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Home My WebLink About198-0957. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 02-08B Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-095 50-029-20155-02-00 12210 Conductor Surface Intermediate Production Liner 8880 80 2715 9124 3207 12091 20" 13-3/8" 9-5/8" 4-1/2" 8881 28 - 108 27 - 2742 26 - 9150 8968 - 12175 28 - 108 27 - 2742 26 - 8328 8176 - 8880 12044 520 2670 3090 7500 None 1530 5380 5750 8430 9866 - 12050 4-1/2" 12.6# 13cr, L80 23 - 8832, 8863 - 8971 8257 - 8883 Structural 3-1/2" HES PHL Packer 8915, 8132 8735, 8915 7985, 8132 Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907-564-4672 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028308 23 - 8064, 8089 - 8178 N/A N/A 307 548 26648 34238 13 15 375 375 740 845 325-380 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S3 Packer 8735, 7985 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 3:15 pm, Aug 08, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.08.08 13:09:09 - 08'00' Bo York (1248) JJL 9/5/25 RBDMS JSB 081425 DSR-9/11/25 ACTIVITY DATE SUMMARY 7/18/2025 LRS CTU #1 1.5" coil 0.134 WT HT-110 Objective: Extended perforating MIRU. RIH w/HES logging tool + 2.25" DJN. L/K tubing w/ 150bbls of KCl. Log interval 8,500' - 10,100'. Paint Flag at 9,800'. POOH. MU HES Perforating Assembly. ***In progress*** 7/19/2025 LRS CTU #1 - Blue Coil 0.136 WT HT-110 Objective: Extended Perforating ***Review Standing Orders and Conduct Well Control Drill with Night Tour and Day shift*** Deploy 130' of 2" MaxForce Perforating Guns. RIH. Perforate 9866-9996'. POOH, Undeploy spent guns. FP well to 2500' w/diesel. RDMO. ***Complete*** Daily Report of Well Operations PBU 02-08B 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 02-08B Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-095 50-029-20155-02-00 341J ADL 0028308 12210 Conductor Surface Intermediate Production Liner 8880 80 2715 9124 3207 11290 20" 13-3/8" 9-5/8" 4-1/2" 8894 28 - 108 27 - 2742 26 - 9150 8968 - 12175 2420 28 - 108 27 - 2742 26 - 8328 8176 - 8880 12044 520 2670 3090 7500 11290 1530 5380 5750 8430 10100 - 12050 4-1/2" 12.6# 13cr, L80 23 - 8832, 8863 - 89718948 - 8883 Structural 3-1/2" HES PHL Packer 4-1/2" Baker S3 Packer 8735, 7985 8915, 8132 Date: Bo York Operations Manager David Bjork david.bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY 7/4/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:45 pm, Jun 24, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.06.24 11:27:52 - 08'00' Bo York (1248) 325-380 10-404 SFD 6/27/2025 DSR-6/30/25JJL 6/24/25 Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment JLC 7/1/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.07.01 14:32:48 -08'00'07/01/25 RBDMS JSB 070225 Ext Add Perf 02-08B PTD:198-095 Well Name:02-08B API Number:50-029-20155-02 Current Status:Operable - Producer Rig:CTU Estimated Start Date:7/4/25 Estimated Duration:2days Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd:Check status Regulatory Contact:Carrie Janowski (907) 564-5179 First Call Engineer:David Bjork (907) 564-4672 (907) 440-0331 Current Bottom Hole Pressure:3,300 psi @ 8,800’ TVD 7.3 PPGE (offset producer 02-17B) Max. Anticipated Surface Pressure:2,420psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:730 psi (Taken on 6/15/25) Min ID:2.81” ‘X’ @ 8,759’ MD Max Angle:97 Deg @ 10,529’ MD, 70 Deg at 9,894’ MD Brief Well Summary: 02-08B was sidetracked in ’98. A tubing swap was performed in ’23. The well is a gravity drainage Z1A lateral. Unswept Z1A remains unperforated. We would like to perforate the remaining footage in the heel. Objective:Perforate remaining unswept Z1A interval Procedure: Coiled Tubing 1. MU drift BHA with GR/CCL in 2.25” carrier, drift to 10,100ft. Note: 2.81” X at 8,759ft. 2. Correlate with attached log information. a. Correct flag and send to OE for confirmation. Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead 1.2x wellbore volume ~190 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 153 bbls b. 4-1/2” tubing – 8,733’ X .0152 bpf = 133 bbls c. 3-1/2” tailpipe 8,733’ – 8,832’ X .0087bpf=0.86 bbls d. 4-1/2” liner 8,863’ – 10,100’ (top perf)’ X .0152bpf=18.8 bbls 3. At surface, prepare for deployment of TCP guns. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Ext Add Perf 02-08B PTD:198-095 Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 5.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. e.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 6.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 2-3/4” Millennium guns or similar Perf Interval (tie-in depths) Lengths Total Gun Length Weight of Gun (lbs) Run #1 9,866’ - 9,996’9,866’ – 9,996’130’~1,442 lbs (11.09 ppf) 7. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 8. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 9. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 10. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 11. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 12. RDMO CTU. 13. Turn well over to Operations POP. Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE Schematic x Standing Orders x Equipment Layout x Sundry Change Form Ext Add Perf 02-08B PTD:198-095 Current Wellbore Schematic Ext Add Perf 02-08B PTD:198-095 Proposed Wellbore Schematic 9,866’ - 9,996’ New Perforations Ext Add Perf 02-08B PTD:198-095 Tie-in Log Ext Add Perf 02-08B PTD:198-095 BOP Schematic Ext Add Perf 02-08B PTD:198-095 Ext Add Perf 02-08B PTD:198-095 Ext Add Perf 02-08B PTD:198-095 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025010 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 211-26 50283201280000 208112 1/27/2025 AK E-LINE PPROF T40287 END 1-41 50029217130000 187032 3/13/2025 HALLIBURTON MFC40 T40288 END 2-14 50029216390000 186149 3/12/2025 HALLIBURTON MFC40 T40289 END 3-33A 50029216680100 203215 3/23/2025 HALLIBURTON COILFLAG T40290 GP AN-17A 50733203110100 213049 12/29/2024 AK E-LINE Perf T40291 KALOTSA 3 50133206610000 217028 3/3/2025 AK E-LINE PPROF T40292 KU 12-17 50133205770000 208089 1/28/2025 AK E-LINE Perf T40293 MPI 2-14 50029216390000 186149 2/17/2025 AK E-LINE Plug/Cement T40294 NCIU A-21 50883201990000 224086 3/28/2025 AK E-LINE Plug-Perf T40295 ODSN-25 50703206560000 212030 3/7/2025 HALLIBURTON CORRELATION T40296 PBU 02-08B 50029201550200 198095 3/17/2025 HALLIBURTON RBT T40297 PBU D-08B 50029203720200 225007 3/22/2025 HALLIBURTON RBT T40298 PBU J-25B 50029217410200 224134 3/10/2025 HALLIBURTON RBT T40299 PBU K-12D 50029217590400 224099 3/18/2025 HALLIBURTON RBT T40300 PBU K-19B 50029225310200 215182 3/27/2025 HALLIBURTON RBT T40301 PBU L1-15A 50029219950100 203120 3/27/2025 HALLIBURTON PPROF T40302 PBU M-207 50029238070000 224141 3/18/2025 HALLIBURTON IPROF T40303 PBU P1-04 50029223660000 193063 3/28/2025 HALLIBURTON PPROF T40304 PBU W-220A 50029234320100 224161 3/11/2025 HALLIBURTON RBT T40305 Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40297PBU 02-08B 50029201550200 198095 3/17/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 13:48:56 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 02-08B Install new tbg Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-095 50-029-20155-02-00 12210 Conductor Surface Intermediate Production Liner 8880 80 2715 9124 3207 8949 20" 13-3/8" 9-5/8" 4-1/2" 8894 28 - 108 27 - 2742 26 - 9150 8968 - 12175 28 - 108 27 - 2742 26 - 8328 8176 - 8880 12044 520 2670 3090 7500 8949 1530 5380 5750 8430 10100 - 12050 4-1/2" 12.6# 13Cr 80 , L-80 23 - 8832 , 8863 - 8971 8948 - 8883 Structural 3-1/2" HES PLS , 8735 , 7985 No SSSV 8735 , 8915 7985 , 8132 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028308 23 - 8064 , 8089 - 320 162 23926 9082 16 265 0 0 748 694 322-166 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S-3 , 8915 , 8968 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:47 pm, Jun 06, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.06.06 13:14:18 -08'00' RBDMS JSB 071723 DSR-6/12/23WCB 2-1-2024 ACTIVITYDATE SUMMARY 5/18/2022 T/I/O = 160/220/40. Temp = SI. T & IA FL (pre CMIT). AL disconnected. T FL near surface. IA FL @ surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:30 5/19/2022 T/I/O = 160/220/40. Temp = SI. CMIT TxIA to 3000 psi (pre rig). AL disconnected. T & IA FL @ surface. Pumped 17.4 bbls of diesel to pressure up TP & IAP to 3308/3317. TP/IAP lost 25/25 in 1st 15 min, 16/16 psi in 2nd 15 min for a 30 min total of 41/41 psi for a PASS. Bled 10.7 bbls. Tag hung. Final WHPs = 110/110/40. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:15 6/1/2022 ***WELL S/I ON ARRIVAL*** SET 4-1/2" x 10' JUNK CATCHER ON XX-PLUG IN X-NIPPLE @ 8,949' MD PULL 1.5" RK-DMY GLV FROM STA #3 @ 8,805' MD ***ST#3 EMPTY FOR CUT RWO *** ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** 6/7/2022 ***WELL S/I ON ARRIVAL*** AKE-LINE 9/32" ELINE OBJECTIVE: CUT 4.5" TUBING 8868' RIH W/ WELLTEC MECHANICAL CUTTER CUT 4.5" TUBING @ 8868'. CCL STOP DEPTH=8847.5'. CCL TO CUTTER=20.5' JOB COMPLETE ***WELL S/I ON DEPARTURE*** 6/12/2022 T/I/O = 140/140/51 (RWO EXPENSE)** Circ Out** Pumped down TBG returns up IA to 02-07 Flow Line with, 5 bbls 50/50 spear followed by 77 bbls baraclean and 724 bbls 1% KCL. Pumped Freeze Protect down IA returns up Tbg to same flow line with 172 bbls diesel then U-tubed until no flow ~1 hour. Freeze protected surface lines to OTT with 3 bbls diesel. FWHP's 200/200/60 Tag Hung, DSO notified and aware of 02- 07 FL not freeze protected. 3/14/2023 ***WELL S/I ON ARRIVAL*** DRIFT TO 2,600' SLM W/ 20' x 3.70" DMY WHIPSTOCK DRIFT ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** ****DRIFT W/ 20' x 3.70" WHIPSTOCK TO 2,600' SLM FOR SUBSIDANCE SURVEILLANCE**** 4/23/2023 T/I/O = SSV/Vac/40. Temp = SI. Bleed C&B lines to 0 psi (pre rig). Flowline & AL disconnected. Wellhouse has been removed, rig scaffolding installed. Control line = 610 psi. Balance line = 520 psi. Bled C&B Lines to 0 psi in 5 min, held open bleed for 20 min. (all gas). Monitored for 30 min. Control line increased 10 psi. Balance line increased 50 psi. Final WHP's = SSV/Vac/40. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:30 4/24/2023 T/I/O=VAC/0/0. Pre TB#01, Set 5' FMC ISA" BPV #538. T-Bar in plug. Removed tree and FMC Gen 1 THA. Installed 13 5/8 CIW BOP. LTT to 500 psi Pass. ***Job Complete*** . Final WHP's BPV/0/0. Daily Report of Well Operations PBU 02-08B RIH W/ WELLTEC MECHANICAL CUTTER CUT 4.5" TUBING @ 8868'. Daily Report of Well Operations PBU 02-08B 4/24/2023 CHECK TUBING HANGER VOID FOR PSI, BLEED OFF RESIDUAL PSI/FLUID, CHECK TUBING, ON VAC., NIPPLE DOWN THA, CLEAN VOID & RING GROOVE, CHECK HANGER LIFT THREADS, CUT & CAP (2) 1/4" CAP LINES, PLUG CAP LINE OUTLETS, INSTALL BLANKING PLUG INTO HANGER LIFT THREADS 9-1/2 LH TURNS, BLANKING PLUG STICKS UP 9-1-2 " FROM TOP OF THE TOP FLANGE TO TOP OF BLANKING PLUG, FUNCTION EACH UPPER LOCK DOWN SCREW 1 AT A TIME, OUT MEASUREMENT IS 3-3/8", RETORQUED LOCK DOWN SCREWS TO 450 FT./LBS, TIGHTENED GLAND NUTS, INSTALLED NEW BX-160, RDMO 4/24/2023 T/I/O = VAC/VAC/40. Temp = SI. Bleed C&B lines (pre RWO). Wellhouse, scaffold, and flowline disconnected. Rig scaffold installed. OA FL near surface. CP/BP = 2/50 psi. Bled CP/BP to 0 psi in <1 min (gas). Held open bleed on control line for 2 hrs. Held open bleed on balance for 6 hrs 30 min. During the last hr of bleeding BP it began dripping fluid returing 1/4 cup. Bled OAP to 0 psi in 5 min (gas). Held open bleed for 4 hrs 30 min. Monitored for 30 min. CP unchanged, BP & OAP increased 9 psi. Final WHPs = VAC/VAC/9. CP/BP = 0/9 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:00 4/30/2023 TBird RWO Job Scope: Tubing Swap Move from TBird yard to location. Spot rig and raise derrick. Spot cellar enclosure over well w/ Well Sppt crane. Spot and RU pits and pump. Cont RU process, RU remaining surface lines & Interconnects. MU choke & Kill lines. Complete hardline to Flow back tanks. Submitt 24 notice for BOP test to AOOGCC. Cont Rig up process **IN PROGRESS** 5/1/2023 TBird RWO Job Scope: Tubing Swap **Continue WSR from 4/30** Continue Initial Rig up process.RU remaining surface lines & Interconnects. Connect Rig Lights. Run Glycol Heater lines. Finish choke & Kill lines. Complete hardline to Flow back tanks. Stand up Rig floor and Rig up wind walls. RU TB Gas detection sensors. RU hydraulic lines from Koomy to BOP . Scaffold & hooch around the Kill manifold. Cont cold weather Rig up on surface lines. BOPE hoses,test joint, test pump, Electricians wired up generators to acuumulator, choke house, and pits. RU BOP test equipment. Shell Test: 5000 psi Initial test.AOGCC required. Good Shell test. Start BOPE test Test BOPE with 4-1/2" Test joint. 250/5000 psi for Rams. 250/2500 psi for Annular. Sean Sullivan Wiaved witness. **IN PROGRESS** 5/2/2023 TBird RWO Job Scope: Tubing Swap **Continue WSR from 5/01** Continued BOPE test Test BOPE with 4-1/2" Test joint. 250/5000 psi for Rams. 250/2500 psi for Annular. Sean Sullivan Wiaved witness. Closing times: Annular 17 sec., Rams 8 sec. RD test equipment. Vault pull blanking plug. Well Sppt pulled ISA BPV. Rock out diesel from Tbg and Circ seawater surface to surface. 657 bbls 6.2 bpm @ 460 psi. FLow check well.(static) MU landing Jt, BOLDS, and pull hanger @ 110K off seat, 98K PUW. LD Hanger. Monitor well, fluid at surface. Secure dual control lines & Start POOH with 4-1/2" BTC Tbg. **IN PROGRESS** 5/2/2023 Install seal on landing joint sub. RIH, m/u LJ to TBG HGR ~13 left hand turns. BOLDS. Pull TBG HGR to floor. Terminate (2) 1/4" CCL's. B/O TBG HGR guide pin. RIH, m/u LJ to TBG HGR ~13 left hand turns.gj BOLDS. Pull TBG HGR to floor. Daily Report of Well Operations PBU 02-08B 5/2/2023 T/I/O=BPV/0/0. T-BIRD Workover, Verified Well was on a VAC with setting tool. Pulled 5" FMC ISA #538 through BOP with T bar. ***Job Complete*** . Final WHP¿s Vac/0/0. 5/3/2023 TBird RWO Job Scope: Tubing Swap **Continue WSR from 5/02** Continued POOH with 4-1/2" BTC Tbg. Pulled 8,868' of 4-1/2 L-80 BTC Tbg. 213 full Jts plus (3) space out pups, SSSV assy, 3 GLM ~4 cut joint. Recovered 53 SS bands. MIRU Pollard Slickline open hole. Set 8.24" x 5' Scoop Guide on 4-1/2" tubing stub at 8,874' slm. Pulled 4-1/2" junk catcher from 8,958' slm, catcher empty. RU Slickline w/PCE to PBDR in stack. Pressure up well to 250 psi, made two attempts to equalize 4-1/2" XX plug @ 8,967' slm, no marks on X-eq device and no pressure change. Possible fill inside plug body. ......Continued on 5/4/23 WSR 5/3/2023 ***T-BIRD RIG ON WELL UPON ARRIVAL*** SET 8.24" SCOOP GUIDE ON TBG STUB @ 8874' SLM. PULLED JUNK CATCHER FROM 8958' SLM. RAN 4 1/2" X EQ CHECKER; S/D @ 8958' SLM. NO PRESSURE CHANGE, UNABLE TO WORK DEEPER, BUT SLEEVE SHEARED. ***CONTINUED ON 5-4-23*** 5/4/2023 ***WSR CONTINUED FROM 5-3-23*** ATTEMPTED TO EQUALIZE XX PLUG @ 8,949' MD RAN 2" SAMPLE BAILER THROUGH PLUG BODY (recovered small rubber piece & 2 small ribbons of teflon) ATTEMPTED TO EQUALIZE PLUG W/ OUT SUCCESS RAN 2 1/2" PUMP BAILER TO PLUG @ 8,949' MD (missing the bailer bottom) RAN 3.75" CENTRALIZER & 3.70" LIB, SAT DOWN IN SCOOP GUIDE @ 8,883' SLM RAN 3.802" BARBELL CENTRALIZERS, 11" EXTENSION & 2.25" MAGNET TO PLUG, NO RECOVERY RAN 2 1/2" HYDROSTATIC BAILER W/ 3.68" FLUTTER CAGE BOTTOM TO TOP OF PLUG W/ NO RECOVERY RAN DOGLESS GS TO PLUG @ 8,949' MD (sheared) ***T-BIRD RIG IN CONTROL ON DEPARTURE, GOING TO PULL THE PLUG W/ THE RIG*** 5/4/2023 TBird RWO Job Scope: Tubing Swap **Continue WSR from 5/03** Ran 2" bailer inside plug body @ 8,967', recovered small chunk of rubber and teflon in bailer. Metal marks on bailer bottom indicate contact w/plug body end cap. Re-run X-Eq prong, no equalization. Ran 2.5" pump bailer to plug body and worked bailer, 2.5" bailer bottom swiveled off and left in hole. Made multiple attempts to fish bailer bottom w/magnet and hydrostatic bailer, no recovery. Notified AOGCC of plan forward to pull plug w/2-7/8" drill pipe. RU BOP test equipment. Set test plug, RILDS. Start BOPE test with 2-7/8" Test joint. Test Annular 250 psi low / 2500 psi high. Test pipe rams 250 psi low / 5000 psi. Austin McLeod Waived witness. M/U YJ Fishing BHA w/Bidi jars & 4" G-Spear. Spot pipe wrangler, prep to run 2-7/8" PH-6 workstring. ......Continued on 5/5/23 WSR 5/4/2023 RIH w/ test plug. Land at verified RKB. RILDS. S/B for BOP test. BOLDS. pull test plug ATTEMPTED TO EQUALIZE XX PLUG @ 8,949' MD@ RAN 2" SAMPLE BAILER THROUGH PLUG BODY (recovered small rubber piece & 2 small ribbons of teflon)) ATTEMPTED TO EQUALIZE PLUG W/ OUT SUCCESS g Continued POOH with 4-1/2" BTC Tbg. Daily Report of Well Operations PBU 02-08B 5/5/2023 TBird RWO Job Scope: Tubing Swap **Continued from 5/4/23 WSR** TIH w/YJ 4" Hyd G-spear on 2-7/8" workstring while monitoring pipe displacement. PU joint # 291, tag & latch plug 8,949'. Work up incrementally and jars fired 12k over, fluid level in stack started falling. Re-tag to ensure plug latched. PUH into 9-5/8" casing and install FOSV and close annular. BH 292 bbls of 1% KCI down backside 4.8 bpm @ 180 psi. Flow check good. CHF .7 bpm. TOH w/2-7/8" 7.9# PH-6 WS. At joint #30, continue TOH. ......Continued on 5/6/23 WSR 5/6/2023 RWO, T/I/O = 0/0/0 MU LJ to 5-3/4" LH Acme hanger lift threads 10-1/2 turns chain tong tight, at full MU the landing sub is 4-1/4" away from shouldering out on hanger neck, PU hanger / LJ assembly and MU in string of 4-1/2", 12.6#, 13CR tubing, land tubing hanger, verify through IA, RILDS and torque to 450 ft lbs, all LDS at 2-13/16" IN measurement, tighten gland nuts, BO LJ, stand by for packer set and test. 5/6/2023 TBird RWO Job Scope: Tubing Swap **Continued from 5/5/23 WSR** TOH w/2-7/8" 7.9# PH-6 workstring. On surface w/3.81" XX plug, recovered Slickline 2.5" mule shoe bailer bottom inside plug. RU TBird TTS and layout completion in running order. RIH with 4-1/2" x 3-1/2" VamTop completion as per tally. M/U and land hanger PUW 105k, SOW 85k. RILDS. BH 200 bbls of 1% KCI w/CI down IA, followed by 290 bbls of KCI. ......Continued on 5/7/23 WSR 5/7/2023 T/I/O=0/0/0. TB #01 Completion. Set 5" ISA BPV #538 through BOP with Dryrod. ***Job Complete*** FInal WHP's BPV/0/0. 5/7/2023 TBird RWO Job Scope: Tubing Swap **Continued from 5/6/23 WSR** Continue chasing 200 bbls of CI w/290 bbls of KCI, 5 bpm @ 700 psi. Drop Ball & Rod (1-3/8" FN, 6.9' OAL, 1-5/16" ball). Set HES PHL packer. MIT-T to 3500 psi for 30 minutes. Bleed tubing pressure to 1500 psi. MIT-IA to 3000 psi for 30 minutes charted. Bleed tubing pressure to zero and shear DCR valve in GLM # 4. LRS pumped 180 bbls of diesel down IA. U- tube diesel to tubing. Install 5" ISA BPV in TBG hanger. RDMO Thunderbird-1. ***Job Complete*** 5/7/2023 Assist Rig. Pumped 4 bbls 60/40 and 180 bbls DSL into IA, taking returns up TBG to open top. 5/8/2023 ***WELL S/I ON ARRIVAL*** RIG UP SLICKLINE. ***CONTINUED ON 5-9-23*** 5/8/2023 RWO, T/I/O = 0/0/0, PPPOT-T (PASS) WS removed BOPs. Re-torqued tubing hanger LDS to 450 ft/lbs, cleaned ring groove, tubing hanger top and neck, verified ISA plug clear of debris, filled hanger void with hyd oil, installed new BX-160, lubed seals, 2 holed new THA with tubing head and set, WS torqued 13-5/8" flange to spec and set 7" flg x 5" bore tree, tested THA 600 psi low for 5 mins, good test, pressure up to 5000 psi, 250 psi loss first 15 mins, 50 psi loss second 15 mins, good test, RDMO. WS to shell test tree and pull 5" ISA plug. gy RIH with 4-1/2" x 3-1/2" VamTop completion as per tally. M/U and landg hanger PUW 105k, SOW 85k. RILDS Drop Ball &g@ Rod (1-3/8" FN, 6.9' OAL, 1-5/16" ball). Set HES PHL packer. MIT-T to 3500 psi for() 30 minutes. Bleed tubing pressure to 1500 psi. MIT-IA to 3000 psi for 30 minutes charted. Daily Report of Well Operations PBU 02-08B 5/8/2023 T/I/O=0/0/0 Pulled 5" ISA BPV. Set 5" ISA TTP. PT tree 300 psi low & 5000 psi high (PASSED). Pulled 5" ISA TTP.Final WHP's 0/0/0. ***JOB COMPLETE*** RDMO. 5/8/2023 T/I/O = 0/0/0. Removed BOPs. Installed THA and torqued to Spec. THA Tested by Kevin Krause, Passed PT. Installed Tree. Removed intergals from IA and OA, installed tapped blinds. Final T/I/O = 0/0/0 5/9/2023 ***WSR CONTINUED FROM 5-8-23*** SET 3 1/2" BAIT SUB, AND GUTTED 2" JD ON B&R @ 8746' SLM. PULLED RK-DGLV FROM STA# 3 @ 5954' MD. PULLED RKP-DCR FROM STA# 4 @ 3594' MD. SET RK-LGLV IN STA# 4 @ 3594' MD SET RK-OGLV IN STA# 3 @ 5954' MD PULL B&R @ 8758' MD PULL RHC BODY @ 8758' MD ***WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED OF STATUS*** 5/10/2023 T/I/O = SI/0/0. Set VR plug. RD OA. RU replacement OA & Torqued. PT against VR plug 300 psi low & 3500 psi high (PASSED). Pull VR plug. RU flange & Torqued. PT against Valve gate 2500 psi (PASSED). Final WHP's = SI/0/0. ***JOB COMPLETE*** RDMO @ PULL RHC BODY @ 8758' MD CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:David Bjork (david.bjork@hilcorp.com) Cc:doa.aogcc.prudhoebay@alaska.gov Subject:20230427 1441 APPROVAL to revision 3 02-08B RWO PTD 198-095 Sundry 322-166 Date:Thursday, April 27, 2023 2:43:34 PM Attachments:02-08B RWO tubing swap sundry rev3.docx David, Hilcorp is approved to the revisions (in red text) in the attachment to Sundry 322-166 on RWO for well PBU 02-08B (PTD198-095) Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Inspectors From: David Bjork <David.Bjork@hilcorp.com> Sent: Monday, April 24, 2023 2:57 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: 02-08B RWO PTD 198-095 Sundry 322-166 Mel, Do to equipment availability we will end up running a production packer with a reduced ID. Therefore we will have to pull the 3.81XX plug after recovering the tubing. Attached is the revised scope of work with the changes noted in red. Please call with any questions. Dave Bjork FS1 OE 564-4672o 440-0331c The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby RWO Procedure WELL: 02-08B PTD: 1980950 Well Name: 02-08B API Number: 500292015502 Current Status: Shut-In Rig: Thunderbird #1 Estimated Start Date: 5/22/2022 Permit to Drill Number: 1980950 First Call Engineer: Dave Bjork 907-564-4672 (O) 907-440-0331 M Second Call Engineer: Ryan Thompson 907-564-5280 (O) 907-301-1240 M Current Bottom Hole Pressure: 3,300 psi @ 8,850’ TVD 7.2 PPGE | SBHPS offsets for DS-02 Max. Anticipated Surface Pressure: 2,415psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 1,800 psi (Taken on 5/09/21) Min ID: ~3.5” ID liner damage @ 11,335’ MD Max Angle: 97 Deg @ 10,529’ Brief Well Summary: Well 02-08B is a July 1998 rig sidetrack resulting from the inability to squeeze a channel in 02-08A due to an obstruction. 02-08B’s completion consists of a 4-1/2" mono-bore with 1180’ of perforated in Z1A. The well produced until 2021 when a multiple tubing leaks were identified. We will now pursue a RWO to replace the L- 80 tubing. Notes Regarding Wellbore Condition: • The 9-5/8” production casing passed CMIT-TxIA to 2,500 psig on 05/10/2021. Objective: Pull the existing 4 ½” L80 tubing out of the well and replace with 13 chrome tubing. Achieve a passing MIT-IA & MIT-T. Pre Sundry Work: DHD 1. CMIT-TxIA to 3,000-psi (DONE 5/19/2022) 2. Cycle LDS’s (DONE 03/02/2022) 3. PPPOT-T to 5,000-psi (DONE 03/02/2022) 4. PPPOT-IC to 3,500-psi (DONE 03/04/2022) Slickline 5. Pull dmy valve from Station 3 @ 8,805ft (DONE 06/01/2022) Sundry Procedure (Approval required to proceed): Eline 6. Cut tubing @ ~ 8,868’ (DONE 06/07/2022) 7. Circulate well to 8.4 ppg 1% KCL or equivalent w/ diesel FP on T & IA (DONE 06/12/2022) Valve Shop/Ops 8. Bleed WHP’s to 0 psi 9. Set and test FMC 5-1/8” ISA BPV 10. Nipple Down Tree and tubing head adapter. Inspect lift threads. Install ISA blanking plug. 11. NU BOPE configured top down, Annular, 2-7/8” x 5” VBRs, Blinds and flow cross. RWO 12. MIRU Thunderbird #1 Rig. RWO Procedure WELL: 02-08B PTD: 1980950 13. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5” VBR’s with a 4-½” test joint. Test the Annular preventer with a 4-1/2” test joint. E. We will not proactively test with 2-7/8” test joints. If a workstring run is required stop and test VBR’s and annular with a 2-7/8” test joint. F. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14. Pull Blanking plug. Pull ISA BPV. Utilize dry rod unless pressure is expected then use lubricator. 15. Rig up control line spooler. 16. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~98K There are no records of control line clamps or bands. Estimate the quantity of missing clamps. 17. Pull 4 1/2” tubing to floor, circulate bottoms up. Lay down tubing. It will not be salvaged. 18. RU Slickline – Set a scoop guide on the 4-1/2” tubing stub. Recover the junk catcher. Rig up shooting nipple and lubricator, recover the 4-1/2” XX plug set at 8,949’. Pull the scoop guide. 19. Bullhead kill wellbore if pressure is observed after pulling the XX plug. Keep the wellbore full or fill at a minimum of 30bph for the remainder of the RWO. 20. Run 4 ½” 13Cr tubing with stacker packer completion as detailed on proposed schematic. 21. Land Hanger and reverse in corrosion inhibited 8.4 ppg 1% KCL or equivalent 22. Drop ball and rod and set packer with 3,500psi pump pressure. 23. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 24. Shear valve in upper GLM. 25. Set TWC 26. Rig down Thunderbird #1. Valve Shop/Ops 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. Slickline 1. Pull Ball and rod and RHC profile. 2. Set GLV’s per GL Engineer 3. RDMO & pop well. Obtain AOGCC witnessed SVS test within 5 days of putting well online Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Existing Tally 5. Proposed Tally 6. 4-1/2” VamTop Tech Sheet 7. Approved Sundry 8. Sundry Revision Change Form RWO Procedure WELL: 02-08B PTD: 1980950 Current Wellbore Schematic RWO Procedure WELL: 02-08B PTD: 1980950 Proposed Wellbore Schematic RWO Procedure WELL: 02-08B PTD: 1980950 RWO BOPs RWO Procedure WELL: 02-08B PTD: 1980950 Existing Tally RWO Procedure WELL: 02-08B PTD: 1980950 Proposed Tally RWO Procedure WELL: 02-08B PTD: 1980950 4-1/2” VamTop Spec Sheet RWO Procedure WELL: 02-08B PTD: 1980950 Approved Sundry RWO Procedure WELL: 02-08B PTD: 1980950 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. 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^ƵŶĚƌǇZĞǀŝƐŝŽŶŚĂŶŐĞ&Žƌŵ 5LVNDVVHVVWRDVVXUHQRJDVRUGHEULVEHORZSRSSHW ZtK WƌŽĐĞĚƵƌĞ t>>͗ϬϮͲϬϴ Wd͗ϭϵϴϬϵϱϬ tĞůůďŽƌĞ ^ĐŚĞŵĂƚŝĐ ZtK WƌŽĐĞĚƵƌĞ t>>͗ϬϮͲϬϴ Wd͗ϭϵϴϬϵϱϬ WƌŽƉŽƐĞĚ tĞůůďŽƌĞ ^ĐŚĞŵĂƚŝĐ ZtK WƌŽĐĞĚƵƌĞ t>>͗ϬϮͲϬϴ Wd͗ϭϵϴϬϵϱϬ ZtK KWƐ ZtK WƌŽĐĞĚƵƌĞ t>>͗ϬϮͲϬϴ Wd͗ϭϵϴϬϵϱϬ Changes to Approved Sundry Procedure 'DWH 6XEMHFW 6XQGU\ $Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHG VXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKH³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJH LVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH 6WHS 3DJH 'DWH 3URFHGXUH&KDQJH +$. 3UHSDUHG %\ ,QLWLDOV +$. $SSURYH G %\ ,QLWLDOV $2*&&:ULWWHQ $SSURYDO 5HFHLYHG 3HUVRQDQG 'DWH $SSURYDO 2SHUDWLRQV0DQDJHU 'DWH 3UHSDUHG 2SHUDWLRQV(QJLQHHU 'DWH • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 0 Post Office Box 196612 Anchorage, Alaska 99519 -6612 a q ) , O 4) August 22, 2011 ° `�`t \ �`� Mr. Tom Maunder PE Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 406 pp1f Anchorage, Alaska 99501 Alms o p. G a Ca t a Subject: Corrosion Inhibitor Treatments of GPB DS -02 ~ fc , hatag e ss Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 � 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -326 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -336 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -346 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 09/30/03 NO. 2981 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD P2-60 iq [--t"~ '~ PROD PROFILE W/DEFT 09/13/03 H-26~_.' ' "~C~f~,~' PROD PROFILE 09/17103 1 E-21A 1~'~-~c~ SBHP SURVEY 09116/03 1 NK-29~'C~( ~ - PROD PROFILE W/DEFT 09109/03 1 D.S. 3-29 '~<~ ~i *-~'~.C~ PROD PROFILE W/DEFT 09/19103 1 D.S. 15-18 ~ ~t.~ --C)('t3(~' SBHP SURVEY 09119/03 u-0eA ~ ICe'S- ,....~L~o_~ . SBHP SURVEY 09/20103 W-24... [ ~/4,<~1~ '--(~. / LDL 09123/03 1 D.S. 9-06 ~ ~ I~'-C~[4 ~ PROD PROFILE W/DEFT 09/20/03 D.S. 2-08B '~(:~:~ ~~ 23375 CH EDIT MCNL 05131103 ~/-23A k~ .... ' ' 23373 OH EDIT LWD IMPULSE DATA -- 04/30103 1 W-23A ~ ,.,~ (3-~c,")~ ('~ 23373 MD VISION RESISTIVITY 04130/03 I ~' .... W-23A ~ -- 23373 TVD VISION RESISTIVITY 04130/03 1 ,W-23A/' 23373 MD BOREHOLE PROFILE 04130/03 1 MPS-02~ ~.,-~._ I~-~2~- 10624537 CH EDIT SCMT GR (PDC) 08109103 MPS-02 ~'~---~ /~'- ~ 23435 SCMT 08/09/03 2 "~" MPS-18N, ~-j~,~c~-h,,~ _~'') ~0559235 CH EDIT SCMT GR (PDC) 03103/03 10559235 SCMT 03/03/03 2 MPS.j 8//C~/~ c.-' ~,'~ -,--- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 07/02/03 NO. 2890 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 4 O0 Anchorage, AK 99504 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD =D.S. 2-05A ~)C)~_-~-L~'~;~c-~ 23376 MCNL 06102/03 :H-27A ~~~ 23349 MCNL 05/09/03 E'02A ~~~ 23275 MCNL , 03/15/03 NK-62A 23277 MCNL 04/27/03 E-01A ~~--~ 23280 MCNL 04/12103 P2'54A~ ~'~_~~ 23274 MCNL 03127/03 D-22B I~ 23348 MCNL 05122103 O.S. 2-08a i~ ~~ MEM PROD PROFILE 05/31103 J-26 ' ' ~ LDL 06~20~03 D.S. 2-29A LDL 06/2~03 D.S. 15-28 LDL 06/21103 D.S. 12-20 LDL 06/03103 J-08 LDL 06/26/03 D.S. 2-25 PRODUCTION PROFILE 06107103 PSI-01 TEMPE~TURE WARMBACK LOG 06~09~03 PSI-06 TEMPE~TURE WARMBACK LOG 06/13/03 PSI-09 TEMPE~TURE WARMBACK LOG 06119103 K-317B SBHP SURVEY 04/05/03 C-04A SBHP SURVEY 06/26103 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. RECEIVED Anchorage, Alaska 99508 Date Delivered: .Anchor~e . Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth A . a eared ' rvices rilling To: Alaska Oil & Gas Conservation Commission Date: January 29, 1999 From: Subject: Terrie Hubble Technical Assistant Permit #98-95, 02-08B Enclosed, in duplicate, is a corrected directional survey which has been received from the vendor, Sperry-Sun. A discrepancy was found with the easting coordinates. I have corrected the below surface locations to reflect this change. The well histories and logs have previously been filed with the Commission and there are no changes. Thank you. /tlh ORIGINAL Well Compliance Report File on Left side of folder 198-095-0 '~MD 12210 _ ~TVD 08879 PRUDHOE BAY UNIT 02-08B 50- 029-20155-02 Completion Date: /'-b~/98 Completed Status: 1-OIL ARCO Current: Name D 8715 Interval Sent Received T/C/D SPERRY GR/EWR4 OH 9/16/98 9/16/98 D 9107 L BHCS L NGP/EWR4-MD L NGP/EWR4-TVD L PEX-CN L PEX-HALS L PEX-LDT L PEX-MCFL L SSTVD O.~~' SCHLUM PEX-BHC/HALS OH 3/24/99 3/26/99 8800-9933 lttojq8. OH 3/24/99 3/26/99 cgI~AL 9056-12210 (~l'~/c/B_ ¢h~k~ O" 9/30/98 9/30/98 gY~q~ L 828%8561 Xl¢ OH 9/30/98 9/30/98 ~F¢Iq'AL 8800-9933 ~/j/,ulq~ OH 3/24/99 3/26/99 .4-rNAL 8800-9933 } OH 3/24/99 3/26/99 .-T4NAL 8800-9933 I OH 3/24/99 3/26/99 .,/tefNAL 8800-9933 OH 3/24/99 3/26/99 qlN~L 8800-9933 OH 3/24/99 3/26/99 R SRVY RPT R SRVY RPT Daily Well Ops $/~//0/~ . ~f Was the well cored? yes ~ Comments: SPERRY 9101.50-1221'0 ' OH 11/25/98 12/2/98 Are Dry Ditch Samples Required? yes ~ And Receive~ Analysis Description R.et~vcd? 2,'cs ne, ~ SampleS~t~W----~' Tuesday, May 30, 2000 Page 1 of 1 3/24/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12454 Compan~ Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole] LIS Well Job # Log Description Date BL Sepia Tape D.S. 2-08B 98422 PEX/BHC/HALS ~10-~, 980618 ! D.S. 2-08B 98422 PEX-HALS 980618 1 1 D.S. 2-08B 98422 PEX-MCFL 980618 1 1 D.S. 2-08B 98422 PEX-CNL 980618 1 1 D.S. 2-08B 98422 PEX-LDT 980618 D.S. 2-08B 98422 BHC 980618 1 1 D.S. 2-08B 98422 SSTVD 980618 1 1 SIGNED: ~~ Please sign and return one copy of this transmittal to Sherrle at the above address. Thank RECEIVED DATE: I.'!~.F~ 2 6 1999 A~aska Oil & Gas Cons. Commi~ion ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 01/29/99 1. Status of Well Classification of Service Well [~ Oil I~ Gas E~ Suspended l--I Abandoned I~ Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 98-95 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20155-02 4. Location of well at surface 9. Unit or Lease Name ~ ........... ~ Prudhoe Bay Unit 3887' NSL, 4276' WEL, SEC. 36, T11N, R14E, UM '. · At top of productive interval : -.~y,~--~., ~ 10. Well Number 1083' NSL, 736' WEb, SEC. 26, T11 N, R14E, UM~"~v~ '. Prudhoe Bay Field02-08B/ At total depth :~_~.r'.; ' 11. Field and Pool 3441' NSL, 451' WEb, SEC. 26, T11 N, R14E, UM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 57.96'I ADb 028308 12. Date Spudded6/12/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband't15' Water depth' if °fish°re I 16' N°' °f C°mpleti°ns6/23/98 6/29/98 N/A MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12210 8879 FT 12091 8881 FT] [~Yes I--~NoI (Nipple) 2025' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, RES/AlT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 100' 32" 500 sx PF II 13-3/8" 72# MN-80 Surface 2742' 17-1/2" 5100 sx PF II 9-5/8" 40# /47# RS-95/MN-80 Surface 9150' 12-1/4" 1500 sx 'G', 125 sx PF II, 200 sx PF 'C' 4-1/2" 12.6# L-80 8968' 12175' 6" ~,55 sx Class 'G' !24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8971' 8915' MD TVD MD TVD 10100' - 12050' 8947' - 8882' i26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 130 Bbls of Diesel ?'~i ~*~ ~'~ ...... 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) . July 4, 1998I Gas Lift ¢~'"'"~'~ Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb ICHOKE SIZE TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 9156' 8332' Shublik 9199' 8369' Sadlerochit 9276' 8438' Zone 2 9533' 8677' 31. List of Attachments Summary of Daily Drilling Reports, Surveys !32. I hereby certify that the foregoin~ is true and correct to the best of my knowledge Signed ,/'~"~,,._ ~,.~. ,,.~::;,~::::::~/ / DanStone Title Senior Drilling Engineer Date I-2-'c~ 02-08B 98-95 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 r'l F! I I_1_ I N Ci S E I::t ~./I I-- I::: S 25-Nov-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 02-08B Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,101.50' MD 9,161.00' MD 12,210.00' 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_ 1998 ,&nch0ra§e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 02, Slot 02.08B 02-08B Job No. AKMW80256, Surveyed: I f June, 1998 S UR VEY REPORT 25 November, 1998 ORIGINAL Your Reft 5002920~5502 KBE 57.96' w~ ground level @ 29.0' Surface Coordinates: 5948799.77 N, 687640.24 E (70° 15'53.84~1" N, ~48° 28'58.008~" W) DRILLING SERVICE=; Survey Reft svy3634 Sperry-Sun Drilling Services Survey Report for 02-08B Your Reft 500292015502 Job No. AKMW80256, Surveyed: 11 June, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 9101.50 33.330 339.000 8228.32 8286.28 9161.00 33.330 341.440 8278.04 8336.00 9192.57 28,380 350.740 8305.14 8363.10 9220.15 26.620 358.860 8329.62 8387.58 9256.50 24.740 9.570 8362.39 8420.35 9290.95 22.260 21.080 8394.00 8451.96 9327.95 21.000 36.200 8428.42 8486.38 9353.83 22.050 41.340 8452.50 8510.46 9386.59 22.170 40.050 8482.85 8540.81 9479.69 20.890 37.870 8569.45 8627.41 9543.31 20.320 36.040 8629.00 8686.96 9572.69 22.990 37.170 8656.31 8714.27 9606.99 27,340 37.600 8687.34 8745.30 9639.34 32.170 36.740 8715.42 8773.38 9668.74 36.500 36.450 8739.69 8797.65 9703.85 41.030 35.580 8767.06 8825.02 9733.14 45.200 36.130 8788.44 8846.40 9765.07 50.140 36.420 8809.93 8867.89 9796.20 55.270 35.940 8828.79 8886.75 9828.57 60.170 37.290 8846.07 8904.03 9860.27 65.560 35.690 8860.52 8918.48 9893.88 71.420 38.110 8872.84 8930.80 9924.44 75,830 38.750 8881.46 8939.42 9954.71 81,200 39.180 8887.48 8945.44 9988.67 85,960 39.440 8891.28 8949.24 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~) (~) (~t) (~t) 2317.65 N 1781.19W 5951072.30 N 685801.84E 2348.41N 1792.25W 5951102.78 N ' 685790.01E 2364.05 N 1796.22W 5951118.32 N 685785.65 E 2376.71N 1797.40W 5951130.94 N 685784.16 E 2392.36 N 1796.30W 5951146.61N 685784.87 E 2405.57 N 1792.75W 5951159.90 N 685788.09 E 2417.46 N 1786.31W 5951171.96 N 685794.23 E 2424.85 N 1780.36W 5951179.49 N 685800.00 E 2434.20 N 1772.32W 5951189.04 N 685807.80 E 2460.75 N 1750.83W 5951216.12 N 685828.62 E 2478.64N 1737.37W 5951234.34 N 685841.64E 2487.34 N 1730.90W 5951243.19 N 685847.89 E 2498.92 N 1722.04W 5951254.99 N 685856.45 E 2511.72 N 1712.35W 5951268.03 N 685865.82 E 2525.03 N 1702.47W 5951281.58 N 685875.37 E 2542.81N 1689,55W 5951299.68 N 685887.84E 2559.03 N 1677,83W 5951316.18 N 685899.15 E 2578.05 N 1663,86W 5951335.55 N 685912.64E 2598.04 N 1649.25W 5951355.89 N 685926.75 E 2619.99 N 1632,93W 5951378.25 N 685942.52 E 2642.67 N 1616.17W 5951401.33 N 685958.71 E 2667.65 N 1597.39W 5951426.78 N 685976.86 E 2690.61N 1579.17W 5951450.19 N 685994.50 E 2713.67 N 1560.52W 5951473.70 N 686012.57 E 2739.77 N 1539.15W 5951500.33 N 686033.29 E Alaska State Plane Zone 4 PBU_EOA DS 02 Dogleg Rate (°~OOff) Vertical Section (ft) Comment 2.253 21,735 15.004 13.754 15.111 15.401 8,337 1.527 1.621 1.352 9.197 12.693 14.988 14.738 12.995 14.295 15.486 16.525 15.542 17.586 18.676 14.570 17,795 14.037 2732.69 2765.33 2781.46 2793.91 2808.58 2820.20 2829.74 2835.10 2841.74 2860.97 2874.21 2880.68 2889.22 2898.68 2908.58 2921.88 2934.03 2948.22 2963.15 2979.46 2996.35 3014.86 3031.59 3048.30 3067.13 Tie-on Survey Window Point Continued... 25 November, 1998 - 10:05 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 02.08B Your Ref: 500292015502 Job No. AKMWS0256, Surveyed: 1~ June, ~998 Prudhoe Bay Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 10020.43 90.000 39.510 8892.40 8950.36 10049.16 92.520 37.840 8891.77 8949.73 10082.12 93.330 35.760 8890.08 8948.04 10114.77 95.390 33.060 8887.60 8945.56 10146.24 93.630 29.440 8885.13 8943.09 10177.96 92.120 28.340 8883.54 8941.50 10209.56 90.740 26.720 8882.75 8940.71 10239.20 89.450 23.330 8882.70 8940.66 10272.27 88.520 20.270 8883.28 8941.24 10306.00 88.710 14.920 8884.10 8942.06 10335.02 90.090 12.730 8884.40 8942.36 10368.35 93.850 10.530 8883.26 8941.22 10401.98 94.990 6.750 8880.66 8938.62 10431.68 95.540 4.970 8877.94 8935.90 10465.84 95.820 1.290 8874.56 8932.52 10497.66 96.020 357.750 8871.27 8929.23 10528.78 96.590 354.280 8867.86 8925.82 10559.81 96.320 352.090 8864.37 8922.33 10593.04 93.940 350.130 8861.40 8919.36 10620.87 92.250 347.530 8859.89 8917.85 10653.91 90.800 345.440 8859.01 8916.97 10685.77 90.710 344.490 8858.59 8916.55 10717.22 91.200 342.610 8858.07 8916.03 10749.16 91.820 342.200 8857.23 8915.19 10781.12 92.430 341.500 8856.04 8914.00 Local Coordinates Global Coordinates Northings Eastings Northings Eastlngs (ft) (ft) (ft) (ft) 2764.27 N 1518.97W 5951525.32 N 686052.84E 2786.69 N 1501.03W 5951548.18 N 686070.23 E 2813.04 N 1481.31W 5951575.02 N 686089.28 E 2839.90 N 1462.91W 5951602.32 N 686107.00 E 2866.71 N 1446.64W 5951629.54N 686122.60 E 2894.45 N 1431.34W 5951657.64 N 686137.21 E 2922.46 N 1416.74W 5951686.01N 686151.10 E 2949.32 N 1404.20W 5951713.17 N 686162.97 E 2980.01 N 1391.92W 5951744.16 N 686174,48 E 3012.14 N 1381,73W 5951776.54N 686183.86 E 3040.32 N 1374.80W 5951804.87 N 686190.09 E 3072.94 N 1368.09W 5951837.65 N 686195.99 E 3106.08 N 1363.05W 5951870.91N 686200.20 E 3135.50 N 1360.03W 5951900.39 N 686202.48 E 3169.43 N 1358.17W 5951934.36 N 686203.49 E 3201.08 N 1358.44W 5951965.99 N 686202.44 E 3231.93 N 1360.59W 5951996.78 N 686199.52 E 3262.54N 1364.25W 5952027.29 N 686195.10 E 3295.24 N 1369.36W 5952059.85 N 686189.17 E 3322.50 N 1374.75W 5952086.97 N 686183.11 E 3354.61N 1382.46W 5952118.88 N 686174.60 E 3385.37 N 1390.73W 5952149.43 N 686165.57 E 3415.53 N 1399.63W 5952179.35 N 686155.92 E 3445.97 N 1409.28W 5952209.54N 686145.51E 3476.32 N 1419.23W 5952239.63 N 686134.81 E Alaska State Plane Zone 4 PBU EOA DS 02 Dogleg Rate (°llOOft) Vertical Section (ft) Comment 12.722 10.521 6.765 10,382 12.758 5.887 6.733 12.237 9.670 15.866 8.919 13.068 11,708 6.249 10.751 11.083 11.233 7.067 9.263 11.131 7.697 2.995 6.177 2.327 2.904 3084.77 3101.07 3120.62 3141.03 3162.02 3184.17 3206.78 3228.89 3254.74 3282.57 3307.55 3336.85 3367.13 3394.43 3426.39 3456.77 3486.93 3517.30 3550.08 3577.74 3610.71 3642,55 3674.00 3705.92 3737,85 Continued... 25 November, 1998 - 10:05 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 02-08B Your Ref: 500292015502 Job No. AKMW80256, Surveyed: ~ June, ~998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10812.25 92.650 341.050 8854.66 8912.62 10843.10 93.200 341.100 8853.09 8911.05 10875.05 93.020 340,070 8851.36 8909.32 10907.09 93.140 339.920 8849.63 8907.59 10942.48 94.220 338.630 8847.36 8905.32 10975.02 93.980 338.490 8845,04 8903.00 11004.74 93.970 338.580 8842.98 8900.94 11039.11 92.800 338.540 8840.95 8898.91 11070.13 92.160 337.920 8839.60 8897.56 11100.81 92.120 337.690 8838.46 8896.42 11134.52 91.230 338.110 8837.47 8895.43 11166.52 90.000 337.440 8837.13 8895.09 11196.45 91.020 337.560 8836.86 8894.82 11229.84 91.730 337.660 8836.06 8894.02 11262.21 90.490 338.810 8835.43 8893.39 11291.12 88.490 339.320 8835.69 8893.65 11324.71 87.380 342.300 8836.90 8894.86 11355.28 86.980 345.180 8838.41 8896.37 11387.67 86.800 348.780 8840.16 8898.12 11418.14 87.910 350.620 8841.57 8899.53 11451.17 89.260 353.290 8842.39 8900.35 11482.63 89.880 356.310 8842.62 8900.58 11514.75 89.600 359.210 8842.77 8900.73 11547.80 89.570 1.990 8843.01 8900.97 11576.56 89.320 4.830 8843.29 8901.25 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 3505.77 N 1429.22W 5952268.83 N 686124.09 E 3534.91N 1439.21W 5952297.71N 686113.38 E 3565.00 N 1449.81W 5952327.53 N 686102.03 E 3595.06 N 1460.76W 5952357.31N 686090.33 E 3628.10 N 1473.26W 5952390.02 N 686077.02 E 3658.31N 1485.12W 5952419.92 N 686064.40 E 3685.90 N 1495.97W 5952447.24 N 686052.87 E 3717.83 N 1508.51W 5952478.85 N 686039.64E 3746.61 N 1520.00W 5952507.33 N 686027.33 E 3775.00 N 1531.59W 5952535.42 N 686015.04 E 3806.22 N 1544.26W 5952566.32 N 686001.59 E 3835.84N 1556.37W 5952595.63 N 685988.76 E 3863.49 N 1567.82W 5952622.98 N 685976.62 E 3894.35 N 1580.53W 5952653.52 N 685963.14 E 3924.41 N 1592.53W 5952683.27 N 685950.39 E 3951.41 N 1602.86W 5952710.00 N 685939.39 E 3983.11N 1613.89W 5952741.41N 685927.57 E 4012.42 N 1622.44W 5952770.50 N 685918.30 E 4043.92 N 1629.73W 5952801.81 N 685910.23 E 4073.87 N 1635.17W 5952831.61 N 685904.04 E 4108.56 N 1639.79W 5952864.18 N 685898.61 E 4137.88 N 1642.64W 5952895.43 N 685894.98 E 4169.98 N 1643.90W 5952927.48 N 685892.92 E 4203.02 N 1643.55W 5952960.52 N 685892.45 E 4231.72 N 1641.84W 5952989.26 N 685893.44 E Alaska State Plane Zone 4 PBU EOA DS 02 Dogleg Rate (°/'tOOft) Vertical Section (ft) Comment 1.608 1.790 3.268 0.599 4.748 0.853 0.304 3.406 2.871 0.760 2.919 4.377 3.431 2.147 5.224 7.139 9.462 9.500 11.112 7.047 9.056 9.799 9.070 8.412 9.913 3768.93 3799.72 3831.59 3863.53 3898.76 3931.11 3960.66 3994.85 4025.72 4056.24 4089.79 4121.64 4151.42 4184.64 4216.88 4245.71 4279.24 4309.77 4342.04 4372.28 4404.92 4435.74 4466.83 4498.37 4525.36 Continued,.. 25 November, 1998 - 10:05 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 02-08B Your Ref: 500292015502 Job No. AKMW80256, Surveyed: ~ June, 1998 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northlngs Eastings Northings Eastings (ft) (ft) (ft) (ft) 11608.06 88.860 7.160 8843.79 8901.75 4263.05 N 1638.55 W 5953020.65 N 685895.95 E 11642.65 88.220 10.530 8644.67 8902.63 4297.21 N 1633.24 W 5953054.94 N 685900.41 E 11672.78 88.000 11.500 8845.66 8903.62 4326.77 N 1627,48 W 5953084.63 N 685905.43 E 11706.00 87.790 13.730 8846.88 8904.84 4359,16 N 1620.23 W 5953117.19 N 685911.87 E 11739.52 89.970 16.900 8847.54 8905.50 4391.48 N 1611.38 W 5953149.72 N 685919.91 E 11766.89 92.550 18.570 8846.94 8904.90 4417.54 N 1603.05 W 5953175.98 N 685927.59 E 11801.62 95.210 19.530 8644.59 8902.55 4450.29 N 1591.74 W 5953209.00 N 685938.08 E 11835.96 95.580 20.040 8841.36 8899.32 4482.46 N 1580.17 W 5953241.45 N 685948.85 E 11863.17 95.820 19.640 8838.66 8896.62 4507.93 N 1570,98 W 5953267.14 N 685957.40 E 11894.99 96.080 20.140 8835.36 8893.32 4537.69 N 1560.21 W 5953297.16 N 685967.42 E 11957.15 93.970 19.030 8829.91 8887.87 4596.02 N 1539.46 W 5953355.99 N 685986.71 E 11989.46 94,060 19.130 8827.65 8885.61 4626.48 N 1528,92 W 5953386.70 N 685996.49 E 12052.19 92.560 20.250 8824.03 8881.99 4685,44 N 1507.82 W 5953446.17 N 686016.11 E 12145.03 90.520 19.210 8821.53 8879.49 4772.80 N 1476.49 W 5953534.28 N 686045.25 E 12210.00 90.520 19.210 8820.94 8878.90 4834.14 N 1455.12 W 5953596.14 N 686065.09 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 343.248° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12210.00ft., The Bottom Hole Displacement is 5048.40ft., in the Direction of 343.248° (True). Alaska State Plane Zone 4 PBU EOA DS 02 Dogleg Rate {°llOOft) Vertical Section (ft) Comment 7.539 9.913 3.299 6.738 11.476 11.228 8.140 1,830 1.708 1.764 3.832 0.416 2.982 2.466 0.000 4554.41 4585.59 4612.23 4641.16 4669.56 4692.11 4720.21 4747.68 4769.42 4794.81 4644.69 4870.82 4921.20 4995.81 5048.40 Projected Survey Continued... 25 November, 1998 - 10:05 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 02-08B Your Ref: 500292015502 Job No. AKMWS0256, Surveyed: 11 June, 1998 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 02 Comments Measured Depth (ft) 9101.50 9161.00 12210.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8286,28 2317.65 N 1781.19 W 8336,00 2348.41 N 1792.25 W 8878,90 4834,14 N 1455.12 W Comment Tie-on Survey Window Point Projected Survey Continued... 25 November, 1998 - 10:05 - 6 - DrillQuest WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. __---- Anchorage, Alaska 99501 i. RE: 5~vVD Formation Evaluation Logs D.S. 2-08B, ~K-MW-80256 September 30, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker. Sperry-Sun Drilling Services, 5631 Silverado Way, #G, .Anchorage, AK 99518 D.S. 2-08B: 2" x 5" MD Resistivity. & Gamma Ray Logs: 50-029-20155-02 2" x 5" TVD Resistiviw & Gamma Ray Logs: 50-029-20155-02 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A FJro..qR~.r Indlmfrip__~ Inn ~nmnnnv WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 September 16, 1998 MWD Formation Evaluation Logs - D.S. 2-08B, AK-MW-80256 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-02%20155-02. 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ,, STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~] Oil I--] Gas [] Suspended J--] Abandoned i--] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 98-95 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20155-02 4. Location of well at surface i'"~ ~.r~r,~4,-;~;¥..~,'?~,;,,,,,r~,., ,~,, , i~~ -~-'2~q"~1. . .- , .- 9. Unit or Lease Name 3887' NSL, 4276' WEL, SEC. 36, T11N, R14E, UM i ' ,- Prudhoe Bay Unit At top of productive interval ~' VE~?E0 ~ 10. Well Number 1083' NSL, 673' WEL, SEC. 26, T11 N, R14E, UM ~. 02-08B At total depth ~ 5"'~ i, --,/~--' .................... ~ 1 1. Field and Pool 3441' NSL,,~!~'~WEL, SEC. 26, T11 N, R14E, UM ::~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 57.96'I ADL 028308 12. Date Spuddedc/12/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °ffsh°re 116' NO' Of cOmpletiOns6/23/98 6/29/98 N/A MSL, One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12210 8879 FTI 12091 8881 FTI [~Yes F-INo (Nipple) 2025' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, RES/ALT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES t~ [~',~ ~ (~ I [~, I I~ ! 23. CASING, L,NER AND CEMENT,NC RECORD ~ F~ 1 LP ~ I ~ ~ L CASING SE~'ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 100' 32" 500 sx PF II 13-3/8" 72# MN-80 Surface 2742' 17-1/2" 5100 sx PF II 9-5/8" 40# /47# RS-95/MN-80 Surface 9150' 12-1/4" 1500 sx 'G', 125 sx PF II, 200 sx PF 'C' 4-1/2" 12.6# L-80 8968' 12175' 6" 455 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8971' 8915' MD TVD MD TVD 10100' - 12050' 8947' - 8882' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 130 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) July 4, 1998I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. /~'f Naska Oil & ~', . l-".rmh0rage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. !Sag River 9156' 8332' Shublik 9199' 8369' Sadlerochit 9276' 8438' Zone 2 9533' 8677' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby ce~f~y t~b_at~the fore~~ue and correct to the best of my knowledge ~'/~/(/~ Si.n d J Title Senior Drilling Engineer Date ~¢' 98-95 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-ln, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility PB DS 02 Well 02-08B Rig Nabors 22E Page 1 Date 21 July 98 Date/Time 04 Jun 98 06:00-07:00 07:00-18:00 18:00-18:30 18:30-02:30 05 Jun 98 02:30-04:30 04:30-06:00 06:00-06:30 06:30-11:30 11:30-12:30 12:30-14:30 14:30-23:00 23:00-05:00 06 Jun 98 05:00-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-21:00 21:00-01:00 07 Jun 98 01:00-01:30 01:30-06:00 06:00-06:30 06:30-13:00 13:00-14:30 14:30-15:30 15:30-18:00 18:00-18:30 18:30-19:00 19:00-02:00 08 Jun 98 02:00-03:00 03:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-10:00 10:00-18:00 18:00-18:30 18:30-06:00 09 Jun 98 06:00-06:30 06:30-10:00 10:00-12:30 12:30-18:00 18:00-18:30 18:30-20:30 20:30-02:00 10 Jun 98 02:00-03:00 03:00-04:00 04:00-04:30 Duration lhr llhr 1/2 hr 8 hr 2hr 1-1/2 hr 1/2 hr 5hr 1 hr 2hr 8-1/2 hr 6hr 1 hr 1/2 hr 4-1/2 hr lhr 2 hr lhr 3 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 4hr 1/2 hr 4-1/2 hr 1/2 hr 6-1/2 hr 1-1/2 hr lhr 2-1/2 hr 1/2 hr 1/2 hr 7hr 1 hr 3hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr lhr 8 hr 1/2 hr 11-1/2 hr 1/2 hr 3-1/2 hr 2-1/2 hr 5-1/2 hr 1/2 hr 2hr 5-1/2 hr 1 hr 1 hr 1/2 hr Activity Held safety meeting Rig moved 100.00 % Held safety meeting Rig moved 100.00 % Installed Wellhead primary components Removed Hanger plug Held safety meeting Circulated at 9390.0 ft Installed Hanger plug Removed Xmas tree Installed BOP stack Tested BOP stack Rigged up Tubing handling equipment Held safety meeting Retrieved Hanger plug Rigged up Tubing handling equipment Laid down 160.0 ft of Tubing Installed Retrievable packer Tested BOP stack Held safety meeting Retrieved BOP test plug assembly Retrieved Retrievable packer Rigged up Completion string handling equipment Laid down 2760.0 ft of Tubing Rigged down Completion string handling equipment Laid down 8000.0 ft of Tubing Held safety meeting Laid down 9380.0 ft of Tubing Removed Accessories Ran Drill collar to 185.0 ft (6-1/4in OD) Removed Accessories Held safety meeting Installed Wear bushing Ran Drillpipe to 9400.0 ft (5in OD) Serviced Top drive motor Circulated at 9400.0 ft Held safety meeting Circulated at 9400.0 ft Pulled out of hole to 9150.0 ft Held safety meeting Rigged up Flowline Worked toolstring at 9164.0 ft Held safety meeting Worked toolstring at 9185.0 ft Held safety meeting Worked toolstring at 9200.0 ft Circulated at 9200.0 ft Pulled out of hole to 0.0 ft Held safety meeting Cleared Flowline Ran Drillpipe in stands to 9300.0 ft Circulated at 9300.0 ft Held safety meeting Batch mixed slurry - 51.000 bbl Facility Date/Time 11 Jun 98 12 Jun 98 13 Jun 98 14 Jun 98 15 Jun 98 Progress Report PB DS 02 Well 02-08B Page 2 Rig Nabors 22E Date 21 July 98 04:30-05:00 06:00-07:00 07:00-08:00 08:00-11:00 11:00-14:00 14:00-15:30 15:30-17:30 17:30-21:00 21:00-06:00 06:00-06:30 06:30-08:00 08:00-09:30 09:30-12:30 12:30-14:00 14:00-15:00 15:00-15:30 15:30-18:00 18:00-18:30 18:30-19:30 19:30-00:00 00:00-06:00 06:00-14:30 14:30-15:00 15:00-15:30 15:30-17:30 17:30-03:00 03:00-03:30 03:30-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-13:00 13:00-14:30 14:30-15:00 15:00-15:30 15:30-21:00 21:00-22:00 22:00-22:30 22:30-23:30 23:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-13:00 13:00-16:30 16:30-18:00 18:00-18:30 18:30-06:00 06:00-08:30 08:30-09:30 09:30-14:00 Duration 1/2 hr 1 hr 1 hr 3hr 3hr 1-1/2 hr 2hr 3-1/2 hr 9 hr 1/2 hr 1-1/2 hr 1-1/2 hr 3 hr 1-1/2 hr 1 hr 1/2 hr 2-1/2 hr 1/2 hr 1 hr 4-1/2 hr 6 hr 8-1/2 hr 1/2 hr 1/2 hr 2 hr 9-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2hr 4-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 5-1/2 hr lhr 1/2 hr 1 hr 4hr lhr 1-1/2 hr 1/2 hr 3 hr lhr 2-1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 11-1/2 hr 2-1/2 hr lhr 4-1/2 hr Activity Displaced slurry - 160.000 bbl Held 1280.0 psi pressure on 1.000 bbl squeezed cement Cleared Cement head Pulled out of hole to 0.0 ft Made up BHA no. 1 R.I.H. to 1630.0 ft Serviced Block line R.I.H. to 8700.0 ft Drilled cement to 9090.0 ft Held safety meeting Drilled cement to 9150.0 ft Circulated at 9150.0 ft Pulled out of hole to 580.0 ft Pulled BHA Worked on BOP - All rams Held safety meeting Made up BHA no. 2 Held safety meeting Functioned downhole tools at 1330.0 ft R.I.H. to 9150.0 ft Drilled to 9170.0 ft Drilled to 9212.0 ft (cont...) Took MWD survey at 9212.0 ft Drilled to 9230.0 ft Took MWD survey at 9230.0 ft Drilled to 9375.0 ft Took MWD survey at 9375.0 ft Drilled to 9407.0 ft Circulated at 9407.0 ft Pulled out of hole to 9407.0 ft Held safety meeting Serviced Block line Pulled out of hole to 1243.0 ft Pulled BHA Held safety meeting Rigged up sub-surface equipment - Retrievable packer Ran Drillpipe in stands to 8870.0 ft Serviced Draw works Ran Drillpipe in stands to 9052.0 ft Tested Casing Pulled out of hole to 0.0 ft Jet wellhead Installed BOP test plug assembly Held safety meeting Tested All functions Installed Wear bushing Made up BHA no. 3 R.I.H. to 9150.0 ft Washed to 9407.0 ft Held safety meeting Drilled to 9690.0 ft Drilled to 9755.0 ft (cont...) Circulated at 9755.0 ft Pulled out of hole to 1243.0 ft Progress Report Facility PB DS 02 Well 02-08B Page 3 Rig Nabors 22E Date 21 July 98 Date/Time 14:00-15:30 15:30-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-22:30 22:30-00:00 16 Jun 98 00:00-06:00 06:00-08:00 08:00-10:00 10:00-11:30 11:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-21:00 21:00-01:30 17 Jun 98 01:30-02:00 02:00-03:30 03:30-05:30 05:30-06:00 06:00-07:30 07:30-09:00 09:00-10:00 10:00-12:00 12:00-14:30 14:30-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-00:00 18 Jun 98 00:00-01:30 01:30-02:00 02:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:30 09:30-18:00 18:00-06:00 19 Jun 98 06:00-18:00 18:00-06:00 20 Jun 98 06:00-06:30 06:30-08:30 08:30-12:30 12:30-13:00 13:00-13:30 13:30-17:30 17:30-19:00 19:00-19:30 19:30-21:30 Duration 1-1/2 hr lhr 1 hr 1/2 hr 1/2 hr 4 hr 1-1/2 hr 6 hr 2 hr 2hr 1-1/2 hr 4-1/2 hr 1 hr lhr 1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 2hr 1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 2hr 2-1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr 1 hr 2 hr 1-1/2 hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 8-1/2 hr 12hr 12hr 12hr 1/2 hr 2hr 4 hr 1/2 hr 1/2 hr 4 hr 1-1/2 hr 1/2 hr 2 hr Activity Pulled BHA Made up BHA no. 4 Serviced Top drive R.I.H. to 200.0 ft Held safety meeting R.I.H. to 9534.0 ft Washed to 9755.0 ft Drilled to 9914.0 ft Drilled to 9963.0 ft Circulated at 9963.0 ft Pulled out of hole to 9050.0 ft Pulled out of hole to 190.0 ft Pulled BHA Rigged down Drillstring handling equipment Held safety meeting Rigged up sub-surface equipment - Toolstring R.I.H. to 9000.0 ft Held safety meeting Installed Subs Set downhole equipment (wireline) Retrieved Cable Retrieved Cable (cont...) Serviced Cable head Set downhole equipment (wireline) Conducted electric cable operations Conducted electric cable operations Retrieved Cable Held safety meeting Pulled out of hole to 0.0 ft Rigged down Rigging equipment Made up BHA no. 5 R.I.H. to 1250.0 ft Tested M.W.D. tool - Via string Serviced Block line Serviced Top drive R.I.H. to 5159.0 ft Held safety meeting R.I.H. to 8969.0 ft Tested MWD - Via string R.I.H. to 9963.0 ft Drilled to 10120.0 ft Drilled to 10305.0 ft Drilled to 10525.0 ft Drilled to 10972.0 ft Held safety meeting Circulated at 10972.0 ft Logged hole with LWD: Formation evaluation (FE) from 10972.0 ft to 9~ Pulled out of hole to 9150.0 ft Flow check Pulled out of hole to 72.0 ft Pulled BHA Installed BOP test plug assembly Tested All functions ~24.0 Progress Report Facility PB DS 02 Well 02-08B Page 4 Rig Nabors 22E Date 21 July 98 Date/Time 21 Jun 98 22 Jun 98 23 Jun 98 24 Jun 98 25 Jun 98 21:30-22:30 22:30-23:30 23:30-00:30 00:30-06:00 06:00-07:00 07:00-07:30 07:30-18:00 18:00-20:30 20:30-21:30 21:30-06:00 06:00-18:00 18:00-01:00 01:00-03:30 03:30-04:30 04:30-05:30 05:30-06:00 06:00-09:00 09:00-12:30 12:30-13:00 13:00-14:00 14:00-18:00 18:00-18:30 18:30-21:00 21:00-22:30 22:30-23:00 23:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-12:30 12:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-22:30 22:30-23:00 23:00-01:30 01:30-02:00 02:00-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-13:00 13:00-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-21:30 Duration 1 hr 1 hr 1 hr 5-1/2 hr lhr 1/2 hr 10-1/2 hr 2-1/2 hr lhr 8-1/2 hr 12hr 7 hr 2-1/2 hr lhr 1 hr 1/2 hr 3hr 3-1/2 hr 1/2 hr lhr 4hr 1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 5 hr 1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1 hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 4 hr 1/2 hr 4-1/2 hr lhr 1 hr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3hr Activity Retrieved BOP test plug assembly Made up BHA no. 6 Serviced Top drive R.I.H. to 9068.0 ft R.I.H. to 10880.0 ft Reamed to 10972.0 ft Drilled to 11417.0 ft Drilled to 11486.0 ft Repaired Draw works Drilled to 11675.0 ft Drilled to 11675.0 ft (cont...) Drilled to 12210.0 ft Circulated at 12210.0 ft Pulled out of hole to 10845.0 ft R.I.H. to 12210.0 ft Circulated at 12210.0 ft Circulated at 12210.0 ft (cont...) Logged hole with LWD: Formation evaluation (FE) from 12210.0 ft to 10900.0 ft Pulled out of hole to 10019.0 ft Logged hole with LWD: Formation evaluation (FE) from 10019.0 ft to 9 ft Pulled out of hole to 3000.0 ft Held safety meeting Pulled BHA Serviced LWD tool Held safety meeting Ran Liner to 3200.0 ft (4-1/2in OD) Held safety meeting Installed Tubing Held safety meeting Ran Tubing to 3000.0 ft (2in OD) Circulated at 3000.0 ft Held safety meeting Ran Drillpipe in stands to 9150.0 ft Rigged up Cement head Circulated at 9150.0 ft Held safety meeting Ran Drillpipe in stands to 12178.0 ft Circulated at 12178.0 ft Held safety meeting Mixed and pumped slurry - 89.000 bbl Functioned Liner hanger Circulated at 12063.0 ft Held safety meeting Pulled Drillpipe in stands to 9000.0 ft Serviced Block line Serviced Top drive motor Laid down 3000.0 ft of Tubing Tested Liner Held safety meeting Rigged up Tubing handling equipment Held safety meeting Rigged up sub-surface equipment - Gun assembly '30.0 Progress Report Facility PB DS 02 Well 02-08B Rig Nabors 22E Page 5 Date 21 July 98 Date/Time 21:30-23:00 23:00-23:30 23:30-01:30 26 Jun 98 01:30-06:00 06:00-06:30 06:30-08:00 08:00-09:30 09:30-10:00 10:00-11:30 11:30-12:00 12:00-15:30 15:30-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-23:00 23:00-05:00 27 Jun 98 05:00-06:00 06:00-06:30 06:30-09:30 09:30-09:45 09:45-18:00 18:00-18:30 18:30-20:00 20:00-20:30 20:30-21:30 21:30-22:00 22:00-05:00 28 Jun 98 05:00-06:00 06:00-06:30 06:30-07:00 07:00-10:00 10:00-12:30 12:30-13:30 13:30-14:30 14:30-15:30 15:30-18:00 18:00-18:30 18:30-19:30 19:30-21:30 21:30-01:00 29 Jun 98 01:00-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:30 09:30-15:00 15:00-17:00 Duration 1-1/2 hr 1/2 hr 2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 2-1/2 hr 1/2 hr 3hr 1 hr 1/2 hr 6 hr 1 hr 1/2 hr 3hr 1/4 hr 8-1/4 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 1/2hr 7 hr lhr 1/2 hr 1/2 hr 3 hr 2-1/2 hr lhr lhr lhr 2-1/2 hr 1/2 hr 1 hr 2 hr 3-1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 1/2 hr lhr 1 hr 1 hr 5-1/2 hr 2hr Activity Ran Tubing in stands to 3300.0 ft Held safety meeting Rigged up sub-surface equipment - Retrievable packer Ran Drillpipe in stands to 9500.0 ft Held safety meeting Ran Drillpipe in stands to 12045.0 ft Perforated Circulated at 8650.0 ft Bullhead well Worked toolstring at 8675.0 ft Pulled out of hole to 0.0 ft Ran Drill collar to 285.0 ft (5in OD) Held safety meeting Ran Drillpipe in stands to 8600.0 ft Circulated at 8600.0 ft Worked toolstring at 8675.0 ft Pulled Drillpipe in stands to 3000.0 ft Laid down 1350.0 ft of Tubing Held safety meeting Laid down 1417.0 ft of Tubing Held safety meeting Retrieved Gun assembly Held safety meeting Laid down 270.0 ft of Drill collar Removed Wear bushing Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 6900.0 ft (4-1/2in OD) Installed SCSSSV Held safety meeting Tested Dual control line Ran Tubing to 8971.0 ft (4-1/2in OD) Circulated at 8971.0 ft Rigged up Tubing hanger Installed Tubing hanger Rigged down Tubing handling equipment Rigged down All functions Held safety meeting Rigged down All functions Installed Adapter spool Installed Xmas tree Retrieved Hanger plug Tested Xmas tree Tested Tubing Held safety meeting Tested Permanent packer - Via annulus Freeze protect well - 130.000 bbl of Diesel Installed Accessories Laid down 3290.0 ft of 5in OD drill pipe Removed Swab gate valve 0 F! I I_1--11~ G S E I::! ~./I r- E S 03-Aug-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,101.50' MD 9,161.00' MD 12,210.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 14, 1998 THRU' Blair Wondzell, ~ P. I. Super vi so~/j FROM' Larry Wade, ¢- SUBJECT: Petroleum Inspector FILE NO: .DOC BOP test Nabors 22E PBU DS 2-08A June 14,1998: I traveled to ARCO's DS 2 to witness a BOP test on Nabors 22E. Other than a leaking needle valve the test went well. There was a relief driller on the rig but the floor hands were experienced and the test time reflects that. SUMMARY: I witnessed a BOP test on Nabors 22E, 0 failures, 3 % hours. Attachments: aeogfnfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors Rig No. Operator: ARCO Well Name: DS 2-08B Casing Size: 9 5/8 Set @ 9,598 Test: Initial Weekly X Other 22E PTD # Rep.' Rig Rep.: Location: Sec. DATE: June 14,1998 98-095 Rig Ph.# 659-4454 Phil Smith Rodney Kiepzig 36 T. 11N R. 14E Meridian Umiat Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: ok Well Sign X Upper Kelly / IBOP Housekeeping: ok (Gen) Drl. Rig ok Lower Kelly / IBOP 1 PTD On Location X Hazard Sec. X Ball Type 1 Standing Order Posted X Inside BOP 1 Quan. Pressure P/F f 250/5,000 P P 250/5,000 250/5,000 BOP STACK: Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves 1 Check Valve Quan. Test Press. P/F P 250/2500 250/5,000 P 1 250/5, OO0 P I 250/5,000 P I 250/5,000 P 250/5,000 250/5,000 250/5,000 P P MUD SYSTEM: Visual Alarm Tdp Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F f8 I 250/5,000 l P 42 250/5,000 P 2 Functioned P I Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8~ 1800 3,000 i 1,600 minutes 35 sec. minutes 45 sec. "X Remote: 'X Psig. Number of Failures: 0 ,TestTime: 3.5 Hours. Number of v alv es tested 24 Repair or Replacement of Failed Equipment will be made within 'days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. i. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade ---'- F1-021L (Rev. 12/94) aeogfnfe.xls TONY KNOWLES, GOVERNOR .~LASKA OIL AND GAS CONSERVATION COM~HSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: '907) 276-7542 .Xlav 15. 1998 James E. Smith Senior Drilling Engineer :\RCO Alaska. Inc. POBox 196612 Anchorage, AK 0t)519-6612 Re: Prudhoc Bay Unit ~.)2-08B .ARCO Alaska. Inc. Permit No. 98-95 Sur. Loc. 3887'NSL. 4276'WEL. Sec. 56. T1 IN. RI4E. UM Btmnholc Loc. 3245'NSL. 505'WEL. Sec. 26. TI IN. R14E. UM Dear Mr. Smith' Enclosed is thc approved application for permit to rcdrill thc above referenced xvcll. Thc permit to rcdrill docs not cxcmpt you from obtaining additional pcrlnits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required pcrmitting determinations arc made. Bloxvout prevention cquipmcnt (BOPE) must bc tested in accordancc with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must bc given to allow a representative of thc Commission to witness a test of' BOPE installed prior to drilling new hole. Notice may be given iw contacting thc Commission petroleum field inspector on thc North Slope pager at 65~-3607. BY ORDER OF THE COMMISSION dlf/Enclosurcs CC: Depamncnt of Fish & Gamc. Habitat Section w/o cnct. Department of Environmental Conscn'ation w/o cncl. STATE OF ALASKA ALASKA ~,:-~_ AND GAS CONSERVATION COb, ....,:SSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [--I Drill I~Redrill lb. Typeofwell I--IExploratory [] Stratigraphic Test I~ Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB -- 60' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028308 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3887' NSL, 4276' WEL, SEC. 36, T11 N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 1307' NSL, 598' WEL, SEC. 26, T11N, R14E, UM 02-08B At total depth 9. Approximate spud date Amount $200,000.00 3245' NSL, 505' WEL, SEC. 26, T11N, R14E, UM 05/19/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028307, 2035'I 02-08A, 150' at 11331' MD 2560 11957' MD /8835' TVD 16. To be completed for deviated wells ,17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9155' Maximum Hole Angle 92° Maximum surface 2520 psig, At total depth (-rVD) 8800' / 3400 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 BTO-Mod 4005' 9000' 8200' 11957' 8838' 355 sx Class 'G' .,;' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ._._-iZ.:,~ Present well condition summary ~ ~-%:;fL~ Total depth truemeasuredvertical 1 89110085 feetfeet Plugs (measured) Effective depth: measured 10850 feet Junk (measured) Fish' 10' x 1.25" Eq Prong (06/96) true vertical 8919 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 500 sx PF II 100' 100' Surface 2684' 13-3/8" 5100 sx PF II 2742' 2742' Intermediate Production 9945' 9-5/8" 1500 sx 'G', 125 sx PF II, 200 sx PF 9702' 8792' Liner 1459' 2-7/8" 48 sx Class 'G' 9409' - 10868' 8545' - 8919' Perforation depth: measured 10095'-10478', 10559'-10647', 10767'-10832' ~"i :~'"'~ i ~1 ~\! ~ L true vertical 8932' - 8922', 8923' - 8922', 8919' - 8919' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer NamelNumben Gavin Kidd, 564-5516 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify th~,~he foregoing is tr/~ and correct to the best of my knowledge ,-. - . Signed' '~--' A ~_,~'~~.~, ~. r~)/ ?(~ James E. Sm....~ ~b'~-~ Title Senior Drilling Engineer Date v// Commission Use Only Permit Number I APl Number Approval Date I See cover letter ¢¢" ~,,~I 50-029-20155-02 .~-'~'- - / ,,,~-'-' ~I for other requirements Conditions of Approval: Samples Required [~Yes ~No Mud Log Required []Yes ~No Hydrogen Sulfide Measures D~lYes []No Directional Survey Required "j~Yes~No Required Working Pressure for BOPE []2M; ,J~[3M; [] 5M; [] 10M; [] 15M Other: griglR8! Sigrlec! I~y by order of Approved By David W. J0hnstol~ Commissioner the commission Date~'""~./,,.,~'.-- Form 10-401 Rev. 12-01-85 Submit In Triplicate IWell Name: 12-08BI Sidetrack Plan Summary Type of Redrill (producer or injector): Surface Location: X=687766.24 Target 1 Location: Bottom Hole Location: IPr°ducer I Y=5949811.77 3887'FSL, 4276'FEL, Sec. 36, T11N, R14E, UM X=686096 Y=5952471 1307' FSL, 598'FEL, Sec. 26, T11N, R14E, UM X=686139 Y=5954411 3245' FSL, 505'FEL, Sec. 26, T11N, R14E, UM I AFE Number: I 4J0381 I Estimated Start Date: I 5/19/98 I Rig: I Nabors22E Operating days to complete: IMD: Ill,957, I ITvD: 18835, I Design (conventional, slimhole, etc.): [RKB ~60' I Ultra-slimhole Horizontal Side-track Objective: I Replace 2-08A to provide offtake point in deepest producible Zone I (Romeo) Sands. Mud Program Production Mud Properties:l Solids Free 4% KCI Quikdriln Density Viscosity LSR LSRV Filtrate pH (PPG) YP 8.6-8.8+ 45-65 10-18 >35000 NC 8.5-9.0 Keep Sand content at less than 0.25% in the production interval Directional KOP: J9,155' MD 92° Maximum Hole Angle: Close Approach Well' Formation Markers Formation Tops MD TVD (SS) Inclination and Azimuth TSAG 9146 8265' 33.31 degrees, 340.78 degrees Shublik 9200 8303 34.43 degrees, 345.25 degrees TSAD 9280 8374 21.27 degrees, 357.05 degrees Zone 3 9446 8462 10.06 degrees, 71.22 degrees Zone 2C 9518 8605 14.90 degrees, 82.85 degrees CGOC 9790 8804 58.74 degrees, 31.74 degrees TD 11,957 8838 92.22 degrees, 17.14 degrees BSAD N/A 8890 Casing/Tubing Program Hole Size Csg Wt/Ft Grade Conn Length Top Btm MD/TVDss MD/'I'VDss Existing 9-5/8" 47# L-80 BTRS 9,155 Surface 9,155'/8332' 6" 4.5" 12.6# L-80 BTC-MOD 4005' 9000'/8200' 11,957'/8838' Tubing 4.5" 12.6# L-80 BTC-MO D 8700' Surface 8,900'/8150' Cement Lead Cement Tail Cement Casing/Liner Sx / Wt / Yield Sx / Wt / Yield . Comments 4-1/2" 355/15.8/1.15 Solid Cemented Liner, Class "G", TOC to 200' above liner top Volume assumptions: Gauge hole + 50% excess; 80' shoe joints; TOC as listed. Inner String job Logging Program ILogs: 6" Hole DPC Logs: MWD/GR from KOP to horizontal, MWD/GR/RES in horizontal section. Platform Express will be run through the build section after reaching horizontal. Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Bottom hole pressure is expected to be 3400 psi @ 8800 ft TVD Maximum expected surface pressure is 2520 psi (assuming gas column of 0.1 psi/E) Diverter, BOPE and mud fluid system schematics on file with AOGCC. 2-08B Well Permit 04/29/98 2 Hazards DS 2 is not an H2S drillsite. Stuck pipe/lost circulation has been reported. Shallow gas (Ugnu, W. Sak) and Put River (gas) will not be penetrated. Potential Lost Circulation in Shublick Thick Shales in Lower Romeo can impair directional drilling. Aggressive Directional Profile. Kingkak not penetrated. Disposal 2-08B Class II drilling wastes will be disposed at CC-2A grind and inject facility. If Class I wastes are generated, they will be taken to Pad 3 disposal site. 2-08B Short Well Summary Well 2-08A is currently not capable of producing. The last test was on 5/24/97 at 955 BOPD and 24,860 GOR. The well was horizontally sidetracked with coiled tubing in the lower Romeo during June 1995. To date several attempts have been made to retrieve a prong that was lost in the well while trying to pull the SSSV. The well has not sustained production since 3/28/97. A new horizontal will restore wellbore integrity, maximize standoff from gas and improve areal drainage. The objective is to pull the existing 4.1/2" completion tubing, repair the 9 5/8" casing as necessary, mill a window by whipstock through the 9 5/8" casing @ 9,155ft and directionally sidetrack the well in 6" hole. DPC logs will be run in the build interval to identify the GOC and the 2,100 ft horizontal leg will be drilled to +/- 11,957' MD. A 4Y2" solid liner will be run and perforated with DPC guns. The well will be completed with 4 Y2" L-80 tubing. The objective of the pre-rig work is to ascertain the condition of the tubing presently in the hole ( which should be good). P & A all open perforations, chemically cut the 4 Y~" tubing above the production packer, circulate seawater into the wellbore and freeze protect the permafrost zone. There is also a reported leak in the 2.7/8" liner at 9,820 ft which will be covered by the P & A cement job. Pre-Rig Operations: The objective of the pre-rig work is to ascertain the condition of the tubing presently in the hole ( which should be good). P & A all open perforations, chemically cut the 4 Y~" tubing above the production packer, circulate seawater into the wellbore and freeze protect the permafrost zone. There is also a reported leak in the 2.7/8" liner at 9,820 ft which will be covered by the P & A cement job. 1. Notify the AOGCC 24 hours prior to commencing abandonment operations. 2. RU slickline and drift 4Y~"tubing, tag obstruction.( last recorded @ 9,907 ft MD) 3. Ensure annulus is fluid packed and Test tubing/IA and report results. 4. P & A open perforations. RU CTU and RIH. Attempt to get past obstruction- establish injectivity. 2-08B Well Permit 04/29/98 3 5. Pump cement @ 15.8 ppg, 1.15 ft3/sx, Class 'G' cement displaced by seawater. Volume from 9,907' ( last tag on obstruction to 100 ft below bottom perforation) to well TD is 5 bbls. This would be the minimum volume pumped, final volumes will be dictated by the injection test. Cement top MUST NOT be above 9,550 ft MD. Tag and test cement plugback. 6. RU electric line and make a chemical tubing cut in the first full joint above top of 2-7/8" liner which is at 9,409 ft. (cut at _+ 9,390' MD). Circulate well to seawater through the cut. Freeze protect to _+ 2,200ft MD. Note: Tubing is plastic coated and should be in good condition, run a double anchor acid cylinder cutter. 7. Test the 9 5/8" packoff and carefully cycle the LDS. 8. Set a BPV in preparation of the rig sidetrack. Rig Sidetrack Procedure 1. MIRU. ND Tree, NU and test B©PE. Circulate well clean. 2. Pull 4-1/2" tubing completion ( Tubing is in good condition) 3. Set EZSV in 9.5/8" below TSAG. 4. Set whipstock, kick off @ 9,155 ft MDand directionally drill 6" hole to horizontal in zone 1- Romeo sands 5. Run DPC logs through build and turn section to identify GCC 6. Directionally drill 6" hole to TD in Zone 1 horizontal target with four phase Resistivity on the MWD. 7. Run and cement 4-1/2", L-80 production liner. 8. Perforate production liner via DPC guns 9. Run 4.1/2", L-80 tubing completion 10. ND BOPE, NU and test tree. RDMO. Casing Shoe Kick Tolerance The kick tolerance for 9.5/8" shoe is calculated as infinite influx assuming a swabbed gas influx at the top of the Sadlerochit along the planned directional path. Based on 8.0 ppg EMW pore pressure and a minimum fracture gradient of 11.0 ppg at the 9.5/8" shoe. Fault Evaluation There is a 40 ft throw fault tracking the horizontal wellbore 150 ft to the East. 2-08B Well Permit 04/29/98 4 D~,i_~ 2-08B Producer (Sidetrack out of 9-5/8" Casing) SSSV · 72#/ff, MN- 4 1/2', 12.6 #, L-80 ~ Production Tubing ! with 3-4 4-1/2' GLMs 4-1/2' X 9 5/8' Production J~ /' Packer @ -8,900' MD / I tX' Completion (future CT I I[ IJ 4-1/2" X 9 5/8' Hanger/Packer I" I~ ~,ooo,~ ~:~:~ Obst~ction ~ 9,907 ~o~orations :.100~5- I .... :.:..... ; ; ~ 10478ff, 10,559-10647 ::::::::::::::::::::::: 2-7/8', 6.4~, L-80 Liner fl, 10,767- 10,832 fl ~':::: [ J ~0,8~8' MO I DATE REVISED BY COMMENTS 3/19/98 TAB Proposed Sidetrack Completion PRUDHOE BAY UNIT WELL: DS 2-08B 3/31/98 GNK APl NO 50-029-20155-02 BP E~loration (Alaska) Anadritl Schlumberger Alaska Distric~ 1111 Eas~ $0~k Avenue Anchorage, AK 995L6 (907) 349-4511 Fax 344-2160 D~RECTEONAL [~ELL PLAN for S~Ln2qHED SERVICES DRILLING Well ......... : DSO2-08B (P3) Field ........ : Prudhoe Bay, DS02 Computations.: Minimum Cua-va~ure Units ........ : FEET Surface Lag..: 70.26771197 N Surface Lonq,; 148.48155947 W 5~1 Description Surface ...... ~ 3857 FS6 4276 FEL Tie-in survey: 924 FSL 776 FEL Target S~art.: 5367 FgL 598 FEL Ta_~cjet Turn..: 1833 FSL 48~ FEL Target Turn..: 2656 FSL 614 FEL BHL .......... : 3245 FSL SOS FEL LOCATIONS - ALAS~ Zone: 4 X-Coord ~-Coord S36 TI[N R14E UM 687766.0~ S26 Ti[N R14Z L~ 6~5927.66 $9S2~84.36 S26 TllN R14E IR~ 686280.00 5953008.00 S26 Ti~ R14E ~ 686046.00 PROPOSED RELL PROFILE STAT/ON M}t~SURED INCLN IDENTIFICATION ~EPTH A~GLM DI REC~EOI~ VERTICAL - D~THS AZIMUTH TVD SUB-H~A T[E-~ SURVEY 9101.50 33.33 TOP SAG 9146.00 33.31 TOP ~HPSTCK 12/100 9t55.00 33.31 CI/RUE 14.21/100 9~85.~0 36.47 9200.00 3~43 DEPART Prepared ..... : 28 Apr 1998 Vert seck az.: 6.95 KB elevation.: 59.50 f~ ~m~metic Dcln: ~28.266 (g) Scale Factor.: 8.999940~$ Convergence,.: +1.42931~59 ANADR~LL AKA-DPC FEASIBILITY PLAN NOT' APPROVED FOR EXECUTION · '"'k~. PLAN # ODORDI~ATES-FRO~ ~ELI~AD 339.00 8287.32 8227.82 2085,25 23L7.65 N 1781.19 340,78 8324,50 8265.00 2107,02 2340.60 N 1789.59 341.14 8332.02 8272.52 2111,47 2345.27 N I792.21 34~.17 835S.63 8297.[3 2~27.11 2361.65 N [796.30 345.25 8365.85 8309.35 2135.16 2570.04 ~ 1798.60 ALASKA Zoae 4 Y 685927.66 5952064~36 6859[8.69 5952107.09 6B5916.96 5952111.72 6~591[.~6 ~952127.9~ 665~08.95 5952~36,30 FAC~ lO0 92R <TIE 9~R 2.20 30R 2.20 163R 162R [4.21 /> Z ~U H CURV~. ?.ss/[oo TOP ZOnE 3 9300.00 21.27 9400.00 10.91 94~6,00 9500.00 13.60 357,05 6457.13 8397.63 2179.53 24L5.73 N 1806.77 34.71 8553.32 8493.82 2205.9[ 244[.76 N 1802.29 71,00 8598.60 8539.10 2211.52 244~.65 N I796.03 71,22 8599.50 8540.00 2211.59 2446,70 N TF95.88 80.62 865[.46 8591.96 2215.35 2449~2I N [?85.33 685~99.64 H952181.77 685903.47 5952207.90 685909.61 S952212.9~ 685909.76 $g52213.0~ 685920.25 5952215.7~ 152R 1~.2~ l15R 14.21 33R 14.21 33R 7.58 ITl (AnadriI1 (cl98 0208BP3 3.2C 10:55 ~4 P} bO DS02-0BB (73) WTAT ION IDEi~?Z F I CAT I ON =_-- T~DP ZONE 2 C~JRVE 20/100 END 20/100 CURVE CURVE 20/~00 END 20/1 O0 CURVE CURVE 9/100 ~ ~/lOO c'w~vE CURVE ~/100 hlE,~U'R_EJ3 INCLN DEPTH ANGLE 9518.62 14.90 9520.00 lS.O0 9581.49 23.54 9610,32 23.54 9700.00 39.65 9500.00 58,74 9900.00 78,15 9960.36 90.00 9967.30 91.28 9968,42 91.50 10149,96 91.50 10200.00 91.41 10300-00 93.22 10400.00 90.99 10500.00 90.75 10526.67 90.70 11400.00 91,04 11500.00 91.91 11600.00 91.96 END 87100 CURVE 11664.50 92.22 TO 4-]/2" ~m PT<Ii> 11957.04 92.22 PROPOSED MELL PROFILE DIRECTION A%IMUTH %¢ERTICAL-DEPTHS TVD SUB-SEA 82.85 $669.50 86]0.00 83.00 8670.84 8611.34 55_30 8728.94 8669.44 55.30 8755-37 8695.87 39.34 8831.63 $772.13 EC~ ION DE PART ~_=====_-_- 2216.55 2216.64 2226.76 2234 .41 2270.66 31.74 8896 .73 8837.23 2336 ,96 26 ,53 8933 ,31 8873.81 2422 ~7~ 23.79 8939 .$7 8880.07 2480.05 23 .50 8939 -50 8880 -00 2486.31 23.53 ~939.47 BB?9 . ~7 2487.38 23.53 8934.7~ $~75,24 2661.31 19.03 8933.47 8573.97 2709.76 10.03 8931.17 8871.67 2808.76 1.03 8929,23 8869.73 2988.61 352.03 8927.71 8865-2t 3006-85 350-53 8927.50 8868.00 3022.89 350.53 8917.50 8858,00 3~04.4~ 356.01 8916.46 8856~96 3870.99 3.~9 8914.23 8854~73 3970.15 11.99 8911.20 8851.70 ~070,01 $7.14 8908.84 8849.34 4133.88 I7.14 $897-50 8838.00 4421-58 28 Apr 1998 Page 2 COORDINATES - FROM WELLHE.~D 2449.86 N 1780.79 2449.91 N 1780.44 2457.90 N 1762.37 2464.46 N 175~.91 2496.92 N ALAS~ Zome ~ X Y ...... :=== ..... 685924.76 5952216.54 685929.12 5952216.59 685942.97 5992225.03 685952.27 5952231.82 1719.62 ~ 685984.74 5952265.I0 2555.~4 N 3676.30 2639.39 M !631,50 2694.00 N 1605,87 2699.99 N 1603,25 270].01 ~ 1602,81 686026.51 5952327_67 686069.27 5952409.72 686093.53 5952664.95 686096-00 ~95~471.00 686096.42 5952472,~3 TOOL 06/ FACE 10O 22R 3.68 611 7.58 HS 20.00 34L 0.00 20L 20.00 i$L 20.00 131 20.00 131 20-00 9R 20.00 HS 20.00 2867.40 N 1530.34 ~ 686164.70 5992640.16 911 0.00 2914.00 N 1512-19 W 686181.69 5952687.26 911 9.00 3010.68 N 1487-13 ~ 6~620{,32 5952714.47 9~L 9.00 3110.09 N 1477.51 W 686211.46 5952884.08 921 9.00 3209.79 ~ 1483.$5 W 686202.94 ~952983.60 921 9.00 3226.27 ~ 1486.~8 ~ 686200.00 $953000.00 ~S 9.00 4029.91 ~ 1620.08 ~ 686046.00 5953800.00 86R O,00 4097.94 N 1628.11 W f86036.21 5953%67.80 gTR 8.00 4197.83 N 1621.Z1 W 686033,79 5953967.66 87R 8-00 4296.73 N 1614.23 W 686045.20 5954066.67 87R B.O0 4359.10 N 1598.03 W 686059.84 5954129.62 RS 4638,~3 N 1511,86 W 686139.00 5954421.00 0.0O Z ~> H 0 (Anadrill (c)98 020BBP3 3.2C 10:55 AiWZ:D~:! L AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR E, ,ECUTION PLAN O4/28/199B 15'49 907-344-2160 AHADRILL DPC PAGE 04 SHARER SERV'TCES DRTLE IN6 blarker Tdenti ficat Jori NB N/S A) T]:E-IN SURVEY 9~02 234_8 N ~78~ ~ CURVE ,4.~,/,00 9,85 ,362 N ,796~ L) ENO 8/tO0 CURVE ]~665 4359 N H) fO 4-~/2" LNR PT<II> JJ957 46~8 ii ii 11 i DS02-08B (P3) PLAN VIEN i ii ii ~ CLOSURE ' 4879 feet aZ Azimuth ;34~.g5 DECLINATION.' +28.266 (E) SCALE · ~ inch = 800 feet BRAWN ' 28 Apr ~_998 mm ~nadri 1] £ch'lumberge¢ /Ttrg,t Tut [Point) . rye 'urn (Point) · · % · .... , 2800 2400 2000 1500 1200 800 400 0 400 800 <- NEST' EAST -> 88¸ 930~ 96C 1800 SHARED ,, SE'RV ICE S '"DR I'LL I R-G I! __ . i I Il ii i ii i i Anadr ] ] J Schlumberger i ii i .. i iii VERTICAL SECTION VIEW Section at: 6.95 , ' ! TVD Scale.: ~ inch = 300 Feet ' x, Dep Scale.: 1 inch.: 300 feet ._ \ ..... Drawn ..... : 28 Apr ]998 ~ i i iii , · ....... ~pker Identification ~IO BK8 SEt. IN INCL \ AJ TIE-IN SURVEY 9t02 8287 2085 23.2 % · B) fOP NHPSTCK 12/100 gi55 8332 2111 33.3 "~ C) CURVE 14.2~/100 9185 8357 2~27 36.4 ' " D) P. Ur~VE 7.58/~00 9446 8599 22~2 tO.O A '-'1 J E) CURVE 20/100 9520 B§7:] 22'17 t5.0 ........... .. T~'-~¢~ F) END 20/100 CURVE 9581 8729 2227 23,5 r.' .. G) CURVE 20/100 9610 8755 2234 23,5 ~] END 20/100 CURVE 9968 8939 2487 , 'n CUnVE 9/~00 ~0~50 8985 2B~1 _~.~ X J} END 9/i00 CUP, YE 105~7 8927 3023 90.7 · " ~~ · ] K) CURVE B/lO0 1133~ 89']7 3804 90.7 'T~p-Z~'~='I~K~--~ -'ii' '~{ L) E~ 8/100 CURVE 11665 8909 4J34 "~ 1'4) lO 4-'I/2" LNR PT<I I > 11957 8897 4422 92.2 \ ,. t ......... 1 ' I d K % ..... lg5O 2~00 2~50 2400 2550 2700 2850 3000 3~50 5300 3450 34]00 3758 5900 4050 420(] ~350 45D0 ........... Sect ~on, Bepantur,,e' ................. "0 IT1 ' SH-AR O SERVICES DRILL[lNG ill I II III ~I II o ..... DS02-08B (P3) VERTICAL SECTION VIEW ! ~ 600 ..... Sec(~on at' 6,95 TVQ Scsle.' ~ ~nch ~ 1200 feet Oep Scale' ~ ~nch ~ t~00 feet i200 ' ' - Brawn ' 28 Apr ~998 AnadcJ ]1 Schlumberger Mar~ep Ident~fXcat~on ND BKB SECTN INOLN ~400 ...... ~) TIE-tN SURVEY 9102' 8287 2085 33.33 B] TOP WHPSTCK 12/100 9155 8332 21tl 33.3~ C) CURVE 14.2t/100 9185 8357 2127 36,~7 3000 .... --- D) CURVE 7.58/100 9446 8599 22t2 10,00 El CURVE 20/100 9520 8671 22t7 15.oo ~ F) END ~0/100 CURVE 9581 8729 2227 23.54 I , 6) CURVE 20/100 9610 8755 2234 23,5d V 3600 ~ ~ ..... H1 END 20/100 CURVE 9968 8939 2487 91.50 ' I1 CURVE 9/100 101~0 8935 2661 91,50 ~ J) END 9/100 CURVE 10517 8927 3023 90.70 ~ K) CURVE 8/100 11331 8917 3804 90.70 ~ L) END 8/t00 CURVE 11665 8909 ~134 92.22 ~ N) TO 4-1/2" LNR PT<II > 11957 8897 4422 92.22 4800 '"- ~ "' 5400-~ *'-----"-- ............ 6000 ..... % 66oo-~ \ · /~M · 7800 .... '~'~ 8~oo~~ ~~°~-'~* .............. ........ "_~ ........ " " ~,T .... ~ ~n~.~¢~c~¢.-~.~ Iurn (Point) ilO00 ........ ~ I } ...... K L M-'- ,., 9600 - " 10200 .......... rOB00 '" ] - 0 600 1200 1800 2~00 3000 3600 4200 4800 5400 6000 6500 7200 7800 .... Section Dgparture ....... WELL NAME: IDRILLING PERMIT/SUNDRY/PRE-RIG I COVER SHEET IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) [ I DRILLING PERMIT o P~rEmit Prepared: : Reviewed: Date.'~//~JO0 TA: PRE-RIG WORK Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date:~ Pre-Rig Sundry Application Reviewed: SDE/ES: Date:~ Pre-Rig Sundry Application Submitted: TA: Date: SUNDRY NOTICE ['~ Sundry Documentation Prepared: ODE: Date: ["~ Sundry Application Reviewed: SDE/ES: Date: D Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT Reason for Sundry (Check all that apply) Change to sumitted Drilling Permit Change to approved Drilling Permit Abandon Wellbore Workover of Injection Well Reenter Suspended Well Suspend Wellbore Change Well Type (Injector, Producer) Extending Expired Permit Other (Explain): APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: H 13 G 0 8 2 o~..':~,'~ oo.~6o.: ,,~ VENDOR ALAS½ASTI4 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 03249@ CKO32498D i00.00 i00.00 HANDL[N~ INST' S/H TERRI HUBBLE X rilE A~ACHED CHECK IS IN PAYME~ FOR ~MS DE~RIBED ABOVE. · WELL PERMIT CHECKLIST COMPANY/'~C'-~L__~ FIELD & POOL /"'~ ~"~'~,Z'..~',,-'J INIT CLASS /-~::~,/ GEOL AREA _~:?¢~ UNIT# //'~'~"'¢'J ON/OFFSHORE ADMINISTRATION 1. Permit fee attached ....................... '~ 2. Lease number appropriate ................... '~ 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance 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 ........... -- N N 'N N N N N N N N N N N ENGINEERING OEdEb--6~? .......... 14. Conductor string provided ................... Y N/~ [, 15. Surface casing protects all known USDWs ........... Y N ('..,,t 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ ..~ N 18. CMT will cover all known productive horizons .......... rCy..,' N 19. Casing designs adequate for C, T, B & permafrost ....... ~~N ~ 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 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 ..... (~ N 25. BOPEs, do they meet regulation ................ ~ N 26. BOPE press rating appropriate; test to ':~~ pslg. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N ' 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............ /' Y N 34. Contact name/phone for we,ekly,pro~lress reDo, ds .... .~ . Y N lexp~ora~ory omyj REMARKS GEOLOGY: ENGINEERING: COMMISSION: RPJ~ BE ', DWJ ,.~ JD .,.,~ RNC~ CO Comments/Instructions: A:\GEN. Misc\FORMS\cheklist rev 09/97 dlf' C'\msoffice\wordiar)\diarm\r:l ~('mldisl 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. * ALASKA COMPUTING CENTER * . . . ............................ . ....... SCHLUMBERGER ....... . ............................ . COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 02-08B FIELD NAME : PRUDHOE BAY BOROUGH · NORTH SLOPE STATE · ALASKA API NUMBER : 500292015502 REFERENCE NO : 98422 RECEIVED [,..~z>,R 26 1999 Alaska Oil & Gas Cons. Commission LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1999 16:15 PAGE .. **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/03/16 ORIGIN · FLIC REEL NAME : 98422 CONTINUATION # : PREVIOUS REEL : CO~94ENT : ARCO ALASKA, INC., DS 02-08B, PRUDHOE BAY, #50-029-20155-02 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/03/16 ORIGIN : FLIC TAPE NAME : 98422 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : ARCO ALASKA, INC., DS 02-08B~ PRUDHOE BAY, #50-029-20155-02 TAPE HEADER PRUDHOE BAY OPEN HOLE WIRELINE LOGS 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 (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING RUN1 98422 D. PALMER J. RAY DS 02-08B 500292015502 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 16-MAR-99 RUN 2 RUN 3 36 llN 14E 3972 597 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 9.688 9170.0 58.00 57.00 29.00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1999 16:15 3RD STRING PR OD UC TI ON REMARKS: STRING CONTAINED HEREIN IS THE PEX/BHC/HALS DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 02-08B ON 16-JUN-98. THE DATA PRESENTED ON THIS TAPE WAS DIGITIZED FROM THE FIELD BLUELINES OF 16-JUN-98. ONLY THE CURVES PRESENTED ON THE BLUELINESARE PRESENTED IN THIS EDIT. THE DIGITIZ- ING SAMPLE RATE IS .5'. NO HIGH-RESOLUTION DATA IS PRESENTED ON THIS TAPE. THIS DATA HAS BEEN SHIFTED TO A BASE GAMMA RAY (GR.MRG) MADE UP OF GR.BCS FROM THE PARENT WELL FROM 8750'-9150', AND GR.MWD FROM THE SIDETRACK WELL FROM 9150'-12149'. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 99/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MAIN PASS All tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUF~ARY LDWG TOOL CODE DLL CNT SDN BCS $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 9928.0 8764.0 9896.0 8764.0 9910.0 9143.0 9880.0 9143.0 BASELINE DEPTH .............. 88888 0 9902 5 9890 5 9878 5 9869 5 9852 0 9828 5 9820 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... DLL CNT SDN BCS 88873.0 9887.5 9876.0 9863.0 9854.0 9837.5 9812.5 9803.5 LIS Tape Verification L'isting Schlumberger Alaska Computing Center 9813 0 9807 5 9802 5 9780 5 9771 5 9756 0 9732.0 9719.5 9711.5 9704.5 9695.5 9670.0 9668.0 9664.5 9659.5 9645.5 9633.5 9627.5 9614.0 9608.0 9604.0 9578.0 9545.0 9518.5 9513.0 9491.5 9477.0 9458.0 9449.5 9443 0 9398 0 9381 5 9368 5 9362 5 9321 5 9311 0 9299.0 9277.0 9239.0 9227.5 9204.5 9198.5 9162.5 9155.0 9122.0 9064.0 9036.0 9014.5 8984.0 8969.0 8961.0 8914.5 8888.0 8881.5 8879.0 9796.5 9790.5 9786.0 9763.0 9755.0 9740.5 9714.0 9703.5 9695.0 9688.5 9683.5 9655.0 9652.5 9649.5 9645.0 9632.0 9620.0 9612.5 9601.0 9594.5 9591.0 9563.5 9533.5 9505.0 9500.5 9478.0 9463.5 9445.0 9436.5 9428.5 9384.5 9368.0 9357.0 9349.5 9307.5 9298.0 9285.5 92 63.5 9224.5 9212.5 9191.5 9186.0 9148.5 9140.0 9106.5 9047.5 9020.0 8999.5 8969.5 8955.5 8946.0 8900.0 8873.0 8867.0 8864.0 16-I,y~-1999 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1999 16:15 PAGE: 8864.5 8844.0 8817.0 8808.5 8784.5 8780.5 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ RE~zARKS: 8850 5 8829 0 8802 5 8793 5 8770 5 8766 5 86 0 RUN NO. PASS NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MAIN PASS. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE MAIN PASS GA94~A RAY TO GR.I~RG (SEE TAPE HEADER REMARKS). ALL OTHER CURVES WERE CARRIED WITH THE GAiV~4A RAY SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1999 16:15 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185974 O0 000 O0 0 1 1 1 4 68 SP DLL MV 1185974 O0 000 O0 0 1 1 1 4 68 GR DLL GAPI 1185974 O0 000 O0 0 1 1 1 4 68 TENS DLL LB 1185974 O0 000 O0 0 1 1 1 4 68 CNTC CNT CPS 1185974 O0 000 O0 0 1 1 1 4 68 CFTC CNT CPS 1185974 O0 000 O0 0 1 1 1 4 68 NPHI CNT PU-S 1185974 O0 000 O0 0 1 1 1 4 68 DT BCS US/F 1185974 O0 000 O0 0 1 1 1 4 68 CALl SDN IN 1185974 O0 000 O0 0 1 1 1 4 68 DRHO SDN G/C3 1185974 O0 000 O0 0 1 1 1 4 68 PEF SDN BN/E 1185974 O0 000 O0 0 1 1 1 4 68 RHOB SDN G/C3 1185974 O0 000 O0 0 1 1 1 4 68 MSFL SDN OHMMl185974 O0 000 O0 0 1 1 1 4 68 MINVSDN OH~M 1185974 O0 000 O0 0 1 1 1 4 68 I4NORSDN OPiMMl185974 O0 000 O0 0 1 1 1 4 68 LLS DLL OHMMl185974 O0 000 O0 0 1 1 1 4 68 LLD DLL OH~Ml185974 O0 000 O0 0 1 1 1 4 68 GR MRG GAPI 1185974 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 12149.000 SP.DLL -999.250 CR.DLL -999.250 TENS.DLL CNTC. CNT -999.250 CFTC. CNT -999.250 NPHI. CNT -999.250 DT.BCS CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 RHOB.SDN MSFL.SDN -999.250 MINV. SDN -999.250 MNOR.SDN -999.250 LLS.DLL LLD.DLL -999.250 GR.I~RG 58.721 DEPT. 8750.000 SP.DLL -999.250 GR.DLL -999.250 TENS.DLL CNTC. CNT -999.250 CFTC. CNT -999.250 NPHI.CNT -999.250 DT.BCS CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 RHOB.SDN MSFL.SDN -999.250 MINV. SDN -999.250 ~!NOR.SDN -999.250 LLS.DLL LLD.DLL -999.250 GR.RIRG 134.621 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 99/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~9~RY FILE HEADER FILE NUMBER 2 RAW MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH PEX 9950.0 8720.0 BHC 9950.0 8720.0 HALS 9950.0 8720.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 16-JUN-98 8Cl-205 600 16-JUN-98 10440.0 9948.0 8800.0 9933.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ........... AMS AUX. MEAS. SONDE AMS-A BHC COMP. SONIC DSLT-TCC PEX PLATFORM EXPRESS HILTB-DTB HALS LA TEROLOG HALS- B $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 9170.0 9143.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1999 16:15 PAGE: BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OH~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : QUICK DRIL-N 8.60 62.0 9.0 0. 200 56.0 O. 195 56.0 O. 287 56.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: DEPTH CORRELATED TO SPERRY-SUN MWD GR LOG 16-JUN-98. (NOT TIED INTO DATA BASE GR FOR CONSISTANCY ON THIS WELL). APPROX. 14' SHIFT TO DATA BASE GR. TOOLS RAN WITH 1/2" STANDOFFS ON RESISTIVITY AND SONIC. CNL AND DENSITY RAN WITH 4.5" TOOL TURNERS. HALS (LATERLOG) RAN. THIS FILE CONTAINS THE RAW, DIGITIZED DATA FOR THE MAIN PASS. THIS DATA WAS DIGITIZED AT .5' SAMPLE RATE FROM THE FIELD PRINTS OF 16-JUN-98. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1999 PAGE: TYPE REPR CODE VALUE 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 SP HALS MV 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 GR HALS GAPI 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 TENS HALS LB 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC PEX CPS 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC PEX CPS 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI PEX PU 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 DT BHC US/F 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 RHOZ PEX G/C3 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 HDRA PEX G/C3 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 PEFZ PEX 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 P24IN PEX OH~4M 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 HMNO PEX Otflvff41185974 O0 000 O0 0 2 1 1 4 68 0000000000 RXOZ PEX 0P2~41185974 O0 000 O0 0 2 1 1 4 68 0000000000 HLLD HALS 0~1185974 O0 000 O0 0 2 1 1 4 68 0000000000 HLLS HALS 0H~f1185974 O0 000 O0 0 2 1 1 4 68 0000000000 HCAL PEX IN 1185974 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9950.000 SP.HALS -0.023 GR.HALS 53.415 TENS.HALS CNTC. PEX 3882.495 CFTC. PEX 1883.599 NPHI.PEX 22.597 DT. BHC RHOZ.PEX 2.351 HDRA.PEX 0.060 PEFZ.PEX 2.467 H~IN. PEX P24NO.PEX 3.353 RXOZ.PEX 9.333 HLLD.HALS 29.034 HLLS.t~ALS HCAL.PEX 5.991 DEPT. 8720.000 SP.HALS 20.240 GR.HALS 148.796 TENS.HALS CNTC. PEX 1386.514 CFTC. PEX 333.271 NPHI.PEX 56.089 DT. BHC RHOZ.PEX 1.651 HDRA.PEX 0.696 PEFZ.PEX 1.288 HMIN. PEX H~VO.PEX -0.019 RXOZ.PEX 0.205 HLLD.HALS 0.313 HLLS.HALS HCAL.PEX 8.627 2147.996 77.332 4.892 22.017 1444.702 -48.750 0.061 0.205 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1999 ~ ~15 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SO?4FIAR Y FILE HEADER FILE NUMBER 3 RAW REPEAT PASS Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH PEX 9940.0 8750.0 HALS 9940.0 8750.0 BHC 9940.0 8750.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE BHC COMP. SONIC 16-JUN-98 8Cl-205 600 16-JUN-98 10440.0 9948.0 8800.0 9933.0 1800.0 TOOL NUMBER ........... AMS-A DSLT-TCC LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1999 PAGE: 10 PEX PLATFORM EXPRESS HALS LA TEROLOG $ HILTB-DTB HALS-B BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) '. 6.000 9170.0 9143.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): QUICK DRIL-N 8.60 62.0 9.0 O. 200 56.0 O. 195 56.0 O. 287 56.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: DEPTH CORRELATED TO SPERRY-SUN MWD GR LOG 16-JUN-98. (NOT TIED INTO DATA BASE GR FOR CONSISTANCY ON THIS WELL). APPROX. 14' SHIFT TO DATA BASE GR. TOOLS RAN WITH 1/2" STANDOFFS ON RESISTIVITY AND SONIC. CNL AND DENSITY RAN WITH 4.5" TOOL TURNERS. HALS (LATERLOG) RAN. THIS FILE CONTAINS THE RAW, DIGITIZED DATA FOR THE REPEAT PASS. THIS DATA WAS DIGITIZED AT .5' SAMPLE RATE FROM THE FIELD PRINTS OF 16-JUN-98. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE N73M~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185974 O0 000 O0 0 3 1 i 4 68 0000000000 SP HALS MV 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 GR HALS GAPI 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 TENS HALS LB 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC PEX CPS 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX PU 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US/F 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 RHOZ PEX G/C3 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 HDRA PEX G/C3 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 PEFZ PEX 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 HMIN PEX OH~ff41185974 O0 000 O0 0 3 1 1 4 68 0000000000 HIqNO PEX OHFk41185974 O0 000 O0 0 3 1 1 4 68 0000000000 RXOZ PEX 0HI~41185974 O0 000 O0 0 3 1 1 4 68 0000000000 HLLDHALS OHMMl185974 O0 000 O0 0 3 1 1 4 68 0000000000 HLLS HALS Otff4Ml185974 O0 000 O0 0 3 1 1 4 68 0000000000 HCAL PEX IN 1185974 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9940.000 SP.HALS 0.004 GR.HALS 83.918 TENS.HALS CNTC. PEX 4153.434 CFTC. PEX 2123.822 NPHI.PEX 20.483 DT. BHC RHOZ.PEX 2.403 HDRA.PEX 0.141 PEFZ.PEX 1.947 H~4IN. PEX HMNO.PEX 0.564 RXOZ.PEX 7.240 HLLD.HALS 44.296 HLLS.HALS 1803.441 77.837 0.440 35.886 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-MAR-1999 PAGE: 12 HCAL. PEX 13 . 617 DEPT. 8750.000 SP.HALS CNTC. PEX 1380.136 CFTC. PEX RHOZ.PEX 1.652 HDRA.PEX HMNO. PEX 0.448 RXOZ.PEX HCAL. PEX 13.778 28.941 GR.HALS 415.077 NPHI. PEX 0.097 PEFZ.PEX 0.544 HLLD.HALS 106.891 TENS.HALS 45.676 DT. BHC 4.760 H~IN. PEX 0.207 HLLS.HALS 1099.755 55.459 0.453 0.203 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 99/03/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/16 ORIGIN : FLIC TAPE NAME : 98422 CONTINUATION # : 1 PREVIOUS TAPE : CO~fl~ENT : ARCO ALASKA~ INC. , DS 02-08B, PRUDHOE BAY, #50-029-20155-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/03/16 ORIGIN : FLIC REEL NAME : 98422 CONTINUATION # : PREVIOUS REEL CON, lENT : ARCO ALASKA, INC., DS 02-08B, PRUDHOE BAY, #50-029-20155-02 ,. J Sperry-Sun Drilling Services LIS Scan Utility Thu Sep 10 10:24:09 1998 Reel Header Service name ............. LISTPE Date ..................... 98/09/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/09/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-80256 T.MCGUIRE P. WILSON RECENED SEP 1 6 1998 2 - 0 8 g ,~i~ 0ii & G~ Cons. Commi~io~ 500292015502 ~CO ALAS~, INC. SPERRY-SUN DRILLING SERVICES 10-SEP-98 MWD RUN 2 AK-MW-80256 T.MCGUIRE P. WILSON MWD RUN 3 AK-MW-80256 T.MCGUIRE P. WILSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-80256 A.WEAVER P.WILSON MWD RUN 4 AK-MW-80256 A.WEAVER P.WILSON MWD RUN 5 AK-MW-80256 A.WEAVER P.WILSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: MWD RUN 51 AK-MW-80256 A.WEAVER P.WILSON MWD RUN 52 AK-MW-80256 A.WEAVER P.WILSON 36 TOWNSHIP: liN RANGE: 14E FNL: FSL: 3887 FEL: 4276 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 58.00 DERRICK FLOOR: 58.00 GROUND LEVEL: 29.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 13.375 2747.0 3RD STRING 9.625 9161.0 PRODUCTION STRING 6.000 12210.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 3. MWD RUNS 4 AND 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4. CHANGE FROM SCINTILLATION TYPE GAMMA RAY (NGP) TO DUAL GAMMA RAY (DGR) AT 9910'MD, 8937'TVD. 5. 3 MEASUREMENT AFTER DRILLING (MAD) PASSES WERE PERFORMED AFTER MWD RUNS 4 AND 5, AND ARE PRESENTED AS A TAIL ON THIS LOG. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12210'MD, 8880'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. CURVE WITH THE EXTENSION "M" ARE MEASUREMENT AFTER DRILLING (MAD). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 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 GR ROP RPS RPX FET RPD RPM $ START DEPTH 8994 0 9042 5 9909 0 9909 0 9909 5 9909 5 9909 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 8994.0 9019.5 9028.5 9075 0 9100 5 9102 0 9107 0 9128 5 9131 0 9140.5 9148.0 9152.0 9158.0 12165.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: GR 9010 0 9035 5 9042 5 9087 5 9119 5 9121 5 9126 5 9147 0 9150 0 9155 5 9163 0 9165 5 9171 0 12178.5 STOP DEPTH 12149.0 12200.5 12156.0 12156.0 12156.0 12156.0 12156.0 EQUIVALENT UNSHIFTED DEPTH 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 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 1 9056.0 9409.0 2 9409.0 9756.0 3 9756.0 9963.0 4 9963.0 10970.0 5 10970.0 12210.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 8994 12200.5 10597.2 6414 ROP 1.0654 2429.3 107.501 6317 GR 18.25 604.849 68.8241 6311 RPX 7.2207 145.357 39.5677 4495 RPS 8.5897 220.52 54.1464 4495 RPM 9.0296 2000 69.3447 4494 RPD 8.7714 2000 67.4783 4494 FET 0.5339 50.7026 2.96779 4494 First Reading 8994 9042.5 8994 9909 9909 9909.5 9909.5 9909.5 Last Reading 12200.5 12200.5 12149 12156 12156 12156 12156 12156 First Reading For Entire File .......... 8994 Last Reading For Entire File ........... 12200.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 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 ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9676.0 12157.0 RPD RPM RPS RPX FET $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: 9682.5 12165.5 9682.5 12165.5 9682.5 12165.5 9682.5 12164.5 9711.0 12165.5 MAD RUN NO. MAD PASS NO. 4 51 52 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 9963.0 10970.0 10970.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD API 4 1 68 4 2 RPX MAD OHMM 4 1 68 8 3 RPS MAD OHMM 4 1 68 12 4 RPM MAD OHMM 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 FET MAD HOUR 4 1 68 24 7 MERGE BASE 10970.0 12210.0 12210.0 Name Min Max Mean Nsam DEPT 9676 12165.5 10920.8 4980 GR 18.4411 182.459 72.615 4963 RPX 0.238 2000 20.9184 4965 RPS 0.5251 2000 31.3756 4967 RPM 1.3549 2000 47.6091 4967 RPD 1.8232 2000 55.0279 4967 FET 6.009 182.514 46.8779 4910 First Reading 9676 9676 9682.5 9682.5 9682.5 9682.5 9711 Last Reading 12165.5 12157 12164.5 12165.5 12165.5 12165.5 12165.5 First Reading For Entire File .......... 9676 Last Reading For Entire File ........... 12165.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 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 ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9010.0 ROP 9056.5 $ 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 9353.5 9408.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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) 13-JUN-98 ISC 5.07, ISC 5.07 2.22A, 5.74 MEMORY 9409.0 9056.0 9409.0 22.4 31.3 TOOL NUMBER NGP SPC 280 6.000 6.0 QUICK DRIL-N 8.60 70.0 9.0 22000 8.2 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 .000 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 40.0 First Name Min Max Mean Nsam Reading DEPT 9010 9408.5 9209.25 798 9010 GR 23.4402 604.849 84.2536 688 9010 ROP 1.0654 1976.87 344.582 705 9056.5 Last Reading 9408.5 9353.5 9408.5 First Reading For Entire File .......... 9010 Last Reading For Entire File ........... 9408.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 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 ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW 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 9353.5 ROP 9408.5 $ 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 9700.0 9756.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 15-JUN-98 ISC 5.07, ISC 5.07 2.22A, 5.74 MEMORY 9756.0 9409.0 9756.0 20.3 41.0 TOOL NUMBER PCG 61 6.000 6.0 QUICK DRIL-N 8.60 65.0 8.2 22000 8.0 .000 .000 .000 .000 42.2 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 .0 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 9353.5 9756.5 9555 807 9353.5 GR 18.25 117.5 32.1777 694 9353.5 ROP 4.5266 724.111 88.0289 697 9408.5 Last Reading 9756.5 9700 9756.5 First Reading For Entire File .......... 9353.5 Last Reading For Entire File ........... 9756.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW 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 9672.5 ROP 9756.5 $ 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 9906.5 9963.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY {S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 16-JUN-98 ISC 5.07, ISC 5.07 2.22A, 5.74 MEMORY 9963.0 9756.0 9963.0 45.2 74.3 TOOL NUMBER 6.000 6.0 QUICK DRIL-N 8.60 65.0 8.2 22000 8.0 .000 .000 .000 .000 42.2 .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 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 9672.5 9963 9817.75 582 9672.5 GR 21.1154 135.172 47.4559 469 9672.5 ROP 6.4294 257.645 57.6512 414 9756.5 Last Reading 9963 9906.5 9963 First Reading For Entire File .......... 9672.5 Last Reading For Entire File ........... 9963 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9917.0 10921.5 RPS 9922.0 10928.5 RPX 9922.0 FET 9922.5 RPD 9922.5 RPM 9922.5 ROP 9964.5 $ # 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 10928.5 10928.5 10928.5 10928.5 10970.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 20-JUN-98 ISC 5.07, ISC 5.07 2.22A, 5.74 MEMORY 10970.0 9963.0 10970.0 81.2 96.6 TOOL NUMBER P1006GR4 P1006GR4 6.000 6.0 QUICKDRILN 8.70 65.0 8.6 20000 6.6 .210 .210 .200 .300 56.3 .0 Frame Spacing ..................... 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 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 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 ROP MWD 4 FT/H 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 9917 38 8652 7 2207 8 5897 9 0296 9 9751 6 5729 0.7015 First Max Mean Nsam Reading 10970 10443.5 2107 9917 162.477 81.5156 2010 9917 57.3773 27.3179 2014 9922 72.379 35.07 2014 9922 76.9395 39.247 2013 9922.5 79.0862 39.076 2013 9922.5 2142.97 69.3126 2012 9964.5 50.7026 3.85735 2013 9922.5 Last Reading 10970 10921.5 10928.5 10928.5 10928.5 10928.5 10970 10928.5 First Reading For Entire File .......... 9917 Last Reading For Entire File ........... 10970 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10922.0 FET 10929.0 RPD 10929.0 RPM 10929.0 RPS 10929.0 RPX 10929.0 ROP 10971.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): ~OP 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE {DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ STOP DEPTH 12162.0 12169.0 12169.0 12169.0 12169.0 12169.0 12210.5 23-JUN-98 ISC 5.07, ISC 5.07 2.22A, 5.74 MEMORY 12210.0 10970.0 12210.0 87.8 96.1 TOOL NUMBER P1006GR4 P1006GR4 6.000 6.0 QUICKDRILN 8.70 63.0 8.5 19500 6.2 · 190 · 103 · 175 .260 60.9 .0 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 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 5 API 4 1 RPX MWD 5 OHMM 4 1 RPS MWD 5 OHMM 4 1 RPM MWD 5 OHMM 4 1 RPD MWD 5 OHMM 4 1 ROP MWD 5 FT/H 4 1 FET MWD 5 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 First Name Min Max Mean Nsam Reading DEPT 10922 12210.5 11566.2 2578 10922 GR 27.6907 151.881 68.1578 2481 10922 RPX 9.2095 145.357 49.5117 2481 10929 RPS 10.1862 220.52 69.6321 2481 10929 RPM 9.1669 2000 93.7651 2481 10929 RPD 8.7714 2000 90.5231 2481 10929 ROP 4.594 2429.3 87.6328 2479 10971.5 FET 0.5339 26.5907 2.24603 2481 10929 Last Reading 12210.5 12162 12169 12169 12169 12169 12210.5 12169 First Reading For Entire File .......... 10922 Last Reading For Entire File ........... 12210.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9875.0 10921.0 RPD 9884.0 10929.0 RPM 9884.0 10928.5 RPS 9884.0 10928.5 RPX 9884.0 10928.5 FET 9964.0 10928.5 $ 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: 20-JUN-98 ISC 5.07, ISC 5.07 2.22A, 5.74 MEMORY 10970.0 9963.0 10970.0 81.2 96.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P1006GR4 P1006GR4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: QUICKDRILN 8.70 65.0 8.6 20000 6.6 .210 .210 .200 .300 56.3 NEUTRON TOOL MATRIX: Dat Name DEPT GR RPX RPS RPM RPD FET MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 REMARKS: a 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 Service Order Units Size Nsam Rep FT 4 1 68 MAD 4 API 4 t 68 MAD 4 OHMM 4 1 68 MAD 4 OHMM 4 1 68 MAD 4 OHMM 4 1 68 MAD 4 OHMM 4 1 68 MAD 4 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 Name Min Max Mean DEPT 9875 10929 10402 GR 32.107 178.778 80.3156 RPX 6.8212 36.9646 17.9051 RPS 8.2151 57.5505 25.3742 RPM 8.6746 72.8295 32.8254 RPD 9.5386 74.981 35.5354 FET 3.9551 50.7088 24.0842 Nsam 2109 2093 2090 2090 2090 2091 1930 First Reading 9875 9875 9884 9884 9884 9884 9964 Last Reading 10929 10921 10928.5 10928.5 10928.5 10929 10928.5 First Reading For Entire File .......... 9875 Last Reading For Entire File ........... 10929 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5000 51 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10841.5 12170.0 FET 10848.5 12178.5 RPD 10848.5 12178.5 RPM 10848.5 12178.5 RPS 10848.5 12178.5 RPX 10848.5 12177.5 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 23-JUN-98 ISC 5.07, ISC 5.07 2.22A, 5.74 MEMORY 12210.0 10970.0 12210.0 87.8 96.1 TOOL NUMBER P1006GR4 P1006GR4 6.000 6.0 QUICKDRILN 8.70 63.0 8.5 19500 6.2 .190 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 .103 .175 .260 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 t GR MAD 51 API 4 1 68 4 2 RPX MAD 51 OHMM 4 1 68 8 3 RPS MAD 51 OHMM 4 1 68 12 4 RPM MAD 51 OHMM 4 1 68 16 5 RPD MAD 51 OHMM 4 1 68 20 6 FET MAD 51 HOUR 4 1 68 24 7 60.9 Name DEPT GR RPX RPS RPM RPD FET Min 10841.5 23 4141 4 5393 7 4855 9 9872 8 7499 7 6492 First .Max Mean Nsam Reading 12178.5 11510 2675 10841.5 182.459 68.4721 2658 10841.5 2000 20.9136 2659 10848.5 109.499 34.3235 2661 10848.5 2000 61.7049 2661 10848.5 2000 73.384 2661 10848.5 81.6961 36.0448 2661 10848.5 Last Reading 12178.5 12170 12177.5 12178.5 12178.5 12178.5 12178.5 First Reading For Entire File .......... 10841.5 Last Reading For Entire File ........... 12178.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 52 MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9689.0 9977.5 RPD 9695.5 9984.5 RPM 9695.5 9985.0 RPS 9695.5 9985.0 RPX 9695.5 9985.0 FET 9724.0 9985.0 $ LOG HEADER DATA DATE LOGGED: 23-JUN-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07, ISC 5.07 DOWNHOLE SOFTWARE VERSION: 2.22A, 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 12210.0 TOP LOG INTERVAL (FT): 10970.0 BOTTOM LOG INTERVAL (FT): 12210.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.8 MAXIMUM ANGLE: 96.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): TOOL NUMBER P1006GR4 P1006GR4 6.000 6.0 QUICKDRILN 8.70 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 63.0 8.5 19500 6.2 .190 .103 .175 .260 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD 52 API 4 1 68 4 2 RPX MAD 52 OHMM 4 1 68 8 3 RPS MAD 52 OHMM 4 1 68 12 4 RPM MAD 52 OHMM 4 1 68 16 5 RPD MAD 52 OHMM 4 1 68 20 . 6 FET MAD 52 HOUR 4 1 68 24 7 60.9 First Name Min Max Mean Nsam Reading DEPT 9689 9985 9837 593 9689 GR 18.4411 155.285 57.2454 578 9689 RPX 0.238 2000 30.635 580 9695.5 RPS 0.5251 2000 36.8195 580 9695.5 RPM 1.3549 2000 29.0308 580 9695.5 RPD 1.8232 2000 33.213 579 9695.5 FET 123.586 182.514 173.526 523 9724 Last Reading 9985 9977.5 9985 9985 9985 9984.5 9985 First Reading For Entire File .......... 9689 Last Reading For Entire File ........... 9985 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/09/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/09/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File