ConocoPhiiii ps { ConocoPhillips Alaska, Inc. MWD <0 -12005'>,36 slot #36, Pad 1 E CLEARANCE LISTING Page 2 Date Printed: 12-May-2004 Kuparuk River Unit, North Slope, Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated "~i. BAKER HUGHES INTEQ ( "Y" ConocoPhillips ConocoPhillips Alaska, Inc. MWD <0 - 12005'>, 36 slot #36, Pad 1 E CLEARANCE LISTING Page 3 Date Printed: 12-May-2004 Kuparuk River Unit, North Slope, Alaska r4i. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] fdeql fftl 4841.10 3995.55 3227.71S 240.31W 98.5 1195.09 4842.07 3996.28 3228.34S 240.48W 98.4 1194.43 6330.00 3995.55 3051.29S 1422.31W 6332.02 3996.28 3053.15S 1421.99W 26A 26A Offset Wellbore Survey Tool PrOQrams Well lwellbore , Survey Name 26A """,.,.26A GMS <0-8017'> IMDrftl I Survey Tool 8017 .Oa Level Rotor Gvro I Error Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated { ¥ ConocoPhillips ConocoPhillips Alaska, Inc. MWD <0 -12005'>,36 slot #36, Pad 1 E CLEARANCE LISTING Page 4 Date Printed: 12-May-2004 Kuparuk River Unit, North Slope, Alaska r'¡. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] [deql [ftl 4675.22 3995.55 2663.96S 1225.45W 26.9 434.48 6330.00 3995.55 3051.29S 1422.31W 28 Offset Well bore Survey Tool Proarams Well Iwellbore I Survey Name 28 28 GMS <0-7665'> IMDrftl I Survey Tool 7665.od Level Rotor Gvro I Error Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ~. y ConocoPhillips ConocoPhillips Alaska, Inc. MWD <0 -12005'>,36 slot #36, Pad 1 E CLEARANCE LISTING Page 5 Date Printed: 12-May-2004 Kuparuk River Unit, North Slope, Alaska r'¡. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] rvD[ft] North[ft] East[ft] M D[ft] rvD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] [deql [ftl 4317.62 3995.55 1819.63S 859.10W 24.6 1354.32 6330.00 3995.55 3051.29S 1422.31W 30 Offset Well bore Survey Tool PrOQrams Well Iwellbore I Survev Name 30 30 GMS <0-7310'> I Morftl I Survev Tool 731 o.od Level Rotor Gyro I Error Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated f Y 'I ConocoPhllips ConocoPhillips Alaska, Inc. MWD <0 - 12005'>, 36 slot #36, Pad 1 E CLEARANCE LISTING Page 6 Date Printed: 12-May-2004 Kuparuk River Unit, North Slope, Alaska r,.. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MO[ft] TVD[ft] North[ft] East[ft] From Plane Separation Hìghside Distance [ft] [deql [ftl 5640.11 3995.55 3570.14S 546.85W 120.7 1017,66 5641.51 . 3996.28 3571.33S 546.81W 120.6 1017,08 6330.00 3995.55 3051.29S 1422.31W 6332.02 3996.28 3053.15S 1421.99W 31 31 Offset Wellbore Survey Tool Proarams Well Wellbore r Survey Name 31 31 I MWD <8798 - 10023'> MO[ftl Survey Tool 10023,O( ISCWSA MWD Error Model Basic MWO - ISCWSA - 28 JAN 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Actual Datum 113.0ft above mean sea level) Reference MO's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ~!, ¥ ConocoPhillips ConocoPhillips Alaska, Inc. MWD <0 - 12005'>, 36 slot #36, Pad 1 E CLEARANCE LISTING Page 7 Date Printed: 12-May-2004 Kuparuk River Unit, North Slope, Alaska Ri. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] [deql [ftl 5640.11 3995.55 3570.14S 546.85W 120.7 1017.66 5641.51 3996.28 3571.33S 546.81W 120.6 1017.08 6330.00 3995.55 3051.29S 1422.31W 6332.02 3996.28 3053.15S 1421.99W 31 PB1 31 PB1 Offset Wellbore Survey Tool Proarams Well Wellbore I Survey Name 31PB1 31 PB1 I MWD <0 - 9130'> MDfftl I Survey Tool 9130.0~ ISCWSA MWD I Error Model I Basic MWD - ISCWSA - 28 JAN 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated Date: 12/9/97 .{ f ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 =============================================================================== WELL:1E-31 WELL ID: AK8901 AFC: AK8901 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/29/97 START CaMP: RIG:PARKER 245 0% WI: SECURITY: 0 TYPE: AFC EST/UL:$ 2160M/ 2590M API NUMBER: 50-029-22791-00 BLOCK: FINAL: =============================================================================== 07/28/97 (D1) TD: 120' ( 120) SUPV:JT/SRFJ DAILY: $ 07/29/97 (D2) TD: 3 6 6 0' (3 54 0 ) SUPV:FJ DAILY: $ 07/30/97 (D3) TD: 5 8 3 0' (21 7 0 ) SUPV:FJ DAILY: $ 07/31/97 (D4) TD: 5 8 3 0' ( 0 ) SUPV:FJ DAILY: $ 08/01/97 (D5) TD: 5 8 3 0' ( 0 ) SUPV:FJ DAILY: $ 08/02/97 (D6) TD: 5 8 3 0' ( 0 ) SUPV:FJ DAILY: $ 08/03/97 (D7) MW: 8.6 VISC: 101 PV/YP: 27/29 DRILLING 12.25" HOLE AT 732' Moved rig from 1E-32 to 1E-31. Accepted rig at 1700 hrs. 7/28/97. Cleaned out conductor from 94' to 120'. 46,682 CUM:$ 46,682 ETD:$ 82,314 EFC:$ 2,124,368 APIWL: 9.2 MW: 9.9 VISC: 68 PV/YP: 24/24 CIRC BU AFTER SHORT TRIP Drilled and surveyed 12.25' hole from 3660' to 4072'. Tagged ledge at 1857'. Circ low/high sweep around. Circ out lots of clay and gravel. Drilled from 4072' to 5830'. 72,324 CUM:$ 119,006 ETD:$ 372,336 EFC:$ 1,906,670 APIWL: 6.4 MW: 9.8 VISC: 58 PV/YP: 20/22 WIPER TRIP Drilled and surveyed 12.25" hole from 3660' to 4072'. Tagged ledge at 1857'. Circ low/high sweep around. Circ out lots of clay and gravel. Drilled from 4072' to 5830'. 74,335 CUM:$ 193,341 ETD:$ 555,582 EFC:$ 1,797,759 APIWL: 5.0 MW: 9.8 VISC: 57 PV/YP: 21/18 RUNNING 9-5/8" CASING CBU, pump low/high vis sweeps, wiper trip. Tight 3984' to 3795', 2930' to 2670'. Back ream 2580' to 1742'. Monitor well. Wash 2010' to 2022', tight at 3920'. RU to run 9-5/8" casing. Run casing. Wash 2617' to 2826'. Continue to run casing. 172,421 CUM:$ APIWL: 5.4 365,762 ETD:$ 555,582 EFC:$ 1,970,180 MW: 9.9 VISC: 48 PV/YP: 18/16 NU AND TEST BOP Finished running 9-5/8" casing. Pump cement. Dropped opening bomb. Pumped away mud, no returns. Attempted to establish circulation. Shut down. Cemented 2nd stage cement 177,425 CUM:$ 543,187 ETD:$ 555,582 EFC:$ 2,147,605 APIWL: 6.0 MW: 9.2 VISC: 42 PV/YP: 12/10 RUNNING 1" AT 270' Held safety meeting. Tested BOP equipment to 300/5000 psi. Tagged top of cement at 5476'. Cleaned out cement from 5476' to 5573'. Circulated out very thick contaminated mud. Ran CBT-GR log. . 79,490 CUM:$ 622,677 ETD:$ APIWL: 9.6 555,582 EFC:$ 2,227,095 MW: 8.9 VISC: 44 PV/YP: 16/10 APIWL: 14.4 TD: 5 8 3 0' ( SUPV:FJ 0) ( :( DRILLING 8.5" HOLE AT 5900' Ran 1" CS Hydril tubing down 12.25" OH x 9-5/8" annulus to 340' RKB. Could not work down further. Cemented 12.25" OH Joe: 9-5/8" surface casing annulus. Pressure tested 9-5/8" casing to 2000 psi for 30 min. Cleaned out firm cement froIT { ~ ( oPhy. (onoc IIlips ConocoPhillips Alaska, Inc. MWD <0 -12005'>,36 slot #36, Pad 1 E CLEARANCE LISTING Page 8 Date Printed: 12-May-2004 Kuparuk River Unit, North Slope, Alaska Hi. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] rdeql rftl 4789.97 3995.55 1629.62S 2066.55W -24.4 1560,83 6330,00 3995.55 3051.29S 1422.31W 17 Offset Well bore Survey Tool PrOQrams Well Iw. ellbore I Survev Name 17 17 GMS<0-7885'> IMDfftl J Survev Tool 7885.0 Level Rotor Gyro I Error Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 113.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated ( Conoc~hillips ConocoPhillips Alaska, Inc. MWD <0 -12005'>,36 slot #36, Pad 1 E CLEARANCE LISTING Page 9 Date Printed: 12-May-2004 Kuparuk River Unit, North Slope, Alaska "~i. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MO[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] rdeql rftl 5591.11 3995.55 3456.82S 1489.18W -170.6 411.01 5592.37 3996.28 3457.64S 1489,82W -170.5 410.14 6330.00 3995.55 3051.29S 1422.31W 6332.02 3996.28 3053.15S 1421.99W 4 4 Offset Wellbore Survey Tool Proarams Well Iwellbore I Survey Name 4 4 GMS <0-9150'> MOrftl I Survey Tool 9150.od Level Rotor Gvro I Error Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Actual Datum 113,Oft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated .iII. ~ I~ f ConocoPhillips Alaska, Inc. Location: North Slope, Aìaska Slot: slot #36 , Field: Kuparuk River Unit Well: 36 II Installation: Pad 1 E Well bore: 36 Created by: Planner Oato plotted: 12-May-2004 -PTcit re~-rèi,cels-3~ - - - Ref weUparh is MWD <0 . 12005'>. Coordtnales are in feel reference sJot #36 Tru() VertICal Depths are reference Rig Datum Measur~ Q<!pths are rcference Rig Datum Rtg Datum: Aclual Datum Rig Dafum to mean sea level: 113.00 It Plot North IS aligned to TRUE North. 1~';¡ F.(,' ' ConocJ:)hillips -2~~ale_~~Ch ~2;~O ft-2600 -2500 -2400 -nOD -2200 ,2100 -2000 -1900 -1S00 -1700 -1600 E~~~0(fe-~1~ ->-1300 -1200 -1100 -1000 -900 -SOD -700 -600 -SOD -400 -300 -200 I I I I L- j I -- 3996 TVD ,//// .,,,'-""/'" // ð/ ,,/"- / // ,.// / / //' ~N" //'/""'// I- ~9J// 320 Ft. / / rW I..,,=~...J , ~ .100 -1400 -1500 -1600 -1700 -1S00 -1900 -2000 - -2100 - -2200 - -2300 - -2400 - -2500 - -2600 -2700 -2800 -2900 -3000 ^ -3100 ' Z 0 ;:¡. -3200 ::r ¡: 2- -3300 -- - -3400 - .3500 -3600 - -3700 - -3800 - -3900 - .4000 .4100 -- .4200 -- -4300 -4400 .4500 -- -4600 -4700 C/) &1 ¡¡; -- -4800 ~ " -4900 g ;:þ CASING I TUBING I LINER DETAIL Tubing or Csq Description WELL: DATE: 1 OF 1 LENGTH 1 E-36 10/30/98 PAGES DEPTH TOPS ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN RKB to Landing Ring 40.60 FMC Fluted Mandrel Casing Hanger 2.25 40.60 61 jts 9-5/8", 40.0#, L-80, ABM-BTC Casing ( Jt #102 - #162) 2327.77 42.85 IIB" 9-5/8", 40.0#, L-80, ABM-BTC Casing - Baker Locked 40.87 2370.62 Gemoco 754 Cementing Stage Collar 2.88 2411.49 "All 9-5/8", 40.0#, L-80, ABM-BTC Casing - Baker Locked 38.67 2414.37 98 Jts 9-5/8", 40,0#, L-80, ABM-BTC Casing (Jt #4 - #101) 3756.79 2453.04 Gemoco Insert Shut-Off Baffle 6209.83 1 Jt 9-5/8",40.0#, L-80, ABM-BTC Casing ( Jt #3: 38.89 6209.83 Gemoco Float Collar 1.50 6248.72 2 Jts 9-5/8", 40.0#, L-80, ABM-BTC Casing ( Jt #1 & #2) 78.57 6250.22 Gemoco Float Shoe 1.69 6328.79 6330.48 TD 6347.00 Rathole 16.52 Jt A, Stage Collar, Jt B between #101 and #102 Run Total of 162 Jts Leave Out 7 Jts #163 -#169 Centralizers Run 1 Bow Spring / Jt 1 st 15 Jts (Stop Ring on #1 & 2) Run 1 Bow Spring / Jt every 3rd Jt to Surface (See Tally) Run 1 Solid Centralizer on Jt A and Jt B Total of 62 Bow Springs Remarks: Parker Rig #245 Drilling Supervisor: Donald Lutrick A88t.. ~" ARCa Alaska, Inc. I Cementing Details I Casing Size 9 5/8" Well Name: 1 E-36 Rig Name: RIG # 245 % washout: Centralizers Comments: Mud Comments: Wash Comments: 0 Spacer Comments: 0 Lead Cement 0 Comments: Stage 1 & 2 Tail Cement 0 Comments: Stage 2 - 60 sx AS1 Displacement 0 Comments: Calculated top of cement: Surface Report Date: 10/30/98 AFC No.: AK 9165 Report Number: 5 Field: Hole Diameter: 12 1/4" LC Depth: 6210 Angle thru KRU: I Shoe Depth: 69.64 @ csg depth 6330 State type used, inteNa/s covered and spacing Ran bow springs on 1st 15 jts and every 3rd jt to surface Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): 10/9.6 29 19 29 22 Gels before: Gels after: Total Volume Circulated: 13/67 10/38 861 bbls @ 10 bpm Type: Volume: Weight: ARCO Wash 20 8.4 Type: Volume: Weight: ARCO 40 10.5 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: AS III Lite 75 165/443 10.5 4.42 Additives: Class G + 50% D124 + 3.5% D44 + 0.4% D46 + 30% D53 + 1.5% S1 + 1.5% D79 Type: I Mix wtr temp: I No. of Sacks: I Weight: I Yield: G 75 925 15.8 1.15 Additives: Class G + 1% S1 + 0.2% D46 + 0.3% D65 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: 9.5 9 270k Reciprocation length: Reciprocation speed: Str. WI. Down: 15 10 fpm 160k Theoretical Displacement: Actual Displacement: Str. WI. in mud: 470/183 472/185 CP: Bumped plug: I Floats held: Date: 1 0/30/98 yes yes Time:18:21 hrs Remarks:Pump both stages w/100% returns. Circ out cement contaminated mud after open stage tool. Approx 100 bbls 10.5 cement to surface on 2nd stage. Stage tool opened at 2900 psi and closed at 1300 psi. I Cement Company: DS I Rig Contractor: PARKER APproved By: Donald Lutrick .4~ ~" ARCO Alaska, Inc. Date 11/13/98 Daily Drilling Report AFC No. AK 9165 Well: 1 E-36 RptNo 19 Depth (MDITVD) I Rig Accept - hrs 10/26/9805:00:00 12005/6193 Prey Depth MD: 12005 Days Since AccepVEst: 18.42/17 Rig Relase - hrs: 11/13/9815:00:00 Contractor: PARKER Daily Cost $ 73403 Rig Name: RIG # 245 Last Csg: 3.1/2" Tubing Operation At 0600: Rig Released - Moving to 1C Pad, Well #17 Upcoming Operations: Cum Cost $ 2258733 Next Csg: Progress: 0 Est Cost To Date $ 2215000 Shoe Test: MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL DiesellWater N TST 11/08/98 11/06/98 WEIGHT ROTwr SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL ppg 10/27/98 10/17/98 VISCOSITY puwr MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc N SPACE 11/09/98 11/10/98 PVNP sowr TYPE TYPE TYPE FUEL & WATER I GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED I I APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 0 11/13/98 BBLS HTHP WL TRQ BTM DEPT,H IN DEPTH IN POTABLE WATER 100 mll30 min INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & % 1R-18D PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP of 8 400bbl III I I 1 E-36 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 12 11213 I ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 45° 6 I 5.5 I 5,5 I LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of .15.32 % III Water Base Muds 1630 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 1 0 III I II II IIII1 0 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 32 $ III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $152811 III III III 1630 COMPANY MUD wr GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 BAROID III III III 16455 PERSONNEL TOTAL 44 TIME I END HOURS I OPS CODE I HOLE SECT I PI;jASEOPS I iQPERA~IONS FROM~OQQO,~'OQOO 00:00 01:00 1.00 CIRC COMP Completion Continue reverse circulating until getting clean water returns, 5.75 BPM. Reversed 715 Bbls clean water. 01:00 02:00 1.00 RUN_COMP COMP Completion Stab seals back in & recheck space out. LD 2 jts. Install space out pups under jt #356 & MU circulating line on top of #356. 02:00 03:00 1.00 CIRC COMP Completion Reverse circulate 100 Bbls Diesel into annulus. U-tube diesel back into tubing until equalized, for freeze protection. 03:00 06:30 3.50 RUN_COMP COMP Completion MU tubing hanger & landing joint on jt #356. MU SSSV control line & retest to 5000 psi, OK. Land tubing hanger. RILDS. 145K# Up, 105K# Down. Test tubing to 3500 psi for 10 minutes, OK. Test annulus to 3500 psi for 10 minutes, OK. RD control line spool. LDLJ. Set BPV. 06:30 08:00 1.50 BOPE COMP Completion Change upper & lower pipe rams. 08:00 09:30 1.50 NU_ND COMP Completion NO BOPE. 09:30 14:00 4.50 NU_ND COMp Completion NU FMC Gen 4 tubing head adapter & WKM lower master valve. Had trouble getting THA over extended neck on tubing hanger. Got another THA & redressed neck on hanger. NU THA & lower master valve. Tested packott & flange to 5000 psi, OK. 14:00 15:00 1.00 PREP COMP Completion Cut off 100' of drilling line. Release rig. Released Rig @ 1500 hrs, 11/13/98. (Moving to 1C Pad, Well #17) 15.00 Supervisor: DON E. BREEDEN Daily Drilling Report: 1 E-36 11/13/98 Page 1 ,/? AI~ ~~ ARCQ Alaska, Inc. IDate 11/12/98 AFC No. AK 9165 Well: 1 E.36 RptNo 18 Depth (MDITVD) Daily Drilling Report Contractor. PARKER Daily Cost $ 188942 Rig Name: RIG # 245 Last Csg: 4.1/2" @ 11408' to 12004' Operation At 0600: Changing rams in BOPs Upcoming Operations: ND BOPE, NU THA & lower master valve, Release Rig, I Rig Accept - hrs 10/26/9805:00:00 12005/6193 Prey Depth MD: 12005 Cum Cost $ 2185330 Next Csg: 3-1/2" Tubing MUD DATA MUD TYPE FW WEIGHT 8.34ppg VISCOSITY 28sqc PV/YP / GELS / / APIWL HTHP WL ml/30 min SOLIDS % HOLE VOLUME 400bbl MBT ph LGS % PIT VOL 0 DAILY MUD $1230 TOTAL MUD $152811 COMPANY BAROID TIME I END 00:00 01 :00 DRILLING DATA DEPTH ROT WT PUWT SOWT AVG DRAG MAX DRAG TRQ BTM TRQ OFF PUMP PRES III PUMP NO 1/2/3/ LINER SZ 6 I 5.5 I 5.5 I SPM 1 1/1 GPM2 1/1 SPS 1 1/1 SPP 1 1// MUD WT 1/1 HOURS 1.00 BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 TFA JETS III/ I BIT COST DULL 1/1 GRADE II/ , OPS CODE OTHER BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 TFA JETS 1/111 BIT COST DULL III GRADE III Days Since AccepUEst: 17.79/16 Move to 1C-17 HOLE SECT /PHASeORS PROD Casing and Cementing 01:00 04:00 3.00 TRIP_OUT PROD Casing and Cementing 04:00 04:30 0.50 PREP COMP Completion 04:30 05:00 0.50 RIGS COMP Completion 05:00 05:30 0.50 PREP COMP Completion 05:30 06:30 1.00 TEST COMP Completion 06:30 21:00 14.50 RUN_COMP COMP Completion 21:00 00:00 New Daily Drilling Report 3.00 CIRC COMP Completion EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG 11/11/98 , INJECTION INJECTION WELL 1R-18D SOURCE WELL 1 E.36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base MUds 870 0 0 0 0 TOTAL VOL (bbl) 870 TOT FOR WELL (bbl) 14825 Rig Relase - hrs: Progress: 0 Est Cost To Date $ 2150000 Shoe Test: DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 11/08/98 11/06/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 11/10/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 11/09/98 FUEL & WATER FUEL USED 3173 DRILL WATER USED- BBLS POTABLE WATER USED - BBLS 750 100 TEMP OF WEATHER & PERSONNEL DATA 8 WIND SPEED WIND DIRECTION 315° CHILL FACTOR OF 8.00 ARCO PERSONNEL CONTRACTOR PERSONNEL 32 MISC PERSONNEL 5 SERVICE PERSONNEL 10 TOTAL I OPERATIONS fR~MQOOO .~OOQO Pre. Tour safety meeting. Parker Supervisors discussed recent fall on rig with new crew & proper way to hook 'D'-rings on bOdy harness & seat strap into shackle on air tugger line. Also discussed current & upcoming operations on well. POH LDDP. Make service breaks & break down Baker C2 liner setting tool & pup joints. RU to run 3-1/2" completion assembly. Service rig. Pre-Job safety meeting on running completion string. RU & test 7" casing & 4-1/2" liner to 3500 psi for 30 minutes, no pressure loss, OK. RD test equipment. Run 3-1/2" completion assembly. Circulate at 200 jts ( 6435') & before making up SSSV on jt #300 (9615'). Tested control line to 5000 psi when MU to SSSV & maintained pressure on line while running rest of string, OK. Stabbed seals into SBE below liner hanger & marked pipe for space out. Verified Position with pump & weight indicator. Unsting seals' & PU until muleshoe is in 5-1/4" ID tie-back stem, , Circulate bottoms up & circulate out contaminated mud, 6 BPM, 2000 psi. Switch lines, close annular, & reverse circulate to displace mud with clean fresh water. Pumped 50 Bbls water, followed by 40 Bbl of 150 vise sweep, followed by 100 Bbls dirty water, then clean fresh water. Getting viscous sweep out at midnight. Reversing at 5 BPM to 5.75 BPM. (Continued reversing until getting clean water returns at 0100 hrs). 48 Page 1 /' /. /~' ~ ~~ ~,.. ARCO Alaska, Inc. AFC No. I Date AK 9165 11/11/98 Well: 1 E-36 Daily Drilling Report RptNo 17 Depth (MDfTVD) I Rig Accept - hrs 10/26/9805:00:00 12005/6193 Prev Depth MD: 12005 Cum Cost $ 1996388 Next Csg: 3-1/2" Tubing Days Since AccepVEst: 16.79/15.5 Rig Relase - hrs: Contractor: PARKER Daily Cost $ 106502 Rig Name: RIG # 245 Last Csg: 4-1/2" @ 11408' to 12004' Operation At 0600: Testing casing & liner to 3500 psi for 30 minutes. Upcoming Operations: Run 3.1/2" Completion Assembly Progress: 0 Est Cost To Date $ 2000000 Shoe Test: MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND N TST 11/08/98 11/06/98 WEIGHT ROT wr SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 12.1ppg 10/27/98 10/17/98 VISCOSITY puwr MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 62sqc N SPACE 11/09/98 11/10/98 PV/YP sowr TYPE TYPE TYPE FUEL & WATER 31/19 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2076 6/15/ APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 500 4.8 11/11/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 9.0m1l30 min INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER& 15.5% 1R-18D PERSONNEL, DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP OF 14 384bbl III / / 1 E-36 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 14 17.5 1/213/ ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 1800 8.9 6 I 5.5 I 5.5 I LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -10.99 2.3% III Water Base Muds 1160 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 1 350 III 11111 11111 0 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 32 $1103 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $151581 III III II/ 1160 COMPANY MUD wr GRADE GRADE TOT FOR WELL (bbl) . SERVICE 9 BAROID III III III 13955 PERSONNEL TOTAL 47 TIME I END HOURS I OPS CODE I HOLE.SECT' I RHASE O~S I OPEIM;J110NSF:ROMOOOO-. 0000 00:00 01:30 1.50 CIRC PROD Casing and Circulate to condition mud & hole for cementing, 40 SPM, Cementing 3.4 BPM, 1700 psi. Reciprocate pipe, 225K# Up, 125K# Down. Circulated 1063 Bbls total. 01:30 03:00 1.50 CASG PROD Casing and Cement 4-1/2" Liner: Dowell flushed lines with 5 Bbls Cementing water; Test lines to 4500 psi; Pump 10 Bbls ARCO Wash, 3.2 BPM, 1500 psi; Pump 30 Bbls, 13.5 ppg ARCO Spacer, 2.9 BPM, 1300 psi; Pump 21 Bbls, 100 sx, 15.8 ppg batch mixed Class G "GasBlok" cement, 3.0 BPM, 1100 psi; Flush cement out of line to head with 5 Bbls water; Drop DP wiper plug; Switch to rig pump & displace with mud, 4.0 BPM to 3.5 BPM, 1900 psi (slowed rate to 1.4 BPM for latch-up of DP wiper into Liner wiper plug); Bumped plug. Pressured up to 3200 psi & held. Set 20K# down on liner hanger, OK. PU to neutral & pressured up to 4200 psi & held. Bled off pressure & checked floats, OK. Rotate 16 turns to release running tool. Pressure up to 850 psi, PU & saw pressure drop when seals cleared. Continued circulating at 2.3 BPM to lift & keep excess cement above liner. Set 60K# down on liner tie-back stem to verify & complete liner hanger set & packoff, repeated once. CIP @ 0230 hrs. Had full returns. Reciprocated pipe until pre-flush & spacer neared shoe. 03:00 04:00 1.00 CIRC PROD Casing and Continue circulating & PU about 5'. Circulated out Cementing pre-flush, spacer, & excess cement, roughly 44 Bbls total. Circulated 376 Bbls, 59 SPM, 5,0 BPM, 3350 psi. 04:00 06:00 2.00 CIRC PROD Casing and Blowdown standpipe. Reverse circulate 24 Bbls, slowly Cementing pressured up to 3500 psi. Switch valves & try to circulate, no go. Pull single with cement head. Pull 15 stands to 9954', up to 100K# overpull. New Daily Drilling Report Page 1 (' 06:00 07:30 1.50 CIRC PROD Casing and Work & rotate pipe & establish circulation. Circulate out Cementing cement contaminated, very thick mud. Clean up mud & recondition adding thinner, bicarb, pH 6, & water. 07:30 12:00 4.50 CIRC PROD Casing and RIH 8 stands & circulate hole clean at 10711'. RIH 7 stands Cementing & single. Stabbed stinger back into liner SBE & set down on top of liner with setting dogs at 11408'. Circulated hole clean. 12:00 14:30 2.50 CIRC PROD Casing and Reverse circulate hole clean, 5.3 BPM, 2850 psi. Reversed Cementing 425 Bbls total, LD 2 jts. Pump slug, 14:30 00:00 9.50 TRIP_OUT PROD Casing and POH LDDP. Cementing 00:00 24.00 Supervisor: DON E. BREEDEN " New Daily Drilling Report Page 2 ,{ ~ ~~ ~" ARCa Alaska, Inc. AFC No. I Date AK 9165 11/10/98 Well: 1E-36 RptNo 16 Depth (MDfTVD) I Rig Accept - hrs 10/26/9805:00:00 12005/6193 Prey Depth MD: 12005 Days Since AccepUEst: 15.79/14.5 Contractor: PARKER Daily Cost $126762 Cum Cost $1889886 Rig Name: RIG # 245 Last Csg: 7" @ 11597' Next Csg: 41/2" @ 12005 Operation At 0600: Circulating out cement contaminated mud (Liner CIP @ 0230 hrs, 11/11/98) Upcoming Operations: RBIH 15 stands & circulate SBE clean, LDDP, Run completion MUD DATA MUD TYPE LSND WEIGHT 12.6ppg VISCOSITY 76sqc PVNP 32 / 43 GELS 11/24/ APIWL 3.6 HTHP WL 8.0m1/30 min SOLIDS 17.0% HOLE VOLUME 392bbl MBT 20.0 ph 7.8 LGS 1.4% PIT VOL 640 DAILY MUD $3572 TOTAL MUD $150478 COMPANY BAROID TIME I END 00:00 19:00 19:00 00:00 DRILLING DATA DEPTH 12005 ROT WT PUWT 225 SOWT 125 AVG DRAG 5 MAX DRAG 10 TRQ BTM TRQ OFF PUMP PRES 1700 III PUMP NO 112131 LINER SZ 6 I 5.5 I 5.5 I SPM 1 140 II GPM2 /143/1 SPS 1 III SPP 1 III MUDWT III HOI.:JRS 19.00 00:00 24.00 New Daily Drilling Report 5.00 BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADTIAST I WOB2 RPM 1 TFA JETS " " I BIT COST DULL III GRADE III IOPS,CODE CASG CIRC BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST I WOB2 RPM 1 TFA JETS " III BIT COST DULL III GRADE III EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG 11/10/98 INJECTION INJECTION WELL 1R-18D SOURCE WELL 1 E-36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 0 0 0 0 0 TOTAL VOL (bbl) 0 TOT FOR WELL (bbl) 12795 Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date $1900000 Shoe Test: 16.0 DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 11/08/98 11/06/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 11/10/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 11/09/98 FUEL & WATER FUEL USED 2109 DRILL WATER USED- BBLS POTABLE WATER USED - BBLS 250 100 WEATHER & PERSONNEL DATA TEMP of 16 WIND SPEED 2 WIND DIRECTION 225° CHILL FACTOR OF 16.00 ARCO PERSONNEL CONTRACTOR PERSONNEL 31 MISC PERSONNEL 5 SERVICE PERSONNEL 9 TOTAL I QPER~TIONS FROMOOOO~;OOOO , I MU 4-1/2" liner assembly. RIH on 3-1/2" DP. CBU & circulate out gas cut mud at 3060', 6048', 9073', & 11538'. Continue RIH, MU Baker top-drive cementing head, & tag bottom at 12005'. Circulate to condition mud & hole for cementing, 40 SPM, 3.4 BPM, 1700 psi. Reciprocate pipe, 225K# Up, 125K# Down. HOLESEQT IpHASeiiOPS PROD Casing and Cementing PROD Casing and Cementing 46 Supervisor: DON E. BREEDEN Page 1 { AI8~ ~" ARCO Alaska, Inc. AFC No. AK9165 ¡Date 11/09/98 RptNo 15 I Rig Accept - hrs 10/26/9805:00:00 AM 12005/6193 Prev Depth MD: 11975 Days Since Accept/Est: 14.79/14 Well: 1 E.36 Depth (MDfTVD) Contractor: PARKER Rig Name: RIG # 245 Daily Cost $ 82455 Last Csg: 7" @ 11597' Operation At 0600: RIH w/liner Upcoming Operations: Cement liner. LD DP. MUD DATA MUD TYPE LSND DRILLING DATA DEPTH 12005 BIT NO. 5 WEIGHT 12.5ppg VISCOSITY 77sqc ROTWT 150k PUWT 225k SIZE 61/8 MAKE HTC PVIYP 42/35 GELS 13/22/ APIWL 3.5 HTHP WL 7.8m1130 min SOLIDS 18.0% HOLE VOLUME 446bbl MBT 20.0 ph 8.4 LGS 4.2% SOWT 130k AVG DRAG 10k MAX DRAG 10k TRO BTM 6k TRO OFF 8k PUMP PRES 3500 III PUMP NO 112131 LINER SZ 6 I 5.5 I 5.5 I SPM 1 11551 TYPE STR09D SERIAL NO U43YE DEPTH OUT 12005 DEPTH IN 11597 FOOTAGE 408 ADT/AST 14.31/ WOB2 22 - 25 RPM 1 90 - TFA .450 PIT VOL 640 GPM2 111961 JETS 141141141 I I DAILY MUD $4831 SPS 1 2013511 BIT COST 8415 TOTAL MUD SPP 1 DULL $146905 87511600 I I 1111ERIA COMPANY MUD WT GRADE BAROID 12.3112.31 I E oINoITD ;rIMe 1 END ,,'HQUR$ I QPÆ¡CQQE 12:00 AM 01 :00 AM 1.00 DRIL 01 :00 AM 01 :30 AM 0.50 WIPERTRP 01 :30 AM 02:30 AM 1.00 PRB_EFC 02:30 AM 03:00 AM 0.50 WIPERTRP 03:00 AM 03:30 AM 0.50 DRIL 03:30 AM 07:00 AM 3.50 PRB_WC 07:00 AM 08:30 AM 1.50 WIPERTRP 08:30 AM 10:30 AM 2.00 CIRC 10:30 AM 06:00 PM 7.50 TRIP_OUT 06:00 PM 10:00 PM 4.00 BHA 10:00 PM 10:30 PM 0.50 OTHER 10:30 PM 12:00 AM 1.50 CASG 24.00 Daily Drilling Report: 1 E-36 11/09/98 BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 TFA JETS III1I BIT COST DULL III GRADE III Cum Cost $ 1763124 Next Csg: 4 1/2" @ 12091 EH&S INCIDENT EMPLOYER SPILL Y TYPE Water Base Mud VOLUME 20 gals LAST SAFETY MTG 11/09/98 iNJECTION INJECTION WELL 1R.18D SOURCE WELL 1 E.36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 0 0 0 0 0 TOTAL VOL (bbl) 0 TOT FOR WELL (bbl) 12795 Daily Drilling Report Rig Relase - hrs: Progress: 30 Est Cost To Date $ 1750000 Shoe Test: 16.0 DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 11/08/98 11/06/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 10/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 11/09/98 FUEL & WATER FUEL USED 2480 DRILL WATER USED. BBLS POTABLE WATER USED - BBLS 250 100 WEATHER& PERSONNEL DATA TEMP of 17 WIND SPEED 23 WIND DIRECTION 80° CHILL FACTOR of .17.12 ARCO PERSONNEL CONTRACTOR PERSONNEL 30 MISC PERSONNEL 5 SERVICE PERSONNEL 10 TOTAL I'" PPEMliIQN$FRQMPPQQSOOQQ Drlg f/11,975' to 11,999'. ADT - .78 hrs. 4" oteco valve washed out in pump room. Flange washed out in Baylor brake room. 20 gal. mud spill to pad. Rebuild valve. RIH. No problems. Drlg f/11,999' to 12,005'. ADT - .31 hrs. Had gas to surface. Cont' circ and increase wt to 12.5 ppg. Pump out of hole to shoe. POH w/10 stds. RIH to TD. CBU. Had small amount of gas at bottoms up. POH slow. No problems. LD BHA. Download Sperry Sun and remove source, Held pre job safety meeting. ,HQlþESEPr,' . IPHA§E'QR$ PROD Making Hole PROD Making Hole PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Casing and Cementing Casing and Cementing 46 RIH w/4 1/2" liner. Supervisor: DONALD LUTRICK Page 15 ~~ ~" ARCO Alaska, Inc. AFC No. AK9165 Well: 1 E-36 ¡Date 11/08/98 RptNo 14 Depth (MDfTVD) I Rig Accept - hrs 10/2619805:00:00 AM 11975/6173 Prev Depth MD: 11597 Contractor: PARKER Daily Cost $119202 Rig Name: RIG # 245 Last Csg: 7" @ 11597' Operation At 0600: Increase MW to 12.5 PPG Upcoming Operations: P.oH. Run 4" Liner MUD DATA MUD TYPE LsND WEIGHT 12.3ppg VISCOSITY 65sqc PVNP 34/27 GELS 8/17/ APIWL 3.6 HTHP WL 8.2ml/30 min SOLIDS 16.5% HOLE VOLUME 406bbl MBT 20.0 ph 8.1 LGS 2.7% PIT VOL 640 DAILY MUD $41713 TOTAL MUD $142075 COMPANY BAR.oID ,TIME' 12:00 AM 01 :00 AM 02:30 AM 03:00 AM 04:30 AM I ENQ' 01 :00 AM 02:30 AM 03:00 AM 04:30 AM 05:30 AM 05:30 AM 11 :00 AM 11 :00 AM 03:00 PM 03:00 PM 12:00 AM DRILLING DATA DEPTH 11975 ROTwr 150k puwr 240k sowr 118k AVG DRAG 10k MAX DRAG 10k TRQ BTM 6k TRQ OFF 8k PUMP PRES 3500 III PUMP NO 112131 LINER SZ 6 I 5.5 15.5 I SPM 1 11551 GPM2 111961 SPS 1 2013511 SPP 1 87511600 I I MUDwr 12.3112.31 I HOQRS' 1.00 1.50 0.50 1.50 1.00 5.50 4.00 9.00 24.00 BIT NO. 5 SIZE 61/8 MAKE HTC TYPE sTR09D SERIAL NO U43YE DEPTH OUT DEPTH IN 11597 F.oOTAGE 378 ADT/AST 13.23 / WOB2 22 - 25 RPM 1 90 - TFA .450 JETS 141141141 1 I BIT COST 8415 DULL III GRADE III 1...iIOP$...ÇpOE CLN_.oUT CIRC DRIL CIRC CAsG DRIL PRB_WC DRIL Daily Drilling Report: 1 E-36 11/08/98 BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 TFA JETS 111I1 BIT COST DULL III GRADE III I , H.0L!E:,SECT PR.oD PR.oD PR.oD PR.oD PR.oD PR.oD PROD PR.oD TOTAL , I . " OPSBATIONSF.RQMQQQQSQQQO Finish drill out cement and float shoe. Displace to 12.1 ppg mud. Drlg f/11,597' to 11,607'. ADT..5 hrs CBU and condition mud. FIT. 5943' TVD + 12.1 mud + 1210 psi suñace press = 16 PPG EMW. Drlg f/11,607' to 11,713'.(TVD 6008') ADT. 5.44 hrs Had gas cut mud to suñace. Circ until gas subsided. Check flow. .oK. CBU. Gas cut mud 12.1.11.1. Increase mud wt f/ 12.1 to 12.3 ppg. Drlg f/11,713' to 11,975'. ADT -7.58 hrs Days Since AccepUEst: 13.79/13 Cum Cost $ 1680669 Next Csg: 41/2" @ 12091 EH&s INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG 11/08/98 INJECTIoN INJECTION WELL 1R-18D SOURCE WELL 1 E-36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 1185 0 0 0 0 TOTAL V.oL (bbl) 1185 TOT FOR WELL (bbl) 12795 , IPH~SEpeS Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Daily Drilling Report Rig Relase - hrs: Progress: 378 Est Cost To Date $ 1750000 Shoe Test: 16.0 DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 11/08/98 11/06/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 10/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 FUEL & WATER FUEL USED 2124 DRILL WATER USED- BBLS POTABLE WATER USED - BBLS 250 100 WEATHER,& PERSONNEL DATA TEMP of WIND SPEED 13 WIND DIRECTION 80° CHILL FACTOR of -2.87 ARCO PERSONNEL CONTRACTOR PERSONNEL 30 MISC PERSONNEL 5 SERVICE PERSONNEL 8 44 Supervisor: D.oNALD LUTRICK Page 14 ..1II111rr. ~" ARCa Alaska, Inc. AFC No. AK9165 Well: 1E-36 I Date 11107198 RptNo 13 I Rig Accept - hrs 10126/9805:00:00 AM 11597/5943 Prev Depth MD: 11597 Days Since AccepUEst: 12.79/11.9 Depth (MDfTVD) Contractor: PARKER Rig Name: RIG # 245 Operation At 0600: Drilling Upcoming Operations: TD 6 1/8" Hole MUD DATA MUD TYPE LSND WEIGHT 12.1ppg VISCOSITY 72sqc PVIYP 49/30 GELS 8/13/ APIWL 5.4 HTHP WL ml130 min SOLIDS 17.0% HOLE VOLUME 395bbl MBT 20.0 ph 7.8 LGS 5.4% PIT VOL 600 DAILY MUD $5694 TOTAL MUD $100361 COMPANY BAROID 12:00 AM 01 :00 AM 05:00 AM 05:00 AM 12:00 PM 12:00 PM 12:30 PM 12:30 PM 04:30 PM 04:30 PM 06:00 PM 06:00 PM 07:30 PM 07:30 PM 09:00 PM 09:00 PM 10:00 PM 10:00 PM 12:00 AM Daily Cost $ 90123 Last Csg: 7" @ 11597' DRILLING DATA DEPTH 11597 BIT NO. 5 BIT DATA BIT NO. ROT WT 153k PUWT 250k SIZE 61/8 MAKE HTC SIZE MAKE SOWT 118k AVG DRAG 10k MAX DRAG 15k TRQ BTM 10k TRQ OFF 10k PUMP PRES 3100 III PUMP NO 112131 LINER SZ 6 I 5.5 I 5.51 SPM 1 1160 I TYPE STR09D SERIAL NO U43YE DEPTH OUT TYPE SERIAL NO DEPTH OUT DEPTH IN 11597 FOOTAGE 0 ADT/AST / WOB2 DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 RPM 1 TFA .450 TFA GPM2 112141 JETS 141141141 I I JETS I1III SPS 1 III BIT COST BIT COST AM SPP 1 DULL DULL III III III MUDWT GRADE GRADE III III III ,HOUR$ I aRSOQDE I . HOL,E'$EOJ 1.00 OTHER PROD 4.00 BHA PROD 7.00 TRIP_IN PROD 0.50 RIGS PROD 4.00 TRIP_IN PROD 1.50 CIRC PROD 1.50 CASG PROD 1.50 AINJ PROD 1.00 OTHER PROD 2.00 CLN_OUT PROD 24.00 Daily Drilling Report: 1 E-36 11/07/98 Cum Cost $ 1561467 Next Csg: 4 1/2" @ 12091 EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG 11/05/98 INJEC'11()N INJECTION WELL 1R-18D SOURCE WELL 1 E-36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 290 0 0 0 0 TOTAL VOL (bbl) 290 TOT FOR WELL (bbl) 11610 if Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date $1600000 Shoe Test: 16.0 DRILLS/BOP DATA LAST BOPIDIVERT LAST BOP/DRILL TST 11/01/98 11/06/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 10/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 FUEL & WATER FUEL USED 5095 DRILL WATER USED- eelS POTABLE WATER USED - eBlS 250 100 WEATHER& PERSONNELDATA TEMP of 21 WIND SPEED 9 WIND DIRECTION 240° CHILL FACTOR of 6.91 ARCO PERSONNEL CONTRACTOR PERSONNEL 30 MISC PERSONNEL 5 SERVICE PERSONNEL 8 'HHA$E/OPS Casing and Cementing Making Hole TOTAL I " '08EBf'.JJONsFROMPQQQpQQQo Finish LD DP fI derrick. 44 Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole MU BHA. Suñace test MWD. No test. Reprogram. Held safety meeting. Load sources. PU Dc. PU and RIH w/3 1/2" HWDP and 3 1/2" DP. Service rig. Finish PU DP. Tag cement at 11,460'. Circ ou cement contaminated mud. Test csg to 3500 psi f/ 30 min. Flush outer annulus w/ 300 bbls FW. Freeze protect w/75 bbls diesel. PU and std back 7 stds DP. Drill out cement and FE to 11 550'. Supervisor: DONALD LUTRICK Page 13 AII8~ ~'" ARCa Alaska, Inc. Well: 1 E-36 Depth (MDnvD) I Rig Accept - hrs 10/2619805:00:00 AM 11597/5943 Prev Depth MD: 11597 Cum Cost $ 1471341 Next Csg: 4 1/2" @ 12091 AFC No. AK9165 I Date 11/06198 RptNo 12 Contractor: PARKER Daily Cost $ 122492 Rig Name: RIG # 245 Last Csg: 7" @ 11597' Operation At 0600: PU and RIH wI 3 1/2" DP Upcoming Operations: Drill out FE. LOT. Displace wI 12.2 mud MUD DATA DRILLING DATA BIT DATA MUD TYPE DEPTH BIT NO. BIT NO. LSND WEIGHT ROT WT SIZE SIZE 9.7ppg VISCOSITY PUWT MAKE MAKE 53sqc PVIYP SOWT TYPE TYPE 19/14 GELS AVG DRAG SERIAL NO SERIAL NO 5/7/ APIWL MAX DRAG DEPTH OUT DEPTH OUT 4.4 HTHP WL TRQ BTM DEPTH IN DEPTH IN ml130 min SOLIDS TRQ OFF FOOTAGE FOOTAGE 9.0% HOLE VOLUME PUMP PRES ADT/AST ADT/AST 431bbl III / / MBT PUMP NO WOB2 WOB2 20.0 112131 - ph LINER SZ RPM 1 RPM 1 8.4 6 I 5.5 I 5.5 I LGS SPM 1 TFA TFA 7.3% III PIT VOL GPM2 JETS JETS 510 III 1III1 I1III DAILY MUD SPS 1 BIT COST BIT COST $525 III TOTAL MUD SPP 1 DULL DULL $94667 III III III COMPANY MUD WT GRADE GRADE BAROID III III III TIME I gNP HOURS' I CRSICODE 'I HOLE SECT 12:00 AM 02:00 AM 2.00 CEMENT PROD 02:00 AM 04:00 AM 2.00 NU_ND PROD 04:00 AM 06:30 AM 2.50 CASG PROD 06:30 AM 09:00 AM 2.50 NU_ND PROD 09:00 AM 11:00AM 2.00 BOPE PROD 11:00 AM 03:00 PM 4.00 BOPE PROD 03:00 PM 04:30 PM 1.50 OTHER PROD 04:30 PM 05:00 PM 0.50 OTHER PROD 05:00 PM 12:00 AM 7.00 OTHER PROD 24.00 Daily Drilling Report: 1 E-36 11/06/98 Days Since AccepUEst: 11.79/11.5 EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG 11/05/98 INJECTiON INJECTION WELL 1R-18D SOURCE WELL 1E-36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 290 0 0 0 0 TOTAL VOL (bbl) 290 TOT FOR WELL (bbl) 11320 Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date $1550000 Shoe Test: DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 11/01/98 11/06/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 10/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 FUEL & WATER FUEL USED 2295 DRILL WATER USED - 0 BBLS POTABLE WATER 100 USED - BBLS WEATHER& PERSONNEL DATA TEMP of 17 WIND SPEED 5 WIND DIRECTION 250° CHILL FACTOR of 13.26 ARCO PERSONNEL 2 CONTRACTOR 30 PERSONNEL MISC PERSONNEL 5 SERVICE 9 PERSONNEL IPHAß¡:,PRs Casing and Cementing TOTAL I QPERAJI0NSERPM.QOQQS(QOOO, Test lines to 3500 psI. Pump 20 bbls Arco wash, 40 bbls ARCO spacer, 35 bbls 15.8 cement and displaced with rig pumps wI mud. Bumped plug. Floats OK. ND BOP. Set slips w/185k csg wt on slips. Cut off csg. Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing 46 Install tbg head. Test packoff to 3000 psi. NU BOPE. Change top and bottom pipe rams. Change top drive over to 3 1/2" IF. RU test equipment. Test BOPE to 300 I 5000 psi wI annular to 3000 psi. Wìtness of test waived by AOGCC rep John Spalding. RD test equipment. Install wear bushing. Blow down all lines and choke manifold. Held prejob safety meeting on LD DP. LD 5" DP from derrick. Supervisor: DONALD LUTRICK Page 12 ( ~ ..--... ~r ARCa Alaska, Inc. Daily Drilling Report I Rig Accept - hrs 10/26/9805:00:00 AM 11597/5943 Prey Depth MD: 11597 Date 11/05/98 AFC No. AK9165 Rpt No 11 Days Since AccepUEsl: 10.79/10.8 Rig Relase - hrs: Well: 1 E.36 Depth (MDfTVD) Progress: 0 Est Cost To Date $ 1480000 Shoe Test: N/A Contractor: PARKER Rig Name: RIG # 245 Operation At 0600: Test BOPE Upcoming Operations: LD 5" DP & PU and RIH w/3 1/2" DP Daily Cost $ 217911 Last Csg: 9-5/8" @ 6330' Cum Cost $1348849 Next Csg: T' @ 11597' MUD DATA MUD TYPE LsND DRILLING DATA DEPTH BIT DATA BIT NO. EH&S INCIDENT N DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 11/01/98 10/31/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 1 0/13/98 BIT NO. 4RR WEIGHT 9.7ppg VISCOSITY 53sqc ROTwr SIZE 81/2" MAKE HTC SIZE EMPLOYER LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 puwr MAKE SPILL N PVIYP 19/14 GELS 517/ APIWL 4.4 HTHP WL mll30 min SOLIDS 9.0% HOLE VOLUME 431bbl MBT 20.0 ph 8.4 LGS 7.3% sowr TYPE R417G SERIAL NO 0119925 DEPTH OUT 11597 DEPTH IN 9830 FOOTAGE 1767 ADT/AST 11.86/2.69 WOB2 10 - 25 RPM 1 100 - mm TFA .557 TYPE TYPE FUEL & WATER AVG DRAG SERIAL NO VOLUME FUEL USED 1973 MAX DRAG DEPTH OUT LAST SAFETY MTG 11/05/98 DRILL WATER USED- BBLS POTABLE WATER USED - BBLS 250 TRQ BTM DEPTH IN 100 IN-IEG1:1Ç)N INJECTION WELL 1R-18D SOURCE WELL 1 E-36 RATE (bpm) TRQ OFF FOOTAGE WEATHER& PERSONNEL DATA PUMP PRES III PUMP NO 112131 LINER SZ 6 I 5.5 I 5.5 I SPM 1 III ADT/AST / WOB2 TEMP of 12 WIND SPEED 10 RPM 1 PRESSURE (psi) WIND DIRECTION 45° TFA INJECTION FLUIDS CHILL FACTOR of -6.18 Water Base Muds 540 PIT VOL 510 GPM2 III JETS JETS 11111111111111 IIIII 111 BIT COST 0 ARCO PERSONNEL 2 0 0 DAILY MUD $862 SPS 1 III BIT COST CONTRACTOR PERSONNEL 30 0 0 TOTAL VOL (bbl) 540 TOT FOR WELL (bbl) TOTAL MUD SPP 1 DULL $94143 III 1121btln COMPANY MUDwr GRADE BAROID III x I 0 I no I td 3.00 03:00 AM 03:30 AM 0.50 OTHER 03:30 AM 04:30 AM 1.00 RIGS 04:30 AM 05:30 AM 1,00 CAsG 05:30 AM 09:30 PM 16.00 CASG 09:30 PM 12:00 AM 2.50 CIRC 24.00 DULL III GRADE III MISC PERSONNEL 5 SERVICE PERSONNEL TOTAL I ' QPERATIONSF80MoPQP"OOOO LD HWDP and DC's. Pull wear bushing. 9 46 , IPHA~.I;'Qes Making Hole Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing HOLE.,g,ECT PROD PROD PROD Cut and slip drlg line. PROD RU csg tools. Held prejob safety meeting. PROD RIH w/7" csg to 11,597'. Circ hole every 50 jts. PROD Circ and condition mud at 6 bpm. Supervisor: LUTRICK I PUTNAM Daily Drilling Report: 1 E-36 11/05/98 Page 11 ....~ ~" ARCa Alaska, Inc. AFC No. AK9165 I Date 11/04198 Well: 1 E-36 Contractor: PARKER Rig Name: RIG # 245 Operation At 0600: RIH w/7" Csg Upcoming Operations: Cement Csg MUD DATA MUD TYPE LSND DRILLING DATA DEPTH WEIGHT 9.6ppg VISCOSITY 47sqc ROTwr puwr PVIYP 17 /13 GELS 5/7/ APIWL 4.0 HTHP WL ml130 min SOLIDS 8.0% HOLE VOLUME 762bbl MBT 27.5 ph 8,6 LGS 6.1% sowr AVG DRAG MAX DRAG TRQ BTM TRQ OFF PUMP PRES 3100 III PUMP NO 112131 LINER SZ 6 1 5.5 I 5.5 I SPM 1 7811801 PIT VOL 620 GPM2 330 I I 293 I DAILY MUD $16084 SPS 1 3014511 RptNo 10 Depth (MDITVD) Daily Cost $ 93294 Last Csg: 9-5/8" @ 6330' BIT NO. 4RR SIZE 81/2" MAKE HTC TYPE R417G SERIAL NO 0119925 DEPTH OUT 11597 DEPTH IN 9830 FOOTAGE 1767 ADT/AST 11.86/2.69 WOB2 10 - 25 RPM 1 100 - mm TFA .557 I Rig Accept - hrs 10/26/9805:00:00 AM 11597/5943 Prey Depth MD: 10010 BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 TFA JETS JETS 11 111111 111111 I II I I 111 BIT COST 0 BIT COST TOTAL MUD SPP 1 DULL DULL $93281 475 1 625 I 1 III III COMPANY MUDWf GRADE GRADE BAROID 9.619.611 III III TIME I END HOURS I OPSCOD,E I HOLESECT 12:00 AM 02:00 PM 14.00 DRIL PROD 02:00 PM 04:00 PM 2.00 CIRC PROD 04:00 PM 06:00 PM 2.00 WIPERTRP PROD 06:00 PM 08:00 PM 2.00 CIRC PROD 08:00 PM 12:00 AM 4.00 TRIP_OUT PROD 24.00 Daily Drilling Report: 1 E-36 11/04/98 Days Since AccepVEst: 9.79/9.8 Cum Cost $ 1130938 Next Csg: 7" @ 1159T EH&S INCIDENT EMPLOYER SPILL TYPE VOLUME LAST SAFETY MTG 11/04198 INJECTION INJECTION WELL 1R-18D SOURCE WELL 1 E-36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS 0 0 0 0 0 TOTAL VOL (bbl) 0 TOT FOR WELL (bbl) Daily Drilling Report Rig Relase - hrs: Progress: 1587 Est Cost To Date $ 1250000 Shoe Test: N/A DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 11/01/98 10/31/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 10/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 FUEL & WATER FUEL USED DRILL WATER USED- BBLS POTABLE WATER USED - BBLS WEATHER& PERSONNEL DATA TEMP OF WIND SPEED WIND DIRECTION CHILL FACTOR of ARCO PERSONNEL CONTRACTOR PERSONNEL MISC PERSONNEL SERVICE PERSONNEL TOTAL I ' OPERATIQNSFROMPOOPHOO.QQ Drlg f/10110' to 11597'. ADT - 9.50 hrs Check flow. Circ lo/hi vis sweep. Made 25 std wiper trip. No problems. Circ and condition mud for csg. POH. No problems. PHASEQRS, Making Hole Making Hole Making Hole Making Hole Making Hole 1389 1000 100 17 160° 13.26 2 30 5 9 46 Supervisor: LUTRICK / PUTNAM Page 10 rj' ~~ ~" ARCO Alaska, Inc. AFC No. AK9165 Well: 1 E-36 I Date 11/03/98 RptNo 9 Depth (MDfTVD) Contractor: PARKER Rig Name: RIG # 245 Operation At 0600: Drlg Upcoming Operations: TD intennediate. Wiper trip for csg. MUD DATA MUD TYPE LSND WEIGHT 9.6ppg VISCOSITY 68sqc PVNP 27/31 GELS 12/17/ API VVL 3.4 HTHP VVL ml130 min SOLIDS 10.0% HOLE VOLUME 668bbl MBT 30 ph 8.8 LGS 10.0% PIT VOL 596 DAILY MUD $7240 TOTAL MUD $77196 COMPANY miME I ,END' 12:00 AM 01 :00 AM 01 :00 AM 07:30 AM 07:30 AM 09:30 AM 01 :30 PM 02:30 PM 03:00 PM 07:30 PM 08:00 PM 09:30 AM 01 :30 PM 02:30 PM 03:00 PM 07:30 PM 08:00 PM 12:00 AM DRILLING DATA DEPTH 10010 ROT WT 165k PUWT 200k SOWT 135k AVG DRAG 10k MAX DRAG 10k TRQ BTM 14k TRQ OFF PUMP PRES 3100 III PUMP NO 112131 LINER SZ 6 1 5.5 I 5.51 SPM 1 781180 I GPM2 330 I I 293 I SPS 1 3014511 SPP 1 475 I 6251 I MUD WT 9.6 19.6 I I HOURS 1.00 6.50 2.00 4.00 1.00 0.50 4.50 0.50 4.00 24.00 Daily Cost $ 84620 Last Csg: 9-5/8" @ 6330' BIT NO. 3 SIZE 8.5 MAKE STC TYPE S88HPX SERIAL NO JR7240 DEPTH OUT 9830 DEPTH IN 6367 FOOTAGE 3463 ADT/AST 20.86 /1.48 WOB2 4 -15 RPM 1 100 - mm TFA .614 JETS 8.10 I I I II BIT COST 8000 DULL 1111btla GRADE x 1 0 1 bu I pr TOTAL I ' oPSMTlQN&FRQM'.()DOPAOOQo . Held fall protection safety meeting with all on duty personnel. Drlg f/9274' to 9830". ADT - 5.82 hrs. PR rate slow for this section of hole. Clrc lo/hi vis sweep. POH. No problems. Change bits. Download Sperry Sun MWD. Service rig and top drive. RIH. Fill pipe every 20 stds. CBU while rotate and reciprocate pipe. Drlg f/9830' to 10110'. ADT - 2.35 hrs I Rig Accept - hrs 10/26/9805:00:00 AM 10010/5360 Prey Depth MD: 9274 Days Since AccepUEst: 8.79/8.4 Cum Cost $1037644 Next CS9: 7" @ 11677' BIT DATA EH&S BIT NO. INCIDENT 4RR N SIZE EMPLOYER 8 1/2" MAKE SPILL HTC N TYPE TYPE R417G SERIAL NO VOLUME 0119925 DEPTH OUT LAST SAFETY MTG 11/03/98 DEPTH IN 9830 INJECTION FOOTAGE INJECTION WELL 180 1R-18D ADTIAST SOURCE WELL 2.36 1 .64 1 E-36 WOB2 RATE (bpm) 10 - 25 RPM 1 PRESSURE (psi) 100 - mm TFA INJECTION FLUIDS .557 Water Base Muds 570 JETS 11 111111111111 0 111 0 BIT COST 0 0 DULL III GRADE III 0 TOTAL VOL (bbl) 570 TOT FOR WELL (bbl) 10200 DRIL CIRC TRIP_OUT BHA RIGS TRIP_IN CIRC DRIL Daily Drilling Report: 1 E-36 11/03/98 I'QB~'QQPE'I HQLE&EOTIRHASEQRs OTHER PROD Making Hole PROD Making Hole PROD PROD PROD PROD PROD PROD PROD Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Daily Drilling Report Rig Relase - hrs: Progress: 736 Est Cost To Date $ 1125000 Shoe Test: N/A DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 11/01/98 10/31/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 10/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 FUEL & WATER FUEL USED 1838 DRILL WATER USED- BBLS POTABLE WATER USED - BBLS 250 100 WEATHER & PERSONNEL DATA TEMP OF 26 WIND SPEED 12 WIND DIRECTION 90. CHILL FACTOR OF 7.72 ARCO PERSONNEL 2 CONTRACTOR PERSONNEL 33 MISC PERSONNEL SERVICE PERSONNEL 9 49 Supervisor: DONALD LUTRICK Page 9 ...'" ~" ARCa Alaska, Inc. AFC No. AK9165 Date 11/02198 RptNo 8 Well: 1E-36 Depth (MDITVD) I Rig Accept - hrs 10/26/9805:00:00 AM 9274/5060 Prey Depth MD: 8064 Cum Cost $ Next Csg: 7" @ 11677' Contractor: PARKER Daily Cost $ Rig Name: RIG # 245 Last Csg: 9-5/8" @ 6330' Operation At 0600: Drig at 9750' Upcoming Operations: TD for intermediate MUD DATA DRILLING DATA BIT DATA MUD TYPE DEPTH BIT NO. BIT NO. LSND 9274 3 WEIGHT ROTwr SIZE SIZE 9.5ppg 160k 8.5 VISCOSITY puwr MAKE MAKE 64sqc 190k STC PVfYP sowr TYPE TYPE 20 / 24 135k S88HPX GELS AVG DRAG SERIAL NO SERIAL NO 11/18/ 5k JR7240 API WI.. MAX DRAG DEPTH OUT DEPTH OUT 3.7 5k HTHP WI.. TRQ BTM DEPTH IN DEPTH IN ml/30 min 6k 6367 SOLIDS TRQ OFF FOOTAGE FOOTAGE 9.0% 2907 HOLE VOLUME PUMP PRES ADT/AST ADT/AST 549bbl 3100 I II 15,04/1.48 / MBT PUMP NO WOB2 WOB2 20.0 112131 4 -15 ph LINER SZ RPM 1 RPM 1 8.5 6 I 5.5 I 5.5 I 100 - mm LGS SPM 1 TFA TFA 9.0% 78 I I 802 I .614 PIT VOL GPM2 JETS JETS 608 330 I I 293 I 8"101 I I I I II11I DAILY MUD SPS 1 BIT COST BIT COST $12787 3014511 8000 TOTAL MUD SPP 1 DULL DULL $69956 475 I 650 I I III III COMPANY MUDwr GRADE GRADE BAROID 9.519.511 III III TIME I 'END, HQURS I. QRS.,ÇODE I HOLE\SECT 12:00 AM 12:30 AM 0.50 PRB_TH PROD 12:30 AM 04:30 AM 4.00 PRB_TH PROD 04:30 AM 06:30 AM 2.00 CIRC PROD 06:30 AM 02:00 PM 7.50 DRIL PROD 02:00 PM 03:30 PM 1.50 CIRC PROD 03:30 PM 05:00 PM 1.50 WIPERTRP PROD 05:00 PM 05:30 PM 0.50 RIGS PROD 05:30 PM 08:00 PM 2.50 PRB_MISC PROD 08:00 PM 09:30 PM 1.50 WIPERTRP PROD 09:30 PM 12:00 AM 2.50 DRIL PROD 24.00 Daily Drilling Report: 1 E-36 11/02/98 Days Since AccepUEst: 7.79/7.8 EH&S INCIDENT Y EMPLOYER Parker SPILL N TYPE VOLUME LAST SAFETY MTG 11/01/98 INJECTION INJECTION WELL 1 R-18D SOURCE WELL 1 E-36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 580 0 0 0 0 TOTAL VOL (bbl) 580 TOT FOR WELL (bbl) 9630 leH~SEZOR.s Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Making Hole Daily Drilling Report Rig Relase - hrs: Progress: 1210 Est Cost To Date $ Shoe Test: N/A DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 11/01/98 10/31/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 10/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 FUEL & WATER FUEL USED 1626 DRILL WATER USED- BBLS POTABLE WATER USED - BBLS 250 100 WEATHER & PERSONNELDA TA TEMP of WIND SPEED 5 WIND DIRECTION 230° CHILL FACTOR of 15.36 ARCO PERSONNEL 2 CONTRACTOR PERSONNEL 30 MISC PERSONNEL 5 SERVICE PERSONNEL 7 TOTAL I, ORERATIONSFROMOOOQeQ()QQ Finish circ hole clean at shoe. Wash and ream f/6367' to 8064'. No problems. Circ lo/hi vis sweep. Drig f/8064' to 8994'. ADT. 5.43 hrs Pump lo/hi vis sweep while reciprocate and rotate pipe. POH to shoe. No problems. Service top drive. Had fall Incident while servicing top drive. (See accident report) Replace chains and hooks on tuggers. Held safety meeting for use new equipment Installed. RIH. No problems. Drlg f/8994' to 9274'. ADT. 1.96 hrs 44 Supervisor: DONALD LUTRICK Page 8 ~III... ~" ARCO Alaska, Inc. Daily Drilling Report Well: 1 E.36 Depth (MDfTVD) I Rig Accept - hrs 10/26/9805:00:00 AM 806414619 Prey Depth MD: 6367 Days Since AcceptJEst: 6.79/7 Rig Relase - hrs: AFC No. AK9165 Date 11/01/98 RptNo 7 Contractor: PARKER Rig Name: RIG # 245 Operation At 0600: Drlg Upcoming Operations: Drill 8 1/2" hole Daily Cost $ 92493 Last Csg: 9-5/800 @ 6330' Cum Cost $ 862937 Next Csg: 7" @ 11677' Progress: 1697 Est Cost To Date $ 925000 Shoe Test: N/A MUD DATA DRilLING DATA BIT DATA EH&S DRillS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL lSND 8064 2RR 3 N TST 10/22/98 10/31/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1ppg 145k 8.5 8.5 10/27/98 10/17/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 55sqc 210k STC STC N SPACE 09/16/98 10/13/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 18/23 125k FDSS+2 S88HPX GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 2182 12/16/ 5k lS8740 JR7240 APIWl MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 500 5.9 5k 6357 1 0/30/98 BBLS HTHP Wl TRO BTM DEPTH IN DEPTH IN POTABLE WATER 100 mU30 min 10k 6347 6367 \NJEC1)9N USED - BBLS SOLIDS TRO OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 6.0% 10 1697 1R-18D PERSÖNNELDATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 23 551bbl 2800 III / 7.65/ .63 1 E-36 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 4 17.5 112131 4 -15 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 45° 8.7 6 I 5.5 I 5.5 I 100 - mm LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 23.00 6.0% 781180 I Open .614 Water Base Muds 780 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 550 330 I I 285 I 1I1I1 8'101111 I 0 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 30 $11982 2013511 0 8000 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $57169 225126011 111/rr a III 780 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 7 BAROID 9.1111 e I 0 I no 1 bha III 9050 PERSONNEL TOTAL 43 TIME I EN,O, 12:00 AM 12:30 AM displace hole with new mud. 12:30 AM 02:30 AM 2.00 TRIP_OUT PROD Making Hole Pump pili. POH. 02:30 AM 03:30 AM 1.00 RIGS PROD Making Hole Cut and slip drlg line. 03:30 AM 04:30 AM 1.00 BHA PROD Making Hole MU and orient BHA. 04:30 AM 06:30 AM 2.00 TRIP_IN PROD Making Hole RIH. 06:30 AM 06:00 PM 11.50 DRll PROD Making Hole Drlg fl6367' to 8064'. ADT - 7.62 hrs Pump sweep every 200'. 06:00 PM 07:00 PM 1.00 CIRC PROD Making Hole CBU. Pump dry job. 07:00 PM 11:30 PM 4.50 PRB_TH PROD Making Hole POH to 7510. Started swabbing. Pump out of hole to 7355. Hole packed off. Unable to work pipe down or rotate. Work pipe free. (Had jar action) POH to shoe w/ 50k to 75k over up wt. Drill string free after bit reached shoe. 11:30 PM 12:00 AM 0.50 PRB_TH PROD Making Hole Circ and reciprocate pipe at shoe. 24.00 Supervisor: DONALD LUTRICK Daily Drilling Report: 1 E-36 11/01/98 Page 7 ~~ ~~ ARCa Alaska, Inc. I Date 10/31/98 Daily Drilling Report Well: 1E-36 Depth (MDfTVD) I Rig Accept - hrs 10/2619805:00:00 AM 6367/4008 Prey Depth MD: 6347 Days Since AccepUEst: 5.79/5.8 Rig Relase - hrs: AFC No. AK9165 Rpt No 6 Contractor: PARKER Rig Name: RIG # 245 Operation At 0600: Drill 8 1/2" Hole Upcoming Operations: Drill Daily Cost $ 85685 last Csg: 9-5/8" @ 6330' Cum Cost $ 765444 Next Csg: 7" @ 11677' Progress: 20 Est Cost To Date $ Shoe Test: N/A MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRlll LSND 2RR N TST 10/22198 10/31/98 WEIGHT ROTwr SIZE SIZE EMPLOYER LAST H2S DRill LAST FIRE DRill 8.4ppg 8.5 1 0/27/98 10/17/98 VISCOSITY puwr MAKE MAKE SPill LAST CONFINED lAST SPill DRill 38sqc STC N SPACE 09/16/98 10/13/98 PVIYP sowr TYPE TYPE TYPE FUEL & WATER 6/6 FDSS+2 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1827 3/41 LS87 40 APIWL MAX DRAG DEPTH OUT DEPTH OUT lAST SAFETY MTG DRill WATER USED - 2500 15.6 10/30/98 BBlS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 mll30 min INJECTION USED - BBlS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WEll WEATHER & 1.0% 1R.18D PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WEll TEMP of 7 431bbl III I I 1E-36 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 0 5.0 112131 - ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 0° 9.0 6 I 5.5 I 5.5 I lGS SPM 1 TFA TFA INJECTION FLUIDS CHill FACTOR of 7.00 1.0% III Open Water Base Muds 2180 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 1 595 III 111I1 I11II ° ° DAilY MUD SPS 1 BIT COST BIT COST CONTRACTOR 30 $8310 III 0 ° PERSONNEL ° TOTAL MUD SPP 1 DUll DUll TOTAL VOL (bbl) MISC PERSONNEL 5 $45187 III III III 2180 COMPANY MUDwr GRADE GRADE TOT FOR WEll (bbl) SERVICE 6 BAROID III III III 8270 PERSONNEL TOTAL 42 'TIME I END HOURS I QRS\CQDE I HQL:E;,SECT F1HASEQpS I, OPERATlONS FROMOQQO" OO,OQ 12:00 AM 01 :00 AM 1.00 BOPE PROD Other Test BOPE to 300 - 3000 psi. Witness of test waived by AOGCC rep John Spalding. 01 :00 AM 02:00 AM 1.00 OTHER PROD Other RD test equip. Set wear bushing. 02:00 AM 03:00 AM 1.00 BHA PROD Other MU BHA 03:00 AM 04:30 AM 1.50 TRIP_IN PROD Other PU and RIH wI 5" DP. 04:30 AM 09:00 AM 4.50 CLN_OUT PROD Other CBU. Test csg to 2000 psi. Drill out stage tool and cement. Test csg to 2000 psi. 09:00 AM 11:00 AM 2.00 TRIP_IN PROD Other PU and RIH wI DP. 11:00 AM 12:00 PM 1.00 CIRC PROD Other Circ out thick mud. 12:00 PM 12:30 PM 0.50 RIGS PROD Other Service top drive. 12:30 PM 01 :00 PM 0.50 TRIP_IN PROD Other RIH to TOC at 6067'. 01 :00 PM 02:30 PM 1.50 CLN_OUT PROD Other Drill out cement to 6209'. CBU. 02:30 PM 04:00 PM 1.50 CASG PROD Other RU test equip. Test csg to 3000 psi I 30 mins. 04:00 PM 09:00 PM 5.00 CLN_OUT PROD Other Drill out cement FE and 20' new formation to 6367'. 09:00 PM 09:30 PM 0.50 CIRC PROD Other CBU 09:30 PM 10:30 PM 1.00 CASG PROD Other Peñ LOT. 3995' TVD + 8.8 mud + 1062 psi = 13.9 EMW. 10:30 PM 12:00 AM 1.50 CIRC PROD Other Displace hole wI 90 bbl spacer and new mud. 24.00 Supervisor: DONALD LUTRICK Daily Drilling Report: 1 E-36 10/31/98 Page 6 ~~ ~" ARCa Alaska, Inc. Well: 1 E.36 Depth (MDfTVD) I Rig Accept. hrs 10/26/9805:00:00 AM 6347/4001 Prey Depth MD: 6347 Cum Cost $ 679759 Next Csg: 7" @ 11677' AFC No. AK9165 Date 10/30/98 RptNo 5 Contractor: PARKER Daily Cost $ 261379 Rig Name: RIG # 245 Last Csg: 9.5/8" @ 6330' Operation At 0600: Drill out stage tool Upcoming Operations: Drill FE and lOT MUD DATA DRilLING DATA BIT DATA MUD TYPE DEPTH BIT NO. BIT NO. SPUD WEIGHT ROTWT SIZE SIZE 9.6ppg VISCOSITY PUWT MAKE MAKE 60sqc PVIYP SOWT TYPE TYPE 19/22 GELS AVG DRAG SERIAL NO SERIAL NO 13/67/ APIWL MAX DRAG DEPTH OUT DEPTH OUT 4.8 HTHP WL TRQ BTM DEPTH IN DEPTH IN ml/30 min SOLIDS TRQ OFF FOOTAGE FOOTAGE 9.5% HOLE VOLUME PUMP PRES ADT/AST ADTlAST 481bbl III / / MBT PUMP NO WOB2 WOB2 27.5 112131 ph LINER SZ RPM 1 RPM 1 8.1 6 I 5.5 I 5.5 I LGS SPM 1 TFA TFA 9.5% III PIT VOL GPM2 JETS JETS 125 III 11111 11111 DAILY MUD SPS 1 BIT COST BIT COST $1164 III TOTAL MUD SPP 1 DULL DULL $36877 III III III COMPANY MUD WT GRADE GRADE BAROID III III III TIME I END HOURS I OPSCODE' I 'HOLESEpr 12:00 AM 12:30 AM 0.50 BHA SURF 12:30 AM 02:00 AM 1.50 CASG SURF 02:00 AM 12:00 PM 10.00 CASG SURF 12:00 PM 01 :30 PM 1.50 CIRC SURF 01 :30 PM 04:00 PM 2.50 CEMENT SURF 04:00 PM 05:00 PM 1.00 CIRC SURF 05:00 PM 06:30 PM 1.50 CEMENT SURF 06:30 PM 07:30 PM 1.00 OTHER SURF 07:30 PM 08:30 PM 1.00 NU_ND SURF 08:30 PM 09:00 PM 0.50 CASG SURF 09:00 PM 11:00 PM 2.00 NU_ND PROD 11:00 PM 12:00 AM 1.00 BOPE PROD 24.00 Daily Drilling Report: 1 E-36 10/30/98 Days Since AccepUEst: 4.79/4.6 EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG . 10/30/98 IN"ECTlON INJECTION WEll 1R-18D SOURCE WELL 1E-36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 1160 0 0 0 0 TOTAL VOL (bbl) 1160 TOT FOR WEll (bbl) 6090 Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date $ Shoe Test: N/A DRillS/BOP DATA LAST BOP/DIVERT LAST BOPIDRILL TST 10/22/98 10/26/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 10/13/98 LAST FIRE DRILL 10117/98 LAST SPILL DRilL 09116/98 FUEL &WATER FUEL USED 1843 DRilL WATER USED- BBlS POTABLE WATER USED - BBLS 2000 100 WEATHER& PERSONNEL DATA 21 WIND SPEED 5 WIND DIRECTION 45° CHILL FACTOR of 17.46 ARCO PERSONNEL CONTRACTOR PERSONNEL 30 MISC PERSONNEL 5 SERVICE PERSONNEL 8 TOTAL I OPERATlaNSFROMPPOQ"QOPO Finish lD BHA RU to run 9 5/8" csg. Held prejob safety meeting. I pHASE,qps Making Hole Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing 44 RIH w/9 5/8" csg. Circ 1 csg volume at 2000' and 3900'. MU hanger and land csg at 6330'. Circ and condition mud @ 10 bpm. Total - 870 bbls, Test lines to 3500 psi. Pump 20 bbla wash, 40 bbls spacer, 130 bbls 10.5 lead, 175 bbls 15.8 tail cement and displaced w/ rig pumps. Bumped plug. load top plug. Open stage tool w/ 2990 psi. Circ out cement contaminated mud. Condition mud for stage 2. Pump 30 bbls FW and 349 bbls 10.5 cement. Pump 10 bbls tail. Displaced with rig pumps. Closed stage tool at 1300 psI. Approx 100 bbls 10.5 cement to suñace. Flush out diverter. RU floor. ND diverter. MU FMC Gen IV csg head. Torque to 12000 ft Ibs. NU BOPE. RU BOP test equipment. Page 4 II i~ A8~ ~" ARCO Alaska, Inc. Daily Drilling Report Contractor: PARKER Rig Name: RIG # 245 Operation At 0600: RIH w/9 5/8" csg Upcoming Operations: Cement csg Depth (MDITVD) Daily Cost $ 85020 Last Csg: 16" @ 121' I Rig Accept - hrs 10/26/9805:00:00 AM 6347/4001 Pre... Depth MD: 5400 Cum Cost $ 418380 Next Csg: 9-5/8" @ 6279' Days Since AccepUEst: 3.79/3.5 Rig Relase - hrs: AFC No. AK9165 I Date 1 0/29/98 RptNo 4 Well: 1E..J6 Progress: 947 Est Cost To Date $ 450000 Shoe Test: N/A MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOPIDRILL SPUD 6347 1 TST 10/22/98 1 0/26/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 155k 12-1/4" 10/27/98 10/17/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 66sqc 190k STC SPACE 09/16/98 1 0/13/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 26 / 29 140k MA 1 SL GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1873 10/40 / 10k LS6953 API WI.. MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1500 3.4 10k 10/29/98 BBLS HTHP WI.. TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 ml/30 min 10k 121 INJEC:r/QN USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEA THE.R& 11.0% 6226 1R-18D PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 14 935bbl 2600 III 36.61/19.45 / 1E.36 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 0 30.0 112131 30 - 50 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION O. 8.2 6 I 5.5 I 5.5 I 70 - mm LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 14.00 11.0% 7818511 0.422 Water Base Muds 1450 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 1 581 331 13031 I 10 1151151 I I 11III 0 0 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 30 $7626 III 14,636 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $35714 III 2121rg g III 1450 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 8 BAROID III e I 3 I no I td III 4930 PERSONNEL TOTAL 44 . TIME I, END HOURS I OPSCQDE' I HOLESECT 'lpI::IA§~QRS' I OPI;RADoNsEROM,OQOQ+.OQQQ 12:00 AM 08:30 AM 8.50 DRIL SURF Making Hole Drlg f/5400' to 6347'. ADT 7.16 hrs 08:30 AM 10:30 AM 2.00 CIRC SURF Making Hole Circ and condition mud. 10:30 AM 01 :30 PM 3.00 WIPERTRP SURF Making Hole POH to drill collars. 01 :30 PM 02:00 PM 0.50 RIGS SURF Making Hole Lube rig and service top drive. 02:00 PM 04:30 PM 2.50 WIPERTRP SURF Making Hole RIH to TD. No problems. 04:30 PM 07:00 PM 2.50 CIRC SURF Making Hole Circ and condition mud for csg. 07:00 PM 09:30 PM 2.50 TRIP_OUT SURF Making Hole POH. 09:30 PM 12:00 AM 2.50 BHA SURF Making Hole LD BHA. Download Sperry Sun. 24.00 Supervisor: DONALD LUTRICK Daily Drilling Report: 1 E-36 10/29/98 Page 3 ...... ~" ARGO Alaska, Inc. AFC No. AK9165 Well: 1 E-36 I Date 10/28/98 Contractor. PARKER Rig Name: RIG # 245 Operation At 0600: Dr1g at 6120' Upcoming Operations: TD at 6310'. Wiper trip. Run csg. Depth (MDfTVD) Daily Cost $ 96687 Last Csg: 16" @ 121' I Rig Accept - hrs 10/26/9805:00:00 AM 5400/3665 Prev Depth MD: 3227 Cum Cost $ 333360 Next Csg: 9-5/8" @ 6279' MUD DATA MUD TYPE SPUD WEIGHT 9.8ppg VISCOSITY 83sqc PVIYP 30/34 GELS 13/58/ APIWl 4.2 HTHP Wl ml/30 min SOLIDS 11.0% HOLE VOLUME 459bbl MBT 27.5 ph 8.1 LGS 11.0% PIT VOL 553 DAILY MUD $12837 DRILLING DATA DEPTH 4438 ROTWT 160k PUWT 185k SOWT 130k AVG DRAG 10k MAX DRAG 10k TRQ BTM 10k TRQ OFF 8k PUMP PRES 2450 III PUMP NO 112131 LINER SZ 6 I 5.5 I 5.5 I SPM 1 7818511 GPM2 331 13031 I SPS 1 III RptNo 3 BIT NO. 1 SIZE 12-1/4" MAKE STC TYPE MA1SL SERIAL NO LS6953 DEPTH OUT DEPTH IN 121 FOOTAGE 5279 ADT/AST 29.15/17.79 WOB2 30 - 50 RPM 1 70-mm TFA 0.422 JETS 10115115 I II BIT COST 14,636 BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 TFA JETS III1I BIT COST TOTAL MUD SPP 1 DULL DULL $28088 III III III COMPANY MUD WT GRADE GRADE BAROID III III III TIME I ,'END, HOURS I QPS'CODE ,I HOLESEGT 12:00 AM 12:30 AM 0.50 WIPERTRP SURF 12:30 AM 01 :00 AM 0.50 CIRC SURF 01:00 AM 08:00 PM 19.00 DRIL SURF 08:00 PM 08:30 PM 0.50 PRB_EFC SURF 08:30 PM 12:00 AM 3.50 DRIL SURF 24.00 Daily Drilling Report: 1 E-36 10/28/98 Days Since AccepVEst: 2.79/2.9 EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG 10/28/98 INJECTION INJECTION WELL 1R-18D SOURCE WELL 1 E-36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 1160 0 0 0 0 TOTAL VOL (bbl) 1160 TOT FOR WELL (bbl) 3480 IPI;tASEOPS Making Hole Making Hole Making Hole Making Hole Making Hole Daily Drilling Report Rig Relase - hrs: Progress: 2173 Est Cost To Date $ 350000 Shoe Test: N/A DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 10/22/98 10/26/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 1 0/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 FUEL & WATER FUEL USED DRILL WATER USED- BBLS POTABLE WATER USED - BBLS WEATHER& PERSONN,EL DATA WIND SPEED WIND DIRECTION CHILL FACTOR of ARCO PERSONNEL CONTRACTOR PERSONNEL MISC PERSONNEL SERVICE PERSONNEL TOTAL I ' OPERATIONS F80M 0000 ,+POOQ , Finish RIH. No problems. CBU Dr1g f/3227' to 5125'. ADT -11.93 hrs. Replace boot in flowline. Dr1g f/5125' to 5400'. ADT - 2.09 hrs. 2062 1000 100 16 4 45° 16.00 32 7 45 Supervisor: DONALD LUTRICK Page 2 ~, A8~ ~~ ARCO Alaska, Inc. AFC No. AK9165 Well: 1E-36 I Date 10/27/98 Contractor: PARKER Rig Name: RIG # 245 Operation At 0600: Drig Upcoming Operations: TD Surface Hole MUD DATA MUD TYPE SPUD WEIGHT 9.5ppg VISCOSITY 120sqc PVIYP 31/46 GELS 16/38/ APIWL 6.5 HTHP WL ml130 min SOLIDS 8.5% HOLE VOLUME 454bbl MBT 22.5 ph 8.7 LGS 8.1% PIT VOL 520 DAILY MUD $10702 DRILLING DATA DEPTH 3227 ROT WT 150k PUWT 175k SOWT 130k AVG DRAG 5k MAX DRAG 5k TRQ BTM 6k TRQ OFF PUMP PRES 2300 III PUMP NO 112131 LINER SZ 6 15.5 I 5.51 SPM 1 7517511 GPM2 3181270 I I SPS 1 III Depth (MDfTVD) Daily Cost $ 88014 Last Csg: 16" @ 121' I Rig Accept - hrs 10/26/9805:00:00 AM 3227/2588 Prey Depth MD: 454 Cum Cost $ 236673 Next Csg: 9-518" @ 6279' RptNo 2 BIT NO. 1 SIZE 12-1/4" MAKE STC TYPE MA1SL SERIAL NO LS6953 DEPTH OUT DEPTH IN 121 FOOTAGE 3106 ADT/AST 15.57/11.13 WOB2 30 - 50 RPM 1 70 - mm TFA 0.422 JETS 101151151 I I BIT COST 14,636 BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 TFA JETS 11111 BIT COST TOTAL MUD SPP 1 DULL DULL $15251 III III III . COMPANY MUDWT GRADE GRADE BAROID III III III ,TIME, , I ' E;NP , HOURS' I ORSCODE I HQLE;sE;C;r 12:00 AM 09:30 PM 21.50 DRIL SURF 09:30 PM 10:00 PM 0.50 CIRC SURF 10:00 PM 11:00 PM 1.00 WIPERTRP SURF 11:00 PM 12:00 AM 1.00 WIPERTRP SURF 24.00 Daily Drilling Report: 1 E-36 10/27/98 Days Since AccepUEst: 1.79/1.8 EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG INJECTION INJECTION WELL 1R-18D SOURCE WELL 1E-36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 2030 0 0 0 0 TOTAL VOL (bbl) 2030 TOT FOR WELL (bbl) 2320 (" Daily Drilling Report Rig Relase - hrs: Progress: 2773 Est Cost To Date $ 250000 Shoe Test: N/A DRILLS/BOP DATA LAST BOPIDIVERT LAST BOP/DRILL TST 10/22/98 10/26/98 LAST H2S DRILL 10/27/98 LAST CONFINED SPACE 1 0/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 FUEL & WATER FUEL USED DRILL WATER USED - BBLS POTABLE WATER USED - BBLS WEATHER & PERSONNEL DATA TEMP of WIND SPEED WIND DIRECTION CHILL FACTOR of ARCO PERSONNEL CONTRACTOR PERSONNEL MISC PERSONNEL SERVICE PERSONNEL 1.8.!cIAS.E;PPS, Making Hole Making Hole Making Hole Making Hole TOTAL I QpE;BATlONSRROMQQQQ+QQOQ Drig f/454' to 1927', ADT -12.72 hrs CBU POH to HWDP. Tight at 1715' - 1690' -1180'. RIH. No problems. 1659 1750 100 6 0 O. 6.00 31 5 7 44 Supervisor: DONALD LUTRICK Page 1 ...... ~" ARCa Alaska, Inc. IDate 10/26/98 AFC No. AK 9165 Well: 1E-36 Contractor: PARKER Rig Name: RIG fI. 245 Operation At 0600: Drilling @ 1179' Upcoming Operations: Drill 12-1/4" Surface Hole MUD DATA MUD TYPE SPUD WEIGHT 8.7ppg VISCOSITY 165sqc PVNP 16 I 47 GELS 39 142 I APIWL 12.0 HTHP WL ml/30 min SOLIDS 3.0% HOLE VOLUME 59bbl MBT 15.0 ph 10.5 LGS 3.0% PIT VOL 585 DAIL Y MUD $4549 TOTAL MUD $4549 COMPANY BAROID BHA DESCRIPTION BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: TIME I END 00:00 05:00 DRILLING DATA DEPTH 454 ROT WT 115 PUWT 120 SOWT 110 AVG DRAG MAX DRAG TRQ BTM 2000 TRQ OFF PUMP PRES 1500 III PUMP NO 112131 LINER SZ 6 I 5.5 I 5.5 I SPM 1 6816811 GPM2 531111 SPS 1 III SPP 1 III MUD WT III RptNo 1 Depth (MDm/D) Daily Cost $148659 Last Csg: 16" @ 121' BIT NO. 1 SIZE 12-1/4" MAKE STC TYPE MA1SL SERIAL NO LS6953 DEPTH OUT DEPTH IN 121 FOOTAGE 333 ADTIAST 2.6/1.17 WOB2 5 -10 RPM 1 70 - 135 TFA 0.422 JETS 101151151 I 1 BIT COST 14,636 DULL III GRADE III I Rig Accept - hrs 10/26/9805:00:00 454/454 Prev Depth MD: 121 BIT DATA BIT NO. SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOl:AGE ADTIAST I WOB2 RPM 1 TFA JETS 11111 BIT COST DULL III GRADE III ,{ 'I Daily Drilling Report Days Since AccepUEsl: 0.79/0.7 Cum Cost $ 148659 Next Csg: 9-5/8" @ 6279' EH&S INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG INJECTION INJECTION WELL 1R-18D SOURCE WELL 1 E.36 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS Water Base Muds 290 0 0 0 0 TOTAL VOL (bbl) 290 TOT FOR WELL (bbl) 290 Rig Relase - hrs: Progress: 333 Est Cost To Date $110000 Shoe Test: DRILLS/BOP DATA LAST BOPIDIVERT LAST BOP/DRILL TST 10122/98 10/26/98 LAST H2S DRILL 06/08/98 LAST CONFINED SPACE 10/13/98 LAST FIRE DRILL 10/17/98 LAST SPILL DRILL 09/16/98 FUEL & WATER FUEL USED 2198 1 454 00 5" 5" ID 4.276" 3" WEIGHT 19.50# 49.30# HOLE SECT ,I PHASFOPS MOVE Other 05:00 08:00 3.00 NU_ND SURF Other 08:00 14:30 6.50 PREP SURF Other 14:30 15:00 0.50 BOPE SURF Other 15:00 16:00 1.00 BHA SURF Other 16:00 17:30 1.50 BHA SURF Other 17:30 19:30 2.00 DRIL SURF Making Hole 19:30 20:00 0.50 RIGS SURF Making Hole 20:00 20:30 0.50 PRB_MISC SURF Making Hole 20:30 00:00 3.50 DRIL SURF Making Hole 24,00 Daily Drilling Report: 1 E-36 10/26/98 DRILL WATER USED - BBLS POTABLE WATER USED - BBLS 2250 100 WEATHER & PERSONNEL DATA TEMP of 16 WIND SPEED 7 WIND DIRECTION 225° CHILL FACTOR of 5.92 ARCO PERSONNEL CONTRACTOR PERSONNEL 30 MISC PERSONNEL SERVICE PERSONNEL TOTAL 43 I BHA #1: Bit #1 + Navidrill Mach 1 (1.30' AKO) + NM Stab + NMDC + NM Stab + XO + MWD + FS + UBHO Sub + 3 NMDC + 3 SDC + XO + 4 HWDP + Jars (#0484 UJ) + 25 HWDP DRJLLPIPEDATA GRAD,e CONNECTIQN G 4-1/2 IF HWDP 4.1/2 IF HOURS 5.00 34 \ OPS CODE MIRU CLASS 2 Premium Premium 29 jts I OPERA nONSFRQM .oOOQ-.OOOO Jack up Utility Module, back up, turn & move down pad. PU stomper, jack up Drilling Module, back up, turn, & move down pad past UM. Set DM on 1E.36. Move UM & mate up to DM. Rotated rig 180' & moved 990' North to other side of pad, from 1 E.35 to 1 E-36. Accept rig. Accepted Rig @ 0500 hrs, 10/26/98 NU Diverter system. Skid rig 2" to DW side. PU & stand back 210 jts of 5" DP, 29 jts HWDP & Jars, 6 DCs. Function test Diverter system. Test accumulator. Witnessing of test waived by Chuck Scheve, AOGCC Field Inspector. PU Sperry Sun MWD & program tool. PU BHA & orient motor & MWD. Spud in &,drill from 121' to 187'. Gyro survey. (1.00 ADT) Service rig. Replace Disc Flow pump. Drill to 454' & drilling ahead. Gyro survey as needed. (1.60 ADT) Page 1 I~ { CASING I TUBING I LINER DETAIL Tubinq or Csg Description ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 277 jts 2 jts Remarks: Parker Rig #245 - RKB to Tbg Head Parker Rig #245 - RKB to Casing Head 7" 26# L-80 BTC-Mod Csg Gemoco Float Collar 7" 26# L-80 BTC-Mod Csg Gemoco Float Shoe Run Total of 279 Jts Centralizers Run 1 Bow Spring I Jt 1 st 20 Jts (Stop Ring on #1 & 3) Total of 20 Bow Springs Run 18 Centering Guides - See Tally Parker Rig #245 Drilling Supervisor: Lutrick / Putnam WELL: 1 E-36 DATE: 11/5/98 1 OF 1 PAGES LENGTH DEPTH TOPS 36.02 38.28 11472.02 38.28 1.29 11510.30 83.94 11511.59 1.47 11595.53 11597.00 ( At.... ...." ARCO Alaska, Inc. I Well Name: 1 E-36 Rig Name: RIG f 245 Report Date: 11/06/98 AFC No.: AK 9165 Cementing Details \ Report Number: 12 Field: Kuparuk Casing Size r Hole Diameter: 81/2" Angle thru KRU: 55 Deg At the Shoe Shoe Depth: 11597' LC Depth: 11512' % washout: Centralizers Comments: State type used, intervals covered and spacing 1 Bow Spring per jt for the 1st 20 jts. Ran standoff bands every 3rd jt f/ KOP to 2300' (18 total) Mud Comments: LSND Weight: 9.7/9.7 PV(prior cond): 17 PV(after cond): 19 YP(prior cond): 13 YP(after cond): 14 Gels before: 517 Gels after: 517 Total Volume Circulated: 510 bbls at 6 bpm Volume: . Wash Comments: 0 Type: ARCO Wash 20 Weight: 8.4 Spacer Comments: 0 Type: ARCO Volume: 40 Weight: 12.0 Lead Cement 0 Comments: Type: Mix wtr temp: No. of Sacks: Weight: Yield: Additives: Tail Cement 0 Comments: Type: G Mix wtr temp: 75 No. of Sacks: 170 Weight: 15.8 Yield: 1.16 Displacement 0 Comments: Additives: G + .2% D46 + .15% D65 + .23% D800 Rate(before tail at shoe): 6 Rate(tail around shoe): 6 Str. Wt. Up: 245k Str. Wt. Down: 65k Reciprocation length: 15 Reciprocation speed: 10 fpm Actual Displacement: 439 Str. Wt. in mud: Theoretical Displacement: 440 Calculated top of cement: 10797 CP: Date: 11/6/98 I Time:01:30 hrs Remarks:No mud loss to formation while RIH. Circ and condition mud with no problems. Pumped spacers, cement and displaced with mud. Had 100% retums. No flow back from annulus after bump plug. Bumped plug: yes Floats held: yes I Cement Company: DS I Rig Contractor: PARKER APproved By: Donald Lutrick Drming Supervisor: I Nick Scales Ipump used: I Other - see comments; ';¡¡;> ¡ Barrels Type of ~est: 1 Annulus Leak ~ffTest for Disposal Adequacy 1...1 Pumping down 1 annulus. ... Hole Size: ! Other - See comment~. Casing Shoe Depth Hole Depth RKB-CHF: 1Ft 6,367 IFt-MDI 3,995 Ft-TVD IFt-MD I Casinq Size and Description: 9-5/8" 4O#/Ft L-80 BTC Chanqes for Annular AdeQuacy Test )uter casing shoe test results 6.8 in comments Description references outer 8.8 casing string. ;ize is that drilled below outer 6,367 casing. ;timated TOe for Hole Depth. Enter inner casing 00 at right We!! Name: 1 E-36 I R:,...I ~ E~!~" ~ 7 2000. L1J c::: ::::> ~ 1000. L1J c::: c.. 1 500 - PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. I Date: I 5/8/2004 I Ft-TVD 1.1 Pressure InteqrityTest Mud Weight: 6.8 ppg Inner casing OD: 7.0 In. 16.0 ppg 1911 psi #REF! PIT 15 Second Shut-in Pressure, psi 1250 .., ~\~"\~g~.~ -'c.f?k{tJ---:- '/).\'#:A~,\/)"iA~ ..Vtê~~ ro..\~~~ ~ \~I).. ~ 500. 0 0 3 Barrels 4 "'-CASING TEST ~LEAK-OFF TEST Hot Oil Pump Unit for LOT Comments: 9-5/8" x 7" annulus. 6 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point I Volume Input Pump Rate: ..... Bbls/Strk ... Bbl/min ... ... Casing Test Pumping Shut-in Bbls psi Min psi 0 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Desired PIT EMW: Estimates for Test: Steel Volume During Casing Test = 0 bbl ! ...1 Inner String Displacement = 0 bbl EMW = Leak-off Pressure + Mud Weight = 1525 + 6 8 0.052 x TVD . 0.052 x 3995 . EMW at 6367 Ft-MD (3995 Ft-TVD) = 14.1 30 Volume Pumped 0.0 tSbls Volume Bled Back I tSbls Pressure Integrity Test Pumping Shut-in Bbls psi Mín psi 0.25 300 1 1275 0.5 440 2 1250 0.75 580 3 1225 1 720 4 1200 ~" 1.25 860 5 1190 1.5 975 6 1175 1.75 1125 7 1150' 2 1300 8 1130 2.25 1425 9 1110 2.5 1550 10 1100 2.75 1700 0 3 1675 0 3.25 1650 0 3.5 1525 0 3.75 1450 0 4 1375 0 4.25 1350 0 4.5 1325 0 4.75 1310 0 5 1310 0 0 0 .-. Volume Pumped 5.0 tSbls Voume Bled Back I tSbls RIG #: I DISPOSING INTO ANNULUS OF WELL: I ORIGIN OF FLUIDS PUMP RATE START TIME END TIME (BPM) rlÛHT DlSPOSAL SUPERVlSOR: ,,--_...-.......... ..... STATIC PRESSURE (PSI) CPAI - DAIL V ANNULAR DISPOSAL RECORD Page- 0'- DA TE: 5/8/2004 0000 HRS TO 0000 HRS 1 E-36 BARRELS DISPOSED (List under proper fluid type) FOR MUD ONLY: DISPOSAL PRESSURE (PSI) Operation that generated Waste Mud WATER for DIESEL for Flushing Freeze Annulus Protecting OTHER (specify in comments) TOTAL CUMULATIVE VOLUME Rig Wash Water WEIGHT (PPG) FUNNEL VISCOSITY Mud COMMENTS ~~ 300 Completed 10/26/98 Rig 75 370 20 Diesel used for LOT 05/08/04 20 ~~ MUD Total for Today Cummulative Total from WATER DlESEL WASH WATER OTHER Previous Day New Total for this Annulus I I I 395 GEL Q-GEL X-TND BICARB PH 6 TOTAL VOLUMES FOR DA Y: I ADDITIVES USED: NIGHTS DAYS IDA Y DlSPOSAL SUPERVlSOR: rPAI SUPERVISOR: Nick Scales r""IAI r""\AII " A""I~IIII Ar-t n,llï,.....-rII""\fl.1 nïr"l"r"\nn ~(,(,"ITT n ~l=vt.Jnl n~ 1 ?-?n-n1 Weatherford Gemoco 9-5/S" DV Stage Collar Stnd. Grade BTC Threads (set +1- 200 TVD below permafrost) Surface csg. 95/8" 40# L-80 BTC (+1- 6279' MD I 3999' TVD) All depths reference Parker 245 RKB 4-1/2" Liner Top: 200' above 7" shoe (+/- 11477' MD I SSS9' TVD) Intermediate csg. 7" 26# L-SO BTC-Mod set above KUP, run to surface (+1- 11677' MD I 5996' TVD) Liner 4-1/2" 12.6# L-SO NSCT (+1- 12091' MD 16233' TVD) ( KRU 1 E-36 Producer Completion 6-1/8" Hole / 4-1/2" Liner Option U~ ~ ~ ~ ~ ~ ::í ::í ::í ::í ~ ~ ~ ::í .'" ~ ::í ~ ~ ::í ::í ::í ::í ~ ~ ::í ~ ::í ..""',. ~ ~ ::í ~ ~ ::í ~ ::í ~ ::í ::í ::í ¡p'.'."","', ~ : ::í ~ ~ ~ ::í ~ ::í ::í ::í ~ ::í ~ ~ ~ ::í ~ ~ ~ ~ ~ ~ ~ ~ ::í ::í ..',"', ' ~ , ~ :~ ~ ~~ ~ ~ ~ ::í ~ ~ ::í ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ::í ~ ~ ::í ~ :;: ::í ~ ~ :;: :;: :;: ::í ::í ::í ~ ::í ::í ::í ::í ::í ~ ~" ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ :;: :::: ::í ~ ~ :;: ::í ::í ::í ~ ~ ~ ¡:; ¡:: ¡::: ;::: ~ ~ ;::: ;::: :;: ;::: ;::: ;::: ;::: ;::: ;::: ;::: ;::: ¡:; :;: ;::: ;::: ;::: :;: ;::: ~ :;: :;: ;::: ;::: ~ ;::: ~ ;::: ;::: ;::: ~ ;::: ~ ~ ;::: ~ ~ ;::: ~ ;::: ~ ;::: ::í ~ ~ ;::: :;: ~ ~ ~ ~ :;: ~ ~ ;::: :;: ;::: ;::: ~ ;::: ;::: ;::: ;::: ~ ;::: ;::: ;::: ;::: ;::: ~ ;::: ~ ~ ~ ;::: ~ ~ ~ ;::: ;::: ;::: ~ ;::: ;::: ;::: :::: ~ ;::: ;::: :::: :::: :::: ;::: :::: ::í ::í ¡;, 7- ~ ;:::- ;::: ;::: ::í ::í ~ ~ ... ----=...... ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ I. 3-1/2" SM FMC Gen IV tubing hanger with 3-1/2" L-SO EUE BRD-Mod pin down H. 3-1/2" 9.3# L-80 EUE SRD-Mod tubing to surface G. 3-1/2" Camco 5M TRDp.4E SSSV, EUE 8RD-Mod, 3-1/2" x 6' pups installed above & below, EUE 8RD-Mod. Control line and bands. set at +1- 1800' MD F. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to SSSV wi 3-1/2"x 1" Camco 'KBMM' mandrels wi DV's & BK latches, EUE 8RD-Mod connections, 3- 112" x 6' pups installed L-BO EUE BRD-Mod. Spaced out as follows: G.I.MJt TVD-RKB MD-RKB TBD TBD TBD E. 3-1/2" x 1-1/2" Camco 'MMM' mandrel wi DV & RK latch, 3-1/2" x 6' pups installed, L-80 EUE BRD-Mod D. 1 it 3-1/2" L-BO EUE 8RD-Mod tubing C. 3.1/2" Camco "D" landing nipple wi 2.75" ID, NoGo profile, EUE 8RD- Mod,3 1/2" x 6' pups on either side B. 1 jt 3-1/2" L-80 EUE BRD-Mod tubing A. Baker 3-1/2" 'GBH-22' Seal Assembly wi 10' of seals and special locator to locate in liner tieback sleeve. Locator 5.125" OD. seals 4,0" 10. 3-1/2" x 6' L-BO handling pup installed on top. XO EUE 8RD to NSCT « Liner Assembly (run on drillpipe): .. Baker 'C-2' tieback sleeve with locator, 6' -- Baker 5" x 7" 'ZXP' Liner Top Isolation Packer u Baker 5" x 7" 'HMC' Hydraulic Liner Hanger -- Baker 'BO-40' 10' Seal Bore Extension (4.0" ID seal bore), 4-1/2" NSCT pin dowr Future Perforations 4-1/2" NSCT landing collar/FS/FC SG, 10/8198. v.1 f NOTE TO FILE 1 E-36...198-213...304-213 Request for Annular Disposal Approval Summary This well was drilled in late 1998 and a disposal authorization was not requested at that time. ConocoPhillips (CPAI) is planning to drill up to 12 new West Sak wells from 1 E pad and desires to use the annulus of this well. This document analyzes the information submitted by CPAI and recommends denying their request. Offset Weill nformation There are 5 wells within % mile of 1 E-36's surface casing shoe. The surface casing of 1 E-36 was set below the West Sak. Any Kuparuk pool well with a number of 31 or more had it's surface casing similarly set below the West Sak. Of the 5 wells with % mile, 4 did not have surface casing set through the West Sak. At the surface casing depth of 1 E-36 (4000' tvd) wells 1 E-28 is approximately 500' NE and 1 E- 04 is approximately 350' due south. According to the plotted well trajectories on the spider plot, 1 E-28 crosses under 1 E-36 and diverges away with the closest approach being the 500' distance mentioned earlier. In contrast, 1 E-04 lies above 1 E-36 and converges with it as depths increase. Where the wellbores cross 1 E-04 is about 200' above 1 E-36. Neither 1 E-28 nor 1 E- 04 was cemented across the holes sections immediately proximate to 1 E-36. Well 1 E-36 Information The surface casing was run and successfully cemented to surface in 2 stages. Cement was circulated off the stage tool. Prior to pumping the 2nd stage cement, it is noted that contaminated mud was circulated from the well. 100 bbls of cement was circulated on the 2nd stage. The casing was successfully pressure tested prior to drilling out hard cement. The formation below the shoe was tested to 13.9 EMW, however it is not clear if the pressure held or fluid was pumped into the formation. CPAI has recently performed an injectivity test down the OA. In this most recent test, steady pump in occurs at about 13.1 EMW. After shut down, the pressure exhibits a steady decline and appears to be nearing stabilization around 12.1 EMW. If half water, half diesel is used as the fluid column; the EMWs are about 1 ppg higher. It is indicated that the surface casing of 1 E-36 is satisfactorily cemented. The well was drilled to the top of the Kuparuk reservoir and 7" casing string was set and cemented without problems. On drillout, the formation was tested to 15.0 EMW without leakoff. It is indicated that the 7" casing is well cemented and that the Kuparuk sands are isolated. This well has not been reported as required by the sustained casing pressure order. Recommendation Although 1 E-36 appears to have been satisfactorily constructed for annular disposal, the wellbores most proximate to it are not cemented at the surface casing shoe depth of 1 E-36. Given the proximity to the casing shoe and the known absence of cement, confinement of any wastes to depth at or below the casing shoe of 1 E-36 cannot be assured. Based on the presented information, I recommend that ConocoPhillips' request for annular disposal in 1 E-36 (198-213) be denied. b~~\f0~ Sr. Petroleum Engineer G: \common \tommaunder\ Well Information \By Subj ect\Annular Disposal\040621- _198-213--KRU _1 E-36 _AD .doc FW: FW: Locked up injection well ( Subject: FW: FW: Locked up injection well From: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com> Date: Mon, 21 Jun 200407:19:45 -0800 To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> ( Here ya go. Steve -----Original Message----- From: Michaelson, Bill G [mailto:William.Michaelson@bakerhughes.com] Sent: Thursday, June 17, 2004 4:18 PM -- To: Shultz, Steven M Cc: Hnatiuk, Owen J. Subject: RE: FW: Locked up injection well Oops I forgot to attach it. Here it is now. b Bill Michaelson Baker Hughes INTEQ office: 267-6624 cell: 301-3570 -----Original Message----- From: Shultz, Steven M [maiJ..to:Steven.M.Sh.uJ..tz@conocophi,11ips.com] Sent: Thursday, June 17, 2004 3:50 PM To: Michaelson, Bill G Subject: FW: FW: Locked up injection well Bill, The state needs the spider plot a little more precise by showing trajectories of the wells and tick marks every hundred feet, 500' above the plane to 500' below. Is this possible? Steve -----Original Message----- From: Thomas Maunder [ma.::Llto: torn tTlaunde:t:,'@admin. state. ak. us] Sent: Thursday, June 17, 2004 2:04 PM To: Shultz, Steven M Subject: Re: FW: Locked up injection well Steve, Yes, this information was in the application. The horizontal distance at the shoe depth is presented in this report. It would appear that the distance given for 28 is possibly the closest, but I think 4 may have a closer approach looking at the trajectory. Looking at the plot, I am curious how the tvds of 28, 4 and 36 relate withing the 1/4 mile. Is it possible to get a plot with tvd tick marks for the interval 3900 tvd to 4100 tvd?? My concern is similar to what we discussed on 1E-112 and that is that there are long sections of the production string fairly proximate to the 9-5/8" shoe of 36 that are not cemented. Call and we can discuss. Tom Shultz, Steven M wrote: 10f3 6/21/20044: 13 PM FW: FW: Locked up injection well Tom, I'm not sure if I sent this info over to you guys in the request or not. Steve -----Original Message----- From: Mi chae 1 son, Bill G [~9.:.~--~.~g..:._'?!._~_;h_!.L~~_}1i..~_h~~l:_§.?_~~.~<?:.~_~E!2~.gh.~~_:.._S;~~] Sent: Thursday, June 17, 2004 8:52 AM To: Shultz, Steven M Cc: Hnatiuk, Owen Subject: RE: Locked up injection well Steve: I found these files that were generated on 05/12/2004. One is a plot and one is the horizontal clearance report. They are for 1E-36 Will this do? b Bill Michaelson Baker Hughes INTEQ office: 267-6624 cell: 301-3570 -----Original Message----- From: Shultz, Steven M [mailto:Steven.M.Shultz@conocophillips.com] Sent: Wednesday, June 16, 2004 5:12 PM To: Michaelson, Bill G Subject: FW: Locked up injection well Bill, Can you help me out here? Thanks Steve -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, June 16, 2004 4:42 PM To: Shultz, Steven M Subject: Re: Locked up injection well Steve, You should have the approvals for annular disposal on 1E-33 and 1E-35. 1E-36 is going to be tough due to the proximity of #4 and #28? I looked for another email on lE-36 but only found my hand note saying I talked to you about how far away these wells are from 1E-36 in the plan at the surface casing shoe. Do you have those distances?? Tom Maunder, PE AOGCC Shultz, Steven M wrote: They are in the process of being reviewed by AOGCC. Steve 20f3 6/21/2004 4: 13 PM FW: FW: Locked up injection well -----Original Message----- From: Doyon 141 Company Man Sent: Monday, June 14, 2004 4:28 PM To: Shultz, Steven M Cc: Thomas, Randy L¡ NSK Fld Drlg Supv Subject: Locked up injection well A note for all to remember the 1E-34 well we were injecting into locked up on the end of this well. The pressure had always ran high from the first injection @ 1700 to 1750. It did clean up a little and the pressure went down to 1300 to 1500 psi depending on what was pumped. It finally pressured up so we had little red pump a 85 bbl freeze protect while we could. Other than 1E-33 are the other 2 wells ( 35 & 36) permitted. ?? Dearl Gladden Doyon 141 Company Man 907-659-7170 Content-Description: 1E36 lE36 AnnularInjectionPlot2.pdf Content-Type: application/octet-stream Content-Encoding: base64 30f3 6/21/20044:13 PM ..: ¡¡;';:¡:-F.Q---- ~ ,.. ' ConocoPhillips Alaska, Inc. Location: -NorthSlOpe. Alàska-. Field: Kuparuk River Unit Installation: Pad 1 E ConocÓPhillips --'------'---'--------- Slot: slot #36 Well: 36 Wellbore: 36 . -----------'Cìi,aled'bÿ-c-Plàrine,---- --- ._-, I Dolo ploned: '7 .,)un-2004 ¡ P'()\rere'rë'nëe1S~.'-"----'-' --. -~ ._-- I Ref wel1path is MWD <0. '2005')- I Coordinates are In feet reference slo1136. I TNe Vertical Depths are reference R9 Datum. I Measure-d Depths are reference Rig Datum. Rig Datum: Aclual Datum , Rig Datum 10 mean sea eve I: 113.00 n. , Plot North Is aligned 10 TRUE North, -2~ale.;~ch ~2;~O ft'2600 .2500 .2400 .2300 .2200 .2'00 .2000 -'900 .'800 .'700 .'600 E~~~(fe.~1Jo -> .'300 .'200 -"00 .'000 .900 -ðOO t.___1 _.L_L.....l...__L ,j---~-1_-._L __~.,,_L_;_~-L_._l.- &' <J-- ~ I / 3700 TVD / , , ,/ 3800 TVD , , 4100 TVD /\ 3800 TVD I / 1/' 4000 / . / 4100 TVD I . . . -- 3900 TVD " ' '41100 TVD ".' 4100 TVD /.' '4200TVD / 4300 TVD 3500 TVþ- ~/' ~-- /~~;:- / j./"/ ............... :~'N' [3.-g:{ / 1 320 F t.-_.--------- / / [?~] 4200 TVD 4300 TVD / 4400 TVD 4500 TVD / / / / / / / -700 -800 .= .400 _':"'___L__.l --- t-_-L.- .L._:"""""".._l_- L-...L._-:"'. -- ~-l- _j___~L___L --L-.,....!- ~-_L.",- læ I @) .~' .fJ /' ". /3500 TVO': -" .-' 3800 TVD .. , ' 3700 TVD / ' 3800 TVD .' 3900 TVD /' 4000 TVD " 4100 TVD " ~OTVD /' 4300 TV .,' 4400 TVD ..' . . 4500 TVD I / ,/! / I I /' ;' ,. 3500 TVQ' , .. .." 3800 TVD /" 3700 TVD / ' 3800 TVD / 3900 TVD /- 4000 TVO / 4100 TVD , , , , / I 3500 TVD 4200 TVD / 4300 TVD I 4400 TVD .' 4500 TVD 3500 TVD 3800 TVD 3800 TVD 3700 TVD 3800 TVD 3900 TVD 4000 TVD ~~ 4400 TVD 4400 TVD ,:' I \ 4500 TVD @ ~ ~ ~oo .200 ~ / 3500 TVD - 3600TVD - -1800 / 3800 TVD / 4000 TVD 4200 TVD 4400 TVD ! 3800 TVD j 3900 TVD ! 4400 TVD i 4500 TVI .'00 -r- ::: - ~800 - -1700 ~~ .. -2000 - .2100 .. .2200 -2300 - -2400 -2500 -2800 ~ - .2700 - -2800 1\ 3800 TVD , - .2900 3700 TVD .. - -3000 ^ -- .3'00 ' Z 0 ;:¡, - -32oo,=: it ~ - -3300 ~ - .3400 - -3500 - -3800 -3700 -3800 -3900 - -4000 ~oo - -4200 ,- -4300 -- -4400 - -4500 - -4600 - -4700 en &1 (õ -~ ~ " -~§ ~ - -260C - -270C 3900 TVß - - -280C r~ - -2\. 3100 TVD- - -30OC - -310{ - -320( - -330C - -340{ ~--. - -350C - -360C - -370{ - -380í "".',"W~"'....W~"-""-'-"""""""~-~""~'--"""-'-"-""-'--.WfN'-~'_~~"--'-N"^W_-~~=-~,-,",~"",~--.--"--~"""~~.",".-,,,-,,,,,-,,=-~='-'-,",-W'_--V=~,"",-'.'...,.~_W.=~-.""---~_N"_-_.---'~"""'#.'''''':_--'~,''U,"-..#^'~~'',-"W"~",-"".-=.;'#N"~-~'-"~',""---~",^,""-'N"_'--""'V_~"""""~"---'"""-~-"""''''--'~'-'-'-~-----~-'-'~'---~~---'----"~-'-~-~~----~~-~'~- ~~:-:T.-~k;'¡'~~~~h:~w.=;.o.¡,;.m"'A!;<''<>~''''A?I',,-~:.yN.~Þ»~kX-:»;_~~-*=,,"/.«~Ù:,;ø¡.m-:¡o;,o¡..-~~*,,"Ä*;.o,:,."W'"~""'.dIØ"~"';'7§~........~,,;o-ÄV..;-;ff~~=*,,"AW'Y''''ffl'7~''':"'TA~.zv.ÿ---~~~~..o!WÆii7-,-'''..;-~~'''-~-m-~-;<I'"..."'~.,w.,"¿.mtÇ-~~ff~~_~w.!"~""'~~""'..7."''''''''..7d.~-A",-'''''-~''''''''''''''~_''''''-A0:""",",.¥K''''.-?>?:-''':_,''~'''''--''''''''~¡"h»\I"'~~""4""....r>:-"'--=:""""'þ",..»'y,,,..,,.,.,..-,,.._,~<T""",,,#>:',*~>, STATE OF ALASKA ^.^s.. o,. co.s c APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska, Inc. Development__X RKB 111 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface '¢~ ,,,/' J 8. Well number 388' FNL, 601' FEL, Sec. 23, T11N, R10E, UM (asp's 560490, 5959276) 1D-129 At top of productive interval 9. Permit number / a~pproval number 2649' FNL, 2604' FEL, Sec. 23, T11N, R10E, UM 1972130 At effective depth 10. APl number 50-029-22830 At total depth 11. Field / Pool 2649' FNL, 2604' FEL, Sec. 23, T11 N, R10E, UM (asp's 558507, 5957000) KRU / West Sak 12. Present well condition summary Total depth: measured 5462 feet '~ Plugs (measured) bridge plug @ 5300' WLM / 5290' DP true vertical 4033 feet ~ Effective depth: measured 5299' WLM/5289' feet Junk (measured) true vertical 3870' feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Early 121' 121' SUR. CASING 5342' 7-5/8" 580 sx AS II 5453' 4042' 460 sx Class G Perforation depth: measured 5010'-5038', 5070'-5090', 5252'-5282', 5183'-5193', 5156'-5166', 5116'-5133' true vertical 3581 '-3609', 3641 '-3661 ', 3823'-3853', 3754'-3764', 3727'-3737', 3687'-3704' Tubing (size, grade, and measured depth 3-1/2", @.3#, L-80 Tbg @ 48'18' MD. Packers & SSSV (type & measured depth) BAKER SCl @ 4891' MD. @ 'MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: As soon as approved 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service . 17. I hereby ce~j~/t~t the foregoing is true and correct to the best of my knowledge. Signed Title: Problem Wells Supervisor Date 3 /. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity__ BOP Test__ Location clearance__I Approved by order of the Commission ,/~"~--~ ~"~'~'"~'~- % Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ConocoPhillips Alaska, Inc. West Sak Well 1D-129 SUNDRY NOTICE 10-403 VARIANCE REQUEST 3/11/03 The purpose of this Sundry Notice is for approval to temporarily gaslift West Sak producer 1D- 129 that is completed as an ESP (electric submersible pump) well. The ESP has failed and a workover is required to pull and replace the ESP. The well makes approximately 500 bopd via ESP, a majority of which may be possible to produce on gaslift. Due to the configuration of the tubing, production is to be up the annulus. Gaslift gas will be piped on the surface to flow down the tubing, exiting into the annulus via the existing mandrel. A 3/16" orifice valve will be installed in the mandrel for gaslift with the check valve removed allowing reverse-direction flow. The maximum anticipated gaslift rate will be 500-800 mcfd. Since there is no packer, flow will move past the pump and up the annulus. Hydraulics are uncertain since the annular area is so large and the oil is viscous, but model predictions are for 600-700 BFPD. The basic gaslift and production facilities layout for 1D-129 will be identical to the current 1D- 110A, 1D-102 and 1D-127 layout. ConocoPhillips has fabricated and will install a new 3" annulus flowline on 1D-129 to replace the existing 2" flowline prior to production. The above installation will decrease the fluid velocity and will minimize the elbows and impingement points to minimize erosion risk. (The same design has been implemented for 1D-110A, 1D-102 and 1D-127 as a pro-active measure, even though there was no indication of active erosion in the 2" line that was on well 1D-110A.) Velocity calculations have been done with maximum anticipated flow rates of 1000 BLPD and total GLR of 600 scf/stb up the annulus and through the 3" annular flow line. Production pressure is approximately 250 PSIG. The maximum velocity through the NPS 3" sch 160 A333 Gr6 line will be 18 ft/s. There have been 16 solids shakeouts on well 1D-129 since January 2002 and they range from 0.01% to 0.1% by volume. ConocoPhillips intends to take production shakeouts both initially and periodically to monitor future performance. On the following page is a table of recent well test information. Inspection Plans: A baseline ultrasonic inspection will be obtained prior to production. Recurring inspection schedule will be as follows, as per agreement with the AOGCC: Perform inspections weekly for the first month. Perform inspections monthly for the next two months. Perform inspections quarterly thereafter. Submit inspections on a quarterly basis .to the AOGCC. As an extra safety feature, a valve handle to the IA API valve has been extended outside the wellhouse and a line from the WI header is connected to the gas injection line for killing the well in case of an emergency. ConocoPhillips proposes that the AOGCC approve this request for a time_period not to exceed 12 months from the approval date. If a workover is not completed within that time peri~- __ ~AOGCC will be contacted to review the status and discuss a plan forward. Attached is a wellbore diagram of down-hole information. ConocoPhillips Alaska, Inc. West Sak Well 1D-129 Well Test Data FORMATION TOTAL FORMATION WELL TEST DATE FLOWING PSI SAND OIL WAT %WC FLUID GAS GOR TYPE D 129 22-FEB-03 15:15 244 AB.D 538 75 12 613 78 8 14 ESP D 129 18-FEB-03 15:00 240 AB.D 481 70 13 552 66 6 13 ESP D 129 12-FEB-03 05:00 218 AB.D 324 55 15 384 46 6 14 ESP D 129 05-FEB-03 14:00 210 AB.D 203 48 19 251 34 4 16 * ESP D 129 05-FEB-03 06:00 206 AB.D 256 36 12 291 37 7 14 * ESP D 129 29-DEC-02 07:10 201 AB.D 223 34 13 257 39 9 17 ESP D 129 16-DEC-02 06:00 209 AB.D 222 33 13 254 39 9 17 ESP D 129 04-DEC-02 0'4:57 209 AB.D 227 31 12 258 40 0 17 ESP D 129 22-NOV-02 05:00 228 AB.D 244 31 11 274 41 I 16 ESP D 129 11-NOV-02 03:38 225 AB.D 158 24 13 182 32 2 20 ESP D 129 02-NOV-02 03:31 210 AB.D 250 30 11 280 43 3 17 ESP D 129 01-NOV-02 20:11 211 AB.D 253 30 11 283 43 3 17 ESP D 129 17-OCT-02 15:30 213 AB.D 435 38 8 . 473 64 4 14 ESP D 129 03-OCT-02 04:49 207 AB.D 380 33 8 413 59 9 15 ESP D 129 29-SEP-02 05:00 222 AB.D 357 32 8 390 54 4 15 ESP D 129 26-SEP-02 05:00 194 AB.D 302 28 8 329 49 9 16 ESP D 129 15-SEP-02 11:09 181 AB.D 383 I 0 384 51 I 13 ESP D 129 10-AUG-02 22:23 222 AB.D 435 29 6 465 68 8 15 ESP D 129 30-JUL-02 04:00 223 AB.D 441 28 6 469 65 5 14 ESP D 129 18-JUL-02 07:09 203 AB.D 443 27 6 470 65 5 14 ESP D 129 14-JUN-02 05:23 223 AB.D 453 25 5 478 67 7 14 ESP D 129 02-JUN-02 11:00 211 AB.D 464 24 5 489 68 8 14 ESP D 129 13-MAY-02 16:00 212 AB.D 421 21 5 442 60 0 14 ESP D 129 09-MAY-02 15:07 211 AB.D 400 20 5 420 55 5 13 ESP D 129 24-APR-02 06:13 235 AB.D 383 17 4 399 56 6 14 ESP D. 129 12-APR-02 10:54 228 AB.D 382 16 4 398 56 6 14 ESP D 129 01-APR-02 07:50 213 AB.D 377 15 4 392 56 6 14 ESP D 129 20-MAR-02 11:02 214 AB.D 371 12 3 382 52 2 14 ESP D 129 08-MAR-02 21:30 211 AB.D 368 12 3 380 48 8 13 ESP D 129 24-FEB-02 04:57 218 AB.D 372 11 3 383 57 7 15 ESP D 129 12-FEB-02 23:00 200 AB.D 380 11 3 391 51 I 13 ESP D 129 30-JAN-02 07:09 216 AB.D 402 11 3 _ 413 60 0 15 ESP D 129 15-JAN-02 17:11 242 AB.D 422 10 2 432 53 3 12 ESP D 129 07-JAN-02 08:09 226 AB.D 421 10 2 431 70 0 16 ESP ConocoPhillips Alaska, Inc. West Sak Well 1D-129 Well Test Data SOLIDS % WC% DATE SHK SHAKEOUT 02/17/03 0.03 14.0 02/15/03 0.07 15.0 02/13/03 0.06 10.0 02/12/03 0.07 18.0 02/11/03 0.05 12.0 02/08/03 0.05 20.0 02/05/03 0.05 22.0 11/10/02 0.08 12.0 10/03/02 0.01 3.0 09/25/02 0.05 5.5 09/19/021 0.05 2.5 09/16/021 ~: 0.01 6.0 04/29/02 0.01 1.8 01/07/02 0.01 1.0 01/03/02 0.03 1.0 01/01/02 0.10 PACKOFF (4750-4790, 0D:2.992) ConocoPhilliPS Alaska, Inc, KRU 1 D-129 1D;129 ~: .... ~-- ~ ~-~ ~- ~- _- ~i ~ _- ..... ~ ~ --~ .~ - ~ APl: 500292283000 SSSV Type: )NE Annular Fluid: Reference Lo~ Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: SUR. CASING CONDUCTOR Size 7.625 16.000 PROD Angle @ TS: Angle @ TD: deg @ I deg @ 5462 11/29/1997 2/6/2000 Rev Reason: Reset slipstop, packoff, pump, set SOV Last Update: 3/10/2003 5462 ftKB i8 deg (~ 2146 T°P I Bo.om] TVD o I 5453 I 4024 0 I 121 I 121 Size Top I Bottom TVD 3.500 0I 4816 3387 IWt I Gradel Thread 29.70 I L-80 I BTC-MOD 62.58 ] H-40 ] Welded Thread EUE 8rd Comment Zero deg. phasing/Iow side; 2 1/8" EJ Zero deg. phasing/Iow side; 2 1/8" EJ HSD-BH 4 1/2" HSD-BH 4 1/2" HSD-BH 4 1/2" Zero deg. phasing/Iow side; BH EJ SEAL (4817-4831, OD:3.500) G 0D:3.500) Interval TVD 5010-5038 3581-3609 5070-5090 3641-3661 5116-5133 3687-3704 5156-5166 3727-3737 5183-5193 3754-3764 5252-5282 3823-3853 Vlv Cmnt MOTOR (4833-4839, 0D:3.500) (4891-4895, OD:6.800) MILLC (4895-49OO, OD:5.500) SLEEVE (49OO-49O3, 0D:5.800) SEAL BORE (49O3-492O, 0D:5.500) BINK PIPE ~ (4923-4984, 0D:4.550) Perf (5O10-5O38) Per~ (5O70-5O9O) Perf (5116-5133) Perf (5156-5166) Pe# (5183-5193) Per~ (5252-5282) SCREEN (4984-529O, 0D:5.100) Description ID SLIPSTOP 3/8/2003 0.000 PACKOFF Packoff set 3/8/2003 0.000 PUMP 32'3" ESP PUMP SET 31812003 4.000 0.000 GAUGE Baker Sentry NIP Centdlift Slotted Nipple 2.992 2.992 XO Centrilift TTC Crossover SEAL Centdlift GSB3 2.992 GEAR Centrilift 525 9.1 2.992 MOTOR Centrilift 1127/27 2.992 Centralizer Centdliff 2.992 PKR Baker SC1 4.000 MILLOUT Baker 4.892 4.892 SLEEVE Baker Sliding Sleeve SEAL Baker BORE SAFE JOINT SCREEN Baker 0.20 Gauge 4.4OO 4.000 BINK PIPE Baker 4.000 4.000 BULL Baker PLUG 4.000 ConocoPhillips Problem Well Supervisor P.O. Box 100360, NSK 69 Anchorage, AK 99510-0360 Phone 907-659-7224 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 March 19, 2003 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice variance request for ConocoPhillips Alaska, Inc., well iD-129. The variance request is for approval to temporarily use gaslift to produce the ESP- completed well. Attached is a discussion and well schematic. Please call MJ Loveland or myself at 907-659-7224 if you have any questions. Sincere/l~ Problem Well Supervisor ConocoPhillips Alaska, Inc. 'ORIGINAL . RECE Alaska Oi! & G~ Com. Ccmmission STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 113 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 1030' FSL, 808' FEL, Sec. 16, T11 N, R10E, UM (asp's 549710, 5960617) 1 E-36 At top of productive interval 9. Permit number / approval number 1642' FNL, 1335' FEL, Sec. 28, T11 N, R10E, UM (asp's 549253, 5952663) 198-213 At effective depth 10. APl number 50-029-22927 At total depth 11. Field / Pool 1869' FNL, 1300' FEL, Sec. 28, T11 N, R10E, UM (asp's 549291, 5952437) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 12005 feet Plugs (measured) Tagged Fill (5/1/00) @ 11788' MD. true vertical 6193 feet Effective depth: measured 1 1788 feet Junk (measured) true vertical 6058 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Early 121' 121' SURFACE 6218' 9-5/8" 608 Sx AS III L, 925 S'x 6330' 3996' Class G, & 60 Sx AS I PRODUCTION 11485' 7" 170 Sx Class G 11597' 5944' LINER 596' 4-1/2" 100 Sx Class G 12004' 6193' . Perforation depth: measured 11720 - 11740'; 11760 - 11780'; 11795 - 11815' true vertical 6017 - 6029'; 6041 - 6053'; 6063 - 6075' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, Tubing @ 11440' MD. RECEIVED Packers & SSSV (type & measured depth) Baker LSA & ZXP Packer @ 11414' MD. Camco TRDP-4E @ 1823' MD. FEB '1 ;5 2001 13. Stimulation or cement squeeze summary Alaska 011 & ~ 00~8, C0mmi~idn Intervals treated (measured) (see atfached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 179 161 515 169 Subsequent to operation 1688 1604 3540 209 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,~ /~llt~,~ Title: Date Prepared by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1 E-36 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 1/26/00: RIH & tagged fill at 11868' MD. 1/28/00: MIRU & PT equipment. Pumped a 'C' Sand Hydraulfc Fracture Treatment using 16/20 mesh proppant, through the open perforation intervals located at: 11720 - 11740' MD 11760 - 11780' MD 11795 - 11815' MD Pumped Breakdown: a) 147 bbls Linear Pre-Pad Gel @ 30 bpm, followed by b) Shutdown. ISIP @ 2190. Resumed pumping Scour Stage: c) 40 bbls 40# Crosslinked Gel w/1 ppa proppant, followed by d) Shutdown. ISIP @ 2275. Resumed pumping Data Frac: e) 100 bbls 40# Crosslinked Gel @ 20 bpm, followed by f) Shutdown. Resumed pumping Frac Treatment: g) h) i) J) Placed a total of 97,601 lbs of proppant into the formation. RD. 1/31/00: Performed a CT proppant fill cleanout to 11912' MD. 5/1/00: RIH & tagged fill at 11788' MD. 270 bbls Crosslinked Pad @ 20 bpm, followed by Crosslinked Slurry stages w/proppant ramped up in stages from 2 to 12 ppa, followed by 58 bbls Flush, followed by Shutdown. Returned the well to production & obtained a valid well test. MEMORANDUM TO: Julie Heusser, Chairman THRU: State of Alaska Alaska Oil and Gas Conservation Commission Tom Maunder, ~-(~)~ P. I. Supervisor kl~,cc~t DATE: January 4, 2001 FROM: SUBJECT: Chuck Scheve; Petroleum Inspector Safety Valve Tests Kuparuk River unit 1E Pad Thursday, January 4, 2001' I traveled to the Kuparuk River Field and witnessed safety valve system testing on 1E Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 9 wells 18 components on 1E pad with 2 failures. The Pilot on well 1E-07 was frozen and the Surface Safety valve on well 1E-24A had a slow leak when pressure tested. A portable heater was brought to location and the above mentioned pilot was thawed out. I requested the portable heater remain on this well until repairs are made on the catalytic heater in the wellhouse. The failed safety valve will be serviced and retested when the grease crew becomes available Earnie Barndt conducted the testing today; he demonstrated, good test procedUres and was a pleasure to work with. I also inspected the well houses on this pad while Witnessing sVs teSting. All the wellhouses were clean and the equipment appeared to be in good condition, Summary: I witnessed the SVS testing at 1E Pad in the Kuparuk River Field. - KRU IE Pad, 9 wells, 18 components, 2 failure, 1t.1% failure rate ~.~,.~\~c..~ 16 wellhouse inspections Attachment: SVS KRU 1E Pad 1-4-01 CS X Unclassified Confidential (Unclassified if doc, remOved ). Confidential ' SVS KRU 1E Pad 1-4-01 CS.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve . Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 1E Pad Separator psi: LPS 85 HPS 1/4/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or C¥CL~ 1E-02 1800500 85 70 60 P P OIL 1E-03 1800560 85 70 45 P P · OIL 1E-05 1800580 1E-06 1800780 1E-07 1800800 85 70 0 2 P OIL 1E-10 1820360 -- 1E-11 1820510 1E-12 1820600 . 1 E- 14 1820790 1E-18 1830160 85 70 50 P P OIL 1E-19 1830170 1E-20 1830050 85 70 50 P P OIL 1E-21 1830020 1E-23 1821840 1E-24A 1971870 85 70 70 P 4 OIL 1E-26 1821660 ' 1E-28 1821580 1E-29 1821540 . 1E-31 1971380 85 70 65 P P OIL 1E-33 1971510 1E-34 1971660 85 70 50 P P OIL 1E-36 1982130 85 70 60 P P ~' OIL Wells: 9 Remarks: Components: 18 Failures: 2 Failure Rate: 11.1%~ 9o Day Pilot on 1E-07 frozen. Portable heater placed on pilot until catalytic repaired Surface Safety on 1E-24A had slow leak, valve to be serviced and retested. 1/9/01 Page 1 of 1 SVS KRu 1E Pad 1-4-01 CS.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, ~'3"' DATE: Commissioner THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor ~[-~(~o FROM: John H Spaulding,~/~,~ .,-'2©. Petroleum Inspector July 22, 2000 SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22, 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E & lX tE - 8 wells, 16 components, I failure, 9 % failure rate, 12 well house insp. 2X - 10 wells. 20 compnents, 1 failure, 5 % failure rate, 12 well house insp. Attachment: Alasl4ffOil and Gas Conservation Commissi6h Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kupamk/Kuparuk R. U./1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 1E-02 1800500 91 70 65 P P OIL 1E-03 1800560 SI 1E-05 1800580 1E-06 1800780 SI 1E-07 1800800 91 60 55, P P OIL 1E-10 1820360 1E-11 1820510 1E-12 1820600 SI 1E-14 1820790 1E-18 1830160 91 60 46 P P OIL 1E-19 1830170 1E-20 1830050 91 60 48 P P OIL 1E-21 1830020 1 E-23 1821840 1E-24A 1971870 91 70 70 P P OIL 1 E-26 1821660 SI 1E-28 1821580 SI 1 E-29 1821540 SI 1E-31 1971380 91 70 70, p p OIL 1E-33 1971510 1E-34 1971660 91 70 70 p p OIL :t'E-36~ '- "~1982130 91 70 70 p p OIL Wells: 8 Components: 16 1 Failure Rate: 9.0% ID 90 r)av Remarks: 8/7/00 Page 1 of 1 svs kuparuk kru 1 e 7-22-00js.Xls Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Barndt AOGCC Rep: John H. Spaulding Submitted By: John Spaulding Date: Field/Unit/Pad: Kuparuk/Kupamk R./2X Separator psi: LPS 96 HPS 22-Jul Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2X-01 1830840 I 2X-02 1831030 2X-03 1831090 2X-04 1831180 3000 2000 2000 P P WAG 2X-05 1831070 3000 2000 2000 P 4 WAG 2X-06 1831100 3000 2000 2000 P P WAG 2X-07 1831130 3500 2000 2000 P P WAG 2X-08 1831140 2X-09 1841620 96 70 60 P P OIL 2X-10 1841630 96 70 65 P P OIL 2X- 11 1841640 96 60 60 P P OIL 2X-12A 1951760 2X-13 1841740 2X-14 1841750 2X- 15 1841760 96 70 70 p P OIL 2X-16 1841720 2X-17 1951710 96 60 50 p P OIL 2X-18 1951600 96 60 50 p P OIL 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% [] 90 var - Remarks: 8/15/00 Page 1 of 1 svs kuparuk kru 2x 7-22-00js.xls Schlumberger NO. 121002 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 1E-36 I 99421 MEMORY GR/CCL ~ c~ ~C~ 991010 1 *pRINTS SENT PREVIOUSLY) ,., ,. .......... ~,,~,~, ~ ~, . ~,,~,:~.~, ~: 't~ ,F '~'~"1 ~,~,~. SIGNED: .... ~, . ' DATE: ".. '., U 8 'i999 .~jaska 0i~ & Gas Coils. C0~¥mi~bt~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Th~~~ 12/7/99 STATE OF ALASKA ...._:. . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 74' RKB 3. Address: Exploratory~ 7. Unit or Property: P.O. Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service ~ I Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1030' FSL, 808' FEL, Sec 16, TllN, FI10E, UM. 1E-36 At top of productive interval: 9. Permit number/approval number: 1642' FNL, 1335' FEL, Sec 28, T11N, RIOE, UM. 98-0213 At effective depth: 10. APl number: 1658' FNL, 1331' FEL, Sec 28, T11N, R10E, UM. 50-029-22927-00 Af fatal depth: 11. Field/Pool: 1869' FNL, 1300' FEL, Sec 28, T11N, R10E, UM. Kuparuk River Field/Pool 12. Present well condition summary Total Depth: measured 12005 feet Plugs (measured) true vertical 6193 feet Effective Deptl measured 11939 feet Junk (measured) true vertical 6152 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 85' 16" 9 cu yds High Early 121' 121' Surface 6294' 9-5/8" 608 Sx AS III LW & 6330' 3996' 925 Sx class G Production 11561' 7" 170 Sx Class G 11597' 5945' Liner 596' 4.5" 100 Sx Class G 12004' 6193' Perforation Depth measured 11720'-11735', 11735'-11740', 11760'-11780', 11795'-11815' 6017'-6026', 6026'-6029', 6041'-6053', 0 F~ I G I~IA L true vertical 6063'-6075' f ~.~ ,""~ Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, @ 11440' MD p , - Packers ond SSSV (type ond meosured depth) Baker ZXP Packer @ 11414' MD; Camco TRDP-4E SSSV @ 1823' MD. (') F'"~ ~_. . 7 ,-, 199.9 13. Stimulation or cement squeeze summary AJask8 0ii & Cons. Commission Reperforated 'C' sands on 10/11-14/99. Intervals treated (measured) Anchorage 11720'-11735', 11735'-11740', 11760'-11780' Treatment description including volumes used and final pressure Perforated using HC/DP guns @ 4 spt & stimstick, final pressure was 1100 psi, stimstick shot pressure 20,375 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 208 146 575 831 166 Subsequent to operation 246 143 575 868 166 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil ~X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~::i Title', ~¢ ~::~ ~ ("- ~'~..~ ¢"' Date Form 10-404 RI 6~ ;8 SUBMIT IN Dt ARCO Alaska, Inc. KUPARUK RIVER UNIT ,LL SERVICE REPORT 1E-36(4-1)) WELL JOB SCOPE JOB NUMBER 1E-36 PERFORATIONS-CT. 1004990119.1 DATE 10/14/99 -DAY 4 FIELD ESTI MATE DALLY WORK STIMSTICK TREATMENT OPERATION COMPLETE J SUCCESSFUL ~ Yes ~'~ NO I ~'~ Yes O No AFC# ICC# I DAILY COST 999154 230DS 10EG $33,124 InitiaITbg IFinalTbg J lnitial IA I 150 PSII 1100 PSq 750 PSI I IKEY PERSON DS-NEWELL ACCUM COST $100,088 Final IA ~lnitial OA I Final OA J'rTL Size 1350PS1~ 500PSI] 700PSIJ 0.000" UNIT NUMBER UNIT #3 SUPERVISOR LIGENZA DAILY SUMMARY FIRED STIMSTICK IN UPPER PERF AREA FROM 11,724' TO 11,736'. KIPSTER PRESSURE DATA; SHOT #1 AT 11,764' - 11778' = 20,375 PSIG. SHOT #2 AT 11,724 - 11,736 = 20,375 PSIG. [Other Stim] TIME 07:00 08:30 09:25 10:10 11:40 11:50 12:00 12:38 14:25 00:00 LOG ENTRY MIRU DS CTU. THAW OUT INJECTOR HEAD.REPLACE ALL LUBRICATOR O-RINGS. MAKE UP TOOL STRING. 6.7' FROM CC TO TOP OF STICK. PT LUBE/LINES TO 2,000 PSI. O-RING LEAKING JUST BELOW INJECTOR HEAD. BREAK DOWN LUBRICATOR AND REPLACE O-RING. PRESSURE TEST LUBE/LINES TO 2,000 PSI. TEST GOOD. TGSM, 5 DAYS IS SHUT IN WELL AT 2200'. OPENED LIFT GAS ALL THE WAY. STOP AT FLAG. CORRECT COUTER DEPTH DEPTH TO 11,772'. BLEED TUBING PRESSURE TO 800 PSI. LOCATE BALL DROP ON SPOOL. BLEED TUBING PRESSURE TO 800 PSI. JUMPER LIFT GAS TO LUBRICATOR AND PRESSURE TUBING UP. DROP BALL. PULL UP TO 11,742.3' TO PLACE TOP OF STICK AT 11,724'-11,736'. BLOCK IN GAS. BEGIN PUMPING AT 1 BPM MAINTAINING MAXIMUM OF 2400 PSI ON cOIL UNTIL BALL SEATS. GUN WENT OFF AFTER 27.5 BBLS PUMPED. 4700 PSI'. POH. NO PROBLEMS PASSING THROUGH D NIPPLE. ON SURFACE. CONFIRMED GUN FIRED. RIG DOWN. KIPSTER PRESSURE DATA SHOT #1 AT 11,764' - 11778' = 20,375 PSIG SHOT #2 AT 11,724 - 11,736 = 20,375 PSIG SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL ,, APC $2,800.00 $15,500.00 BAKER OIL TOOLS $500.00 $2,600.00 DIESEL $0.00 $500.00 DOWELL $10,974.00 $53,926.00 HALLIBURTON $18,850.00 $18,850.00 SCHLUMBERGER $0.00 $8,71~ 2.00 TOTAL FIELD ESTIMATE $33,124.00 $100,088.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT _ELL SERVICE REPORT K1(1E-36(W4-6)) WELL JOB SCOPE JOB NUMBER 1 E-36 PERFORATIONS-CT. 1004990119.1 DATE 10/13/99 DAY 3 FIELD ESTI MATE DALLY WORK STIMSTICK TREATMENT OPERATION COMPLETE I SUCCESSFUL I KEY PERSON O Yes ~ No O Yes ~ No DS-NEWELL AFC# ICC# J DAILY COST ACCUM COST 999154 230DS 10EG $14,074 $66,964 InitiaITbg IFinalTbg J lnitial IA I Final IA I Initial OA IFina OA ITTL size 140Ps~l 1100PSl] 700PSll 1300PSI] 500PSII 600PSll 0.000" UNIT NUMBER UNIT #3 SUPERVISOR LIGENZA IMin ID '- v ~;"D~th 2.750 " I 11375 FT DALLY SUMMARY RAN STIMSTICK. GUN FAILED TO FIRE. WET FIREING HEAD. [Other Stim] J TIME LOG ENTRY 09:00 MIRU DS CTU. CHANGE OUT BAKER COIL CONNECTOR. PULL TEST. 09:45 TGSM. DISCUSS STIMSTICK HAZARDS. DRIFTING SNOW/HIDDEN TRIPS. MAKE UP TOOL STRING. 6.6' FROM CC TO TOP OF STICK. 10:30 PRESSURE TEST TO 2000 PSI ON BACKSIDE, LINES AND LUBE. 10:55 RIH W/WELL FLOWING. 11:20 SHUT IN WELL AT 2300'. LEAVE LIFT GAS FLOWING. 13:10 STOP AT FLAG. ADJUST COUNTER TO 11,772'. STAND BY FOR FLUID LEVEL. 15:45 FLUID LEVEL AT 900'. TUBING PRESSURE AT 1370 PSI, COIL AT 1380 PSI. DROP 1/2" ALUMINUM BALL. 16:00 PULL UP TO 11,717.4' TO SHOOT ZONE FROM 11,724 TO 11,736'. SART PUMPING AT 1 BPM. 16:45 BALL WENT ON SEAT AT 27.9 BBLS PUMPED. PRESSURED UP TO 4950 PSI. GUN FAILED TO GO OFF. BLED COIL OFF AND PRESSURED BACK UP SEVERAL TIMES. GUN FAILED TO FIRE. 17:15 BLEED COIL DOWN TO 1500 PSI. POOH. TOOLS INDICATED WET FIREING HEAD. BRASS CONNECTOR BETWEEN CORD AND HEAD BROKEN. _ 19:10 ON SURFACE. LUBRICATOR HAS BEEN IN THE AIR FOR FOUR DAYS. NEED TO REPLACE O-RINGS. REDRESS STIMSTICK. RIG DOWN FOR THE NIGHT. 19:45 RIG DOWN FOR THE NIGHT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $2,600.00 $12,700.00 BAKER OIL TOOLS $500.00 $2,100.00 i DIESEL $0.00 $500.00 DOWELL' $10,974.00 $42,952.00 ., HALLIBURTON $0.00 $0.00 . SC H LUMBERG ER $0.00 $8,712.00. TOTAL FIELD ESTIMATE :$14,074.00 $66,964.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT ._--'LL SERVICE REPORT K1(1E-36(W4-6)) WELL 1 E-36 DATE 10/12/99 DAY 2 FIELD ESTIMATE JOB SCOPE JOB NUMBER PERFORATIONS-CT. 1004990119.1 DAILY WORK CT STIMSTICK TREATMENT OPERATION COMPLETE I SUCCESSFUL IKEY PERSON Yes ~ No ~ Yes O No DS-NEWELL ACCUM COST $52,890 AFC# ICC# I DAILY COST 999154 230DS 10EG $14,274 Initial Tbg IFinal Tbg I Initial IA I Final IA J lnitial OA IFinal OA I'l-rL Size 200PSII 1190PSII 900PSll 1300PSII 500PSII 600PSII 0.000 " UNIT NUMBER UNIT #3 SUPERVISOR LIGENZA I i.,o 'T~:~pth I 2.750" 111375FT DALLY SUMMARY I RAN TUBING TAIL LOCATOR' SET DOWN IN D NIPPLE' CORRECTED DEPTH TO FLAG ON COIL FIRE STIMSTICK IN I Bo1-rOM PERF FROM 11,764' TO 11,776'. RUN SECOND STIMSTICK TOMORROW. [Other Stim] TIME LOG ENTRY 06:30 MIRU DS CTU. 07:00 PT LUBE / LINES TO 4,000 PSI. TGSM. 5 PEOPLE ON LOCATION. 07:15 RIH WITH 2.25 BAKE CC, 2.13 DOUBLE CHECKS, 2,13 HYD DISCONNECT, 2.5" TTL. 09:20 UNABLE TO PASS THROUGH D NIPPLE AT 11,375'~ POOH. 11 :OO ON SURFACE. 11:30 TGSM. DISCUSS JOB PLAN, DEPTH CONTROL. STIM STICK HAZARDS.. REVIEW HES SAFETY CHECKLIST. 12:00 MAKE UP STIM STICK TOOL STRING. ADD 6.8' TO DEPTH TO TOP oF STIM STICK. PRESSURE TEST TO 4, OO0 PSI. '12:30 RIH WITH WELL FLOWING TO 11757.42'. 13:55 SHUT IN WELL AND GAS LIFT AT 7,500'. 14:45 STOP AT FLAG. ADJUST COUNTER DEPTH TO 11,782'.. PULL UP TO BALL DROP POSITION. SHOOT FLUID LEVEL. 16:00 UNABLE TO SEE FLUID LEVEL. PULL UP TO TARGET DEPTH. PUMP 10 BBLS OF DIESEL DOWN BACKSIDEAT .7 BPM. 16:12 SHUT DOWN PUMP AND STAND BY. 16:40 TUBING IS FLUID PACKED. FLOW WELL DRAW TUBING PRESSURE DOWN TO 800 PSI. OPEN LIFT GAS WIDE OPEN. 17:O0 SHUT IN WELL WITH LIFT GAS FLOWING. ~ 17:30 FLUID LEVEL AT 120'. 18:00 FLUID LEVEL STILL AT 120'. CONNECT HOSE FROM LIFT GAS LINE TO LUBRICATOR. 18:35 FLUID LEVEL AT 590'. WITH WELL HEAD AT1280 PSIG. 18:55 DROP 1/2" DELERON BALL. START PUMPING 1 BPM. WH AT 1275 PSI. COIL AT 1265 PSI. 19:37 30 BBLS PUMPED. COIL VOLUME. BALL NOT ON SEAT. WH AT 1630 PSI. COIL AT 2175 PSI. 19:50 SURGED PUMP. 39.5 BBLS PUMPED. BALL FAILED TO SEAT. LINE UP COIL TO TANKS AND BLEED OF A COUPLE BBLS. INSPECT BALL PORT. BALL IN COIL. 20:07 BRING PUMP BACK ON LINE W/1530 PSI ON WH. RUN COIL TO 4950 PSI AT 1,8 BPM. 45 BBLS PUMPED. PUMP ANOTHER COIL VOLUME AT 1 BPM. 20:30 BALL SEATED AT 61.4. PRESSURED UP TO 4500 PSI. GUN WENT OFF. FELT SURGE IN CAB. COIL JUMPED. 7" ANNULUS AT 1300 PSI. SERVICE COMPANY - SERVICE DAIL'Y ~OST ACCUM TOTAL APC $2,800.00 $10,100.00 BAKER OIL TOOLS $500.00 $1,600.00 DIESEL $0.00 $500.00 DOWELL " $10,974.00 $31,978.00 HALLIBURTON $0.00 $0.00 SCHLUMBERGER $0.00 $8,712.00 TOTAL FIELD ESTIMATE "' ~" $14;~74.00 $52,890.00 ,, ARCO Alaska, Inc. KUPARUK RIVER UNIT · .ELL SERVICE REPORT K1(1E-36(W4-6)) WELL JOB SCOPE JOB NUMBER 1 E-36 PERFORATIONS-CT. 1004990119.1 · DATE 10/11/99 DAY 1 FIELD ESTI MATE DAILY WORK CT CONVEYED PERF OPERATION COMPLETE I SUCCESSFUL I KEY PERSON O Yes ~ No O Yes ~'~ No DS-NEWELL AFC# I CC# I DAILY COST ACCUM COST 999154 230DS 10EG $19,557 $38,616 InitiaITbg IFinalTbg I Initial IA I Final IA I lnitialOA IFina, OA ITTLSize 1000PSII 1100PSII 700PSII 700PSII 550PSII 550PSIJ 0.000 " UNIT NUMBER UNIT #3 SUPERVISOR ICH/~IEY lrvlin ID I Dept~ I o.ooo. I /' o FT DALLY SUMMARY REPERF'D "C" SAND INTERVALS 11720' RKB-11740' RKB & 11760' RKB-11780' RKB. USED CT CONVEYED 2-1/2" HC GUN, DP CHGS, 4 SPF, 180 DEGREE PHASING. [Perf] TIME 06:30 08:30 09:00 11:15 11:40 12:20 13:00 13:15 14:20 14:45 15:00 15:20 17:30 17:40 18:10 19:45 21:00 LOG ENTRY MIRU DOWELL CTU & SWS PERF EQUIP. HELD SAFETY MEETING (6 PEOPLE ON LOCATION). PT'D SURFACE EQUIP TO 4000 PSI. RIH W/1.75" CT, 2.25" COIL CONN, 2.13" DOUBLE CHECK ASSY, 2.13" HYD DISCONNECT, 2.125" X-OVER, 2.125" CBF FIRING HEAD, 2.5" HC DEEP PENETRATING 4SPF 180 DEGREE PHASING 20' GUN. TOTAL BHA LENGTH FROM COIL CONN 30.27'. @ FLAG DEPTH 11782' RKB DROPPED 5/8" BALL & MOVED PIPE TO POSITION TOP SHOT DEPTH @ 11760' RKB. KICKED PUMP OFF @ 1 BPM BALL ON SEAT. HAD TO RAISE CTP TO 4700 PSI TO GET FIRING HEAD TO GO OFF. GUN FIRED AND WHTP SURGED FROM 1400 PSI TO 1700 PSI. PERF INTERVAL 11760' THRU 11780' SHOT. STARTED OOH. @ 8000' CTM POWER PACK ON THE UNIT OVERHEATED AND HAD TO SHUT IT DOWN TO COOL DOWN. WIND BLEW DOOR SHUT INTO ENGINE ROOM, RESUME POOH AFTER COMPLETE INVESTIGATION ON SURFACE. (ASF) CHANGE OUT PERF GUNS. PT'D SURFACE EQUIP TO 2000 PSI. RIH W/1.75" CT, 2.25" COIL CONN, 2.13" DOUBLE CHECK ASSY, 2.13" HYD DISCONNECT, 2.125" X-OVER, 2.125" CBF FIRING HEAD, 2.5" HC DEEP PENETRATING 4SPF 180 DEGREE PHASING 20~ GUN. TOTAL BHA LENGTH FROM COIL CONN 30.27'. @ FLAG DEPTH @ 11782' RKB DROPPED 5/8" BALL & MOVED PIPE TO POSITION TOP SHOT DEPTH @ 11720' RKB. KICKED PUMP OFF @ 1 BPM BALL.ON SEAT. HAD TO RAISE CTP TO 4700 PSI AGAIN TO GET FIRING HEAD TO GO OFF. GUN FIRED AND WHTP SURGED FROM 1600 PSI TO 1900 PSI. PERF INTERVAL 11720' THRU 11740' SHOT. STARTED OOH. ON SURFACE. (ASF) RDFN DOWELL CTU & RELEASED SWS EQUIP. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $3,800.00 $7,300.00 ., BAKER OIL TOOLS $500.00 $1,100.00 DIESEL $300.00 $500.00 DOW ELL $9,245.00 $21,004.00 SCHLUMBERGER $5,712.00 $8,712.00 = , TOTAL FIELD ESTIMATE $19,557.00 $38,616.00 . STATE OF ALASKA "-., ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 74' RKB 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Strafagrapic__ Anchorage, AK 99510-0360 Service . Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1030' FSL, 808' FEL Sec 16, T11N, R10E, UM 1E-36 At top of productive interval: ,9. Permit number/approval number: 1642' FNL, 1335' FEL, Sec 28, T11N, R10E, UM 98-0213 At effective depth: 10. APl number: 1658' FNL, 1331' FEL, Sec 28, T11N, R10E, UM 50-029-22927-00 At total depth: 11. Field/Pool: 1869' FNL, 1300' FEL, Sec 28, T11 N, R10E, UM Kuparuk River Field/Pool 12. Present well condition summary Total Depth: measured 12005 feet Plugs (measured) true vertical 6193 feet Effective Deptl measured 11939 feet Junk (measured) true vertical 6152 feet Casing Length Size Cemented Measured depth . True vertical depth Conductor 85' 16" 9 CU.Yrds high early 121' 121' Surface 6294' 9-5/8" 608 Sx AS Ill LW& 6330' 3996' 925 Sx class G Production 11561' 7" 170 Sx Class G 11597' 5945' Liner 596' 4.5" 100 Sx Class G 12004' 6193' measured 11720'-11735';11760'-11780';11795'-1181~ true vertical 6017' - 6026'; 6041' - 6053'; 6063' - 607,' Tubing (size, grade, and measured depth) ~.~ 3-1/2", 9.3#, L-80, @ 11440' MD Pa~kers and SSSV (type and measured depth) Baker ZXP Packer @ 11414' MD; Camco TRDP-4E SSSV @ 1823' MD 13. Stimulation or cement squeeze summary Added pert interval 11760'-11780' and 11720'-11735' Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representitive Daily Average Production or Injection Data OiI-Bbl ~as-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 186 110 288 1400 170 Subsequent to operation 193 117 339 775 173 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ZX Oil __ZX Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. :Signed ~ ~,~ .~ Title', ~//.,,/,.~ ~~_--~. Date Form 10-404 Rev 06/15~ ~ SUBMIT IN DUPLICATE ~ARCO Alaska, Inc. KUPARUK RIVER UNIT .. : SERVICE REPORT ~' K1(1E-36(W4-6)) WELl' JOB SCOPE JOB NUMBER ''- -- 1 E-36 PERFORATE, PERF SUPPORT 1230981822.3 DATE DAILY WORK UNIT NUMBER 12/31/98 PERFORATE C4 SAND 2150 DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes (") NoI (~) Yes O No V. LONAX SCHUROSKY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTI MATE 999154 230 DSIO E G $18,860 $18,860 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSI 1350 PSI 2200 PSI 2000 PSII 225 PSII 200 PSI DAILY SUMMARY PUMP 20' X 2-1/2" HC PERF GUN(4 SPF, 180 DEG PHASE) DOWN FROM 7610' TO 11850'.PERFORATE 20' C4 SAND FROM 11760' TO 11780'. PUMPED TOTAL OF 150 BBLS DIESEL. (FLOWLINE DISPLACED WITH 55 BBL DIESEL.) RETURN WELL TO DSO. TIME LOG ENTRY 07:30 MIRU SWS E-LINE, HOLD TGSM. MUSTER AND PERF GUN SAFETY. 08:30 BENCH TEST TOOLS. 09:30 PICK UP 20' GUN. 10:30 PT LUB AND BOP STACK TO 3000 PSI. DISPLACE FLOWLINE WITH DIESEL. 10:45 RIH WITH GUN-GAMMARAY/CCL/ROLLERS/SAFE HEAD/20'X 2-1/2" HC, 4SPF DP, 180 DEG PHASING/ ROLLRES ON TOP & BOTTOM OF GUN. 13:30 UNABLE TO WORK DOWN PAST 7610'. RIG UP LITTLE RED TO PUMP DOWN TBG. 15:00 LITTLE RED PUMPED 70 BBLS DIESEL'DOWNHOLE TO PUMP PERF GUN DOWN, WELLHEAD PRESSURE~2500 I 'AT .5 BPM, MADE 250' TO 7860 :: PUMP TRUCK WENT FOR' MORE DIESEL. :' '~ ~ LITTLE RED ON LOCATION..PUMP 5 BBLS, sTART ~)oWNHoLE WITH WIRELINE PUMPING ;3 BPM' UNABLE TO GET PAST 7823'.WHILE PUMPING .5 AT 2900.PSI. POOHTO CHANGE .TOOL sTRING. 16:30 18:00 19:30 PT TO 3000 PSI, RIH WITH SAME GUN, REMOVED BOTTOM ROLLER AND REPLACE WITH SLICKLINE ROLLER . STEM X 6'. '-' ~ 20:45 AT 7850' SET DOWN, START PUMP AT .20~BPM. WORK THRU TIGHT SPOTS 7850' AND DEEPER ..... 22:00 AT 10752' STILL PUMPING AND WORKING THRU HIGH ANGLE AND TIGHT TBG. 22:10 AT11850' PULL UP AND TIE IN FOR DEPTH CONTROL. (USE MWD LOG GAMMA RAY) 22:45 SHOOT GUN WITH TOP SHOT AT 11760', BOTTOM SHOT 11780' TBG. PRESS ON SURFACE 1650 PSI BEFORE AND 1350 PSI AFTER GUN SHOT. GOOD INDICATION ON SURFACE. POOH 00:30 AT SURFACE WITH GUN, CHECK FOR MISFIRES, RDMO. RETURN WELL TO DSO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $2,500.00 $2,500.00 LITTLE RED $2,860.00 $2,860.00 SCH LUMB ERG ER $13,500.00 $13,500.00 TOTAL FIELD ESTIMATE $18,860.00 $18,860.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT fELL SERVICE REPORT -'-K1(1E-36(W4-6)) WELL 1 E-36 DATE 03/04/99 DAY 3 FIELD ESTIMATE JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 1120981810.3 DAILY WORK UNIT NUMBER PERFORATE C4 SAND UNIT #3 OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR ('~ Yes ~ No I ~'~ Yes ~'~ No DS-KONDICS LIGENZA AFC# ICC# I DAILY COST ACCUM COST Si~ 999154 230DSIOEG $32,279 $57,841 InitialTbg IFinalTbg IlnitiallA IFinalIA IlnitialOA IFinalOA ITTLSize IMLn..[I~D~ ,,~"[~t..,h,. 1000PSIJ 700PSIJ 700PSII 500PSI] 250PSI] 250PSI] 0.000 " I 2.750 " ] 11375 FT DAILY SUMMARY RAN MEMORY LOG FROM 11,900 TO 11,300. PERFORATE FROM 11,720 TO 11,735'. 2-1/2" HC, DP, 4 SPF, 180 DEGREE PHASE. [Ped] TIME LOG ENTRY 07:00 MIRU DS CTU & SWS. BATTERIES LOW ON UNIT. WON'T START. PUT HEATERS ON EQUIPMENT. 10:30 TGSM. COLD WEATHER. SLIPS, TRIPS. EVACUATION POINT AT PAD ENTRANCE. 11:10 RIH W/RADIUS, 2.20 X 2.59 MHAA, PORTED XO 0.5', SWS MEMORY TOOLS, TOTAL LENGTH 38.7' 11:40 STOP AT 2,700' FOR DEPTH CORRECTION. 13:35 STOP AT 11,900'. START LOGGING UP TO 11,300' AT 60 FPM. -. 13:50 FLAGGED TUBING AT 11,300°. POH. 15:15 16:00 ON SURFACE. . . PRESSURE TEST TOOLS TO 3500 PSI. SAFETY MEETING. PERF pROcEDURES,' 19:20 PRESSURE TEST LUBE TO 3500 PSI. RIH, CORRECTED DEPTH 11,334' TO TIE IN FLAG'TO TOP SHOT. TIE IN TO FLAG AT 11,317. FLOW BACK LINE TO TANK FROZEN. NEED TO FLOW TO'FLOWLINE. DROP 5/8" BALL. START PUMPING AT 2 BPM. . : · :: PRESSURED UP TO 4,000 PSI BEFORE PIN SHE~RED.'PEH':. PUMPING ~ BPM DOWN WELL BbRE:-' 20:00 20:25 22:20 ON SURFACE. SAFETY MEETING. ALL SHOTS FIRED. RDMO DS. HOT OIL TO DISPLACE FLOWLINE AND WELL. BORE W / 60 / 40 MEOH. ~ · SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $20.00 APC $3,500.00 $6,500.00 ARCO $1,000.00 $1,750.00 DOWELL $19,278.00 $19,278.00 HALLIBURTON $0.00 $4,683.00 LITTLE RED $1,320.00 $6,420.00 RADIUS $0.00 $0.00 SCHLUMBERGER $7,181.25 $19,190.25 TOTAL FIELD ESTIMATE $32,279.25 $57,841.25 ID ICl I I__/I IM G cl lc ICl tJ I I-- lC S WELL LOG TRANSMITTAL To: State of Alaska April 27, 1999 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1E-36, AK-MM-80419 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1Y_~36: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-22927-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22927-00 2" x 5" MD Neutron & Density Logs: 50-029-22927-00 2" x 5" TVD Neutron & Density Logs: 50-029-22927-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia !999 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 0 Ft I I_1_11M G SE I:IL/I r' E S WELL LOG TRANSMYIWAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs April 20, 1999 1E-36, AK-MM-80419 1 LDWG formatted Disc with verification listing. APl#: 50-029-22927-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED ' 50 ', . Date: · ,.;assa Oil & Gas Cons. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 3/12/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATI'N: Sherrie NO. 12431 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date Blueline Sepia 1 E-36 MEMORY GPJCCL 990304 1 1 1 G-07 PRODUCTION PROFILE W/PSP 990218 1 1 1 D-122 C B I./SCMT 990226 1 1 1 D-125 CBLW PSP/SCMT 990220 1 1 2L-323 CBLW PSP/SCMT 990221 1 1 2L-323 PRESS/TEMP SURVEY 990223 1 1 2N-320 CBL/SCMT 990303 1 1 ,2N-345 PRODUCTION PROFILE (PSP) 990227 1 1 SIGNE Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: REGEI\tEt.,, AliSa Oil & Gas Cons. C;omm~ssion An~ora(je 12/21/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12181 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia 1D-110 CBL-SCMT 981020 1 1 2L-329A CBL-SCMT 981122 1 1 2L-329A PRODUCTION LOG 981205 1 1 2L-329A PRODUCTION LOG 981207 1 1 2N-321A CBL-SCMT 981109 1 1 2N-325 CBL-SCMT 981108 1 1 2N-325 MI INJECTION PROFILE 981205 1 1 2N-331 CBL-SCMT 981123 1 1 1 E-35 CEMENT MAPPING LOG 981203 1 1 1 E-35 PRODUCTION LOG 981208 1 1 1 E-36 STATIC PRESS/TEMP 981123 1 1 1G-16 U~q_~ MI INJECTION PROFILE 981202 1 1 1Q-07 STATIC PRESS/TEMP 981119 1 1 1 Y- 15A CBL-SCMT 981109 1 1 2M-34 I~c_. MI INJECTION PROFILE 981110 1 1 2W- 12 PRODUCTION PROFILE 981028 1 1 3F-04 ~(.~ MI INJECTION PROFILE 981203 1 1 3F-12 ~IC. MI INJECTION PROFILE 981204 1 1 3F-19 RST WFL & GLS 981103 1 1 3K-25 ~{[ _, INJECTION PROFILE 981014 1 1 3K-26~~,~ .... ~----~---~ .... INJECTION PROFILE 981014 1 1 ~.,; SIGNE DATE: . Please signland ~.~e co-py~f this transmittal to Sherrie at the above address. Thank you. ~!'~,i~,~,~i~ ~i.~ii i~ .,.: !, ~..~: ~I. ~,,....,I~...~.~ i.~.iit !. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 30, 1998 Mr. Robert W. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1E-36 (Permit No. 98-213) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1E-36. If there are any questions, please call 265-6120. Sincerely, G. L. Alvord Kuparuk Drilling Team Leader AAI Drilling RECEiVFD JAN 1999 ~lasKa Oil & Gas Coil8. C0ffitllI~I0' I GLA/skad STATE OF ALASKA .... LASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~] GAS E~] SUSPENDED E~] ABANDONED'~1 SERVICE r'~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-213 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22927 4 Location of well at surface ~,~.~.~,¢_.~,~,¢ 9 Unit or Lease Name At Top Producing Interval , ! .~. ~' ~-'- ''~' ~ 10 Well Number 1642' FNL, 1335' ,EL, Sec. 28, TI,,, RIOE, UM ' ~-'~-~/~ ]~~;' 1E-36 1869' FNL, 1300' FEL, Sec. 28, Tll N, R10E, UM : . ' KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 41' Pad 72'~ ADL 25660 ALK 470 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~15 Water Depth, ~ offshore 16 No. of Completions 26-Oct-98 09-Nov-98 13-Nov-98~ NA feet MSL 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey ~20 Depth where SSSV set 21 Thickness of permafrost I 12005' MD & 6193' ~D 11939' MD & 6152' ~D YES ~ NO ~ 1823 feet MD 1700 APPROX 22 Type Electric or Other Logs Run MWD/G R/Res/Dens-Neutron 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5¢ H-40 SURF. 121' 24" 9 CY High Lady 9.625" 40¢ L-80 SURF. 6330' 12.25" 608 sx AS III L, 925 sx Class G, 60 sx AS I 7" 26¢ L-80 SURF. 11597' 8.5" 170 sx Class G 4.5" 12.6¢ L-80 11408' 12004' 6.125" 100 sx Class G 24 Pefiorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 11440' N/A 11795'-11815' MD 6063'-6075' ~D 26 ACID, F~CTURE, CEMENT SQUEEZE, ETC 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A Date First Production Method of Operation (Flowing, gas lift, etc.) 1~3/98 Flowing ' A~ch0raae Date of Test Hours Tested PRODUCTION FOF~OIL-BBL GAS-MCF WATER-BBL' CHOKE SIZE J GAS-OIL ~TIO 1~27/98 24 TEST PERIOD 245 154 295 176~ 627 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL G~VI~-API (~rr) Press. 165 1402 24-HOUR RATE: 245 154 295 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit ~re chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ., 9. · 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 11714' 6013' Top Kuparuk A 12005' 6193' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.,~z... ~~'' ~..~.~k.~. -/' Prepared by'Name/Number(.,) Sharon Allsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 12/28/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lE-36 WELL ID: AK9165 TYPE: AFC: AK9165 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:10/26/98 START COMP: RIG:RIG % 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22927-00 10/26/98 (D1) TD: 454'(454) SUPV:DON E. BREEDEN 10/27/98 (D2) TD: 3227' (2773) SUPV:DONALD LUTRICK 10/28/98 (D3) TD: 5400'(2173) SUPV:DONALD LUTRICK 10/29/98 (D4) TD: 6347' (947) SUPV:DONALD LUTRICK 10/30/98 (D5) TD: 6347'( 0) SUPV:DONALD LUTRICK 10/31/98 (D6) TD: 6367' ( 20) SUPV:DONALD LUTRICK 11/01/98 (D7) TD: 8064' (1697) SUPV:DONALD LUTRICK MW: 8.7 rISC: 165 PV/YP: 16/47 DRILLING @ 1179' APIWL: 12.0 Accept rig @ 0500 hrs. 10/26/98. NU diverter system and function test. Spud in and drill from 121' to 454' MW: 9.5 VISC: 120 PV/YP: 31/46 APIWL: 6.5 DRLG Drilling from 454' to 1927' 1690',1180' POH to HWDP. Tight at 1715', MW: 9.8 VISC: 83 PV/YP: 30/34 DRLG AT 6120' APIWL: 4.2 Drilling from 3227' to 5400' MW: 9.8 VISC: 66 PV/YP: 26/29 RIH W/ 9 5/8" CSG APIWL: 3.4 Drilling from 5400' to 6347' MW: 9.6 VISC: 60 PV/YP: 19/22 DRILL OUT STAGE TOOL APIWL: 4.8 Run 9-5/8" casing. Pump cement. ND diverter. NU BOPE. MW: 8.4 VISC: 38 PV/YP: 6/ 6 DRILL 8 1/2" HOLE APIWL: 15.6 Test BOPE to 300/3000 psi. Drill out stage tool and cement. Drill out cement, FE and 20' new formation to 6367' Perform LOT, 13.9 EMW. MW: 9.1 VISC: 55 PV/YP: 18/23 APIWL: 5.9 DRLG Drilling from 6367' to 8064'. CBU. POH to 7510', started swabbing. Pump out of hle to 7355'. Hole packed off. Unable to work pipe down or rotate. Work pipe free. Drill string free after bit reached shoe. Date: 12/28/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/02/98 (D8) TD: 9274'(1210) SUPV:DONALD LUTRICK MW: 9.5 riSC: 64 PV/YP: 20/24 DRLG AT 9750' APIWL: 3.7 Wash and ream from 6367' to 8064'. No problems. Drilling from 8064' to 8994' Had fall incident while servicing top drive. Drilling from 8994' to 9274' 11/03/98 (D9) TD:10010' (736) SUPV:DONALD LUTRICK MW: 9.6 VISC: 68 Pr/Y?: 27/31 DRLG Drilling from 9274' to 10110' APIWL: 3.4 11/04/98 (D10) MW: 9.6 riSC: 47 PV/YP: 17/13 TD:11597'(1587) RIH W/ 7" CSG SUPV:LUTRICK / PUTNAM Drilling from 10110' to 11597' APIWL: 4.0 11/05/98 (Dll) MW: 9.7 VISC: 53 PV/YP: 19/14 TD:11597' ( 0) TEST BOPE SUPV:LUTRICK / PUTNAM RIH w/7" casing to 11597' APIWL: 4.4 11/06/98 (D12) TD:11597' ( 0) SUPV:DONALD LUTRICK MW: 9.7 VISC: 53 PV/YP: 19/14 PU AND RIH W/ 3 1/2" DP Pump cement. Test BOPE to 300/5000 psi. APIWL: 4.4 11/07/98 (D13) TD:11597' ( 0) SUPV:DONALD LUTRICK MW: 12.1 VISC: 72 PV/YP: 49/30 APIWL: 5.4 DRILLING Freeze protect well. Drill out cement and Float equipment to 11550' 11/08/98 (D14) TD:11975' (378) SUPV:DONALD LUTRICK MW: 12.3 VISC: 65 PV/YP: 34/27 INCREASE MW TO 12.5 PPG APIWL: 3.6 Finish drill out cement and float shoe. Drilling from 11597' to 11607' FIT, 16 ppg EMW. Drilling from 11607' to 11713'. Had gas cut mud to surface. Increase mud weight. Drilling from 11713' to 11975' 11/09/98 (D15) TD:12005' ( 30) SUPV:DONALD LUTRICK MW: 12.5 VISC: 77 PV/YP: 42/35 RIH W/ LINER APIWL: 3.5 Drilling from 11975' to 12005'. Had gas to surface. Circ and increase weight to 12.5 ppg. RIH w/ 4.5" liner. 11/10/98 (D16) TD:12005'( 0) SUPV:DON E. BREEDEN MW: 12.6 VISC: 76 PV/YP: 32/43 APIWL: 3.6 CIRCULATING OUT CEMENT CONTAMINATED MUD (LINER CIP @ 0230 HR RIH W/4.5" LINER ASSEMBLY. Date: 12/28/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 11/11/98 (D17) TD:12005' ( 0) SUPV:DON E. BREEDEN 11/12/98 (D18) TD:12005' ( 0) SUPV:DON E. BREEDEN 11/13/98 (D19) TD:12005' ( 0) SUPV:DON E. BREEDEN MW: 12.1 VISC: 62 PV/YP: 31/19 APIWL: 4.8 TESTING CASING & LINER TO 3500 PSI FOR 30 MINUTES. Cement 4.5" liner. MW: 8.3 VISC: 28 PV/YP: 0/ 0 CHANGING RAMS IN BOPS APIWL: 0.0 Run 3.5" completion assembly. MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED - MOVING TO lC PAD, WELL %17 APIWL: 0.0 Continue to run completion assembly. ND BOPE. NU master valve and test. Release rig @ 1500 hrs. 11/13/98. ARCO Alaska, Inc. VVb:LL 1 E-36 11/23/98 L)AY 1 KUPARUK RIVER UNIT ...... /ELL SERVICE REPORT Kl(1E-36(W4-6)) JUI~ bCUUl~b PERFORATE, PERF SUPPORT I~AILY PERF C SAND/SBHP UPI-MA I IUN (DUMP'Lb I b / :;::SU(D(Db~,.%I-UL I KbY I-'bi~:::SUN ~ Yes O No ! (~) Yes O NoI YON Ini lug ~reSS0Psill Final ID 1200PSI I~ress I Initial Inn~r'Anh--10PSII Pinai inner Ann 1200 PSI I initial JUI¢ IXI U IVl ldl- I~ 120981810.3 UP411 NUMUIF_iN ,.~U I-'1- I~VI~UI-~ SCHUROSKY e't~' 7~n n--D-T-F-~ n~ i uute'r-Ann 240 PSI I 240 PSI DALLY SUMMARY PERF WELL UNDER BALANCED WITH 20' X 2 1/2" HC, 4JSPF. FROM 11795' TO 11815'. RAN SBHP LOG AT MID I I PERFS. MID PERF PRESSURE = 3688 PSI [Perf, Pressure Data] TIME LOG ENTRY 11:00 MIRU SCHLUMBERGER AND LITTLE RED SERVICES. 12:00 MAKE UP TOOLS AND TEST ON SURFACE. HOLD TGSM.(COVER GUN SAFETY) 6 TOTAL ON LOCATION. 13:00 PICK UP GUN AND AND PT LUB AND BOP TO 3000 PSI. 13:30 RIH WITH 20' × 2 1/2" HC, 4JSPF PERF GUN, 0 DE(~. PHASE, +- 90 DEG FROM LOW SIDE. CCL, GUN-GAMMA AND ROLLER STEM TOP AND BOTTOM.42' TOTAL 15:15 AT 11950' E-LINE DEPHT. TIE IN TO MWD GAMMA-RAY LOG FOR DEPTH CONTROL. 15:30 EST. BHP AT 2450 PSI. PRESSURED UP 600 PSI ON TBG. EST BHP AT3050 PSI. SET GUN AT 11795' TOP SHOT. SURFACE INDICATION GOOD. LOG TBG. UP TO +-11400'. POOH. PRESSURE AT 850 PSI. 17:00 AT SURFACE WITH TOOLS, BLEED AND BREAK I'UB. ALL SHOTS FIRED. MAKE UP PL TOOLS. 18:00 PT AND RIH WITH CCL, GAMMA-RAY, PRESSURE, TEMP, WITH ROLLER WEIGHTS AT TOP AND BOTTOM. 38' TOTAL. 19:00 AT 11875' TIE FOR DEPTH CONTROL. MAKE STATIC STOPS AT 11805' AND 10300'. MID PERF PRESSURE = 3688 PSI. 20:00 POOH, RDMO. : i' l ljf.I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-01749 Sidetrack No. Page 1 of 4 · -' [li~ -' I :~r,_.-~ Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO - #245 Field KUPARUK RIVER UNIT W~ Well Name & No. PAD-1E/1E-#36 Survey Section Name SPERRY SUN BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 1030.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL D SS[~ Target Description Target Coord. E/W Slot Coord. E/W -808.00 Magn. Declination 27.310 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[-X[ 30m0 10m D Vert. Sec. Azim. 183.75 Magn. to Map Corr. 27.310 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (F'r) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0,00 0,00 0.00 0.00 0.00 TIE IN POINT -- 26-OCT-98 MWD 121.00 0.00 0,00 121.00 121,00 0.00 0.00 0.00 0.00 0.00 9 1/2"MACH 1C-AKO-1.3deg. 26-OCT-98 MWD 191.98 0.79 162.06 70.98 191.98 0.45 -0.47 0.15 1,11 1.11 ! 26-OCT-98 MWD 280.56 0.82 286.95 88.58 280.55 0.88 -0.86 -0.27 1.61 0.03 26-OCT-98 MWD 374.73 2.55 279.76 94.17 374.68 0,50 -0,31 -2.98 1.85 1.84 27-OCT-98 MWD 466.68 5.66 276.30 91.95 466.38 0.09 0.53 -9.50 3.39 3.38 -3.76 i 27-OCT-98 MWD 555.59 8,79 276.65 88.91 554.58 -0,45 1.80 -20.61 3,52 3,52 0.39 27-OCT-98 MWD 647.13 11.15 279.91 91.54 644,73 -1.75 4.14 -36.28 2.65 2.58 3.56 27-OCT-98 MWD 736,57 13.78 277.58 89,44 732,05 -3.39 7.03 -55,36 2,99 2.94 -2.61 27-OCT-98 MWD 827.94 19.04 273,31 91.37 819.67 -4,01 9.33 -81.04 5.90 5,76 -4.67 27-OCT-98 MWD 918,62 22,42 271.22 90,68 904,47 -3.13 10.55 -113.11 3.82 3.73 -2,30 27-OCT-98 MWD 1008.84 24.36 269,76 90,22 987,27 -1,08 10.84 -148.92 2.24 2.15 -1.62 27-OCT-98 MWD 1099.57 27.54 269.24 90.73 1068.85 1,88 10.48 -188.61 3,51 3.50 -0.57 .r' 27-OCT-98 MWD 1192,37 30.61 271.67 92.80 1149.94 4.42 10.89 -233.70 3.54 3.31 2.62 -- 27-OCT-98 MWD 1285.49 32,42 272.93 93,12 1229,33 5.64 12.85 -282.33 2.07 1.94 1.35 27-OCT-98 MWD 1380.56 35.52 272.85 95.07 1308,16 6.44 15.53 -335.37 3,26 3.26 -0.08 27-OCT-98 MWD 1474.93 39.96 272.42 94,37 1382.77 7,57 18.17 -393.06 4.71 4.70 -0.46 27-OCT-98 MWD 1568.44 43.01 272,18 93,51 1452.81 9.14 20.66 -454.95 3.27 3.26 -0.26 27-OCT-98 MWD 1661,41 43,48 270.59 92.97 1520,54 11.78 22.19 -518,62 1.28 0151 -1.71 27-OCT-98 MWD 1753,68 47.13 267.98 92,27 1585,43 16,93 21,33 -584.18 4,44 3.96 -2.83 27-OCT-98 MWD 1847,32 49.83 266,37 93.64 1647.50 24.97 17.85 -654.20 3.16 2,88 -1.72 27~OCT-98 MWD 1940.00 51.40 265,71 92.68 1706.30 34.59 12.90 -725,65 1.78 1,69 -0.71 27-OCT-98 MWD 2033,53 49.55 265,75 93.53 1765,83 44.65 7,53 -797,59 1,98 -1,98 0.04 27-OCT-98 MWD 2126.23 49,24 263.34 92,70 1826,16 55.91 0.84 -867.65 2,00 -0,33 -2.60 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-01749 Sidetrack No. Page 2 of 4 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245 Field KUPARUK RIVER UNIT Well Name & No. PAD-1E/1 E-#36 Survey Section Name SPERRY SUN BHI Rep. ~'jN~"~i~ WELL DATA -- Target TVD (FT) Target Coord. N/S Slot Coord. N/S 1030.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W -808.00 Magn. Declination 27.310 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: lOOft[~ 30m~ lOm~ Vert. Sec. Azim. 183.75 Magn. to Map Corr. 27.310 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Type (F'r) (DD) (DD) (FT) (F-F) (F-F) (FI') (Per 100 FT) Drop (-) Left (-) 27-OCT-98 MWD 2218.79 49.18 260.84 92.56 1886.64 70.07 -8.80 -937.05 2.05 -0.06 -2.70 9 1/2"MACH 1 C-AKO-1.3deg. 27-OCT-98 MWD 2312.58 48.03 258.76 93.79 1948.66 87.02 -21.25 -1006.29 2.07 -1.23 -2.22 27-OCT-98 MWD 2405.13 46.11 253.70 92.55 2011.71 107.36 -37.32 -1072.07 4.51 -2.07 -5.47 27-OCT-98 MWD 2499.99 44.87 249.27 94.86 2078.23 132.95 -58.77 -1136.19 3.58 -1.31 -4.67 27-OCT-98 MWD 2592.59 45.95 242.26 92.60 2143.28 163.89 -85.84 -1196.23 5.51 1.17 ~7.57 27-OCT-98 MWD 2682.84 47.34 237.94 90.25 2205.25 200.26 -118.56 -1253.08 3.81 1.54 -4.79 27-OCT-98 MWD 2775.30 46.04 231.44 92.46 2268.71 242.57 -157.37 -1307.95 5.30 -1.41 -7.03 27-OCT-98 MWD 2868.79 44.17 226.70 93.49 2334.71 289.08 -200.70 -1357.98 4.11 -2.00 -5.07 27-OCT-98 MWD 2961.31 44.83 220.68 92.52 2400.73 338.77 -247.56 -1402.72 4.61 0.71 -6.51 27-OCT-98 MWD 3055.47 44.80 219.30 94.16 2467.53 392.29 -298.40 -1445.37 1.03 -0.03 -1.47 27-OCT-98 MWD 3145.74 45.44 212.79 90.27 2531.26 446.32 -350.08 -1482.95 5.16 0.71 -7.21 28-OCT-98 MWD 3239.95 46.34 208.21 94.21 2596.85 506.70 -408.34 -1517.24 3.62 0.96 -4.86 28-OCT-98 MWD 3332.60 47.90 209.23 92.65 2659.89 568.24 -467.87 -1549.87 1.87 1.68 1.10 , ., 28-OCT-98 MWD 3425.19 48.85 209.04 92.59 2721.39 630.76 -528.33 -1583.57 1.04 1.03 -0.21 ,' 28-OCT-98 MWD 3518.83 49.84 207.87 93.64 2782.40 695.30 -590.78 -1617.41 1.42 1.06 -1.25 28-OCT-98 MWD 3613.75 50.62 206.00 94.92 2843.13 762.36 -655.82 -1650.45 1.72 0.82 -1.97 28-OCT-98 MWD 3706.68 50.85 204.54 92.93 2901.94 829.29 -720.88 -1681.16 1.24 0.25 -1.57 28-OCT-98 MWD 3799.47 52.27 197~80 92.79 2959.67 898.58 -788.60 -1707.34 5.89 1.53 -7.26 28-OCT-98 MWD 3893.88 55.40 192.80 94.41 3015.40 973.22 -862.09 -1727.38 5.41 3.32 -5.30 28-OCT-98 MWD 3986.43 58.47 189.30 92.55 3065.90 1050.13 -938.19 -1742.20 4.59 3.32 -3.78 28-OCT-98 MWD 4079.38 59.34 185.84 92.95 3113.91 1129.53 -1017.08 -1752.67 3.32 0.94 -3,72 28-OCT-98 MWD, 4172.17 59.64 181.46 92.79 3161.04 1209.44 -1096.83 -1757.75 4.08 0.32 -4.72 28-OCT-98 MWD 4264.99 60.09 177.72 92.82 3207.65 1289.48 -1177.08 -1757.17 3.52 0.48 -4.03 28-OCT-98 MWD 4358.24 61.12 178.04 93.25 3253.42 1370.30 -1258.27 -1754.17 1.14 1.10 0.34 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-01749 Sidetrack No. Page 3 of 4 i Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245 Field KUPARUK RIVER UNIT Well Name & No. PAD-1E/1 E-#36 Survey Section Name SPERRY SUN BHI Rep. ~'J~r~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 1030.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -808.00 Magn. Declination 27.310 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft[~ 30m~ lOm~ Vert. Sec. Azim. 183.75 Magn. to Map Corr. 27.310 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'D (DD) (DD) (Fl') (FT) (FT) (F-F) (Per 100 F-r)Drop (-) Left (-) 28-OCT-98 MWD 4451.14 62.76 176.42 92.90 3297.12 1451.74 -1340.14 -1750.20 2.34 1.77 -1.74 9 1/2"MACH 1C-AKO-1.3deg. , -- , 28-0CT-98 MWD 4543.24 64.02 174.36 92.10 3338.37 1533.20 -1422.21 -1743.57 2.42 1.37 -2.24 28-0CT-98 MWD 4636.43 66.10 173.12 93.19 3377.67 1616.41 -1506.20 -1734.35 2.54 2.23 -1.33 28-0CT-98 MWD 4729.62 67.40 170.36 93.19 3414.46 1700.14 -1590.92 -1722.04 3.06 1.39 -2.96 28-0CT-98 MWD 4823.02 68.78 169.29 93.40 3449.31 1784.24 -1676.21 -1706.73 1.82 1.48 -1.15 28-0CT-98 MWD 5009.57 67.90 168.93 186.55 3518.17 1951.99 -1846.46 -1673.98 0.50 -0.47 -0.19 28-0CT-98 MWD 5287.88 67.96 167.92 278.31 3622.74 2200.73 -2099.13 -1622.23 0.34 0.02 -0.36 ... 29-0CT-98 MWD 5565.11 69.13 167.54 277.23 3724.14 2448.73 -2351.25 -1567.39 0.44 0.42 -0.14 . 29-0CT-98 MWD 5845.52 67.97 167.42 280.41 3826.68 2699.26 -2606.03 -1510.81 0.42 -0.41 -0.04 29-0CT-98 MWD 6033.32 70.39 167.79 187.80 3893.43 2867.86 -2777.46 -1473.14 1.30 1.29 0.20 29-0CT-98 MWD 6263.85 69.64 170.61 230.53 3972.23 3077.53 -2990.24 -1432.54 1.19 -0.33 1.22 01-NOV-98 MWD 6523.63 67.41 169.61 259.78 4067.33 3312.44 -3228.38 -1391.04 0.93 -0.86 -0.38 6 3/4"MACH 1XL-AKO-1.2 DEG. 01-NOV-98 MWD 6803.12 69.32 170.19 279.49 4170.38 3564.68 -3484.14 -1345.49 0.71 0.68 0.21 01 -NOV-98 MWD 7077.57 68.39 170.36 274.45 4269.38 3813.60 -3736.43 -1302.25 0.34 -0.34 0.06 -- 01 -NOV-98 MWD 7356.64 67.80 170.72 279.07 4373.49 4065.67 -3991.83 -1259.69 0.24 -0.21 0.13 01 -NOV-98 MWD 7637.46 70.58 170.20 280.82 4473.25 4321.11 -4250.67 -1216.18 1.00 0.99 -0.19 01 -NOV-98 MWD 7917.38 69.80 170.42 279.92 4568.11 4577.25 -4510.26 -1171.85 0.29 -0.28 0.08 02-NOV-98 MWD 8197.07 68.60 170.04 279.69 4667.43 4831.46 -4767.93 -1127.49 0.45 -0.43 -0.14 02-NOV-98 ' MWD 8475.33 67.53 170.34 278.26 4771.37 5082.38 -5022.27 -1083.51 0.40 -0.38 0.11 02-NOV-98 MWD 8754.64 68.86 169.50 279.31 4875.12 5334.18 -5277.58 -1038.11 0.55 0.48 -0.30 02-NOV-98 MWD 8939.73 67,97 169.46 185.09 4943.21 5500.97 -5446.80 -1006.69 0.48 -0.48 -0.02 02-NOV-98 MWD 9221.61 70.59 168.39 281.88 5042.94 5755.81 -5705.50 -956.03 0.99 0.93 -0.38 03-NOV-98 MWD 9501.12 69.30 168.92 279.51 5138.78 6009.31 -5962.93 -904.37 0.49 -0.46 O. 19 03-N 0V.98 MWD 9773.28 68.12 168.68 272.16 5237.60 6254.31 -6211.68 -855.12 0.44 -0.43 -0.09 j~ SURVEY CALCUL,/t, TJON AND FJF--,LO WORKSHEET Job No. 0451-01749 Sidetrack No. Page 4 of 4 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO - #245 Field KUPARUK RIVER UNIT Well Name & No. PAD-1E/1 E-#36 Survey Section Name SPERRY SUN BHI Rep. ~~ WELL DATA -- Target TVD (FT) Target Coord. N/S Slot Coord. N/S 1030.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~- Target Description Target Coord. E/W , Slot Coord. E/W -808.00 Magn. Declination 27.310 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m~ lOm[-J Vert. Sec. Azim. 183.75 Magn. to Map Corr. 27,310 Map North to: OTHER SURVEY DATA Survey Survey. Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FT) (FO (FT) (FO (Per tOO ET) Drop (-) Left (-) -- 03-NOV-98 MWD 10056.59 69.66 168.31 283.31 5339,64 6509.28 -6470.6~6 -802.40 0.56 0.54 -0.13 6 3/4"MACH 1XI-AKO-1,2 DEG. -- __ 04-NOV-98 MWD 10338.22 69.66 167.54 281.63 5437.53 6763.34 -6728.88 -747.16 0.26 0.00 -0.27 04-NOV-98 MWD 10616.08 69.39 169.39 277.86 5534,73 7014.42 -6983.91 -695.11 0.63 -0.10 0.67 04-NOV-98 MWD 10897.20 68.96 169,40 281.12 5634,67 7268.97 -7242.18 -646.75 0.15 -0.15 0.00 04-NOV-98 MWD 11083.65 68,74 169.31 186.45 5701.95 7437.40 -7413.08 -614.63 0,13 -0.12 -0.05 04-NOV-98 MWD 11176.52 66.14 168.78 92.87 5737.57 7520.35 -7497.27 -598.34 2.85 -2.80 -0.57 04-NOV-98 MWD 11271.28 63.82 168,92 94.76 5777.65 7603.33 -7581.51 -581.73 2.45 -2.45 0.15 04-NOV-98 MWD 11363.67 61.15 168.30 92.39 5820.33 7682.42 -7661.83 -565.56 2.95 -2.89 -0.67 04-NOV-98 MWD 11456.98 58.95 168.66 93.31 5866.91 7760.41 -7741.05 -549.41 2.38 -2.36 0.39 04-NOV-98 MWD 11536.49 55.93 168,75 79.51 5909,69 7825.11 -7806.75 -536.28 3.80 -3.80 0.11 08-NOV-98 MWD 11738.88 52.42 172.74 202.39 6028.17 7984.90 -7968.62 -509,78 2.36 -1.73 1.97 6 1/8"HOLE 4 3/4"ROTARY ASSEMB 08-NOV-98 MWD 11833.06 52.02 172.51 94,18 6085.87 8057.93 -8042.44 -500.23 0.47 -0.42 -0.24 08-NOV~98 MWD 11928.63 51.11 175.86 95.57 6145.28 8131.73 -8116.89 -492.63 2.91 -0.95 3.51 09-NOv-98 MWD 11950.43 50.91 175.34 21.80 6159.00 8148.51 -8133.79 -491.33 2.07 -0.92 -2.39 PROJECTED TO TD 09-NOV-98 MWD 12005.00 50.91 175.34 54.57 6193.41 8190.41 -8176.00 -487.89 0.00 0.00 0.00 CLO.DIST=8190.54'AZ1= 183.41 , ,, n Fi I /1_1 I~ OS S E I::l~J I r' E S 01-Dec-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1E-36 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 12,005.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEC 07_ !998 Alaska Oil & Gas Oons. O0mmissio~ Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Kuparuk Unit Kuparuk 1E, Slot 1E-36 1E-36 Job No. AKMMS0419, Surveyed: 9 November, 1998 ORIGINAL DEC 0 ?. 1998 Alaska 0il & Gas Cor~s. Oommbsio~ S UR VEY REPORT 24 November, 1998 Your Ref: API-500292292700 KBE- 112.5' MWD Survey Instrument Surface Coordinates: 5960615.66 N, 549710.74 E (70° 18' 11.4468" N, 149° 35' 50.4048" W) sp~r,r-,~-sun Survey Ref: svyl09 Sperry-Sun Drilling Services Survey Report for 1E-36 Your Ref: API-500292292700 Job No. AKMMS0419, Surveyed: 9 November, 1998 Kuparuk Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -112.50 0.00 121.00 0.000 0.000 8.50 121.00 191.98 0.790 162.060 79.48 191.98 280.56 0.820 286.950 168.05 280.55 374.73 2.550 279.760 262.18 374.68 466.68 5.660 276.300 353.88 466.38 555.59 8.790 276.650 442.08 554.58 647.13 11.150 279.910 532.23 644.73 736.57 13.780 277.580 619.55 732.05 827.94 19.040 273.310 707.17 819.67 918.62 22.420 271.220 791.97 904.47 1008.84 24.360 269.760 874.77 987.27 1099.54 27.540 269.240 956.32 1068.82 1192.37 30.610 271.670 1037.44 1149.94 1285.49 32.420 272.930 1116.83 1229.33- 1380.56 35.520 272.850 1195.66 1308.16 1474.93 39.960 272.420 1270.27 1382.77 1568.44 43.010 272.180 1340.31 1452.81 1661.41 43.480 270.590 1408.04 1520.54 1753.68 47.130 267.980 1472.93 1585.43 1847.32 49.830 266.370 1535.00 1647.50 1940.00 51.400 265.710 1593.80 1706.30 2033.53 49.550 265.750 1653.32 1765.82 2126.23 49.240 263.340 1713.66 1826.16 2218.79 49.180 260.840 1774.14 1886,64 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5960615.66 N 549710.74 0.00 N 0.00 E 5960615.66 N 549710.74 0.47 S 0.15 E 5960615.20 N 549710.89 0.86 $ 0.27W 5960614.80 N 549710.48 0.31S 2.98W 5960615.33 N 549707.77 0.53 N 9.50W 5960616.13 N 549701.24 1.80 N 20.61W 5960617.33 N 549690.12 4.14 N 36.28W 5960619.56 N 549674.44 7.03 N 55.36W 5960622.32 N 549655.34 9.33 N 81.04W 5960624.45 N 549629.64 10.55 N 113.11W 5960625.46 N 549597.56 10.84N 148.92W 5960625.51 N 549561.75 10.48 N 188.60W 5960624.89 N 549522.07 10.89 N 233.70W 5960625.00 N 549476.98 12.85 N 282.33W 5960626.65 N 549428.33 15.53 N 335.38W 5960628.97 N 549375.27 18.17 N 393.06W 5960631.23 N 549317.57 20.66 N 454.95W 5960633.30 N 549255.66 22.19 N 518.62W 5960634.42 N 549191.98 21.33 N 584.18W 5960633.12 N 549126.43 17.85 N 654.20W 5960629.18 N 549056.44 12.90 N 725.66W 5960623.76 N 548985.01 7.53 N 797.60W 5960617.91N 548913.11 0.84N 867.65W 5960610.76 N 548843.11 8.80 S 937.05W 5960600.66 N 548773.77 Dogleg Rate (°~OOft) Vertical Section (ft) E 0.00 E 0.000 0.00 E 1.113 0.45 E 1.611 0.88 E 1.847 0.50 E 3.391 0.09 E 3.521 -0.45 E 2.650 -1.75 E 2.993 -3.39 E 5.903 -4.01 E 3.815 -3.13 E 2.244 -1.08 E 3.515 1.88 E 3.543 4.42 E 2.068 5.64 E 3.261 6.44 E 4.713 7.57 E 3.266 9.14 E 1.276 11.78 E 4.437 16.93 E 3.158 24.97 E 1.781 34.59 E 1.978 44.65 E 2.002 55.91 E 2.046 70.07 Kuparuk 1E Comment Continued... 24 November, 1998 - 14:08 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1E-36 Your Ref: AP1.500292292700 Job No. AKMMS0419, Surveyed: 9 November, 1998 Kuparuk Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2312.58 48.030 258.760 1836.16 1948.66 2405,13 46.110 253.700 1899.21 2011.71 2499.99 44.870 249.270 1965,73 2078.23 2592.59 45.950 242.260 2030.78 2143.28 2682.84 47.340 237.940 2092.75 2205,25 2775.30 46,040 231.440 2156.21 2268.71 2868.79 44.170 226.700 2222,21 2334,71 2961.31 44.830 220.680 2288.23 2400.73 3055.47 44.800 219.300 2355,02 2467,52 3145.74 45.440 212.790 2418.76 2531.26 3239.95 46.340 208.210 2484.35 2596.85 3332,60 47.900 209.230 2547.39 2659,89 3425.19 48.850 209.040 2608.89 2721.39 3518.83 49.840 207.870 2669,90 2782.40 3613.75 50.620 206.000 2730.62 2843.12 3706.68 50.850 204.540 2789.44 2901.94 3799.47 52.270 197.800 2847.17 2959,67 3893.88 55.400 192.800 2902.90 3015.40 3986.43 58.470 189.300 2953.40 3065.90 4079.38 59.340 185.840 3001,41 3113.91 4172.17 59.640 181.460 3048.54 3161.04 4264.99 60.090 177.720 3095.15 3207.65 4358.24 61.120 178.040 3140.92 3253.42 4451.14 62.760 176.420 3184.62 3297.12 4543.24 64.020 174.360 3225,87 3338.37 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 21.25 S 1006.29 W 5960587.75 N 548704.61 E 37.32 S 1072.07 W 5960571.25 N 548638.94 E 58.77 S 1136.19 W 5960549.38 N 548574.96 E 85.83 S 1196.24 W 5960521.91 N 548515.10 E 118.55 S 1253.08 W 5960488.82 N 548458.47 E 157.37 S 1307.95 W 5960449.64 N 548403.86 E 200.70 S 1357.98 W 5960405.98 N 548354.11 E 247.56 S 1402.72 W 5960358.83 N 548309.69 E 298.40 $ 1445.37 W 5960307.70 N 548267.38 E 350.08 S 1482.95 W 5960255.78 N 548230.14 E 408.34 S 1517.25 W 5960197.29 N 548196.23 E 467.87 S 1549.88 W 5960137.54 N 548163.99 E 528.33 S 1583.57 W 5960076.87 N 548130.70 E 590.78 S 1617.41 W 5960014.19 N 548097.27 E 655.82 $ 1650.45 W 5959948.93 N 548064.66 E 720.88 S 1681.16 W 5959883.67 N 548034.38 E 788.60 S 1707.34 W 5959815.78 N 548008.65 E 862.09 S 1727.38 W 5959742.16 N 547989.10 E 938.19 S 1742.20 W 5959665.96 N 547974.79 E 1017.07 S 1752.67 W 5959587.01 N 547964.84 E 1096.83 S 1757.75 W 5959507.23 N 547960.28 E 1177.08 S 1757.17 W 5959426.98 N 547961.39 E 1258.26 S 1754.17 W 5959345.82 N 547964.94 E 1340.14 S 1750.20 W 5959263.97 N 547969.45 E 1422,21 S 1743.57 W 5959181.94 N 547976.62 E Dogleg Rate (°/100ft) 2.067 4.508 3.577 5.514 3.805 5.304 4.110 4.615 1.033 5.158 3.618 1.867 1.037 1.420 1.723 1.241 5.890 5.409 4.587 3.322 4.079 3.518 1.144 2.342 2.423 Vertical Section (ft) 87.02 107.36 132.95 163.89 200.26 242.57 289.08 338.77 392.29 446.32 506.70 568.24 630.76 695.30 762.36 829.29 898.58 973.22 1050.13 1129.53 1209.44 1289.46 1370.30 1451.74 1533.20 Kuparuk 1E Comment Continued... 24 November, 1998 - 14:08 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1E-36 Your Ref: API-500292292700 Job No. AKMMS0419, Surveyed: 9 November, 1998 Kuparuk Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4636.43 66.100 173.120 3265.17 3377.67 4729.62 67.400 170.360 3301.96 3414.46 4823.02 68.780 169.290 3336.81 3449.31 5009.57 67.900 168.930 3405.67 3518.17 5287.88 67.960 167.920 3510.24 3622.74 5565.11 69.130 167.540 3611.64 3724.14 5845.52 67.970 167.420 3714.18 3826.68 6033.32 70.390 167.790 3780.93 3893.43 6263.85 69.640 170.610 3859.73 3972.23 6523.63 67.410 169.610 3954.83 4067.33 6803.12 69.320 170.190 4057.87 4170.37 7077.57 68.390 170.360 4156.87 4269.37 7356.64 67.800 170.720 4260.99 4373.49 7637.46 70.580 170.200 4360.74 4473.24 7917.38 69.800 170.420 4455.61 4568.11 8197.07 68.600 170.040 4554.93 4667.43 8475.33 67.530 170.340 4658.87 4771.37 8754.64 68.860 169.500 4762.62 4875.12 8939.73 67.970 169.460 4830.71 4943.21 9221.61 70.590 168.390 4930.43 5042.93 9501.12 69.300 168.920 5026.28 5138.78 9773.28 68.120 168.680 5125.10 5237.60 10056.59 69.660 168.310 5227.13 5339.63 10338.22 69.660 167.540 5325.03 5437.53 10616.08 69.390 169.390 5422.23 5534.73 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1506.20 S 1734.35 W 5959098.02 N 547986.39 E 1590.92 S 1722.04 W 5959013.38 N 547999.26 E 1676.21 $ 1706.73 W 5958928.20 N 548015.14 E 1846.46 S 1673.98 W 5958758.16 N 548049.02 E 2099.13 S 1622.23 W 5958505.84 N 548102.44 E 2351.25 S 1567.39 W 5958254.09 N 548158.94 E 2606.03 S 1510.82 W 5957999.70 N 548217.20 E 2777.46 S 1473.14 W 5957828.52 N 548256.01 E 2990.24 $ 1432.54 W 5957616.01 N 548298.01 E 3228.38 S 1391.04 W 5957378.15 N 548341.09 E 3484.14 S 1345.49 W 5957122.70 N 548388.33 E 3736.43 S 1302.25 W 5956870.70 N 548433.24 E 3991.83 S 1259.69 W 5956615.59 N 548477.49 E 4250.67 S 1216.18 W 5956357.04 N 548522.71 E 4510.26 $ 1171.85 W 5956097.74 N 548568.76 E 4767.93 S 1127.49 W 5955840.38 N 548614.82 E 5022.27 $ 1083.51 W 5955586.33 N 548660.49 E 5277.58 S 1038.11 W 5955331.33 N 548707.57 E 5446.79 $ 1006.69 W 5955162.32 N 548740.11 E 5705.50 S 956.03 W 5954903.96 N 548792.48 E 5962.93 S 904.38 W 5954646.88 N 548845.84 E 6211.68 S 855.12 W 5954398.46 N 548896.74 E 6470.66 $ 802.41 W 5954139.84 N 548951.17 E 6728.88 $ 747.17 W 5953881.98 N 549008.11 E 6983.91 $ 695.11 W 5953627.30 N 549061.85 E Dogleg Rate (°/lOOft) 2.537 3.058 1.820 0.505 0.337 0.441 0.416 1.302 1.195 0.930 0.710 0.344 0.243 1.005 0.288 0.447 0.397 0.552 0.481 0.995 0.495 0.441 0.557 0.256 0.631 Vertical Section (ft) 1616.41 1700.14 1784.24 1951.99 2200.73 2448.73 2699.26 2867.86 3077.53 3312.44 3564.68 3813.60 4065.67 4321.11 4577.25 4831.46 5082.38 5334.18 5500.97 5755.81 6009.31 6254.31 6509.28 6763.34 7014.42 Kuparuk 1E Comment Continued... 24 November, 1998 - 14:08 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1E-36 Your Ref: API-500292292700 Job No. AKMMS04~I9, Surveyed: 9 November, 1998 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates. Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 10897.20 68.960 169.400 5522.17 5634.67 7242.18 S 646.76 W 5953369.36 N 549111.92 E 11083.65 68.740 169.310 5589.44 5701.94 7413.08 S 614.63 W 5953198.68 N 549145.17 E 11176.52 66.140 168.780 5625.07 5737.57 7497.27 $ 598.34 W 5953114.59 N 549162.02 E 11271.28 63.820 168.920 5665.15 5777.65 7581.51 S 581.74 W 5953030.46 N 549179.18 E 11363.67 61.150 168.300 5707.82 5820.32 7661.83 S 565.56 W 5952950.25 N 549195.89 E 11456.98 58.950 168.660 5754.41 5866.91 7741.05 S 649.41 W 5952871.15 N 549212.56 E 11536.49 55.930 168.750 5797.19 5909.69 7806.75 S 536.29 W 5952805.53 N 549226.12 E 11738.88 52.420 172.740 5915.67 6028.17 7968.62 S 509.78 W 5952643.84 N 549253.69 E 11833.06 52.020 172.510 5973.36 6085.86 8042.44 S 500.23 W 5952570.09 N 549263.73 E 11928.63 51.110 175.860 6032.78 6145.28 8116.89 $ 492.63 W 5952495.69 N 549271.82 E 11950.43 50.910 175.340 6046.50 6159.00 8133.79 S 491.33 W 5952478.80 N 549273.23 E 12005.00 50.910 175.340 6080.91 6193.41 8176.00 S 487.89 W 5952436.61 N 549276.95 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 183.750° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12005.00ft., The Bottom Hole Displacement is 8190.55ft., in the Direction of 183.415° (True). Dogleg Rate (o/looft) 0.153 0.126 2.849 2.452 2.951 2.381 3.799 2.358 0.467 2.906 2.069 0.000 Vertical Section (ft) 7268.97 7437.40 7520.35 7603.33 7682.42 7760.41 7825.11 7984.90 8057.93 8131.73 8148.51 8190.41 Kuparuk 1E Comment Projected Survey Continued... 24 November, 1998 - 14:08 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1E-36 Your Ref: AP1-500292292700 Job No. AKMMS0419, Surveyed: 9 November, 1998 Kuparuk Unit Kuparuk 1E Comments Measured Depth (ft) 0.00 12005.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 6193.41 8176.00 S 487.89 W Comment Tie-on Survey Projected Survey Continued... 24 November, 1998 - 14:08 - 6 - DrillQuest Sperry-Sun Drilling Services North Reference Sheet for IE-36 Kuparuk Unit Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot. Grid Convergence at Surface is 0.379°. Magnetic Declination at Surface is 27.309° (24-Oct-98) True North Magnetic North Grid NOrth l7.3090 26'9300 Magnetic Model: IGBGCF98 Date: 24-Oct-98 Declination: 27.309 Inclination/Dip: 80.618 Horizontal Component: 9337 nT Northerly Component: 8297 nT Easterly Component: 4284 nT Vertical Component: 56511 nT Total Field Strength: 57277 nT Hole Direction Grid North is 0.379° East 'of True North (Grid Convergence) Magnetic North is 27.309° East of True North (Magnetic Declination) Magnetic North is 26.930° East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Subtract 0.379 degrees To convert a Magnetic Direction to a True Direction, Add 27.309 degrees To convert a Magnetic Direction to a Grid Direction, Add 26.930 degrees Kuparuk 1E 24 November, 1998 - 14:08 - 7- DrillQuest 198-213-0 KUPARUK RIV UNIT 1E-36 50- 029-22927-00 PHILLIPS ALASKA ]NC Roll #1: Start: Stop Roll #2: Start Stop MD 12005 TVD 06193 Completion Date: 11/13/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D c 9392 ~/i SCHLUM MEM GR/CCL CH D 9129 '~-4 SPERRY MPT/GR/EWR4/CNP/SLD OH L DEPTH CONTROL t/I~INAL 11300-11850 10/10/99 L DGR/CNP/SLD-MD V/FINAL 6349-12005 L DGR/CNP/SLD-TVD .//FINAL 4001-6193 L DGR/EWR4-MD ~/FINAL 6349-12005 L DGR/EWR4-TVD ~"I~INAL 4001-6193 / L MEM-GR/CCM c~'FINAL 11332-11936 R SRVY CALC ~/ BHI 121-12005. R SRVY RPT j SPERRY 0-12005. Ay CH OH OH OH OH CH 2 CH 5 OH OH 12/7/99 12/8/99 4/20/99 4/27/99 10/21/99 10/27/99 4/27/99 4/27/99 4/27/99 4/27/99 4/27/99 4/27/99 4/27/99 4/27/99 3/12/99 3/18/99 12/21/98 1/5/99 1/5/99 1/5/99 12/1/98 12/2/98 Tuesday, January 09, 2001 Page 1 of 1 TONY KNOWLES, GOVERNOR ALASI~A OIL AND GAS CONSERVATION COMMISSION October 16. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Thomas W. McKav Shallow Sands Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1E-36 ARCO Alaska, Inc. Permit No: 98-213 Sur. Loc. 1030'FSL, 808'FEL, Sec. 16, T1 IN, R10E, UM Btmhole Loc. 1963'FNL, 1287'FEL, Sec. 28, T1 IN, R10E. UM Dear Mr. McKav: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining' additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1E-36. Please note that anv disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1E must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given . spector on the North Slope pager at 659-3607. David W. Jollpston xx -~ Chairn, an ~ _ BY ORDER OF THE OMMISSION dlffEnclosure CC: Dcpamnent of Fish & Gmne. Habitat Section w/o encl. Depamnent of Environmental Conservation w/o encl. STATE OF ALASKA ALAS'~ OIL AND GAS CONSERVATION COMMi'~SION PERMIT TO DRILL ~~,~,~ 20 AAC 25.005 . la. TypeofWork Ddll X Reddll I lb Type of Well ~2 Exploratory Stratigraphic Test Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5.' Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 72' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25660,~LK 470 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1030' FSL, 808' FEL, Sec. 16, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1710' FNL, 1333' FEL, Sec. 28, TllN, R10E, UM 1E-36 #U-630610 At total depth 9. Approximate spud date Amount 1963' FNL, 1287' FEL, Sec. 28, T11N, R10E, UM 10/23/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1E-10 12091' MD 1287' @ TD feet 10.6' @ 350' feet 2560 6233' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 68.99° Maximum surface 3026 psig At total depth (TVD) 3692 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling Length MD TVD MD TVD linclude stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' __200 CF 12.25" 9.625" 40.0# L-80 BTC 6238' 41' 41' 6279' 3999' 1) 162 Sx AS III L & 909 sx Class G 2) 551 sx AS III L & 60 sx AS I 8.5" 7" 26.0# L-80 BTC-Mod 11636' 41' 41' 11677' 5996' 208 Sx Class G 6.125" 4.5" 12.6# L-80 NSTC 614' 11477' 5889' 12091' 6233' 97 sx Class G 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary A L Totaldepth: truemeasuredvertical feetfeet Plugs(measured) ORIGIN Effective depth: measured feet Junk (measured) ........ true vertical feet Casing Length Size Cemented Measur;~d~t.t~ ~ ~ ~r~ l~,cal depth Structural ?(~% ~.~; ~,. Conductor Sudace ~-~' "'~'~'~ ~' ;i~, Intermediate ~ ? ~ ~ Production Liner Perforation depth: measured .~ 0ii & 8a~ ¢,,;011S, true vertical 20. Attachmen'ts Filing fee X Property plat ["- BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot F' Refraction analysis [~ Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ L¢~__ ~ Title Kuparuk Drilling Team Leader Date / Commission Use Only Number I APl number IAppr°val date I Permi~:~ ~,. ~.13 50- O2ff- 2 ~.q 1'") ~ t)~ /O--"[ ~ ~' ~ otherSee cover letterfOrrequirements Conditions of approval Samples required E~ Yes J~ No Mud logrequired F- Yes [~ No Hydrogen sulfidemeasures ~. Yes r'~ No Directional surveyrequired ~ Yes E No Required working pressure forBOPE E~ 2M F' 3M ~ r-; 1OM E 15M Other: u,'~gtnal Signed By Approved by ',}avid W. J0hnst0?comm~ss~oner b~, order of Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Oct 8, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill 1 E-36 Kuparuk Development Production Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1E pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Kuparuk sands in the vicinity of 1E pad. The well is designated as a conventional production well using a 9 5/8" surface casing string, a 7" intermediate casing string, a 4 Y2" liner and 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1 ) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. ~ Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is October 23, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Chip Alvord at (907) 265-6120. Sincerely, Scott Goldb-erg ~ Operations Drilling Engineer CC: Kuparuk 1E-36 Well File Chip Alvord ATO-1200 MJ Loveland NSK6 Drill and Case Plan for 1E-36 Kuparuk Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. , Spud and directionally drill 12 1/4" hole to the surface casing point at 6279' MD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. o · Run and cement 9 5/8" 40# L80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Weatherford Gemaco Stage Collar will be placed in the 9 5/8" casing +2350' MD 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test Make up 8 1/2" bit and BHA and drill stage collar and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town . Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" hole to intermediate casing point at +11,677' MD · Condition hole and mud for casing 10. Run and cement 7" 26# L80 BTC-Mod 11. Make up 6 1/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and faxto town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 1/8" hole to TD at 12,091' · Condition hole and mud for casing 14. Run and cement 4 1/2" 12.6# L80 NSTC Liner 15. Make a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and faxto town 16. Run and land 3 1/2" tubing with gas lift completion 17. Nipple down BOP's. Install production tree and pressure test same. 18. Secure well, release rig 1 E-36 Page 1 SG,10/08/98,vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS Kuparuk 1E-36 Producer Drillinc~ Fluid Type Surface Hole: Intermediate Hole: Production Hole: Extended Bentonite Slurry Low Solids Non-Dispersed System Low Solids Non-Dispersed System Drillinc~ Fluid Properties: Formation Density FV YP PV Filtrate ppg sec/qt lb/100 ft2 cP mi/30 min Permafrost 8.9 120-140 25-40 16-20 12-15 West Sak 9.5-9.8 50-80 15-25 20-26 7-8 Colville 8.8-9.0 35-40 5-8 4-8 8-15 HRZ 9.5 40-50 8-20 15-25 5-6 Kalubik 9.5 40-50 8-20 15-25 5-6 Kuparuk C Sands 12.1 50-60 (Tau 0) 7-9 20-30 12.0 Drillin.q Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps MASP (Maximum Anticipated Surface Pressure): Based on Static Bottom Hole Pressure data from nearby wells, expected reservoir pressures in the Kuparuk sands in the 1 E pad area are approximately 11.65 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 12.1 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 6052'. Calculating MASP based on the most recent reservoir pressure data from nearby wells, and assuming a gas gradient of 0.11 psi/ft from the Kuparuk base to surface, the following MASP can be computed: MASP = (6052 ft)(0.61 - 0.11 psi/ft) = 3026 psi 1 E-36 Page 1 SG, 10/08/98,v. 1 Drilling Area Risks: Drilling risks in the 1E-36 area are lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Borehole instabilty will be addressed through mud treatments and control drilling if necessary. Well Proximity Risks: The nearest existing well to 1E-36 is 1E-10. As designed, the minimum distance between the two wells would be 10.6' at 350' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be p~u. mped down the surface / production casing annulus of a annular disposal permitted existin'~'wel'~-~'~ DS-1E. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumpir~g 'operations. The 1E-36 well will be freeze protected after running the 3 ~" tubing and prior to the drilling rig moving off of the well. 1 E-36 Page 2 SG,10/08/98,v.1 Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200 TVD below permafrost) Surface csg. 9 5/8" 40# L-80 BTC (+/- 6279' MD / 3999' 'I-VD) All depths reference Parker 245 RKB ¢..,;RU 1E-36 Producer CompletL._ , 6-1/8" Hole / 4-1/2" Liner Option I. 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8RD-Mod pin down H. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to surface G. 3-1/2" Camco 5M TRDP-4E SSSV, EUE 8RD-Mod, 3-1/2" x 6' pups installed above & below, EUE 8RD-Mod. Control line and bands. set at +/- 1800' MD F. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to SSSV w/3-1/2"x 1" Camco 'KBMM' mandrels w/DV's & BK latches, EUE 8RD-Mod connections, 3- 1/2" x 6' pups installed L-80 EUE 8RD-Mod. Spaced out as follows: GLM # TVD-RKB MD-RKB TBD TBD TBD E. 3-1/2" x 1-1/2" Camco 'MMM' mandrel w/DV & RK latch, 3-1/2" x 6' pups installed, L-80 EUE 8RD-Mod D. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing C. 3-1/2" Camco "D" landing nipple w/2.75" ID, NoGo profile, EUE 8RD- Mod, 3 1/2" x 6' pups on either side 4-1/2" Liner Top: 200' above 7" shoe (+/- 11477' MD / 5889' TVD) Intermediate csg. 7" 26# L-80 BTC-Mod set above KUP, run to surface (+/- 11677' MD / 5996' TVD) B. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Seal Assembly w/10' of seals and special Iocator to locate in liner tieback sleeve. Locator 5.125" OD, seals 4.0" ID. 3-1/2" x 6' L-80 handling pup installed on top, X© EUE 8RD to NSCT Liner Assembly (run on drillpipe): -- Baker 'C-2' tieback sleeve with Iocator, 6' -- Baker 5" x 7" 'ZXP' Liner Top Isolation Packer -- Baker 5" x 7" 'HMC' Hydraulic Liner Hanger -- Baker '80-40' 10' Seal Bore Extension (4.0" ID seal bore), 4-1/2" NSCT pin down Future Perforations Liner 4-1/2" 12.6# L-80 NSCT (+/- 12091' MD / 6233' TVD) 4-1/2" NSCT landing colladFS/FC SG, 10/8/98, v.1 ARCO Alaska, Inc. Pad 1E 36 slot #36 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 36 Version #4 Our ref : prop3103 License : Date printed : 29-Sep-98 Date created : 16-Aug-98 Last revised : 29-Sep-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 35 26.769 Slot location is nT0 18 11.446,w149 35 50.328 Slot Grid coordinates are N 5960615.553, E 549713.366 Slot local coordinates are 1030.00 N 808.00 W Projection type: alaska - Zone 4, Spheroid: Clarke ~ 1866 Reference North is True North ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 0.00 E 100.00 0.00 270.00 100.00 0.00 N 0.00 E 200.00 0.00 270.00 200.00 0.00 N 0.00 E 250.00 0.00 270.00 250.00 0.00 N 0.00 E 350.00 3.00 270..00 349.95 0.00 S 2.62 W PROPOSAL LISTING Page 1 Your ref : 36 Version #4 Last revised : 29-Sep-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 0.17 KOP 450.00 6.00 270.00 449.63 0.00 S 10.46 W 550.00 9.00 270.00 548.77 0.00 S 23.51 W 650.00 12.00 270.00 647.08 0.00 S 41.74 W 750.00 15.00 270.00 744.31 0.00 S 65.08 W 850.00 18.00 270.00 840.18 0.00 S 93.48 W 950.00 21.00 270.00 934.43 0.00 S 126.85 W 1050.00 24.00 270.00 1026.81 0.00 S 165.12 W 1150.00 27.00 270.00 1117.06 0.00 S 208.16 W 1250.00 30.00 270.00 1204.93 0.00 S 255.87 W 1350.00 33.00 270.00 1290.18 0.00 S 308.12 W 1450.00 36.00 270.00 1372.59 0.00 S 364.75 W 1550.00 39.00 270.00 1451.91 0.00 S 425.62 W 1650.00 42.00 270.00 1527.95 0.00 S 490.56 W 1750.00 45.00 270.00 1600.47 0.00 S 559.38 W 1850.00 48.00 270.00 1669.30 0.00 S 631.91 W 1916.67 50.00 270.00 1713.04 0.00 S 682.23 W 2000.00 49.08 266.95 1767.12 1.68 S 745.59 W 2069.54 48.37 264.34 1813.00 5.64 S 797.69 W 2100.00 48.08 263.17 1833.30 8.11 S 820.27 W 2200.00 47.21 259.29 1900.69 19.36 S 893.28 W 3.00 0.68 3.00 1.54 3.00 2.73 3.00 4.25 3.00 6.11 3.00 8.29 3.00 10.79 3.00 13.61 3.00 16.73 3.00 20.14 3.00 23.84 3.00 27.82 3.00 32.07 3.00 36.56 3.00 41.31 3.00 44.59 Begin Turn to Target 3.00 50.41 3.00 57.77 Base Permafrost 3.00 61.71 3.00 77.71 2300.00 46.47 255.30 1969.11 35.38 S 964.41 W 3.00 98.34 2400.00 45.87 251.22 2038.37 56.13 S 1033.47 W 3.00 123.57 2500.00 45.43 247.08 2108.29 81.57 S 1100.27 W 3.00 153.31 2600.00 45.13 242.87 2178.67 111.60 S 1164.63 W 3.00 187.49 2700.00 44.99 238.64 2249.32 146.17 S 1226.37 W 3.00 226.02 2800.00 45.01 234.40 2320.05 185.16 S 1285.32 W 3.00 268.78 2900.00 45.18 230.17 2390.66 228.47 S 1341.32 W 3.00 315.66 3000.00 45.51 225.98 2460.95 275.99 S 1394.22 W 3.00 366.54 3100.00 45.99 221.84 2530.74 327.59 S 1443.87 W 3.00 421.27 3200.00 46.62 217.78 2599.84 383.11 S 1490.13 W 3.00 479.70 3300.00 47.39 213.82 2668.05 442.42 S 1532.88 W 3.00 541.67 3400.00 48.29 209.96 2735.19 505.34 S 1572.01 W 3.00 607.02 3500.00 49.31 206.21 2801.07 571.71 S 1607.40 W 3.00 675.56 3600.00 50.46 202.58 2865.51 641.34 S 1638.95 W 3.00 747.10 3700.00 51.71 199.08 2928.35 714.05 S 1666.59 W 3.00 821.46 3800.00 53.06 195.70 2989.39 789.63 S 1690.23 W 3.00 898.42 3900.00 54.51 192.44 3048.49 867.87 S 1709.82 W 3.00 977.78 4000.00 56.03 189.30 3105.47 948.57 S 1725.28 W 3.00 1059.31 4100.00 57.64 186.27 3160.17 1031.49 S 1736.60 W 3.00 1142.80 4200.00 59.32 183.35 3212.46 1116.42 S 1743.72 W 3.00 1228.02 4300.00 61.06 180.53 3262.18 1203.12 S 1746.64 W 3.00 1314.72 4400.00 62.85 177.81 3309.21 1291.36 S 1745.35 W 3.00 1402.68 4473.57 64.21 175.86 3342.00 1357.11 S 1741.71 W 3.00 1468.05 4500.00 64.70 175.17 3353.40 1380.88 S 1739.85 W 3.00 1491.65 4600.00 66.59 172.62 3394.64 1471.45 S 1730.14 W 3.00 1581.39 TOp West Sak Sands All data is in feet unless otherwise stated. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 4700.00 68.52 170.14 3432.82 4724.01 68.99 169.55 3441.52 5000.00 68.99 169.55 3540.45 5500.00 68.99 169.55 3719.69 5721.25 68.99 169.55 3799.00 6000.00 68.99 169.55 3898.92 6276.39 68.99 169.55 3998.00 6279.18 68.99 169.55 3999.00 6500.00 68.99 169.55 4078.16 6862.21 68.99 169.55 4208.00 6878.94 68.99 169.55 4214.00 7000.00 68.99 169.55 4257.40 7500.00 68.99 169.55 4436.63 8000.00 68.99 169.55 4615.87 8500.00 68.99 169.55 4795.10 9000.00 68.99 169.55 4974.34 9409.13 68.99 169.55 5121.00 9500.00 68.99 169.55 5153.57 9908.47 68.99 169.55 5300.00 10000.00 68.99 169.55 5332.81 10500.00 68.99 169.55 5512.05 10801.15 68.99 169.55 5620.00 11000.00 68.99 169.55 5691.28 11117.73 68.99 169.55 5733.48 11193.99 67.09 169.55 5762.00 11200.00 66.94 169.55 5764.35 11300.00 64.44 169.55 5805.52 11400.00 61.94 169.55 5850.62 11500.00 59.44 169.55 5899.58 11539.59 58.45 169.55 5920.00 11600.00 56.94 169.55 5952.29 11658.81 55.47 169.55 5985.00 11677.47 55.00 169.55 5995.64 11777.46 55.00 169.55 6052.99 11777.47 55.00 169.55 6053.00 11873.36 55.00 169.55 6108.00 11896.03 55.00 169.55 6121.00 11903.00 55.00 169.55 6125.00 12000.00 55.00 169.55 6180.64 12091.29 55.00 169.55 6233.00 1562.81 S 1716.28 W 1584.84 S 1712.33 W 1838.21 S 1665.59 W 2297.24 S 1580.93 W 2500.36 S 1543.46 W 2756.27 S 1496.26 W 3010.01 S 1449.46 W 3012.57 S 1448.98 W 3215.30 S 1411.59 W 3547.82 S 1350.25 W 3563.19 S 13~7.42 W 3674.32 S 1326.92 W 4133.35 S 1242.25 W 4592.38 S 1157.58 W 5051.40 S 1072.92 W 5510.43 S 988.25 W 5886.04 S 918.97 W 5969.46 S 903.58 W 6344.46 S 834.41 W 6428.49 S 818.91 W 6887.51 S 734.24 W 7163.99 S 683.25 W 7346.54 S 649.58 W 7454.62 S 629.64 W 7524.17 S 616.81 W 7529.61 S 615.81 W 7619.23 S 599.28 W 7706.99 S 583.09 W 7792.73 S 567.27 W 7826.08 S 561.12 W PROPOSAL LISTING Page 2 Your ref : 36 Version #4 Last revised : 29-Sep-98 Dogleg Vert Deg/100ft Sect 3.00 1671.66 3.00 1693.38 EOC 0.00 1943.16 0.00 2395.67 0.00 2595.90 WS10 0.00 2848.18 0.00 3098.31 C90 0.00 3100.84 9 5/8" Casing Pt 0.00 3300.69 0.00 3628.49 C80 0.00 3643.64 Campania~ SS 0.00 3753.20 0.00 4205.71 0.00 4658.22 0.00 5110.73 0.00 5563.24 0.00 5933.52 C50 0.00 6015.76 0.00 6385.43 C40 0.00 6468.27 0.00 6920.78 0.00 7193.33 C30 0.00 7373.29 0.00 7479.83 Begin Angle Drop 2.50 7548.40 C20 2.50 7553.76 2.50 7642.10 2.50 7728.62 2.50 7813.14 2.50 7846.02 Base KRZ 7876.29 S 551.86 W 2.50 7924.35 S 542.99 W 2.50 7939.42 S 540.21 W 2.50 8019.97 S 525.36 W 0.00 8019.98 S 525.35 W 0.00 8097.23 S 511.10 W 0.00 8115.48 S 507.74 W 0.00 8121.10 S 506.70 W 0.00 8199.24 S 492.28 W 0.00 8272.78 S 478.72 W 0.00 7895.52 7942.89 K-1 Marker 7957.76 End Angle Drop / 7" Csg Pt 8037.16 TARGET - Top Kup C4 8037.17 1E-36 Cony Prod 20-May-98 8113.32 Top C3 8131.32 Top C1 8136.85 Top B Shale 8213.88 8286.38 TD - Csg Pt All data is in feet unless otherwise stated. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 36 Version #4 Last revised : 29-Sep-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 1916.67 1713.04 0.00 S 682.23 W Begin Turn to Target 2069.54 1813.00 5.64 S 797.69 W Base Pez~nafrost 4473.57 3342.00 1357.11 S 1741.71 W Top West Sak Sands 4724.01 3441.52 1584.84 S 1712.33 W EOC 5721.25 3799.00 2500.36 S 1543.46 W WSl0 6276.39 3998.00 3010.01 S 1449.46 W C90 6279.18 3999.00 3012.57 S 1448.98 W 9 5/8" Casing Pt 6862.21 4208.00 3547.82 S 1350.25 W C80 6878.94 4214.00 3563.19 S 1347.42 W C~mpanian SS 9409.13 5121.00 5886.04 S 918.97 W C50 9908.47 5300.00 6344.46 S 834.41 W C40 10801.15 5620.00 7163.99 S 683.25 W C30 11117.73 5733.48 7454.62 S 629.64 W Begin Angle Drop 11193.99 5762.00 7524.17 S 616.81 W C20 11539.59 5920.00 7826.08 S 561.12 W Base HRZ 11658.81 5985.00 7924.35 S 542.99 W K-1 Marker 11677.47 5995.64 7939.42 S 540.21 W End Angle Drop / 7" Csg Pt 11777.46 6052.99 8019.97 S 525.36 W TARGET - Top Kup C4 11777.47 6053.00 8019.98 S 525.35 W 1E-36 Cony Prod 20-May-98 11873.36 6108.00 8097.23 S 511.10 W Top C3 11896.03 6121.00 8115.48 S 507.74 W Top C1 11903.00 6125.00 8121.10 S 506.70 W Top B Shale 12091.29 6233.00 8272.78 S 478.72 W TD - Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6279.18 3999.00 3012.57S 1448.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 11677.50 5995.66 7939.45S 540.21W 7" Casing 0.00 0.00 0.00N 0.00E 12091.29 6233.00 8272.78S 478.72W 4 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1E-36 Conv Prod 20-M 549242.000,5952593.000,2.0000 6053.00 8019.98S 525.35W 20-May-98 ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 36 Version #4 Last revised : 29-Sep-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 1030.00 N 808.00 W 0.00 100.00 0.00 270.00 100.00 1030.00 N 808.00 W 0.00 200.00 0.00 270.00 200.00 1030.00 N 808.00 W 0.00 250.00 0.00 270.00 250.00 1030.00 N 808.00 W 0.00 350.00 3.00 270.00 349.95 1030.00 N 810.62 W 3.00 0.00 0.00 0.00 0.00 KOP 0.17 450.00 6.00 270.00 449.63 1030.00 N 818.46 W 3.00 0.68 550.00 9.00 270.00 548.77 1030.00 N 831.51 W 3.00 1.54 650.00 12.00 270.00 647.08 1030.00 N 849.74 W 3.00 2.73 750.00 15.00 270.00 744.31 1030.00 N 873.08 W 3.00 4.25 850.00 18.00 270.00 840.18 1030.00 N 901.48 W 3.00 6.11 950.00 21.00 270.00 934.43 1030.00 N 934.85 W 3.00 1050.00 24.00 270.00 1026.81 1030.00 N 973.12 W 3.00 1150.00 27.00 270.00 1117.06 1030.00 N 1016.16 W 3.00 1250.00 30.00 270.00 1204.93 1030.00 N 1063.87 W 3.00 1350.00 33.00 270.00 1290.18 1030.00 N 1116.12 W 3.00 8.29 10.79 13.61 16.73 20.14 1450.00 36.00 270.00 1372.59 1030.00 N 1172.75 W 3.00 1550.00 39.00 270.00 1451.91 1030.00 N 1233.62 W 3.00 1650.00 42.00 270.00 1527.95 1030.00 N 1298.56 W 3.00 1750.00 45.00 270.00 1600.47 1030.00 N 1367.38 W 3.00 1850.00 48.00 270.00 1669.30 1030.00 N 1439.91 W 3.00 23.84 27.82 32.07 36.56 41.31 1916.67 50.00 270.00 1713.04 1030.00 N 1490.23 W 3.00 2000.00 49.08 266.95 1767.12 1028.32 N 1553.59 W 3.00 2069.54 48.37 264.34 1813.00 1024.36 N 1605.69 W 3.00 2100.00 48.08 263.17 1833.30 1021.89 N 1628.27 W 3.00 2200.00 47.21 259.29 1900.69 1010.64 N 1701.28 W 3.00 44.59 Begin Turn to Target 50.41 57.77 Base Permafrost 61.71 77.71 2300.00 46.47 255.30 1969.11 994.62 N 1772.41 W 3.00 98.34 2400.00 45.87 251.22 2038,37 973.87 N 1841.47 W 3.00 123.57 2500.00 45.43 247.08 2108.29 948.43 N 1908.27 W 3.00 153.31 2600.00 45.13 242.87 2178.67 918.40 N 1972.63 W 3.00 187.49 2700.00 44.99 238.64 2249.32 883.83 N 2034.37 W 3.00 226.02 2800.00 45.01 234.40 2320.05 844.84 N 2093.32 W 3.00 268.78 2900.00 45.18 230.17 2390.66 801.53 N 2149.32 W 3.00 315.66 3000.00 45.51 225.98 2460.95 754.01 N 2202.22 W 3.00 366.54 3100.00 45.99 221.84 2530.74 702.41 N 2251.87 W 3.00 421.27 3200.00 46.62 217.78 2599.84 646.89 N 2298.13 W 3.00 479.70 3300.00 47.39 213.82 2668.05 587.58 N 2340.88 W 3.00 541.67 3400.00 48.29 209.96 2735.19 524.66 N 2380.01 W 3.00 607.02 3500.00 49.31 206.21 2801.07 458.29 N 2415.40 W 3.00 675.56 3600.00 50.46 202.58 2865.51 388.66 N 2446.95 W 3.00 747.10 3700.00 51.71 199.08 2928.35 315.95 N 2474.59 W 3.00 821.46 3800.00 53.06 195.70 2989.39 240.37 N 2498.23 W 3.00 898.42 3900.00 54.51 192.44 3048.49 162.13 N 2517.82 W 3.00 977.78 4000.00 56.03 189.30 3105.47 81.43 N 2533.28 W 3.00 1059.31 4100.00 57.64 186.~7 3160.17 1.49 S 2544.60 W 3.00 1142.80 4200.00 59.32 183.35 3212.46 86.42 S 2551.72 W 3.00 1228.02 4300.00 61.06 180.53 3262.18 173.12 S 2554.64 W 3.00 1314.72 4400.00 62.85 177.81 3309.21 261.36 S 2553.35 W 3.00 1402.68 4473.57 64.21 175.86 3342.00 327.11 S 2549.71 W 3.00 1468.05 Top West Sak Sands 4500.00 64.70 175.17 3353.40 350.88 S 2547.85 W 3.00 1491.65 4600.00 66.59 172.62 3394.64 441.45 S 2538.14 W 3.00 1581.39 All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 16, T11N, R10E and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C O O R D I N 4700.00 68.52 170.14 3432.82 532.81 S 4724.01 68.99 169.55 3441.52 554.84 S 5000.00 68.99 169.55 3540.45 808.21 S 5500.00 68.99 169.55 3719.69 1267.24 S 5721.25 68.99 169.55 3799.00 1470.36 S 6000.00 68.99 169.55 3898.92 1726.27 S 6276.39 68.99 169.55 3998.00 1980.01 S 6279.18 68.99 169.R5 3999.00 1982.57 S 6500.00 68.99 169.55 4078.16 2185.30 S 6862.21 68.99 169.55 4208.00 2517.82 S 6878.94 68.99 169.55 4214.00 2533.19 S 7000.00 68.99 169.55 4257.40 2644.32 S 7500.00 68.99 169.55 4436.63 3103.35 S 8000.00 68.99 169.55 4615.87 3562.38 S 8500.00 68.99 169.55 4795.10 4021.40 S 9000.00 68.99 169.55 4974.34 4480.43 S 9409.13 68.99 169.55 5121.00 4856.04 S 9500.00 68.99 169.55 5153.57 4939.46 S 9908.47 68.99 169.55 5300.00 5314.46 S 10000.00 68.99 169.55 5332.81 5398.49 S 10500.00 68.99 169.55 5512.05 5857.51 S 10801.15 68.99 169.55 5620.00 6133.99 S 11000.00 68.99 169.55 5691.28 6316.54 S 11117.73 68.99 169.55 5733.48 6424.62 S 11193.99 67.09 169.55 5762.00 6494.17 S 11200.00 66.94 169.55 5764.35 6499.61 S 11300.00 64.44 169.55 5805.52 6589.23 S 11400.00 61.94 169.55 5850.62 6676.99 S 11500.00 59.44 169.55 5899.58 6762.73 S 11539.59 58.45 169.55 5920.00 6796.08 S 11600.00 56.94 169.55 5952.29 6846.29 S 11658.81 55.47 169.55 5985.00 6894.35 S 11677.47 55.00 169.55 5995.64 6909.42 S 11777.46 55.00 169.55 6052.99 6989.97 S 11777.47 55.00 169.55 6053.00 6989.98 S 11873.36 55.00 169.55 6108.00 7067.23 S 11896.03 55.00 169.55 6121.00 7085.48 S 11903.00 55.00 169.55 6125.00 7091.10 S 12000.00 55.00 169.55 6180.64 7169.24 S 12091.29 55.00 169.55 6233.00 7242.78 S ULAR ATES 2524.28 W 2520.33 W 2473.59 W 2388.93 W 2351.46 W 2304.26 W 2257.46 W 2256.98 W 2219.59 W 2158.25 W 2155.42 W 2134.92 W 2050.25 W 1965.58 W 1880.92 W 1796.25 W 1726.97 W 1711.58 W 1642.41 W 1626.91 W 1542.24 W 1491.25 W 1457.58 W 1437.64 W 1424.81 W 1423.81 W 1407.28 W 1391.09 W 1375.27 W 1369.12 W 1359.86 W 1350.99 W 1348.21 W 1333.36 W 1333.35 W 1319.10 W 1315.74 W 1314.70 W 1300.28 W 1286.72 W PROPOSAL LISTING Page 2 Your ref : 36 Version #4 Last revised : 29-Sep-98 Dogleg Vert Deg/100ft Sect 3.00 1671.66 3.00 1693.38 EOC 0.00 1943.16 0.00 2395.67 0.00 2595.90 WS10 0.00 2848.18 0.00 3098.31 C90 0.00 3100.84 9 5/8" Casing Pt 0.00 3300.69 0.00 3628.49 C80 0.00 3643.64 0.00 3753.20 0.00 4205.71 0.00 4658.22 0.00 5110.73 Campanian SS 0.00 5563.24 0.00 5933.52 0.00 6015.76 0.00 6385.43 0.00 6468.27 C50 C40 0.00 6920.78 0.00 7193.33 C30 0.00 7373.29 0.00 7479.83 Begin Angle Drop 2.50 7548.40 C20 2.50 7553.76 2.50 7642.10 2.50 7728.62 2.50 7813.14 2.50 7846.02 Base HRZ 2.50 7895.52 2.50 7942.89 2.50 7957.76 0.00 8037.16 0.00 8037.17 K-1 Marker End Angle Drop / 7" Csg Pt TARGET - Top Kup C4 1E-36 Cony Prod 20-May-98 0.00 8113.32 Top C3 0.00 8131.32 Top C1 0.00 8136.85 Top B Shale 0.00 8213.88 0,00 8286.38 TD - Csg Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 16, T11N, R10E and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page Your ref : 36 Version Last revised : 29-Sep-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 1916.67 2069.54 4473.57 4724.01 5721.25 6276.39 6279.18 6862.21 6878.94 9409.13 9908.47 10801.15 11117.73 11193.99 11539.59 11658.81 11677.47 11777.46 11777.47 11873.36 11896.03 11903.00 12091.29 250.00 1713.04 1813.00 3342.00 3441.52 3799.00 3998.00 3999.00 4208.00 4214.00 5121.00 5300.00 5620.00 5733 48 5762 00 5920 00 5985 00 5995 64 6052 99 6053.00 6108.00 6121.00 6125.00 6233.00 1030.00 N 808.00 W KOP 1030.00 N 1490.23 W Begin Turn to Target 1024.36 N 1605.69 W Base Permafrost 327.11 S 2549.71 W Top West Sak Sands 554.84 S 2520.33 W EOC 1470.36 S 2351.46 W WS10 1980.01 S 2257.46 W C90 1982.57 S 2256.98 W 9 5/8" Casing Pt 2517.82 S 2158.25 W C80 2533.19 S 2155.42 W Campanian SS 4856.04 S 1726.97 W C50 5314.46 S 1642.41 W C40 6133.99 S 1491.25 W C30 6424.62 S 1437.64 W Begin Angle Drop 6494.17 S 1424.81 W C20 6796.08 S 1369.12 W Base HRZ 6894.35 S 1350.99 W K-1 Marker 6909.42 S 1348.21 W End Angle Drop / 7" Csg Pt 6989.97 S 1333.36 W TARGET - Top Kup C4 6989.98 S 1333.35 W 1E-36 Cony Prod 20-May-98 7067.23 S 1319.10 W Top C3 7085.48 S 1315.74 W Top C1 7091.10 S 1314.70 W Top B Shale 7242.78 S 1286.72 W TD - Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 1030.00N 808.00W 6279.18 3999.00 1982.57S 2256.98W 9 5/8" Casing 0.00 0.00 1030.00N 808.00W 11677.50 5995.66 6909.45S 1348.21W 7" Casing 0.00 0.00 1030.00N 808.00W 12091.29 6233.00 7242.78S 1286.72W 4 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1E-36 Cony Prod 20-M 549242.000,5952593.000,2.0000 6053.00 6989.98S 1333.35W 20-May-98 ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 36 Version #4 Last revised : 29-Sep-98 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 270.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 270.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 250.00 0.00 270.00 250.00 0.00 N 0.00 E 0.00 0.65 0.65 0.38 N/A 350.00 3.00 270.00 349.95 0.00 S 2.62 W 0.17 0.93 0.92 0.53 270.00 450.00 6.00 270.00 449.63 0.00 S 10.46 W 0.68 1.30 1.19 0.68 270.00 550.00 9.00 270.00 548.77 0.00 S 23.51 W 1.54 1.84 1.47 0.83 270.00 650.00 12.00 270.00 647.08 0.00 S 41.74 W 2.73 2.59 1.78 0.99 270.00 750.00 15.00 270.00 744.31 0.00 S 65.08 W 4.25 3.59 2.11 1.15 270.00 850.00 18.00 270.00 840.18 0.00 S 93.48 W 6.11 4.89 2.47 1.33 270.00 950.00 21.00 270.00 934.43 0.00 S 126.85 W 8.29 6.50 2.87 1.52 270.00 1050.00 24.00 270.00 1026.81 0.00 S 165.12 W 10.79 8.45 3.29 1.73 270.00 1150.00 27.00 270.00 1117.06 0.00 S 208.16 W 13.61 10.77 3.74 1.97 270.00 1250.00 30.00 270.00 1204.93 0.00 S 255.87 W 16.73 13.49 4.22 2.25 270.00 1350.00 33.00 270.00 1290.18 0.00 S 308.12 W 20.14 16.62 4.72 2.57 270.00 1450.00 36.00 270.00 1372.59 0.00 S 364.75 W 23.84 20.18 5.24 2.93 270.00 1550.00 39.00 270.00 1451.91 0.00 S 425.62 W 27.82 24.19 5.78 3.35 270.00 1650.00 42.00 270.00 1527.95 0.00 S 490.56 W 32.07 28.65 6.32 3.81 270.00 1750.00 45.00 270.00 1600.47 0.00 S 559.38 W 36.56 33.58 6.87 4.34 270.00 1850.00 48.00 270.00 1669.30 0.00 S 631.91 W 41.31 38.97 7.42 4.91 270.00 1916.67 50.00 270.00 1713.04 0.00 S 682.23 W 44.59 42.76 7.78 5.33 270.00 2000.00 49.08 266.95 1767.12 1.68 S 745.59 W 50.41 47.40 8.23 5.84 269.70 2069.54 48.37 264.34 1813.00 5.64 S 797.69 W 57.77 51.14 8.61 6.26 269.23 2100.00 48.08 263.17 1833.30 8.11 S 820.27 W 61.71 52.78 8.78 6.44 269.02 2200.00 47.21 259.29 1900.69 19.36 S 893.28 W 77.71 57.97 9.33 7.03 268.13 2300.00 46.47 255.30 1969.11 35.38 S 964.41 W 98.34 62.95 9.88 7.61 267.09 2400.00 45.87 251.22 2038.37 56.13 S 1033.47 W 123.57 67.71 10.42 8-18 265.94 2500.00 45.43 247.08 2108.29 81.57 S 1100.27 W 153.31 72.24 10.95 8.75 264.71 2600.00 45.13 242.87 2178.67 111.60 S 1164.63 W 187.49 76.56 11.48 9.31 263.42 2700.00 44.99 238.64 2249.32 146.17 S 1226.37 W 226.02 80.64 12.00 9.87 262.08 2800.00 45.01 234.40 2320.05 185.16 S 1285.32 W 268.78 84.50 12.51 10.43 260.72 2900.00 45.18 230.17 2390.66 228.47 S 1341.32 W 315.66 88.13 13.01 10.99 259.33 3000.00 45.51 225.98 2460.95 275.99 S 1394.22 W 366.54 91.54 13.50 11.56 257.94 3100.00 45.99 221.84 2530.74 327.59 S 1443.87 W 421.27 94.73 13.98 12.14 256.54 3200.00 46.62 217.78 2599.84 383.11 S 1490.13 W 479.70 97.70 14.45 12.72 255.16 3300.00 47.39 213.82 2668.05 442.42 S 1532.88 W 541.67 100.46 14.93 13.33 253.79 3400.00 48.29 209.96 2735.19 505.34 S 1572.01 W 607.02 103.01 15.41 13.94 252.45 3500.00 49.31 206.21 2801.07 571.71 S 1607.40 W 675.56 105.36 15.91 14.58 251.13 3600.00 50.46 202.58 2865.51 641.34 S 1638.95 W 747.10 107.50 16.43 15.24 249.85 3700.00 51.71 199.08 2928.35 714.05 S 1666.59 W 821.46 109.46 17.01 15.91 248.61 3800.00 53.06 195.70 2989.39 789.63 S 1690.23 W 898.42 111.23 17.65 16.61 247.41 3900.00 54.51 192.44 3048.49 867.87 S 1709.82 W 977.78 112.82 18.38 17.34 246.27 4000.00 56.03 189.30 3105.47 948.57 S 1725.28 W 1059.31 114.23 19.24 18.09 245.18 4100.00 57.64 186.27 3160.17 1031.49 S 1736.60 W 1142.80 115.48 20.23 18.86 244.14 4200.00 59.32 183.35 3212.46 1116.42 S 1743.72 W 1228.02 116.58 21.41 19.67 243.17 4300.00 61.06 180.53 3262.18 1203.12 S 1746.64 W 1314,72 117.52 22.79 20.50 242.25 4400.00 62.85 177.81 3309.21 1291.36 S 1745.35 W 1402.68 118.32 24.41 21.36 241.40 4473.57 64.21 175.86 3342.00 1357.11 S 1741.71 W 1468.05 118.82 25.79 22.01 240.82 4500.00 64.70 175.17 3353.40 1380.88 S 1739.85 W 1491.65 119.00 26.29 22.24 240.61 4600.00 66.59 172.62 3394.64 1471.45 S 1730.14 W 1581.39 119.55 28.46 23.15 239.89 All data is in feet unless otherwise stated. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth Alaska PROPOSAL LISTING Page 2 Your ref : 36 Version #4 Last revised : 29-Sep-98 R E C T A N G U L A R Vert Ellipse Semi Axes Minor C O O R D I N A T E S Sect Major Minor Vert. Azi. 4700.00 68.52 170.14 3432.82 1562.81 S 1716.28 W 1671.66 120.00 30.93 24.09 239.24 4724.01 68.99 169.55 3441.52 1584.84 S 1712.33 W 1693.38 120.10 31.55 24.31 239.08 5000.00 68.99 169.55 3540.45 1838.21 S 1665.59 W 1943.16 121.41 38.91 26.91 237.10 5500.00 68.99 169.55 3719.69 2297.24 S 1580.93 W 2395.67 124.51 52.56 31.63 232.53 5721.25 68.99 169.55 3799.00 2500.36 S 1543.46 W 2595.90 126.46 58.28 33.72 229.83 6000.00 68.99 169.55 3898.92 2756.27 S 1496.26 W 2848.18 128.93 65.49 36.36 226.43 6276.39 68.99 169.55 3998.00 3010.01 S 1449.46 W 3098.31 132.43 71.74 38.97 222.22 6279.18 68.99 169.55 3999.00 3012.57 S 1448.98 W 3100.84 132.46 71.80 38.99 222.17 6500.00 68.99 169.55 4078.16 3215.30 S 1411.59 W 3300.69 135.26 76.79 41.08 218.81 6862.21 68.99 169.55 4208.00 3547.82 S 1350.25 W 3628.49 141.61 83.35 44.50 212.74 6878.94 68.99 169.55 4214.00 3563.19 S 1347.42 W 3643.64 141.91 83.65 44.66 212.46 7000.00 68.99 169.55 4257.40 3674.32 S 1326.92 W 3753.20 144.03 85.84 45.80 210.43 7500.00 68.99 169.55 4436.63 4133.35 S 1242.25 W 4205.71 155.26 92.54 50.53 202.61 8000.00 68.99 169.55 4615.87 4592.38 S 1157.58 W 4658.22 168.50 97.31 55.26 196.24 8500.00 68.99 169.55 4795.10 5051.40 S 1072.92 W 5110.73 183.14 100.75 59.98 191.40 9000.00 68.99 169.55 4974.34 5510.43 S 988.25 W 5563.24 198.70 103.34 64.71 187.80 9409.13 68.99 169.55 5121.00 5886.04 S 918.97 W 5933.52 211.91 105.01 68.58 185.60 9500.00 68.99 169.55 5153.57 5969.46 S 903.58 W 6015.76 214.85 105.38 69.44 185.10 9908.47 68.99 169.55 5300.00 6344.46 S 834.41 W 6385.43 228.36 106.76 73.30 183.42 10000.00 68.99 169.55 5332.81 6428.49 S 818.91 W 6468.27 231.39 107.07 74.17 183.04 10500.00 68.99 169.55 5512.05 6887.51 S 734.24 W 6920.78 248.19 108.54 78.89 181.42 10801.15 68.99 169.55 5620.00 7163.99 S 683.25 W 7193.33 258.43 109.33 81.74 180.65 11000.00 68.99 169.55 5691.28 7346.54 S 649.58 W 7373.29 265.19 109.85 83.62 180.13 11117.73 68.99 169.55 5733.48 7454.62 S 629.64 W 7479.83 269.22 110.14 84.74 179.87 11193.99 67.09 169.55 5762.00 7524.17 S 616.81 W 7548.40 271.79 110.33 85.44 179.70 11200.00 66.94 169.55 5764.35 7529.61 S 615.81 W 7553.76 271.99 110.35 85.49 179.69 11300.00 64.44 169.55 5805.52 7619.23 S 599.28 W 7642.10 275.29 110.60 86.38 179.49 11400.00 61.94 169.55 5850.62 7706.99 S 583.09 W 7728.62 278.52 110.85 87.23 179.31 11500.00 59.44 169.55 5899.58 7792.73 S 567.27 W 7813.14 281.67 111.10 88.04 179.14 11539.59 58.45 169.55 5920.00 7826.08 S 561.12 W 7846.02 282.88 111.19 88.35 179.08 11600.00 56.94 169.55 5952.29 7876.29 S 551.86 W 7895.52 284.73 111.34 88.82 178.98 11658.81 55.47 169.55 5985.00 7924.35 S 542.99 W 7942.89 286.49 111.49 89.25 178.89 11677.47 55.00 169.55 5995.64 7939.42 S 540.21 W 7957.76 287.05 111.54 89.39 178.86 11777.46 55.00 169.55 6052.99 8019.97 S 525.36 W 8037.16 290.04 111.78 90.13 178.72 11777.47 55.00 169.55 6053.00 8019.98 S 525.35 W 8037.17 290.04 111.78 90.13 178.72 11873.36 55.00 169.55 6108.00 8097.23 S 511.10 W 8113.32 292.92 112.02 90.84 178.59 11896.03 55.00 169.55 6121.00 8115.48 S 507.74 W 8131.32 293.59 112.08 91.01 178.56 11903.00 55.00 169.55 6125.00 8121.10 S 506.70 W 8136.85 293.80 112.10 91.06 178.55 12000.00 55.00 169.55 6180.64 8199.24 S 492.28 W 8213.88 296.71 112.34 91.77 178.41 12091.29 55.00 169.55 6233.00 8272.78 S 478.72 W 8286.38 299.45 112.56 92.45 178.30 All data is in feet unless otherwise stated. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 36 Version #4 Last revised : 29-Sep-98 POSITION UNCERTAINTY SUM~B~Y Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 12091 ARCO (H.A. Mag) User specified 299.45 112.56 92.45 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the correspondin~ errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trakmanual. Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 1916.67 2069.54 4473.57 4724.01 5721.25 6276.39 6279 18 6862 21 6878 94 9409 13 9908 47 10801 15 11117 73 11193 99 11539.59 11658.81 11677.47 11777.46 11777.47 11873.36 11896.03 11903.00 12091.29 1713.04 1813.00 3342.00 3441.52 3799.00 3998.00 3999 00 4208 00 4214 00 5121 00 5300 00 5620 00 5733.48 5762.00 5920.00 5985.00 5995.64 6052.99 6053.00 6108.00 6121.00 6125.00 6233.00 0.00 5.64 1357.11 1584.84 2500.36 3010.01 3012.57 3547.82 3563.19 5886.04 6344 46 7163 99 7454 62 7524 17 7826 08 7924 35 7939 42 8019.97 8019.98 8097.23 8115.48 8121.10 8272.78 682.23 797.69 1741.71 1712.33 1543.46 1449.46 1448.98 1350.25 1347.42 918.97 834.41 683.25 629.64 616.81 561 12 542 99 540 21 525 36 525 35 511 10 507.74 506.70 478.72 W Begin Turn to Target W Base Permafrost W Top West Sak Sands W EOC W WS10 W C90 W 9 5/8" Casing Pt W C80 W Campanian SS W C50 W CiO W C30 W Begin Angle Drop W C20 W Base HRZ W K-1 Marker W End Angle Drop / 7" Csg Pt W TARGET - Top Kup C4 W 1E-36 Cony Prod 20-May-98 W Top C3 W Top C1 W Top B Shale W TD - Csg Pt Casing positions in string 'A' Top MD Top TVD' Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6279.18 3999.00 3012.57S 1448.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 11677.50 5995.66 7939.45S 540.21W 7" Casing 0.00 0.00 0.00N 0.00E 12091.29 6233.00 8272.78S 478.72W 4 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1E-36 Cony Prod 20-M 549242.000,5952593.000,2.0000 6053.00 8019.98S 525.35W 20-May-98 ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 0.00 0.00 0.00N 0.00E 100.00 0.00 270.00 100.00 0.00N 0.00E 200.00 0.00 270.00 200.00 0.00N 0.00E 250.00 0.00 270.00 250.00 0.00N 0.00E 350.00 3.00 270.00 349.95 0.00S 2.62W 450.00 6.00 270.00 449.63 0000S 10.46W 550.00 9.00 270.00 548.77 0.00S 23.51W 650.00 12.00 270.00 647.08 O.OOS 41.74W 750.00 15.00 270.00 744.31 O.OOS 65.08W 850.00 18.00 270.00 840.18 0.00S 93.48W 950.00 21.00 270.00 934.43 0.00S i26.85W 1050.00 24.00 270.00 1026.81 0.00S 165.12W 1150.00 27.00 270.00 1117.06 0.00S 208.16W 1250.00 30.00 270.00 1204.93 0.00S 255.87W 1350.00 33.00 270.00 1290.18 0.00S 308.12W 1450.00 36.00 270.00 1372.59 0.00S 364.75W 1550.00 39.00 270.00 1451.91 0.00S 425.62W 1650.00 42.00 270.00 1527.95 0.00S 490.56W 1750.00 45.00 270.00 1600.47 0.00S 559.38W 1850.00 48.00 270.00 1669.30 0.00S 631.91W 1916.67 50.00 270.00 1713.04 0.00S 682.23W 2000.00 49.08 266.95 1767.12 1.68S 745.59W 2069.54 48.37 264.34 1813.00 5.64S 797.69W 2100.00 48.08 263.17 1833.30 8.11S 820.27W 2200.00 47.21 259.29 1900.69 19.36S 893.28W 2300.00 46.47 255.30 1969.11 35.38S 964.41W 2400.00 45.87 251.22 2038.37 56.13S 1033.47W 2500.00 45.43 247.08 2108.29 81.57S 1100.27W 2600.00 45.13 242.87 2178.67 111.60S 1164.63W 2700.00 44.99 238.64 2249.32 146.17S 1226.37W 2800.00 45.01 234.40 2320.05 185.16S 1285.32W 2900.00 45.18 230.17 2390.66 228.47S 1341.32W 3000.00 45.51 225.98 2460.95 275.99S 1394.22W 3100.00 45.99 221.84 2530.74 327.59S 1443.87W 3200.00 46.62 217.78 2599.84 383.11S 1490.13W 3300.00 47.39 213.82 2668.05 442.42S 1532.88W 3400.00 48.29 209.96 2735.19 505.34S 1572.01W 3500.00 49.31 206.21 2801.07 571.71S 1607.40W 3600.00 50.46 202.58 2865.51 641.34S 1638.95W 3700.00 51.71 199.08 2928.35 714.05S 1666.59W 3800.00 53.06 195.70 2989.39 789.63S 1690.23W 3900.00 54.51 192.44 3048.49 867.87S 1709.82W 4000.00 56.03 189.30 3105.47 948.57S 1725.28W 4100.00 57.64 186.27 3160.17 1031.49S 1736.60W 4200.00 59.32 183.35 3212.46 1116.42S 1743.72W PROPOSAL LISTING Page 1 Your ref : 36 Version #4 Last revised : 29-Sep-98 Dogleg Vert G R I D C O 0 R D S Deg/100ft Sect Easting Northing 0.00 0.00 549713.37 5960615.55 0.00 0.00 549713.37 5960615.55 0.00 0.00 549713.37 5960615.55 0.00 0.00 549713.37 5960615.55 3.00 0.17 549710.75 5960615.54 3.00 0.68 549702.90 5960615.48 3.00 1.54 549689.86 5960615.39 3.00 2.73 549671.64 5960615.27 3,00 4.25 549648.30 5960615.12 3.00 6.11 549619.90 5960614.92 3.00 8.29 549586.53 5960614.70 3.00 10.79 549548.27 5960614.44 3.00 13.61 549505.23 5960614.15 3.00 16.73 549457.52 5960613.83 3.00 20.14 549405.29 5960613.48 3.00 23.84 549348.66 5960613.10 3.00 27.82 549287.80 5960612.69 3.00 32.07 549222.87 5960612.25 3.00 36.56 549154.05 5960611.79 3.00 41.31 549081.53 5960611.30 3.00 44.59 549031.22 5960610.97 3.00 50.41 548967.87 5960608.86 3.00 57.77 548915.81 5960604.55 3.00 61.71 548893.25 5960601.93 3.00 77.71 548820.32 5960590.19 3.00 98.34 548749.31 5960573.69 3.00 123.57 548680.40 5960552.48 3.00 153.31 548613.78 5960526.60 3.00 187.49 548549.63 5960496.13 3.00 226.02 548488.13 5960461.16 3.00 268.78 548429.45 5960421.77 3.00 315.66 548373.74 5960378.09 3.00 366.54 548321.17 5960330.22 3.00 421.27 548271.88 5960278.30 3.00 479.70 548225.99 5960222.47 3.00 541.67 548183.64 5960162.88 3.00 607.02 548144.94 5960099.70 3.00 675.56 548110.01 5960033.10 3.00 747.10 548078.92 5959963.27 3.00 821.46 548051.78 5959890.38 3.00 898.42 548028.64 5959814.66 3.00 977.78 548009.59 5959736.29 3.00 1059.31 547994.67 5959655.50 3.00 1142.80 547983.91 5959572.51 3,00 1228.02 547977.36 5959487.54 4300.00 61.06 180.53 3262.18 1203.12S 1746.64W 3.00 1314.72 547975.02 4400.00 62.85 177.81 3309.21 1291.36S 1745.35W 3.00 1402.68 547976.91 4473.57 64.21 175.86 3342.00 1357.11S 1741.71W 3.00 1468.05 547980.99 4500.00 64.70 175.17 3353.40 1380.885 1739.85W 3.00 1491.65 547983.01 4600.00 66.59 172.62 3394.64 1471.45S 1730.14W 3.00 1581.39 547993.32 5959400.83 5959223.14 5959132.65 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance-is 8286.62 on azimuth 183.31 de~rees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska Measured Depth 4700.00 4724.01 5000.00 5500.00 5721.25 6000.00 6276.39 6279.18 6500.00 6862.21 6878.94 7000.00 7500.00 8000.00 8500.00 PROPOSAL LISTING Page 2 Your ref : 36 Version #4 Last revised : 29-Sep-98 Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 68.52 170.14 3432.82 1562.81S 1716.28W 3.00 1671.66 548007.80 5959041.39 68.99 169.55 3441.52 1584.84S 1712.33W 3.00 1693.38 548011.90 5959019.39 68.99 169.55 3540.45 1838.21S 1665.59W 0.00 1943.16 548060.33 5958766.36 68.99 169.55 3719.69 2297.24S 1580.93W 0.00 2395.67 548148.08 5958307.96 68.99 169.55 3799.00 2500.36S 1543.46W 0.00 2595.90 548186.90 5958105.11 68.99 169.55 3898.92 2756.27S 1496.26W 0.00 2848.18 548235.82 5957849.55 68.99 169.55 3998.00 3010.01S 1449.46W 0.00 3098.31 548284.32 5957596.16 68.99 169.55 3999.00 3012.57S 1448.98W 0.00 3100.84 548284.81 5957593.60 68.99 169.55 4078.16 3215.30S 1411.59W 0.00 3300.69 548323.56 5957391.15 68.99 169.55 4208.00 3547.82S 1350.25W 0.00 3628.49 548387.13 5957059.08 68.99 169.55 4214.00 3563.19S 1347.42W 0.00 3643.64 548390.06 5957043.73 68.99 169.55 4257.40 3674.32S 1326.92W 0.00 3753.20 548411.31 5956932.75 68.99 169.55 4436.63 4133.35S 1242.25W 0.00 4205.71 548499.05 5956474.34 68.99 169.55 4615.87 4592.38S 1157.58W 0.00 4658.22 548586.80 5956015.94 68.99 169.55 4795.10 5051.40S 1072.92W 0.00 5110.73 548674.54 5955557.54 9000.00 9409.13 9500.00 9908.47 10000.00 10500.00 10801.15 11000.00 11117.73 11193.99 11200.00 11300.00 11400.00 11500.00 11539.59 68.99 169.55 4974.34 5510.43S 988.25W 0.00 5563.24 548762.29 5955099.14 68.99 169.55 5121.00 5886.04S 918.97W 0.00 5933.52 548834.08 5954724.04 68.99 169.55 5153.57 5969.46S 903.58W 0.00 6015.76 548850.03 5954640.73 68.99 169.55 5300.00 6344.46S 834.41W 0.00 6385.43 548921.71 5954266.24 68.99 169.55 5332.81 6428.49S 818.91W 0.00 6468.27 548937.77 5954182.33 68.99 169.55 5512.05 6887.51S 734.24W 0.00 6920.78 549025.52 5953723.93 68.99 169.55 5620.00 7163.99S 683.25W 0.00 7193.33 549078.37 5953447.83 68.99 169.55 5691.28 7346.54S 649.58W 0.00 7373.29 549113.26 5953265.53 68.99 169.55 5733.48 7454.62S 629.64W 0.00 7479.83 549133.92 5953157.59 67.09 169.55 5762.00 7524.178 616.81W 2.50 7548.40 549147.22 5953088.13 66.94 169.55 5764.35 7529.61S 615.81W 2.50 7553.76 549148.26 5953082.70 64.44 169.55 5805.52 7619.23S 599.28W 2.50 7642.10 549165.39 5952993.21 61.94 169.55 5850.62 7706.99S 583.09W 2.50 7728.62 549182.16 5952905.57 59.44 169.55 5899.58 7792.73S 567.27W 2.50 7813.14 549198.56 5952819.94 58.45 169.55 5920.00 7826.08S 561.12W 2.50 7846.02 549204.93 5952786.64 11600.00 11658.81 11677.47 11777.46 11777.47 11873.36 11896.03 11903.00 12000.00 12091.29 56.94 169.55 5952.29 7876.29S 551.86W 2.50 7895.52 549214.53 5952736.50 55.47 169.55 5985.00 7924.35S 542.99W 2.50 7942.89 549223.72 5952688.50 55.00 169.55 5995.64 7939.42S 540.21W 2.50 7957.76 549226.60 5952673.45 55.00 169.55 6052.99 8019.97S 525.36W 0.00 8037.16 549242.00 5952593.01 55.00 169.55 6053.00 8019.98S 525.35W 0.00 8037.17 549242.00 5952593.00 55.00 169.55 6108.00 8097.23S 511.10W 0.00 8113.32 549256.77 5952515.86 55.00 169.55 6121.00 8115.48S 507.74W 0.00 8131.32 549260.26 5952497.63 55.00 169.55 6125.00 8121.10S 506.70W 0.00 8136.85 549261.33 5952492.02 55.00 169.55 6180.64 8199.24S 492.28W 0.00 8213.88 549276.27 5952413.98 55.00 169.55 6233.00 8272.78S 478.72W 0.00 8286.38 549290.33 5952340.54 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 36 Version #4 Last revised : 29-Sep-98 Comments in wellpath ~(D TVD Rectangular Coords. Comment 250.00 250.00 0.00N 0.00E KOP 1916.67 1713.04 0.00S 682.23W Begin Turn to Target 2069.54 1813.00 5.64S 797.69W Base Permafrost 4473.57 3342.00 1357.11S 1741.71W Top West Sak Sands 4724.01 3441.52 1584.84S 1712.33W EOC 5721.25 3799.00 2500.36S 1543.46W WS10 6276.39 3998.00 3010.01S 1449.46W C90 6279.18 3999.00 3012.57S 1448.98W 9 5/8" Casing Pt 6862.21 4208.00 3547.82S 1350.25W C80 6878.94 4214.00 3563.19S 1347.42W Campanian SS 9409.13 5121.00 5886.04S 918.97W C50 - 9908.47 5300.00 6344.46S 834.41W C~0 10801.15 5620.00 7163.99S 683.25W C30 11117.73 5733.48 7454.62S 629.64W Begin Angle Drop 11193.99 5762.00 7524.17S 616.81W C20 11539.59 5920.00 7826.08S 561.12W Base HRZ 11658.81 5985.00 7924.35S 542.99W K-1 Marker 11677.47 5995.64 7939.42S 540.21W End Angle Drop / 7" Csg Pt 11777.46 6052.99 8019.97S 525.36W TARGET - Top Kup C4 11777.47 6053.00 8019.98S 525.35W 1E-36 Cony Prod 20-May-98 11873.36 6108.00 8097.23S 511.10W Top C3 11896.03 6121.00 8115.48S 507.74W Top C1 11903.00 6125.00 8121.10S 506.70W Top B Shale 12091.29 6233.00 8272.78S 478.72W TD - Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6279.18 3999.00 3012.57S 1448.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 11677.50 5995.66 7939.45S 540.21W 7" Casing 0.00 0.00 0.00N 0.00E 12091.29 6233.00 8272.78S 478.72W 4 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1E-36 Cony Prod 20-M 549242.000,5952593.000,2.0000 6053.00 8019.98S 525.35W 20-May~98 5OO lDO0 1500 2OOO 2500 5000 3500 4.000 4500 5OOO 55OO 60O0 6500 ITCreo[cd by finch For: GOLDBERG Dote plotted : 29-Sep-98 Plot Reference is 56 Version C~rdinotcs arc ~n fcct reference ~lot rue Vc~lcol Depths ore~KB (Porker ~245).J ~ m ARCO Alaska, nc. Structure: Pod I E Well : 36 Field : Kuporuk River Unit Location : North Slope, Alaska <- West (feet) 1800 1200 600 0 Begin Turn to Target Base Permafros _ 183.75 AZIMUTH I SURFACELOCAT.ON: I ',~g.~.L 2?0^, RKB ELEVATION: 115' . . I 10.30' FSL, 808' FELI 8037' (TO TARGET) I SEC. 16. TllN, RIOE m KOP TVD=250 TMD=~50 DEP=0 ' ' 3.00 ***Plane of Proposal*** g.o0 15.00 21 O0 ~ Top West Sok Sends ' DLS: 3.00 deg per 100 ft ~ E~C 27.00 35.00 39.00 ,45.00 [.~0~ BEGIN TURN TO TARGET TVD=1715 TMD=1917 DEP=45 ~ B/ PERMAFROST TVD=1813 TMD=2070 DEP=58 ~WSlO Xk 45.01~5'13 . ' C90~0 J~9J~95/85/8 Casing X 45.51 ~46.62 DLS: 3.00 deg per 100 ft 4829 C80~ Campanian SS ~ 53.06 ~ 56.03 .... ~ 59.~2 ~ TARGET LOCATION: ~ 64.70 T/ W SAK SNDS TVD=5342 TMD=4474. DEP=1468 m 1710. FNL, 1333' FEL J~ ~OC 1VD=34¢2 TMD=4724 DEP=1693 I SEC. 28. T11N, ~ . ' TARGET ws~~,uo=s72, ~[~:2se~. MAXIMUM ANGLE ~%:~q¢¢7 ~, C90 TVD~b~/b~P=3098 ~ ' ' = . 9 5/~D~ T~a=6279 DEP=3101~ ~ ~ ~ : = [~' C8~VD~~D=6862 DEP=3~28~ ~%~.o CAMP SS TVD=4214 TMD=6879 DEP=3644 ~ ~C50 TD LOCAmFION: . I m 1963' FNL 1287' FEL. m ~ c40 C50 TVD=5121 TMD=9409 DEP=5934 L SEC. 28, '~'I]N, C40 TVD=5300 TMD=9908 DEP=6385 ....................... C30 ~D=5620 TMD=10801 DEP=7193 BEGIN ANGLE DROP 1'VD=5733 TMD=11118 OEP=7480 C20 TVD=5762 TMD=11194 DEP=7548 . B/ MAF~KFRHR- Jim ~O = 592 O .,Vt)= 59~"' O = 11TMB= 116~9540 EP=' 6694- ~ C30 ENO ANGLE DROP/7" CS¢~ PT -I-VD=59'96 TMD=11~'/7 DEP=?9)8 '%x 59.44. · ~ ~ ~ . ) '. ~ uegm angm urop TARGET - T/ KUI- C4 TVD:6053 TMD= 1. 1.77 ? DEl =8037 2~_ ,g,n *ng,e orop~ C20 m~o~m *~T~T ~ T/ C~ TVD=6108 TM0=11875 DEP=8113~~ .tt&l%tz.~l Z&INkZl~I?~ .T/ C1 ~D=6121 TMD=11896 DEP=81.}!~.%~ ...... T/ BSHALE TVD=6125 TMD=ll903 OEP=8137 ~J .fly .':-~;'~'~.. m ~'--I ..... I .... ~ .... 1 ....... l ...... 1 ...... I---1 .... ~-----7 .... 1 ..... 7 .... I---~ ....... l ~ ......... I ....... I .... ] .... f T r'---I ......... [ .... 1 ..... r~---r-' ' m '"l--'~ ..... ~--~ ....... q ..... j , , ~ [~] 0 500 1000 1500 2000 2500 3000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 60O 1200 1800 2400 3000 3600 4200 4800 540O 6000 6600 720O - 7800 84O0 Vertical Section (feet) -> Azimuth 183.75 with reference 0.00 N, 0.00 E from slot //36 0 c~ot~. ~x ~.c. For: GOLDBERG Date plotted: 29-Sea-98 p~ot Reference ;s 36 Ve~on ~4. C~r~nates are in fee~ reference ~at T~e Verdca] Oept~s are ref~ence ~B (Park~ 240 200 160 120 40 8O 120 160 2OO 240 280 320 360 400 440 480 520 560 aska, Structure : Pad 1E Well : Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 520 480 4-40 400 360 320 280 240 200 160 120 80 40 0 1900 4100 % 58oo FFOU '(~¢ 2500 22OO 40 8O I I ! ! I t I I I I I t ! I I I I ! ! t I t I I f I 24-0 5 ,oo 000 O0 ~1600 ~0 80 % % o 2000 lg00 5700 !800 56OO 5400 1700 5500 3300 1600 1i 1 3200 1500 2100 500 500 2100 2300 2400 2600 ,- 8O 0 120 -.+. 160 CD --t- 200 I '-.-....3400 500 ,60 520 480 440 400 '--'-'-""---~5800 200 O0 3500 3400 3oo '"'------.~3200 '"""---..~100 '"---.............~900 --~---~2700 _~500 ' ' ' ' ' ' ' ' ' ' ' ' ' ' 8'0 ' 4'0 ' ' 360 320 280 240 200 160 120 0 <- West (feet) I 320 5200 ! 360 f440 480 520 , 550 4tt3 8O 280 240 Ic~o~ ox ~h For: GOLDHERG Oate ~lotted : 2g-$~-g8 6OO -I-- (D 700 4-- 800 0 §00 I IA;"RCO Alaska, Inc. :Structure : Pod 1E Well : 36 Field : Kuparuk River Unit Loc~fion : North Siope, Alosko <- West (feet) 2000 1900 1800 1700 1600 1500 1400 1.300 1200 I 1 O0 1000 900 800 700 600 500 400 I I I I I I I t I I I I I I I I I f I I I I I t ! ! ~ ~ ! ' ] 200 20O ~6100 [~700 ~oo % 5800 % 2500 ~6 1700 16~24 O0 ~ ~oo ~oo~ .......... ~~ 5100 ___ 2100 ....... ~ -% 4900 ..... F ~o0 ~ 4700 4~200 / ~ ~600 ~Y--' ~ 4700 0 L 2O0 200 O0 ' 300 ....~"~500 ~~800 ~~ 300 .,,,,/2600 ~ 400 4OO 50O 500 ?oo .oo . / / / 2900 / / / /sooo 24oc~ / ~~oo ' 2900 ~ / 3100 ~ ~ ssoo s~ 1000 ~ 4100 40 ; .... / 2300 I ,lOO ~"" ~~oo r ~oo ¢ ~2~0 ~ 2~00 2~00 2700 2riO0 . [ 3300 1300 , ~ 1300 ~ 1400 1400 370 0 ~ 3~00 ~ I r ~ ~oo ', 350 ~ ~oo~ ~;oo :/ L ~ ~7oo~ / F ~7oo ~ 35oo ~ ~ 1800 , I I I I lTM ~ I I I I I I I I I I i I ~ I I I I I ~ i ~ I 2000 1900 1500 1700 1600 1500 1~00 1300 1200 1100 1000 900 800 700 600 500 400 700 '--4-- 900 I v c~o~ ~ ,;,~ For: GOLDBERG O~t~ ¢otb=d : ~ot Re~e,ence ;s 36 Ve~on ~4. C~rd~notes ore in feet reference ~at 1400 1600 1800 2OO0 2200 2400 2600 2800 /-" 3000 ,--t,-- 3200 .-I--. 0 3400 I V .3600 3800 4000 4200 4400 4600 4800 5000 5200 Structure : Pad 1E 36 r Field : Kuporuk River Unit h Slope, Aloskc <- West (feet) 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 I I I I I I I I I I I I I 39~/~ ~ '300 '.~ ~ 3500 3700/ 4300/ ~ 4900 , 5100 510~ X 5100 2900 i 5500 5700 ~ ' 59oo 6500 6500 ~ 3700 ~ 3~00 ~ 4100 3500 39oo; 57OO 61 4700 6500 5100 4300 4700 ~ 41 O0 3900 4100 4300 i4500 4700 5300 5500 4~0 200 0 2i00 3500 3700 3900 ¢300 5700 3900 41 O0 4300 5300 3700 .3900 55O0/ 4500 5700/ 5900/ 4700 6300/ O0 ~,~ ~100 I I I I I I I I i i i i i i i i i I i i I I i i i i I 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 <- West (feet) 1400 1600 1800 2OOO 2200 2400 2600 2800 3000 3200 3400 I 36oo V 3800 4000 4200 t4400 4600 48O0 5000 5200 I A-NCO Aiaska c,..~.d by ,;.ch For: GOLDBERG Structure ; Pad 1E ...... II 56 ~o~., ...... ~,~sv.~o~4. Field : Kuparuk River Unit Location : North Slope, C~rd~note~ ar~ ]n ~cet r~fe~ence ~at ~6. J T~¢ Ve~ical <- West (feet) 2600 2400 2200 2000 ltl00 1600 ~400 1200 1000 800 600 ~1400 200 0 200 400 600 I I I I f 1 ~ f I I I I ? I I I . I 4800 , 4700 4800 ~ O0 i ¢g00 ~5oo0 i o 5200 ~ 5200 ~ '"',-..5700 L 5600 ~ 5900 610A' i ceO0 ' ~ I 6000 i l aooo I 6200 62o0 \ o 6600 , ; 5500 ~' ~ 7000 V . i 7200 7400 i h 7400 ~6oo i ~76oo 7800 ~ 5900 7800 8000 8000 ~200 ~ ~ 8200 8400 8~00 8600 8600 I [ I I I I I I I I I I I I I I I I I I I I i I J I I I I I I 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 400 600 <- West (feet) 6400 6600 6800 I V 7000 RC0 Alaska, in Structure : Pad I E Well: ~6 /Field : Kuparuk River Unit Location : North Slope, AlaskaI WELL FIROFILE DATA ..... Point ..... ~10 thc Oir I'VD Narth Eaa[ V. S~c[ Deg/lOO T;e an 0.00 0.CO 0.O0 0.00 O.C0 0.00 0.00 0.~ ~P 2~.C0 0.~ 270.~ 250.00 0.CO O.C0 O. C0 0.~ ~;n Turn to To,et Ig16.67 ~.~ 270.~ 1713.04 0.~0 -682.2344.59 End ef 8~;!d~urn ~724.01 88.gg t69.555~t.52 -15a~.8~ -1712.35 t695.Sa End of H~d I 1117.73 68.gg 169.555753.48 -745~.62 -62g.6~7479.85 End af ~op/Tum11677.4755.~ ~69.555995.64 -7939.+2 -540.217957.76 2.~ To,et 1E-38 C~ P~d 11777.4755.C0 169.556055.00 -8019.98 -525.558057.17 0.~ T.0.~E ........ 2 .... 29 55 .... 9.55 6253.00 -6272.78 -478.72 82~6.~ 0.~ TRUE NORTH 350 0 310 320 330 300 10 2O 2go 3O f>,c. For: GOLDBERG1 Cote ;~c,~,e~: Coordinates are ;~ f~t retere~e ~l~ ~. 5O 11 1700 28O 27O 260 33 1300i 50( 8O 90 lO0 250 1!0 230 220 !50 6601 1 40 acc 900 1 5 0 ~°°° ~ ~oo ~ 2 1 0 soo 700 200 1E --I-190-eetl 80 170 Normol Plone Trovelting Cylinder All depths shown ore Measured depths on Reference Well ARCO Alaska, Inc. Pad 1E slot #36 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE Baker Hughes INTEQ REPORT Your ref = 36 Version Our ref = prop3103 License = Date printed = 29-Sep-98 Date created ~ 16-Aug-98 Last revised = 29-Sep-98 Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 35 26.769 Slot location is nT0 18 11.446,w149 35 50.328 Slot Grid coordinates are N 5960615.553, E 549713.366 Slot local coordinates are 1030.00 N 808.00 W Projection ty~e= alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Object we11path GMS <0-7310 GMS <0-7811 GMS <0-7512 GMS <0-7750 GMS <0-7190 GMS <0-8435 GMS <0-7885 GMS <0-8150 GMS <0-7898 GMS <0-8650 GMS <0-7420 GMS <0-9480 GMS <0-8350 GMS <0-7467 GMS <0-6800 TOTCO Survey, >,,30,Pad 1E >,,10,Pad 1E >,,12,Pad 1E >,,13,Pad 1E >,,14,Pad 1E >,,15,Pad 1E >,,17,Pad 1E >,,18,Pad 1E >,,19,Pad 1E >,,20,Pad 1E >,,21,Pad 1E >,,22,Pad 1E >,,23,Pad 1E >,,25,Pad 1E >,,27,Pad 1E ,WS-2,Pad 1E GMS <0-7310'>,,IA,Pad lB MSS <2819-7345'>,,1,Pad 1E GMS <0-8440'>,,2,Pad 1E GMS <0-7195'>,,5,Pad 1E GMS <0-9837'>,,6,Pad 1E GMS <0-9310'>,,7,Pad 1E GMS <O-7590'>,,8,Pad 1E GMS <0-7000'>,,9,Pad 1E GMS <0-8754'>,,11,Pad 1E GMS <0-6835'>,,29,Pad 1E MSS <2370-3605'>,,26,Pad 1E GMS <0-8017'>,,26A, Pad 1E Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 9-Jul-97 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 4-Aug-92 25-Jun-97 4-Aug-92 25-Jun-97 876.4 10.6 227.1 347.0 465.3 587.1 131.5 768.5 807.8 851.0 894.9 941.3 988.2 1087 3 1347 4 3421 8 873 9 873 9 756 8 415 6 310 1 223 8 180 0 133.1 105.9 1109.7 1138.4 941.5 5340 0 350 0 100 0 100 0 450 0 425 0 4575 0 250 0 250 0 0.0 250.0 0.0 200.0 200.0 100.0 275.0 250.0 250.0 250.0 250.0 275.0 100.0 0.0 100.0 425.0 250.0 250.0 7600.0 5340.0 350.0 100.0 425.0 450.0 3750.0 4575.0 250.0 250.0 0.0 250.0 0.0 200.0 200.0 4840.0 6420.0 5900.0 6540.0 250.0 250.0 275.0 100.0 0.0 100.0 425.0 5420.0 5760.0 7600.0 GMS <O-7715~>,,16,Pa~-~E GMS <0-7413'> <Depth Shifted>,,24,Pad 1E PMSS <5538-8167~>,,24A, Pad 1E PMSS <O-11712~>,,34,Pad 1E GMS <0-8905~>,,3,Pad 1E G~S <O-?665~>,,28,Pad 1E PMSS <121 - 9130">,,31PB1,Pad 1E PMSS <8798-10023">,,31,Pad 1E G~S <0-9150~>,,4,Pad 1E PMSS <9010 - 10951~>,,33,Pad 1E PMSS <121-9505~>,,33PB1,Pad 1E PMSS <121 - 10445~>,,32,Pad 1E 9-Jul-97 8-Nov-9? 12-Nov-9? 20-0ct-97 4-Aug-92 4-Aug-92 16-Aug-98 16-Au9-98 4-Aug-92 17-Au~-98 17-Aug-98 1?-Aug-98 441.0 1035.1 1035.1 432.9 639.8 291.3 480.0 480.0 195.8 1074.6 1074.6 839.7 4175 275 275 100 25O 6060 350 35O 6640 100 100 250 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 4175.0 275.0 11233.3 100.0 250.0 6060.0 8360.0 8360.0 6640.0 100.0 100.0 10940.0 7 I · 6 5 4 I 13 1. 16' - 2000 PSI STARTING HEAD 2_ 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 1:~5/8' - 5000 PSI SPACER SPOOL 4 13-5v1~' - 5000 PSI VARIABLE P!PE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR 5/8" 5000 PSi BOP STACK A(~CUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI, TEST ANNULAR PREVENTOR TO 31:X)0 PSI ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES. AND CHOKES WITH A 250 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT 1S NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO~-FOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PS! FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PS! LOW AND 5000 PSI HIGH "KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC 6 I4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES, . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA. INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"° 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL EE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. DKP 11/9,94 ARCO Alaska, I~r ~;..... pK oU sP~ r(~.[,~' txell~ ;;;1~3pment Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Oct 8, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill 1 E-36 Kuparuk Development Production Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1E pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the Kuparuk sands in the vicinity of 1E pad. The well is designated as a conventional production well using a 9 5/8" surface casing string, a 7" intermediate casing string, a 4 1/2" liner and 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1 ) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is October 23, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Chip Alvord at (907) 265-6120. Sincerely, Operations Drilling Engineer~''~ CC: Kuparuk 1E-36 Well File Chip Alvord ATO-1200 MJ Loveland NSK6 Drill and Case Plan for 1E-36 Kuparuk Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 6279' MD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. , · Run and cement 9 5/8" 40# L80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Weatherford Gemaco Stage Collar will be placed in the 9 5/8" casing +2350' MD 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test , Make up 8 F2" bit and BHA and drill stage collar and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town o Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 Y2" hole to intermediate casing point at +11,677' MD · Condition hole and mud for casing 10. Run and cement 7" 26# L80 BTC-Mod 11. Make up 6 1/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 1/8" hole to TD at 12,091' · Condition hole and mud for casing 14. Run and cement 4 Y2" 12.6# L80 NSTC Liner 15. Make a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 16. Run and land 3 Y2" tubing with gas lift completion 17. Nipple down BOP's. Install production tree and pressure test same. 18. Secure well, release rig 1 E-36 Page 1 SG, 10/08/98,vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS Kuparuk 1E-36 Producer Drillinq Fluid Type Surface Hole: Intermediate Hole: Production Hole: Extended Bentonite Slurry Low Solids Non-Dispersed System Low Solids Non-Dispersed System Drillin.q Fluid Properties: Formation Density FV YP PV Filtrate ppg sec/qt lb/100 ft2 cP mi/30 min Permafrost 8.9 120-140 25-40 16-20 12-15 West Sak 9.5-9.8 50-80 15-25 20-26 7-8 Colville 8.8-9.0 35-40 5-8 4-8 8-15 HRZ 9.5 40-50 8-20 15-25 5-6 Kalubik 9.5 40-50 8-20 15-25 5-6 Kuparuk C Sands 12.1 50-60 (Tau 0) 7-9 20-30 12.0 Drilling Fluid System' Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps MASP (Maximum Anticipated Surface Pressure): Based on Static Bottom Hole Pressure data from nearby wells, expected reservoir pressures in the Kuparuk sands in the 1 E pad area are approximately 11.65 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 12.1 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 6052'. Calculating MASP based on the most recent reservoir pressure data from nearby wells, and assuming a gas gradient of 0.11 psi/ft from the Kuparuk base to surface, the following MASP can be computed: MASP = (6052 ft)(0.61 - 0.11 psi/fi) = 3026 psi 1 E-36 Page 1 SG,10/08/98,v.1 Drilling Area Risks: Drilling risks in the 1E-36 area are lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Borehole instabilty will be addressed through mud treatments and control drilling if necessary. Well Proximity Risks: The nearest existing well to 1E-36 is 1E-10. As designed, the minimum distance between the two wells would be 10.6' at 350' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a annular disposal permitted existing well on DS-1E. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1E-36 well will be freeze protected after running the 3 Y2" tubing and prior to the drilling rig moving off of the well. 1 E-36 Page 2 SG,10/08/98,v. 1 Weatherford Gemoco 9-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200 TVD below permafrost) Surface csg. 9 5/8" 40# L-80 BTC (+/- 6279' MD / 3999' TVD) All depths reference Parker 245 RKB -K:RU 1 E-36 Producer Complet..=, 6-1/8" Hole / 4-1/2" Liner Option I. 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8RD-Mod pin down H. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to surface G. 3-1/2" Camco 5M TRDP-4E SSSV, EUE 8RD-Mod, 3-1/2" x 6' pups installed above & below, EUE 8RD-Mod. Control line and bands. set at +/- 1800' MD F. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to SSSV w/3-1/2"x 1" Camco 'KBMM' mandrels w/DV's & BK latches, EUE 8RD-Mod connections, 3- 1/2" x 6' pups installed L-80 EUE 8RD-Mod. Spaced out as follows: GLM # TVD-RKB MD-RKB TBD TBD TBD E. 3-1/2" x 1-1/2" Camco 'MMM' mandrel w/DV & RK latch, 3-1/2" x 6' pups installed, L-80 EUE 8RD-Mod D. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing C. 3-1/2" Camco "D" landing nipple w/2.75" ID, NoGo profile, EUE 8RD- Mod, 3 1/2" x 6' pups on either side 4-1/2" Liner Top: 200' above 7" shoe (+/- 11477' MD / 5889' TVD) Intermediate csg. 7" 26# L-80 BTCoMod set above KUP, run to surface (+/- 11677' MD / 5996' TVD) B. 1 jt 3~1/2" L-80 EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Seal Assembly w/10' of seals and special Iocator to locate in liner tieback sleeve. Locator 5.125" OD, seals 4.0" ID. 3-1/2" x 6' L-80 handling pup installed on top, XO EUE 8RD to NSCT Liner Assembly (run on ddllDibe~: -- Baker 'C-2' tieback sleeve with Iocator, 6' -- Baker 5" x 7" 'ZXP' Liner Top Isolation Packer -~ Baker 5" x 7" 'HMC' Hydraulic Liner Hanger -- Baker '80-40' 10' Seal Bore Extension (4.0" ID seal bore), 4-1/2" NSCT pin down Future Perforations Liner 4-1/2" 12.6# L-80 NSCT (+/- 12091' MD / 6233' TVD) 4-1/2" NSCT landing colladFS/FC SG, 10/8/98, v. 1 ARCO Alaska, !nc. Pad 1E 36 slot #36 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION D-NCERTAINTIES by Baker Kughes INTEQ Your ref : 36 Version #4 Our ref : prop3103 License : Date printed : 29-Sep-98 Date created : 16-Aug-98 Last revised : 29-Sep-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 35 26.769 Slot location is nT0 18 11.446,w149 35 50.328 Slot Grid coordinates are N 5960615.553, E 549713.366 Slot local coordinates are 1030.00 N 808.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 36 Version #4 Last revised = 29-Sep-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 100.00 0.00 270.00 100.00 0.00 N 0.00 E 0.00 200.00 0.00 270.00 200.00 0.00 N 0.00 E 0.00 250.00 0.00 270.00 250.00 0.00 N 0.00 E 0.00 350.00 3.00 270.00 349.95 0.00 S 2.62 W 3.00 0.00 0.00 0.00 0.00 KOP 0.17 450.00 6.00 270.00 449.63 0.00 S 10.46 W 3.00 550.00 9.00 270.00 548.77 0.00 S 23.51 W 3.00 650.00 12.00 270.00 647.08 0.00 S 41.74 W 3.00 750.00 15.00 270.00 744.31 0.00 S 65.08 W 3.00 850.00 18.00 270.00 840.18 0.00 S 93.48 W 3.00 0.68 1.54 2.73 4.25 6.11 950.00 21.00 270.00 934.43 0.00 S 126.85 W 3.00 1050.00 24.00 270.00 1026.81 0.00 S 165.12 W 3.00 1150.00 27.00 270.00 1117.06 0.00 S 208.16 W 3.00 1250.00 30.00 270.00 1204.93 0.00 S 255.87 W 3.00 1350.00 33.00 270.00 1290.18 0.00 S 308.12 W 3.00 8.29 10.79 13.61 16.73 20.14 1450.00 36.00 270.00 1372.59 0.00 S 364.75 W 3.00 1550.00 39.00 270.00 1451.91 0.00 S 425.62 W 3.00 1650.00 42.00 270.00 1527.95 0.00 S 490.56 W 3.00 1750.00 45.00 270.00 1600.47 0.00 S 559.38 W 3.00 1850.00 48.00 270.00 1669.30 0.00 S 631.91 W 3.00 23.84 27.82 32.07 36.56 41.31 1916.67 50.00 270.00 1713.04 0.00 S 682.23 W 3.00 2000.00 49.08 266.95 1767.12 1.68 S 745.59 W 3.00 2069.54 48.37 264.34 1813.00 5.64 S 79?.69 W 3.00 2100.00 48.08 263.17 1833.30 8.11 S 820.27 W 3.00 2200.00 47.21 259.29 1900.69 19.36 S 893.28 W 3.00 44.59 Begin Turn to Target 50.&l 57.77 Base Permafrost 61.71 77.71 2300.00 46.47 255.30 1969.11 35.38 S 964.41 W 3.00 98.34 2400.00 45.87 251.22 2038.37 56.13 S 1033.47 W 3.00 123.57 2500.00 45.43 247.08 2108.29 81.57 S 1100.27 W 3.00 153.31 2600.00 45.13 242.87 2178.67 111.60 S 1164.63 W 3.00 187.49 2700.00 44.99 238.64 2249.32 146.17 S 1226.37 W 3.00 226.02 2800.00 45.01 234.40 2320.05 185.16 S 1285.32 W 3.00 268.78 2900.00 45.18 230.17 2390.66 228.47 S 1341.32 W 3.00 315.66 3000.00 45.51 225.98 2460.95 275.99 S 1394.22 W 3.00 366.54 31~0.00 45.99 221.84 2530.74 327.59 S 1443.87 W 3.00 421.27 3200.00 46.62 217.78 2599.84 383.11 S 1490.13 W 3.00 479.70 3300.00 47.39 213.82 2668.05 442.42 S 1532.88 W 3.00 541.67 3400.00 48.29 209.96 2735.19 505.34 S 1572.01 W 3.00 607.02 3S00.00 49.31 206.21 2801.07 571.71 S 1607.40 W 3.00 675.56 3600.00 50.46 202.58 2865.51 641.34 S 1638.95 W 3.00 747.10 3700.00 51.71 199.08 2928.35 714.05 S 1666.59 W 3.00 821.46 3800.00 53.06 195.70 2989.39 789.63 S 1690.23 W 3.00 898.42 3900.00 54.51 192.44 3048.49 867.87 S 1709.82 W 3.00 977.78 4000.00 56.03 189.30 3105.47 948.57 S 1725.28 W 3.00 1059.31 4100.00 57.64 186.27 3160.17 1031.49 S 1736.60 W 3.00 1142.80 4200.00 59.32 183.35 3212.46 1116.42 S 1743.72 W 3.00 1228.02 4300.00 61.06 180.53 3262.18 1203.12 S 1746.64 W 3.00 1314.72 4400.00 62.85 177.81 3309.21 1291.36 S 1745.35 W 3.00 1402.68 4473.57 64.21 175.86 3342.00 1357.11 S 1741.71 W 3.00 1468.05 Top West Sak Sands 4500.00 64.70 175.17 3353.40 1380.88 S 1739.85 W 3.00 1491.65 4600.00 66.59 172.62 3394.64 1471.45 S 1730.14 W 3.00 1581.39 All data is in feet unless otherwise stated. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimLun curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 4700.00 68.52 170.14 3432.82 1562.81 S 1716.28 W 4724.01 68.99 169.55 3441.52 1584.84 S 1712.33 W 5000.00 68.99 169.55 3540.45 1838.21 S 1665.59 W 5500.00 68.99 169.55 3719.69 2297.24 S 1580.93 W 5721.25 68.99 169.55 3799.00 2500.36 S 1543.46 W 6000.00 68.99 169.55 3898.92 2756.27 S 1496.26 W 6276.39 68.99 169.55 3998.00 3010.01 S 1449.46 W 6279.18 68.99 169.55 3999.00 3012.57 S 1448.98 W 6500.00 68.99 169.55 4078.16 3215.30 S 1411.59 W 6862.21 68.99 169.55 4208.00 3547.82 S 1350.25 W PROPOSAL LISTING Page 2 Your ref : 36 Version #4 Last revised : 29-Sep-98 Dogleg Vert Deg/100ft Sect 3.00 1671.66 3.00 1693.38 EOC 0.00 1943.16 0.00 2395.67 0.00 2595.90 W~10 0.00 2848.18 0.00 3098.31 C90 0.00 3100.84 9 5/8" Casing Pt 0.00 3300.69 0.00 3628.49 C80 6878.94 68.99 169.55 4214.00 3563.19 S 1347.42 W 0.00 3643.64 7000.00 68.99 169.55 4257.40 3674.32 S 1326.92 W 0.00 3753.20 7500.00 68.99 169.55 4436.63 4133.35 S 1242.25 W 0.00 4205.71 8000.00 68.99 169.55 4615.87 4592.38 S 1157.58 W 0.00 4658.22 8500.00 68.99 169.55 4795.10 5051.40 S 1072.92 W 0.00 5110.73 9000.00 68.99 169.55 4974.34 5510.43 S 988.25 W 0.00 5563.24 9409.13 68.99 169.55 5121.00 5886.04 S 918.97 W 0.00 5933.52 9500.00 68.99 169.55 5153.57 5969.46 S 903.58 W 0.00 6015.76 9908.47 68.99 169.55 5300.00 6344.46 S 834.41 W 0.00 6385.43 10000.00 68.99 169.55 5332.81 6428.49 S 818.91 W 0.00 6468.27 10500.00 68.99 169.55 5512.05 6887.51 S 734.24 W 0.00 6920.78 10801.15 68.99 169.55 5620.00 7163.99 S 683.25 W 0.00 7193.33 11000.00 68.99 169.55 5691.28 7346.54 S 649.58 W 0.00 7373.29 11117.73 68.99 169.55 5733.48 7454.62 S 629.64 W 0.00 7479.83 11193.99 67.09 169.55 5762.00 7524.17 S 616.81 W 2.50 7548.40 11200.00 66.94 169.55 5764.35 7529.61 S 615.81 W 2.50 7553.76 11300.00 64.44 169.55 5805.52 7619.23 S 599.28 W 2.50 7642.10 11400.00 61.94 169.55 5850.62 7706.99 S 583.09 W 2.50 7728.62 11500.00 59.44 169.55 5899.58 7792.73 S 567.27 W 2.50 7813.14 11539.59 58.45 169.55 5920.00 7826.08 S 561.12 W 2.50 7846.02 11600.00 56.94 169.55 5952.29 7876.29 S 551.86 W 2.50 7895.52 11658.81 55.47 169.55 5985.00 7924.35 S 542.99 W 2.50 7942.89 11677.47 55.00 169.55 5995.64 7939.42 S 540.21 W 2.50 7957.76 11777.46 55.00 169.55 6052.99 8019.97 S 525.36 W 0.00 8037.16 11777.47 55.00 169.55 6053.00 8019.98 S 525.35 W 0.00 8037.17 Campanian SS C50 C40 C30 Begin A~gle Drop C20 Base HRZ K-1 Marker End Angle Drop / 7" Csg Pt TARGET - Top Kup C4 1E-36 Cony Prod 20-May-98 11873.36 55.00 169.55 6108.00 8097.23 S 511.10 W 0.00 8113.32 Top C3 11896.03 55.00 169.55 6121.00 8115.48 S 507.74 W 0.00 8131.32 Top C! 11903.00 55.00 169.55 6125.00 8121.10 S 506.70 W 0.00 8136.85 Top B Shale 12000.00 55.00 169.55 6180.64 8199.24 S 492.28 W 0.00 8213.88 12091.29 55.00 169.55 6233.00 8272.78 S 478.72 W 0.00 8286.38 TD - Csg Pt All data is in feet unless otherwise stated. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole dista~ce is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 36 Version #4 Last revised : 29-Sep-98 Conunents in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 1916.67 2069.54 4473.57 4724.01 5721.25 6276.39 6279.18 6862.21 6878.94 9409.13 9908.47 10801.15 11117.73 11193.99 11539.59 11658.81 11677 47 11777 46 11777 47 11873 36 11896 03 11903 00 12091 29 1713.04 1813.00 3342.00 3441.52 3799.00 3998.00 3999.00 4208.00 4214.00 5121.00 5300.00 5620.00 5733.48 5762.00 5920.00 5985.00 5995.64 6052.99 6053.00 6108.00 6121.00 6125.00 6233.00 0.00 5.64 1357.11 1584.84 2500.36 3010.01 3012.57 3547.82 3563.19 5886.04 6344.46 7163.99 7454.62 7524 17 7826 08 7924 35 7939 42 8019 97 8019 98 8097 23 8115 48 8121 10 8272.78 682.23 W 797.69 W 1741.71 W 1712.33 W 1543.46 W 1449.46 W 1448.98 W 1350 25 W 1347 42 W 918 97 W 834 41 W 683 25 W 629 64 W 616 81 W 561 12 W 542.99 W 540.21 W 525.36 W 525.35 W 511.10 W 507.74 W 506.70 W 478.72 W Begin Turn to Target Base Permafrost Top West Sak Sands EOC WS10 C90 9 5/8" Casing Pt C80 Campanian SS C50 C40 C30 Begin Angle Drop C20 Base HRZ K-1 Marker End~%ngle Drop / 7" Csg Pt TARGET - Top Kup C4 1E-36 Conv Prod 20-May-98 Top C3 Top C1 Top B Shale TD - Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6279.18 3999.00 3012.57S 1448.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 11677.50 5995.66 7939.45S 540.21W 7" Casing 0.00 0.00 0.00N 0.00E 12091.29 6233.00 8272.78S 478.72W 4 1/2" Liner Targets associated with this wellpath =========~ ........... Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1E-36 Conv Prod 20-M 549242.000,5952593.000,2.0000 6053.00 8019.98S 525.35W 20-May-98 ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 36 Version #4 Last revised : 29-Sep-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 1030.00 N 808.00 W 0.00 0.00 100.00 0.00 270.00 100.00 1030.00 N 808.00 W 0.00 0.00 200.00 0.00 270.00 200.00 1030.00 N 808.00 W 0.00 0.00 250.00 0.00 270.00 250.00 1030.00 N 808.00 W 0.00 0.00 350.00 3.00 270.00 349.95 1030.00 N 810.62 W 3.00 0.17 450.00 6.00 270.00 449.63 1030.00 N 818.46 W 3.00 0.68 550.00 9.00 270.00 548.77 1030.00 N 831.51 W 3.00 1.54 650.00 12.00 270.00 647.08 1030.00 N 849.74 W 3.00 2.73 750.00 15.00 270.00 744.31 1030.00 N 873.08 W 3.00 4.25 850.00 18.00 270.00 840.18 1030.00 N 901.48 W 3.00 6.11 950.00 21.00 270.00 934.43 1030.00 N 934.85 W 3.00 8.29 1050.00 24.00 270.00 1026.81 1030.00 N 973.12 W 3.00 10.79 1150.00 27.00 270.00 1117.06 1030.00 N 1016.16 W 3.00 13.61 1250.00 30.00 270.00 1204.93 1030.00 N 1063.87 W 3.00 16.73 1350.00 33.00 270.00 1290.18 1030.00 N 1116.12 W 3.00 20.14 1450.00 36.00 270.00 1372.59 1030.00 N 1172.75 W 3.00 23.84 1550.00 39.00 270.00 1451.91 1030.00 N 1233.62 W 3.00 27.82 1650.00 42.00 270.00 1527.95 1030.00 N 1298.56 W 3.00 32.07 1750.00 45.00 270.00 1600.47 1030.00 N 1367.38 W 3.00 36.56 1850.00 48.00 270.00 1669.30 1030.00 N 1439.91 W 3.00 41.31 1916.67 50.00 270.00 1713.04 1030.00 N 1490.23 W 3.00 44.59 2000.00 49.08 266.95 1767.12 1028.32 N 1553.59 W 3.00 50.41 2069.54 48.37 264.34 1813.00 1024.36 N 1605.69 W 3.00 57.77 2100.00 48.08 263.17 1833.30 1021.89 N 1628.27 W 3.00 61.71 2200.00 47.21 259.29 1900.69 1010.64 N 1701.28 W 3.00 77.71 2300.00 46.47 255.30 1969.11 994.62 N 1772.41 W 3.00 98.34 2400.00 45.87 251.22 2038.37 973.87 N 1841.47 W 3.00 123.57 2500.00 45.43 247.08 2108.29 948.43 N 1908.27 W 3.00 153.31 2600.00 45.13 242.87 2178.67 918.40 N 1972.63 W 3.00 187.49 2700.00 44.99 238.64 2249.32 883.83 N 2034.37 W 3.00 226.02 2800.00 45.01 234.40 2320.05 844.84 N 2093.32 W 3.00 268.78 2900.00 45.18 230.17 2390.66 801.53 N 2149.32 W 3.00 315.66 3000.00 45.51 225.98 2460.95 754.01 N 2202.22 W 3.00 366.54 3100.00 45.99 221.84 2530.74 702.41 N 2251.87 W 3.00 421.27 3200.00 46.62 217.78 2599.84 646.89 N 2298.13 W 3.00 479.70 3300.00 47.39 213.82 2668.05 587.58 N 2340.88 W 3.00 541.67 3400.00 48.29 209.96 2735.19 524.66 N 2380.01 W 3.00 607.02 3500.00 49.31 206.21 2801.07 458.29 N 2415.40 W 3.00 675.56 3600.00 50.46 202.58 2865.51 388.66 N 2446.95 W 3.00 747.10 3700.00 51.71 199.08 2928.35 315.95 N 2474.59 W 3.00 821.46 3800.00 53.06 195.70 2989.39 240.37 N 2498.23 W 3.00 898.42 3900.00 54.51 192.44 3048.49 162.13 N 2517.82 W 3.00 977.78 4000.00 56.03 189.30 3105.47 81.43 N 2533.28 W 3.00 1059.31 4100.00 57.64 186.h7 3160.17 1.49 S 2544.60 W 3.00 1142.80 4200.00 59.32 183.35 3212.46 86.42 S 2551.72 W 3.00 1228.02 4300.00 61.06 180.53 3262.18 173.12 S 2554.64 W 3.00 1314.72 4400.00 62.85 177.81 3309.21 261.36 S 2553.35 W 3.00 1402.68 4473.57 64.21 175.86 3342.00 327.11 S 2549.71 W 3.00 1468.05 4500.00 64.70 175.17 3353.40 350.88 S 2547.85 W 3.00 1491.65 4600.00 66.59 172.62 3394.64 441.45 S 2538.14 W 3.00 1581.39 KOP Begin Turn to Target Base Pez~nafrost Top West Sak Sands All data is i~ feet unless otherwise stated. Coordinates from SE Corner of Sec. 16, T11N, R10E and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes LNTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 4700.00 68.52 170.14 3432.82 532.81 S 2524.28 W 4724.01 68.99 169.55 3441.52 554.84 S 2520.33 W 5000.00 68.99 169.55 3540.45 808.21 S 2473.59 W 5500.00 68.99 169.55 3719.69 1267.24 S 2388.93 W 5721.25 68.99 169.55 3799.00 1470.36 S 2351.46 W 6000.00 68.99 169.55 3898.92 1726.27 S 2304.26 W 6276.39 68.99 169.55 3998.00 1980.01 S 2257.46 W 6279.18 68.99 169.55 3999.00 1982.57 S 2256.98 W 6500.00 68.99 169.55 4078.16 2185.30 S 2219.59 W 6862.21 68.99 169.55 4208.00 2517.82 S 2158.25 W 6878.94 68.99 169.55 4214.00 2533.19 S 2155.42 W 7000.00 68.99 169.55 4257.40 2644.32 S 2134.92 W 7500.00 68.99 169.55 4436.63 3103.35 S 2050.25 W 8000.00 68.99 169.55 4615.87 3562.38 S 1965.58 W 8500.00 68.99 169.55 4795.10 4021.40 S 1880.92 W 9000.00 68.99 169.55 4974.34 4480.43 S 1796.25 W 9409.13 68.99 169.55 5121.00 4856.04 S 1726.97 W 9500.00 68.99 169.55 5153.57 4939.46 S 1711.58 W 9908.47 68.99 169.55 5300.00 5314.46 S 1642.41 W 10000.00 68.99 169.55 5332.81 5398.49 S 1626.91 W 10500.00 68.99 169.55 5512.05 5857.51 S 1542.24 W 10801.15 68.99 169.55 5620.00 6133.99 S 1491.25 W 11000.00 68.99 169.55 5691.28 6316.54 S 1457.58 W 11117.73 68.99 169.55 5733.48 6424.62 S 1437.64 W 11193.99 67.09 169.55 5762.00 6494.17 S 1424.81 W 11200.00 66.94 169.55 5764.35 6499.61 S 1423.81 W 11300.00 64.44 169.55 5805.52 6589.23 S 1407.28 W 11400.00 61.94 169.55 5850.62 6676.99 S 1391.09 W 11500.00 59.44 169.55 5899.58 6762.73 S 1375.27 W 11539.59 58.45 169.55 5920.00 6796.08 S 1369.12 W PROPOSAL LISTING Page 2 Your ref : 36 Version #4 Last revised : 29-Sep-98 Dogleg Vert Deg/100ft Sect 3.00 1671.66 3.00 1693.38 EOC 0.00 1943.16 0.00 2395.67 0.00 2595.90 WS10 0.00 2848.18 0.00 3098.31 C90 0.00 3100.84 9 5/8" Casing Pt 0.00 3300.69 0.00 3628.49 C80 0.00 3643.64 Campanian SS 0.00 3753.20 0.00 4205.71 0.00 4658.22 0.00 5110.73 0.00 5563.24 0.00 5933.52 C50 0.00 6015.76 0.00 6385.43 C40 0.00 6468.27 0.00 6920.78 0.00 7193.33 C30 0.00 7373.29 0.00 7479.83 Begin Angle Drop · . 2.50 7548.40 C20 2.50 7553.76 2.50 7642.10 2.50 7728.62 2.50 7813.14 2.50 7846.02 Base ~LRZ 11600.00 56.94 169.55 5952.29 6846.29 S 1359.86 W 2.50 11658.81 55.47 169.55 5985.00 6894.35 S 1350.99 W 2.50 11677.47 55.00 169.55 5995.64 6909.42 S 1348.21 W 2.50 117$7.46 55.00 169.55 6052.99 6989.97 S 1333.36 W 0.00 11777.47 55.00 169.55 6053.00 6989.98 S 1333.35 W 0.00 7895.52 7942.89 K-1 Marker 7957.76 End Angle Drop / 7" Csg Pt 8037.16 TARGET - Top Kup C4 8037.17 1E-36 Cony Prod 20-May-98 11873.36 55.00 169.55 6108.00 7067.23 S 1319.10 W 0.00 8113.32 Top C3 11896.03 55.00 169.55 6121.00 7085.48 S 1315.74 W 0.00 8131.32 Top C1 11903.00 55.00 169.55 6125.00 7091.10 S 1314.70 W 0.00 8136.85 Top B Shale 12000.00 55.00 169.55 6180.64 7169.24 S 1300.28 W 0.00 8213.88 12091.29 55.00 169.55 6233.00 7242.78 S 1286.72 W 0.00 8286.38 TD - Csg Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 16, T11N, R10E and TVD from RF.B (Parker #245) (113.00 Ft a~ove mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum cuz-vature method. Presented by Baker Hughes INTEQ ~tRCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 36 Version #4 Last revised : 29-Sep-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 1916.67 2069.54 4473.57 4724.01 5721.25 6276.39 6279.18 6862.21 6878.94 9409.13 9908.47 10801.15 11117.73 11193.99 11539.59 11658.81 11677.47 11777.46 11777.47 11873.36 11896.03 11903.00 12091.29 250.O0 1713.04 1813.00 3342.00 3441.52 3799.00 3998.00 3999.00 4208.00 4214.00 5121.00 5300.00 5620.00 5733.48 5762.00 5920.00 5985.00 5995 64 6052 99 6053 00 6108 00 6121 00 6125 00 6233 00 1030.00 N 1030.00 N 1024.36 N 327.11 S 554.84 S 1470.36 S 1980.01 S 1982.57 S 2517.82 S 2533.19 S 4856.04 S 5314.46 S 6133.99 S 6424.62 S 6494.17 S 6796.08 S 6894.35 S 6909.42 S 6989.97 S 6989.98 S 7067.23 S 7085.48 S 7091.10 S 7242.78 S 808.00 W 1490.23 W 1605.69 W 2549.71 W 2520.33 W 2351.46 W 2257.46 W 2256.98 W 2158.25 W 2155.42 W 1726.97 W 1642.41 W 1491.25 W 1437.64 W 1424 81 W 1369 12 W 1350 99 W 1348 21 W 1333 36 W 1333 35 W 1319 10 W 1315.74 W 1314.70 W 1286.72 W KOP Begin Turn to Target Base Permafrost Top West Sak Sands EOC WS10 C90 9 5/8" Casing Pt C80 Campanian SS C50 C40 C30 Begin Angle Drop C20 Base HRZ K-1 Marker End Angle Drop / 7" Csg Pt TARGET - Top Kup C4 1E-36 Cony Prod 20-May-98 Top C3 Top C1 Top B Shale TD - Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 1030.00N 808.00W 6279.18 3999.00 1982.57S 2256.98W 9 5/8" Casing 0.00 0.00 1030.00N 808.00W 11677.50 5995.66 6909.45S 1348.21W 7" Casing 0.00 0.00 1030.00N 808.00W 12091.29 6233.00 7242.78S 1286.72W 4 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1E-36 Cony Prod 20-M 549242.000,5952593.000,2.0000 6053.00 6989.98S 1333.35W 20-May-98 ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 36 Version #4 Last revised : 29-Sep-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S Vert Ellipse Semi A,xes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 270.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 270.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 250.00 0.00 270.00 250.00 0.00 N 0.00 E 0.00 0.65 0.65 0.38 N/A 350.00 3.00 270.00 349.95 0.00 S 2.62 W 0.17 0.93 0.92 0.53 270.00 450.00 6.00 270.00 449.63 0.00 S 10.46 W 0.68 1.30 1.19 0.68 270.00 550.00 9.00 270.00 548.77 0.00 S 23.51 W 1.54 1.84 1.47 0.83 270.00 650.00 12.00 270.00 647.08 0.00 S 41.74 W 2.73 2.59 1.78 0.99 270.00 750.00 15.00 270.00 744.31 0.00 S 65.08 W 4.25 3.59 2.11 1.15 270.00 850.00 18.00 270.00 840.18 0.00 S 93.48 W 6.11 4.89 2.47 1.33 270.00 950.00 21.00 270.00 934.43 0.00 S 126.85 W 8.29 6.50 2.87 1.52 270.00 1050.00 24.00 270.00 1026.81 0.00 S 165.12 W 10.79 8.45 3.29 1.73 270.00 1150.00 27.00 270.00 1117.06 0.00 S 208.16 W 13.61 10.77 3.74 1.97 270.00 1250.00 30.00 270.00 1204.93 0.00 S 255.87 W 16.73 13.49 4.22 2.25 270.00 1350.00 33.00 270.00 1290.18 0.00 S 308.12 W 20.14 16.62 4.72 2.57 270.00 1450.00 36.00 270.00 1372.59 0.00 S 364.75 W 23.84 20.18 5.24 2.93 270.00 1550.00 39.00 270.00 1451.91 0.00 S 425.62 W 27.82 24.19 5.78 3.35 270.00 1650.00 42.00 270.00 1527.95 0.00 S 490.56 W 32.07 28.65 6.32 3.81 270.00 1750.00 45.00 270.00 1600.47 0.00 S 559.38 W 36.56 33.58 6.87 4.34 270.00 1850.00 48.00 270.00 1669.30 0.00 S 631.91 W 41.31 38.97 7.42 4.91 270.00 1916.67 50.00 270.00 1713.04 0.00 S 682.23 W 44.59 42.76 7.78 5.33 270.00 2000.00 49.08 266.95 1767.12 1.68 S 745.59 W 50.41 47.40 8.23 5.84 269.70 2069.54 48.37 264.34 1813.00 5.64 S 797.69 W 57.77 51.14 8.61 6.26 269.23 2100.00 48.08 263.17 1833.30 8.11 S 820.27 W 61.71 52.78 8.78 6.44 269.02 2200.00 47.21 259.29 1900.69 19.36 S 893.28 W 77.71 57.97 9.33 7.03 268.13 2300.00 46.47 255.30 1969.11 35.38 S 964.41 W 98.34 62.95 9.88 7.61 267.09 2400.00 45.87 251.22 2038.37 56.13 S 1033.47 W 123.57 67.71 10.42 g.18 265.94 2500.00 45.43 247.08 2108.29 81.57 S 1100.27 W 153.31 72.24 10.95 8.75 264.71 2600.00 45.13 242.87 2178.67 111.60 S 1164.63 W 187.49 76.56 11.48 9.31 263.42 2700.00 44.99 238.64 2249.32 146.17 S 1226.37 W 226.02 80.64 12.00 9.87 262.08 2800.00 45.01 234.40 2320.05 185.16 S 1285.32 W 268.78 84.50 12.51 10.43 260.72 2900.00 45.18 230.17 2390.66 228.47 S 1341.32 W 315.66 88.13 13.01 10.99 259.33 3000.00 45.51 225.98 2460.95 275.99 S 1394.22 W 366.54 91.54 13.50 11.56 257.94 3100.00 45.99 221.84 2530.74 327.59 S 1443.87 W 421.27 94.73 13.98 12.14 256.54 3200.00 46.62 217.78 2599.84 383.11 S 1490.13 W 479.70 97.70 14.45 12.72 255.16 3300.00 47.39 213.82 2668.05 442.42 S 1532.88 W 541.67 100.46 14.93 13.33 253.79 3400.00 48.29 209.96 2735.19 505.34 S 1572.01 W 607.02 103.01 15.41 13.94 252.45 3500.00 49.31 206.21 2801.07 571.71 S 1607.40 W 675.56 105.36 15.91 14.58 251.13 3600.00 50.46 202.58 2865.51 641.34 S 1638.95 W 747.10 107.50 16.43 15.24 249.85 3700.00 51.71 199.08 2928.35 714.05 S 1666.59 W 821.46 109.46 17.01 15.91 248.61 3800.00 53.06 195.70 2989.39 789.63 S 1690.23 W 898.42 111.23 17.65 16.61 247.41 3900.00 54.51 192.44 3048.49 867.87 S 1709.82 W 977.78 112.82 15.38 17.34 246.27 4000.00 56.03 189.30 3105.47 948.57 S 1725.28 W 1059.31 114.23 19.24 18.09 245.18 4100.00 57.64 186.27 3160.17 1031.49 S 1736.60 W 1142.80 115.48 20.23 18.86 244.14 4200.00 59.32 183.35 3212.46 1116.42 S 1743.72 W 1228.02 116.58 21.41 19.67 243.17 4300.00 61.06 180.53 3262.18 1203.12 S 1746.64 W 1314.72 117.52 22.79 20.50 242.25 4400.00 62.85 177.81 3309.21 1291.36 S 1745.35 W 1402.68 118.32 24.41 21.36 241.40 4473.57 64.21 175.86 3342.00 1357.11 S 1741.71 W 1468.05 118.82 25.79 22.01 240.82 4500.00 64.70 175.17 3353.40 1380.88 S 1739.85 W 1491.65 119.00 26.29 22.24 240.61 4600.00 66.59 172.62 3394.64 1471.45 S 1730.14 W 1581.39 119.55 28.46 23.15 239.89 All data is in feet unless otherwise stated. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 36 Version #4 Last revised : 29-Sep-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi A.xes Minor Depth Degrees Degrees Depth C 00 R D I N A T E S Sect Major Minor Vert. Azi. 4700.00 68.52 170.14 3432.82 1562.81 S 1716.28 W 1671.66 120.00 30.93 24.09 239.24 4724.01 68.99 169.55 3441.52 1584.84 S 1712.33 W 1693.38 120.10 31.55 24.31 239.08 5000.00 68.99 169.55 3540.45 1838.21 S 1665.59 W 1943.16 121.41 38.91 26.91 237.10 5500.00 68.99 169.55 3719.69 2297.24 S 1580.93 W 2395.67 124.51 52.56 31.63 232.53 5721.25 68.99 169.55 3799.00 2500.36 S 1543.46 W 2595.90 126.46 58.28 33.72 229.83 6000.00 68.99 169.55 3898.92 2756.27 S 1496.26 W 2848.18 128.93 65.49 36.36 226.43 6276.39 68.99 169.55 3998.00 3010.01 S 1449.46 W 3098.31 132.43 71.74 38.97 222.22 6279.18 68.99 169.55 3999.00 3012.57 S 1448.98 W 3100.84 132.46 71.80 38.99 222.17 6500.00 68.99 169.55 4078.16 3215.30 S 1411.59 W 3300.69 135.26 76.79 41.08 218.81 6862.21 68.99 169.55 4208.00 3547.82 S 1350.25 W 3628.49 141.61 83.35 44.50 212.74 6878.94 68.99 169.55 4214.00 3563.19 S 1347.42 W 3643.64 141.91 83.65 44.66 212.46 7000.00 68.99 169.55 4257.40 3674.32 S 1326.92 W 3753.20 144.03 85.84 45.80 210.43 7500.00 68.99 169.55 4436.63 4133.35 S 1242.25 W 4205.71 155.26 92.54 50.53 202.61 8000.00 68.99 169.55 4615.87 4592.38 S 1157.58 W 4658.22 168.50 97.31 55.26 196.24 8500.00 68.99 169.55 4795.10 5051.40 S 1072.92 W 5110.73 183.14 100.75 59.98 191.40 9000.00 68.99 169.55 4974.34 5510.43 S 988.25 W 5563.24 198.70 103.34 64.71 187.80 9409.13 68.99 169.55 5121.00 5886.04 S 918.97 W 5933.52 211.91 105.01 68.58 185.60 9500.00 68.99 169.55 5153.57 5969.46 S 903.58 W 6015.76 214.85 105.38 69.44 185.10 9908.47 68.99 169.55 5300.00 6344.46 S 834.41 W 6385.43 228.36 106.76 73.30 183.42 10000.00 68.99 169.55 5332.81 6428.49 S 818.91 W 6468.27 231.39 107.07 74.17 183.04 10500.00 68.99 169.55 5512.05 6887.51 S 734.24 W 6920.78 248.19 108.54 78.89 181.42 10801.15 68.99 169.55 5620.00 7163.99 S 683.25 W 7193.33 258.43 109.33 81.74 180.65 11000.00 68.99 169.55 5691.28 7346.54 S 649.58 W 7373.29 265.19 109.85 83.62 180.13 11117.73 68.99 169.55 5733.48 7454.62 S 629.64 W 7479.83 269.22 110.14 84.74 179.87 11193.99 67.09 169.55 5762.00 7524.17 S 616.81 W 7548.40 271.79 110.33 85.44 179.70 11200.00 66.94 169.55 5764.35 7529.61 S 615.81 W 7553.76 271.99 110.35 85.49 179.69 11300.00 64.44 169.55 5805.52 7619.23 S 599.28 W 7642.10 275.29 110.60 86.38 179.49 11400.00 61.94 169.55 5850.62 7706.99 S 583.09 W 7728.62 278.52 110.85 87.23 179.31 11500.00 59.44 169.55 5899.58 7792.73 S 567.27 W 7813.14 281.67 111.10 88.04 179.14 11539.59 58.45 169.55 5920.00 7826.08 S 561.12 W 7846.02 282.88 111.19 88.35 179.08 11600.00 56.94 169.55 5952.29 7876.29 S 551.86 W 7895.52 284.73 111.34 88.82 178.98 11658.81 55.47 169.55 5985.00 7924.35 S 542.99 W 7942.89 286.49 111.49 89.25 178.89 11677.47 55.00 169.55 5995.64 7939.42 S 540.21 W 7957.76 287.05 111.54 89.39 178.86 11777.46 55.00 169.55 6052.99 8019.97 S 525.36 W 8037.16 290.04 111.78 90.13 178.72 11777.47 55.00 169.55 6053.00 8019.98 S 525.35 W 8037.17 290.04 111.78 90.13 178.72 11873.36 55.00 169.55 6108.00 8097.23 S 511.10 W 8113.32 292.92 112.02 90.84 178.59 11896.03 55.00 169.55 6121.00 8115.48 S 507.74 W 8131.32 293.59 112.08 91.01 178.56 11903.00 55.00 169.55 6125.00 8121.10 S 506.70 W 8136.85 293.80 112.10 91.06 178.55 12000.00 55.00 169.55 6180.64 8199.24 S 492.28 W 8213.88 296.71 112.34 91.77 178.41 12091.29 55.00 169.55 6233.00 8272.78 S 478.72 W 8286.38 299.45 112.56 92.45 178.30 All data is in feet unless othe~Nise stated. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Vertical section is from wellhead on azimuth 183.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ · ~RCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 36 Version #4 Last revised : 29-Sep-98 POSITION UNCERTAINTY SUM~2%RY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 12091 ARCO (H.A. Mag) User specified 299.45 112.56 92.45 1 Ellipse dimensions are half axis. 2 Casing dimensions are not included. 3 Ellipses are calculated on 2.58 standard deviations. 4 Uncertainty calculations start at drill depth zero. 5 Surface position uncertainty is not included. 6 Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trakmanual. Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 1916.67 1713.04 2069.54 1813.00 4473.57 3342.00 4724.01 3441.52 5721.25 3799.00 6276.39 6279.18 6862.21 6878.94 9409.13 9908.47 10801 15 11117 73 11193 99 11539 59 11658 81 11677 47 11777 46 11777 47 11873 36 11896 03 11903 00 12091.29 3998.00 3999.00 4208.00 4214 O0 5121 O0 5300 O0 5620 O0 5733 48 5762 00 5920 00 5985 00 5995.64 6052.99 6053.00 6108.00 6121.00 6125.00 6233.00 0.00 5.64 1357.11 1584.84 2500.36 3010.01 3012.57 3547.82 3563.19 5886.04 6344.46 7163 99 7454 62 7524 17 7826 08 7924 35 7939 42 8019 97 8019.98 8097.23 8115.48 8121.10 8272.78 S 682.23 W Begin Turn to Target S 797.69 W Base Permafrost S 1741.71 W Top West Sak Sands S 1712.33 W EOC S 1543.46 W WS10 S 1449.46 W C90 S 1448.98 W 9 5/8" Casing Pt S 1350.25 W C80 S 1347.42 W Campanian SS S 918.97 W C50 S 834.41 W C40 S 683.25 W C30 S 629.64 W Begin Angle Drop S 616.81 W C20 S 561.12 W Base HRZ S 542.99 W K-1 Marker S 540.21 W End Angle Drop / 7" Csg Pt S 525.36 W TARGET - Top Kup C4 S 525.35 W 1E-36 Cony Prod 20-May-98 S 511.10 W Top C3 S 507.74 W Top C1 S 506.70 W Top B Shale S 478.72 W TD - Csg Pt Casing positions in string 'A' Top MD Top TVD' Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6279.18 3999.00 3012.57S 1448.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 11677.50 5995.66 7939.45S 540.21W 7" Casing 0.00 0.00 0.00N 0.00E 12091.29 6233.00 8272.78S 478.72W 4 1/2" Liner Targets associated with this wellpath __ Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1E-36 Cony Prod 20-M 549242.000,5952593.000,2.0000 6053.00 8019.98S 525.35W 20-May-98 ARCO Alaska, Inc. Pad 1E,36 Kuparttk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 36 Version #4 Last revised : 29-Sep-98 Dogleg Vert G R I D C O O R D S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 0.00E 0.00 0.00 549713.37 5960615.55 100.00 0.00 270.00 100.00 0.00N 0.00E 0.00 0.00 549713.37 5960615.55 200.00 0.00 270.00 200.00 0.00N 0.00E 0.00 0.00 549713.37 5960615.55 250.00 0.00 270.00 250.00 0.00N 0.00E 0.00 0.00 549713.37 5960615.55 350.00 3.00 270.00 349.95 0.00S 2.62W 3.00 0.17 549710.75 5960615.54 450.00 6.00 270.00 449.63 0.00S 10.46W 3.00 0.68 549702.90 5960615.48 550.00 9.00 270.00 548.77 0.00S 23.51W 3.00 1.54 549689.86 5960615.39 650.00 12.00 270.00 647.08 0.00S 41.74W 3.00 2.73 549671.64 5960615.27 750.00 15.00 270.00 744.31 0.00S 65.08W 3.00 4.25 549648.30 5960615.12 850.00 18.00 270.00 840.18 0.00S 93.48W 3.00 6.11 549619.90 5960614.92 950.00 21.00 270.00 934.43 0.00S i26.85W 3.00 8.29 549586.53 5960614.70 1050.00 24.00 270.00 1026.81 0.00S 165.12W 3.00 10.79 549548.27 5960614.44 1150.00 27.00 270.00 1117.06 0.00S 208.16W 3.00 13.61 549505.23 5960614.15 1250.00 30.00 270.00 1204.93 0.00S 255.87W 3.00 16.73 549457.52 5960613.83 1350.00 33.00 270.00 1290.18 0.00S 308.12W 3.00 20.14 549405.29 5960613.48 1450.00 36.00 270.00 1372.59 0.00S 364.75W 3.00 23.84 549348.66 5960613.10 1550.00 39.00 270.00 1451.91 0.00S 425.62W 3.00 27.82 549287.80 5960612.69 1650.00 42.00 270.00 1527.95 0.00S 490.56W 3.00 32.07 549222.87 5960612.25 1750.00 45.00 270.00 1600.47 0.00S 559.38W 3.00 36.56 549154.05 5960611.79 1850.00 48.00 270.00 1669.30 0.00S 631.91W 3.00 41.31 549081.53 5960611.30 1916.67 50.00 270.00 1713.04 0.00S 682.23W 3.00 44.59 549031.22 5960610.97 2000.00 49.08 266.95 1767.12 1.68S 745.59W 3.00 50.41 548967.87 5960608.86 2069.54 48.37 264.34 1813.00 5.64S 797.69W 3.00 57.77 548915.81 5960604.55 2100.00 48.08 263.17 1833.30 8.11S 820.27W 3.00 61.71 548893.25 5960601.93 2200.00 47.21 259.29 1900.69 19.36S 893.28W 3.00 77.71 548820.32 5960590.19 2300.00 46.47 255.30 1969.11 35.38S 964.41W 3.00 98.34 548749.31 5960573.69 2400.00 45.87 251.22 2038.37 56.13S 1033.47W 3.00 123.57 548680.40 5960552.48 2500.00 45.43 247.08 2108.29 81.57S 1100.27W 3.00 153.31 548613.78 5960526.60 2600.00 45.13 242.87 2178.67 111.60S 1164.63W 3.00 187.49 548549.63 5960496.13 2700.00 44.99 238.64 2249.32 146.17S 1226.37W 3.00 226.02 548488.13 5960461.16 2800.00 45.01 234.40 2320.05 185.16S 1285.32W 3.00 268.78 548429.45 5960421.77 2900.00 45.18 230.17 2390.66 228.47S 1341.32W 3.00 315.66 548373.74 5960378.09 3000.00 45.51 225.98 2460.95 275.99S 1394.22W 3.00 366.54 548321.17 5960330.22 3100.00 45.99 221.84 2530.74 327.59S 1443.87W 3.00 421.27 548271.88 5960278.30 3200.00 46.62 217.78 2599.84 383.11S 1490.13W 3.00 479.70 548225.99 5960222.47 3300.00 47.39 213.82 2668.05 442.42S 1532.88W 3.00 541.67 548183.64 5960162.88 3400.00 48.29 209.96 2735.19 505.34S 1572.01W 3.00 607.02 548144.94 5960099.70 3500.00 49.31 206.21 2801.07 571.71S 1607.40W 3.00 675.56 548110.01 5960033.10 3600.00 50.46 202.58 2865.51 641.34S 1638.95W 3.00 747.10 548078.92 5959963.27 3700.00 51.71 199.08 2928.35 714.05S 1666.59W 3.00 821.46 548051.78 5959890.38 3800.00 53.06 195.70 2989.39 789.63S 1690.23W 3.00 898.42 548028.64 5959814.66 3900.00 54.51 192.44 3048.49 867.87S 1709.82W 3.00 977.78 545009.59 5959736.29 4000.00 56.03 189.30 3105.47 948.57S 1725.28W 3.00 1059.31 547994.67 5959655.50 4100.00 57.64 186.27 3160.17 1031.49S 1736.60W 3.00 1142.80 547983.91 5959572.51 4200.00 59.32 183.35 3212.46 1116.42S 1743.72W 3.00 1228.02 547977.36 5959487.54 4300.00 61.06 180.53 3262.18 1203.12S 1746.64W 3.00 1314.72 547975.02 5959400.83 4500.00 64.70 175.17 3353.40 1380.88S 1739.85W 3.00 1491.65 547983.01 5959223.14 4600.00 66.59 172.62 3394.64 1471.45S 1730.14W 3.00 1581.39 547993.32 5959132.65 All data in feet unless otherwise stated. Calculation uses minimum curvature methqd. Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 36 Version #4 Last revised : 29-Sep-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 00 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 4700.00 68.52 170.14 3432.82 1562.81S 1716.28W 3.00 1671.66 548007.80 5959041.39 4724.01 68.99 169.55 3441.52 1584.84S 1712.33W 3.00 1693.38 548011.90 5959019.39 5000.00 68.99 169.55 3540.45 1838.21S 1665.59W 0.00 1943.16 548060.33 5958766.36 5500.00 68.99 169.55 3719.69 2297.24S 1580.93W 0.00 2395.67 548148.08 5958307.96 5721.25 68.99 169.55 3799.00 2500.36S 1543.46W 0.00 2595.90 548186.90 5958105.11 6000.00 68.99 169.55 3898.92 2756.27S 1496.26W 0.00 2848.18 548235.82 5957849.55 6276.39 68.99 169.55 3998.00 3010.01S 1449.46W 0.00 3098.31 548284.32 5957596.16 6279.18 68.99 169.55 3999.00 3012.57S 1448.98W 0.00 3100.84 548284.81 5957593.60 6500.00 68.99 169.55 4078.16 3215.30S 1411.59W 0.00 3300.69 548323.56 5957391.15 6862.21 68.99 169.55 4208.00 3547.82S 1350.25W 0.00 3628.49 548387.13 5957059.08 6878.94 68.99 169.55 4214.00 3563.19S 1347.42W 0.00 3643.64 548390.06 5957043.73 7000.00 68.99 169.55 4257.40 3674.32S 1326.92W 0.00 3753.20 548411.31 5956932.75 7500.00 68.99 169.55 4436.63 4133.35S 1242.25W 0.00 4205.71 548499.05 5956474.34 8000.00 68.99 169.55 4615.87 4592.38S 1157.58W 0.00 4658.22 548586.80 5956015.94 8500.00 68.99 169.55 4795.10 5051.40S 1072.92W 0.00 5110.73 548674.54 5955557.54 9000.00 68.99 169.55 4974.34 5510.43S 988.25W 0.00 5563.24 548762.29 5955099.!4 9409.13 68.99 169.55 5121.00 5886.04S 918.97W 0.00 5933.52 548834.08 5954724.04 9500.00 68.99 169.55 5153.57 5969.46S 903.58W 0.00 6015.76 548850.03 5954640.73 9908.47 68.99 169.55 5300.00 6344.46S 834.41W 0.00 6385.43 548921.71 5954266.24 10000.00 68.99 169.55 5332.81 6428.49S 818.91W 0.00 6468.27 548937.77 5954182.33 10500.00 68.99 169.55 5512.05 6887.51S 734.24W 0.00 6920.78 549025.52 5953723.93 10801.15 68.99 169.55 5620.00 7163.99S 683.25W 0.00 7193.33 549078.37 5953447.83 11000.00 68.99 169.55 5691.28 7346.54S 649.58W 0.00 7373.29 549113.26 5953265.53 11117.73 68.99 169.55 5733.48 7454.62S 629.64W 0.00 7479.83 549133.92 5953157.59 11193.99 67.09 169.55 5762.00 7524.17S 616.81W 2.50 7548.40 549147.22 5953088.13 11200.00 66.94 169.55 5764.35 7529.61S 615.81W 2.50 7553.76 549148.26 5953082.70 11300.00 64.44 169.55 5805.52 7619.23S 599.28W 2.50 7642.10 549165.39 5952993.21 11400.00 61.94 169.55 5850.62 7706.99S 583.09W 2.50 7728.62 549182.16 5952905.57 11500.00 59.44 169.55 5899.58 7792.73S 567.27W 2.50 7813.14 549198.56 5952819.94 11539.59 58.45 169.55 5920.00 7826.08S 561.12W 2.50 7846.02 549204.93 5952786.64 11600.00 56.94 169.55 5952.29 7876.29S 551.86W 2.50 7895.52 549214.53 5952736.50 11658.81 55.47 169.55 5985.00 7924.35S 542.99W 2.50 7942.89 549223.72 5952688.50 11677.47 55.00 169.55 5995.64 7939.42S 540.21W 2.50 7957.76 549226.60 5952673.45 11777.46 55.00 169.55 6052.99 80t9.97S 525.36W 0.00 8037.16 549242.00 5952593.01 11777.47 55.00 169.55 6053.00 8019.98S 525.35W 0.00 8037.17 549242.00 5952593.00 11873.36 55.00 169.55 6108.00 8097.23S 511.10W 0.00 8113.32 549256.77 5952515.86 11896.03 55.00 169.55 6121.00 8115.48S 507.74W 0.00 8131.32 549260.26 5952497.63 11903.00 55.00 169.55 6125.00 8121.10S 506.70W 0.00 8136.85 549261.33 5952492.02 12000.00 55.00 169.55 6180.64 8199.24S 492.28W 0.00 8213.88 549276.27 5952413.98 12091.29 55.00 169.55 6233.00 8272.78S 478.72W 0.00 8286.38 549290.33 5952340.54 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #36 and TVD from RKB (Parker #245) (113.00 Ft above mean sea level). Bottom hole distance is 8286.62 on azimuth 183.31 degrees from wellhead. Total Dogleg for wellpath is 148.21 degrees. Vertical section is from wellhead on azimuth 183.75 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1E,36 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 36 Version #4 Last revised : 29-Sep-98 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00N 0.00E KOP 1916 2069 4473 4724 5721 6276 6279 6862 6878 9409.13 9908 47 10801 15 11117 73 11193 99 11539 59 11658 81 11677 47 11777 46 11777 47 11873 36 11896.03 11903.00 12091.29 .67 1713.04 .54 1813.00 .57 3342.00 .01 3441.52 .25 3799.00 .39 3998.00 .18 3999 00 .21 4208 00 .94 4214 00 5121 00 5300 00 5620 00 5733 48 5762 00 5920.00 5985.00 5995.64 6052.99 6053.00 6108.00 6121.00 6125.00 6233.00 0.00S 682.23W Begin Turn to Target 5.64S 797.69W Base Permafrost 1357.11S 1741.71W Top West Sak Sands 1584.84S 1712.33W EOC 2500.36S 1543.46W WS10 3010.01S 1449.46W C90 3012.57S 1448.98W 9 5/8" Casing Pt 3547.82S 1350.25W C80 3563.19S 1347.42W Campanian SS 5886.04S 918.97W C50 ' 6344.46S 834.41W C40 7163.99S 683.25W C30 7454.62S 629.64W Begin Angle Drop 7524.17S 616.81W C20 7826.08S 561.12W Base HRZ 7924.35S 542.99W K-1 Marker 7939.42S 540.21W End Angle Drop / 7" csg Pt 8019.97S 525.36W TARGET - Top Kup C4 8019.98S 525.35W 1E-36 Cony Prod 20-May-98 8097.23S 511.10W Top C3 8115.48S 507.74W Top C1 8121.10S 506.70W Top B Shale 8272.78S 478.72W TD - Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 6279.18 3999.00 3012.57S 1448.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 11677.50 5995.66 7939.45S 540.21W 7" Casing 0.00 0.00 0.00N 0.00E 12091.29 6233.00 8272.78S 478.72W 4 1/2" Liner Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1E-36 Cony Prod 20-M 549242.000,5952593.000,2.0000 6053.00 8019.98S 525.35W 20-May-98 5OO 1000 1500 20OO 25OO 3000 35O0 4000 45OO 5000 55[]0 6000 6500 D~tc plotted : 29-Sep-98 / Plot Reference is 36 Version 14. / RKB ELEVATION: 113' KOP TVD=250 TMD=~50 DEP=O 5.00 9.00 15.00 21.00 DLS: 3.00 deg per 100 ft 27.00 33.00 39.00 45.00 ARCO Alaska, Inc. StrtJcture : Pod 1E Well : 36 Field : Kuporuk River Unit Location : North Slope, AIoskc <-- West (feet) 1800 1200 600 0 I I I I I ..... L... I i Begin Turn to Target l Base P e r m a f r o s~j.~_.___ ____~__.~_(~ 1 83.75 AZIMUTH sU~AC~ LOOAT,ON: 1030' FSL. 808' FEL ~ SEC. 16. TllN, RIOE [1037 (TO TAI(OErl') ***Plane of tTop West Sok Sends ~n rm BEGIN TURN TO TARGET TVD=1713 TMD=1917 DEP=45 . ~_~.~2~1 B/ PERMAFROST TVD=1813 'IMD=2070 DER=58 ~'~.87 '~, 4.5.1.3 , ~45.01 X 45.51 0.46 C8~ Camponmn SS ~5% 52 ,TARGET LOCATION: ~'~4 70 T/ W SAK SNDS TVD=3342 TMD=4474 DEP=1468 1710' FNL, 1355' FEL J ~-' EOC TVD=3442 TMD=4724 DEP=1695 SEC. 28. Tl lN. RIOE J WolO 'IVl9=379,)'IUD,:-:5721 DE'1'=2536 '--. MAXIMUM ANGIZ....... .., C90 1VD=3998 1MD=6276 DEP=3098 ~ ' · .......... ~, 9 5/8" CSG PT WD=3ggg 1MD=6279 DEP=3101~ [~ O0 ~ DEP=8037 ' ~ U U. ;J 0 I Jib ~ SOUTH 80nO CS0 ;rv~=4208 TMD=6862 DEP=3~?~ WEST 525~ CAMF SS TVD=4214 'rMD= 6879 DEP=3644 %~ ~"~~~_ ......................................... -~ .~cX~'~. C40 IVD=5300 TMD=9908 DEP=6385 ~ ............................................ C30 '1VD=5620 '[MD=lO801 OEP=7193 ~ F~i:(;IN AN(';I[. I)ROP 1'VD=5753 I'MD=l1118 DEP=7480 ~ C20 TVD=5762 TMD=11194 DEP=7548 ~ E,NI) ANCt E /)ROP~7" CS(' PT TVB=5996 'l'~[)=11677 DEP=7958 ~x 59.44 ...... IAR(,EF - 1'/ KUI 64 [VD=6053 FMD=l].777 I)EI =8037 %_ - c2o r~.~)f~[~ *~T~ ~ T/ C3 TVD=6108 TMf)=11875 DEP=8113~ ,? , ~-, tAt~t~bl J-~t~bl~l, T/ C1 WQ=6121 ~D=11896 ~E~.~ .,~ %~}~-, 7uose T/ B S~IALE I'VO = 612.) TM() =. 11903' DE~-~ ~ 37 "~-J ~ TARGET -.-. Top Ku TD .. Csg Pt ..... T ..... I ...... ~ ....... f ........ I ....... I .......... f ..... 1 ..... 1 ...... I .......... I ...... ~ ....... 1 ....... I ......... I ..... 1 ...... I ......... 1 .......... I .......... I ..... 1 ...... ~ '--T .... 1 ....... 1 ......... ~ ...... ~ ........... I ......... r ...... f ....... I ........ I ........ ~ ..... I ...... ~ ..... 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 Vertical Section (feet) -> Azimuth 183.75 with r'eferer~ce 0.00 N, 0.00 E from slot /t36 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 840O 5.6O 240 t 2C0 ~20 1 40 -~ 520 ~80 190O 2300 4100 120 t !60 ~ 2a0 i 280 q 320 39C0 22OO 3800 360 400 2600 27OO 440 3400 48O 3JCO 520 560 560 520 480 z. 40 400 ARCO Alaska, Inc.I Structure : Pad 1E Well : 36 I Field : Kuparuk River Unit Location : North Slope, Alaskai <- West (feet) 4CO 360 320 280 240 2~O 160 120 80 40 0 40 - ~ '1800 -, oo ~ ",~!700 '00 ~00 ' ~0 ~ ~ 0 ~ ~ ~ -. ...... ~ .................... -~ 57O0 1100~ lOOO~ 2100 900~00 5600 2000 1900 1800 3500 3400 1700 55OO 3300 1600 ~2~0 ~ ~ ~; 2100 5400 3100 12300 3000 ~ 2400 2600 1500 O0 2400 3500 2300 3500 OO 3400 3300 3200 3100 2900 2700 ~500 5OO 3200 /1500 3100 ~00~, 360 350 280 240 240 160 120 8'0 4'0 6 <- West (feet) 8O : 240 L 200 L i160 ~ 120 I L 40 L. 8o 120 160 200 240 280 320 I x6n 5200 F ~" h L 440 I I480 t520 i OOU 8O For: GOLDBERG Rot Reference ,s 36 ve~on f4. C~rd,na(el a~ ;n fee( reference Ve~,cal Oeptnl ~re ~ef~ence (D 7C0 -+--. 800 ] I ~cc i v RCO Alaska, nc. ,' Structure : Pad 1E Well : 36 Field : Kuporuk River Unit Location : North Slope, Alasko! ~ ccc -i 1100~ 12C0 ! 2800 1300 ; ~ 3!00 1700 ', ~ 3500 ~800 t <- West (feet) 2000 1 gOO I ~O0 ~ 700 ~ 600 ; .500 14CO 1300 1200 ; i O0 I CO0 900 800 700 ~C,3 500 400 5:oo .... 2:oo ............ 1C0 ~ ~0¢900 ..... ~ 100 i~~4700 ,~'~200 / ' '" 4600 ~00 i 200 g~an p 200 o 20o c . ~ k ~oo 3800 .,,,,,,. .... ~ 2600 ~ 400 ,, ..... 25C0 500 500 600 ~~uu &cO0 ~'uu p 600 / /2900 ( ,, 7OO ,, 2n,30 ~~uu i "' 3~co '~ ~- ~ ~oo ~:~. ~. ~CCC 2300 3200 ~C z~ ~ ~ 200 -; 3o0 i~' 2800~ !~0 32o~- L 3500 , . , ~V , , , , ~ , ~ .... ~ . ~ ~ 1800 2000 19C0 : ~00 1700 1600 1500 1400 ! 500 ! 200 11 O0 1000 900 800 700 6C0 50~ 400 <- West (feet) aska, Inc. " .......... ~v,~, ~,. I ] Field : Kuparuk River Unit Location : North Slope, Alaska Coordinole~ Ot~ ,~ fe~ reference ~at ~8. ~e~m~ are re~ence ~8 (Par~ <- Wesf (feet) 3000 2800 2600 2400 22C0 2C00 4.~.~0 2CO 0 / 3700~-'~ 3500 / 3900_//!, ~oo I w~- ~ 3500 3700~/ 4300 ~ 3900 ~800! 4500~'~// i- 4'00'~/ ~ ~oo ~ 5100~ ~ 5100 2900 22oo4 s~co~ '~ ~ _ ~ ~ ~ ' . 300 zz~ 291i I ,~ ocUU ~ i~ 5700 ~ 5900 1400 2 ! CO ]go0 F 100 ~- 1600 1 !500 ~- i700 ~ 1800 ~.gOC b 4300 I 4700 j- 2000 2400 2600 2800 3000 ~100 ,500 5100 6100 6300 6500 4700 3500 3g003700 /00 4100 500 330O 100 3500 I i !- 2200 ~- 2,~00 / ~5oo 12800 ! / L 3700 - SO00 , / , 5200 ~10 5 O( / 3___ ~/ 3800~ ~x \ ~CC i ~;oo/ 4000 j 5500 4500 51 5700 nO00 6 ~oo II ~D ~oo 3000 2800 2600 2400 2200 2000 !800 1600 1400 !200 1000 800 600 400 2C0 0 <- West (feet) / / 41,30 3900 / / ,/~-3c~ t / / ~500 / ~oo i/~ 5900 / i 3200 3~00 3600 3800 F - 4200 4600 4800 5000 5200 [ A RCO Alaska ~ c,~ w ,~.¢~ For: GOLDBERG; ~ ' / Structure : Pad 1E Well: 36 J Oote ~lo~te~ : 2~-Sea-98 ~ ~o, ..,.,.~. ,, ~ v.~.. ~. il jj Field : Kuparuk River Unit Location : North Slope. Alaskaj r · j <- West 2600 2400 2200 2000 1800 ~ 600 ~ 400 1200 1CO0 800 600 ~ 400 200 0 200 ~00 600 4800 5000 5200 5400 5800 1 6000 1 6200 l , 6~o0 ] ® "-" 6600 j _C 0 6800 ~ \/ 7000 ~ I 72C0 ~ 7400 J 7600 ! 7800 ~ 8000 ] 8200 l 8400 t 8600! ~4700 4900 ', , O0 2~--~Ai6500 5700 , , ~ 5900 ~ 61oo , , ¢900 F 5000 O0 ~200 ~ h~4oo '"'-~.5700 ' ~ ~ ~5600 ~~ 5800 F b6000 6200 k ~ 6400 ! F ~ 6800 L 7CCC 72OO 7400 7500 7800 8000 8200 L8400 8600 2600 2400 2200 2000 1800 i 600 1400 i 200 1000 800 600 400 200 0 200 400 600 <- Wesf (feel) 4800 A aska, Inc. Structure : Pad 1E Field : Kuparuk River Unit WELL PROFILE DATA o.co c.oo o.co o.co c.oo ~.~ 270.~ 250.00 o.co o.co ~.~ 270.~ I 7 t 3.04 0.C0 -682.23 5~.gg I ~9.55 3~1.52 -158~.8¢ -1712.~3 58.gg 16955 5733.48 -745¢.62 -629.6¢ 55.~ ~ 69.55 5995.64 -7939.~2 -540.21 Well: Location : North Slope, Aloskc! T<]r~e[ IE-58 CGnv Prcd] 1777.d~7 !T~. & Ina of H<~d ~2091.29 55.C0 169.55 605].G0 -8019.98 -525.55 8057.17 55.00 86g.55 62]3.00 -8272.78 -478.72 8=88.~.~ 320 $30 340 300 3!0 °~'TRUE NORTH I ! 350 0 1t0 I 290 280 270 2u~ 25~, 180 / i50 ! 0 9,0 cs 20 :~ / sO / I \ mo ssa 11oo -3ac! / / // / / 1700 7O 5OO i!Q 230 / i \ " 130 220 X ! 40 800 900 ~ .~? !CCO 1!00 ~ 2 ! 0 soo 700 200 1 190 ! 80 170 Normei Plcne Travelling Cylinder - Feet Ail depths shown ore Measured deaths on Reference ARCO Alaska, Inc. Pad 1E 36 slot #36 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE bl; Baker Hughes IHTEQ REPORT Your ref : 36 Version #4 Our ref : prop3103 License : Date printed : 29-Sep-98 Date created : 16-Aug-98 Last revised : 29-Sep-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 35 26.769 Slot location is n70 18 11.446,w149 35 50.328 Slot Grid coordinates are N 5960615.553, E 549713.366 Slot local coordinates are 1030.00 N 808.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath GMS <0-7310'> GMS <0-7811'> GMS <0-7512'> GMS <0-7750'> GMS <0-7190'> GMS <0-8435'> GMS <0-7885'> G-'MS <0-8150'> GMS <0-7898t> G-'MS <0-8650'> G'MS <0-7420'> GMS <0-9480'> GMS <0-8350'> GMS <0-7467'> G-'MS <0-6800'> ,30.Pad 1E ,10.Pad 1E ,12.Pad 1E ,13.Pad 1E ,14.Pad 1E ,15.Pad 1E ,17.Pad 1E ,18.Pad 1E ,19.Pad 1E ,20.Pad 1E ,21,Pad 1E ,22,Pad 1E ,23,Pad 1E ,25,Pad 1E ,27,Pad 1E TOTCO Survey,,WS-2,Pad 1E GMS <O-7310'>,,1A,Pad 1E MSS <2819-7345'>,,1,Pad 1E GMS <0-8440'>,,2,Pad 1E GMS <0-7195'>,,5,Pad 1E GMS <0-9837'>,,6,Pad 1E GMS <O-9310'>,,7,Pad 1E GMS <0-7590'>,,8,Pad 1E GMS <0-7000'>,,9,Pad 1E GMS <0-8754'>,,11,Pad 1E GMS <O-6835'>,,29,Pad 1E MSS <2370-3605'>,,26,Pad 1E GMS <O-8017'>,,26A,Pad 1E Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 9-Jul-97 876.4 5340.0 5340.0 4-Aug-92 10.6 350.0 350.0 4-Aug-92 227.1 100.0 100.0 4-Aug-92 347.0 100.0 425.0 4-Aug-92 465.3 450.0 450.0 4-Aug-92 587.1 425.0 3750.0 4-Aug-92 131.5 4575.0 4575.0 4-Aug-92 768.5 250.0 250.0 4-Aug-92 807.8 250.0 250.0 4-Aug-92 851.0 0.0 0.0 4-Aug-92 894.9 250.0 250.0 4-Aug-92 941.3 0.0 0.0 4-Aug-92 988.2 200.0 200.0 4-Aug-92 1087.3 200.0 200.0 4-Augo92 1347.4 100.0 4840.0 4-Aug-92 3421.8 275.0 6420.0 4-Aug-92 873.9 250.0 5900.0 4-Aug-92 873.9 250.0 6540.0 4-Aug-92 756.8 250.0 250.0 4-Aug-92 415.6 250.0 250.0 4-Aug-92 310.1 275.0 275.0 4-Aug-92 223.8 100.0 100.0 4-Aug-92 180.0 0.0 0.0 4-Aug-92 133.1 100.0 100.0 4-Aug-92 105.9 425.0 425.0 25-Jun-97 1109.7 250.0 5420.0 4-Aug-92 1138.4 250.0 5760.0 25-Jun-97 941.5 7600.0 7600.0 GMS <O-7715*>,,16,P~JIE GMS <0-7413'> <Depth Shifted>,,24,Pad 1E PMSS <5538-8167~>,,24A, Pad 1E PMSS <0-11712~>,,34,Pad 1E G~S <O-8905~>,,3,Pad 1E GMS <0-?665*>,,28,Pad 1E PMSS <121 - 9130*>,,31PB1,Pad 1E PMSS <8798-10023*>,,31,Pad 1E GMS <0-9150~>,,4,Pad 1E PMSS <9010 - 10951*>,,33,Pad 1E PMSS <121-9505~>,,33PB1,Pad 1E PMSS <121 - 10445~>,,32,Pad 1E 9-Jul-97 8-Nov-97 12-Nov-97 20-0ct-97 4-Aug-92 4-Aug-92 16-Aug-98 16-Aug-98 4-Aug-92 17-Aug-98 1?-Aug-98 17-Aug-98 441.0 1035.1 1035.1 432.9 639.8 291.3 480.0 480.0 195.8 1074.6 1074.6 839.7 275.0 275.0 100.0 250.0 6060.0 350.0 350.0 6640.0 100.0 100.0 250.0 4175.0 275.0 11233.3 100.0 250.0 6060.0 8360.0 8360.0 6640.0 100.0 100.0 10940.0 4 13 1. 16' - 2000 PSI STARTING HEAD 2_ 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 195/8' - 5000 PSI SPACER SPOOL 4 13-5~' - 5000 PSI VARIABLE P!PE .:;AMS 5. 13-5/8'- 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR 5/8" 5000 PSi BOP STACK ACCUMULATOR CAPACITY TI~$T CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PS! AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES, 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES, 7. TEST TO 250 PSI AND 5000 PS! AS IN STEP 4 CONTINUE TESTING ALL VALVES, LINES, ANO CHOKES WITH A 250 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE, 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 5000 PS! FOR 3 MINUTES. 9. OPEN PIPE RAMS. 8ACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES, BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE ,,-EST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH KUPARUK RIVER UIqlT 20" DIVERTER SCHEMATIC 6 l4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES, MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TC ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. 2. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA. INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) '097 ; "' -' ,~. · ;',S ~_':, % ;' :"" '"" ....,.,;.,.. ;.~1,.,., 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-I/16"- 2000 PSI BALL VALVE. 4. 20' - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL EE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKI311,,9~ FIELD&POOL.~ ~ [J I~ COMPANY /~1~ C C) WELL NAME INIT CLASS ~ ~ ~ 'i I]~ ~ ~ m pRoGRAI~: ex.p [] dev ,1~ redrl, I:] set, ., wellb .ore .s. eg !1 ann. di.s.p, osal para GEOL AREA~:~ ~ ~' UNIT# ~//~(~ ON/OFF SHORE ~, !,~, ADMINISTRATION ._ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well Iocaled proper dislance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CM'r vol adequate to circulate on conductor & surf csg ..... 17. CM'I' vol adequate to tie-in long string to surf csg ........ '18. CM 1' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a q0-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. C~SN (~N GEOLOGY A,~R DA'rE _ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Dala presented on potential overpressure zone~.~s ~ 32. Seismic analysis of shallowgas~~.....' ........ Y N 33. Seabed con~'tion~lm,~f(lr-off-shore) ............. Y N 34. C~l~~w ee kly progress reports ....... Y N ory only] ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will co.waste in a suitable receiving zone; ....... APPR DATE (B) will not con[~inate freshwater; or cause drilling waste... to surface; wiJ] "ri'~t-impair._mec'ha,.nical integrity of the well used for disposal; (C) will nol damage produhsi.ng formation or impair recovery from a GEOLQGY: Y N I~.~'~O t.k, ro A,~ut,,.'$ oF F~..~r'rT~c) ~-/I5'Z~ ~G I,~¢..~.L. O,,~ OS/E. Y N pool; and will nol circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: UIC/Annular COMMISSION: BEW JDH_~.~.~ WM ~kJ J~ DWJ t CO ~ ,o~,U Comments/Instructions: M:cheklisl fey 05129198 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Apr 19 14:50:45 1999 Reel Header Service name ............. LISTPE Date ..................... 99/04/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/04/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAI)E HEADER KUPARUK RIVER UNIT ~wn/~ nOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (~T FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 A/K-MM- 80419 P. SMITH D. LUTRICK RECEIV APR 2_ 7' 1999 Al~a Oil & 6as Cons. 1E-36 500292292700 ~CO ~~, INC. SPERRY-S~ DRILLING SERVICES 19-APR-99 MWD RUN 3 MWD RUN 4 AK-MM- 80419 AK-MM- 80419 P. SMITH T. MCGUIRE D. LITRICK D.LUTRICK 16 lin 10E 38 638 .00 112.50 71.50 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 118.0 12.250 9.625 6330.0 8.500 7.000 11597.0 6.125 12005.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA R_AY (DGR) . 4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO DENSITY (SLD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC. ON 09 DECEMBER, 1998. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 1E-36. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12005'MD 6193'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GA/VLMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BEST BIN BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = ~ORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = 6.125" 500 PPM. 12.2 PPG. 14545' PPM. 1.0 G/CC. 2.65 G/CC. SANDSTONE. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/19 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 curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH PEF GR 6308.5 ROP 6349.0 FET 11591.0 RPD 11591.0 RPM 11591.0 RPS 11591.0 RPX 11591.0 DRHO 11605.0 R/ROB 11605.0 FCNT 11606.0 NCNT 11606.0 NPHI 11606.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 11968.0 12004.5 11975.0 11975.0 11975.0 11975.0 11975.0 11947.0 11947.0 11931.5 11931.5 11931.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 6349.0 9830.0 3 9830.0 11597.0 4 11597.0 12005.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lo99in9 DirDction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 ROP MWD FT/H 4 1 68 RPS MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 RPX MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 NPHI MWD P.U. 4 1 68 FET MWD HOUR 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 6308.5 12004.5 9156.5 11393 GR 35.0803 492.929 133.056 11320 ROP 0.64 902.874 211.312 11312 RPS 0.84 1555.13 19.957 769 RPD 1.75 1927.19 63.1058 769 RPX 1.49 530.67 17.0396 769 RPM 1.48 1982.24 41.6993 769 NPHI 21.31 63.05 40.3157 652 FET 0.45 88.5 3.21501 769 R/{OB 2.1 3.17 2.49533 685 DRHO -0.19 0.23 0.0303796 685 PEF 2.92 16.11 7.45931 685 FCNT 150.76 621.4 267.963 652 NCNT 20896.5 40385.2 27453.3 652 First Reading 6308.5 6308.5 6349 11591 11591 11591 11591 11606 11591 11605 11605 11605 11606 11606 Last Reading 12004.5 11968 12004.5 11975 11975 11975 11975 11931.5 11975 11947 11947 11947 11931.5 11931.5 First Reading For Entire File .......... 6308.5 Last Reading For Entire File ........... 12004.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RgkW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6308.5 ROP 6349.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9788.5 9830.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 03-NOV-98 ISC 5.06/INSITE 3.2 CIM 5.46/EwP4 1.38/TM .41 MEMORY 9830.0 6349.0 9830.0 67.4 70.6 TOOL NUMBER Pl135CG60 8.500 8.5 LSND 9.50 64.0 8.5 300 3.7 .000 .000 50.1 MUD FILTR3kTE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6308.5 9830 8069.25 7044 6308.5 GR 51.5027 258.38 116.169 6961 6308.5 ROP 10.312 902.874 233.962 6963 6349 First Reading For Entire File .......... 6308.5 Last Reading For Entire File ........... 9830 Last Reading 9830 9788.5 9830 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9789.5 ROP 9831.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11555.0 11597.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 04-NOV-98 ISC 5.06/INSITE 3.2 CIM 5.46/EWP4 1.38/TM .41 MEMORY 11597.0 9830.0 11597.0 55.9 69.7 TOOL NUMBER Pl135CG6 8.500 8.5 LSND 9.60 47.0 8.5 300 3.8 .000 .000 .000 55.9 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9789.5 11597 10693.2 3616 9789.5 GR 35.0803 492.929 175.798 3532 9789.5 ROP 13.6792 562.354 205.12 3532 9831.5 · Last Reading 11597 11555 11597 First Reading For Entire File .......... 9789.5 Last Reading For Entire File ........... 11597 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE N-UMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. 4 .5000 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP PEF DRHO RHOB FCNT NCNT NPHI $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 11566.0 11591 0 11591 0 11591 0 11591 0 11591 0 11598 5 11605.0 11605.0 11605.0 11606.0 11606.0 11606.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON $ BOREHOLE AN~ CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : STOP DEPTH 11968.0 11975.0 11975.0 11975.0 11975.0 11975.0 12004.5 11947.0 11947.0 11947.0 11931.5 11931.5 11931.5 09-NOV-98 ISC 5.06/INSITE 3.2 CIM 5.46/EWP4 1.38/TM .41 MEMORY 12005.0 11597.0 12005.0 50.9 52.4 TOOL NUMBER P1043GR4 P1043GR4 P1043GR4 6.130 6.1 BOREHOLE CONDITIONS MUD TYPE: MI/D DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OMMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 12.20 65.0 8.1 500 3.6 2.920 1.470 2.000 2.600 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OPIMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 NPHI MWD 4 P.U. 4 1 68 24 7 ROP MWD 4 FT/H 4 1 68 28 8 FET MWD 4 HOUR 4 1 68 32 9 RHOB MWD 4 G/CC 4 1 68 36 10 DRHO MWD 4 G/CC 4 1 68 40 11 FCNT MWD 4 CNTS 4 1 68 44 12 NCNT MWD 4 CNTS 4 1 68 48 13 PEF MWD 4 BARN 4 1 68 52 14 First Name Min Max Mean Nsam Reading 61.0 Last Reading DEPT 11566 GR 41.34 RPX 1.49 RPS 0.84 RPM 1.48 RPD 1.75 NPHI 21.31 ROP 0.64 FET 0.45 RHOB 2.1 DRHO - 0.19 FCNT 150.76 NCNT 20896.5 PEF 2.92 12004.5 152 85 530 67 1555 13 1982 24 1927 19 63 05 255 15 88.5 3.17 0.23 621.4 40385.2 16.11 11785.2 878 92.2917 805 17.0396 769 19.957 769 41.6993 769 63.1058 769 40.3157 652 44.8282 813 3.21501 769 2.49533 685 0.0303796 685 267.963 652 27453.3 652 7.45931 685 11566 11566 11591 11591 11591 11591 11606 11598.5 11591 11605 11605 11606 11606 11605 12004.5 11968 11975 11975 11975 11975 11931.5 12004.5 11975 11947 11947 11931.5 11931.5 11947 First Reading For Entire File .......... 11566 Last Reading For Entire File ........... 12004.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/04/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/04/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF - Physical EOF End Of LIS File
