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Home My WebLink About202-2017. 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 J-01B Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-201 50-029-20020-02-00 341J ADL 0028281 10758 Conductor Surface Intermediate Liner Liner 9026 932 4220 3521 575 2697 9800 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9002 39 - 950 38 - 4258 37 - 8558 8089 - 8664 8061 - 10758 2620 39 - 950 38 - 4258 37 - 8846 8088 - 8663 8060 - 9026 10724 520 1540 4760 6820 10530 9800 1530 3090 6870 7740 10160 9580 - 10717 4-1/2" 12.6# 13cr, L-80 35 - 80849005 - 9024 Structural 26 30" 40 - 66 40 - 66 4-1/2" Baker S3 Packer 4-1/2" TIW HBBP-R Packer 7857, 7856 8019, 8018 Date: Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 PRUDHOE BAY 12/18/2025 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 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.12.05 09:07:42 - 09'00' Torin Roschinger (4662) 325-741 By Grace Christianson at 11:29 am, Dec 05, 2025 10-404 DSR-12/5/25 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 J.Lau 12/8/25 TS 12/8/25JLC 12/8/2025 12/09/25 Page 1 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Well Name:J-01B API Number:50-029-20020-02 Current Status:Ivishak Producer PTD #202-201 Estimated Start Date:12/18/2025 Rig:Coil Tubing Reg.Approval Reqstd?10-403, 10-404 Estimated Duration:2 days Regulatory Contact:Abbie Barker 907-564-4915 (O) First Call Engineer:Brenden Swensen 907-748-8581 (M) Second Call Engineer:Leif Knatterud 907-564-4667 (O) Current Bottom Hole Pressure:3,200 psi @ 8,800 TVD (7.0 ppge, based on offsets) Maximum Expected BHP:3,500 psi @ 8,800 TVD (est.) 7.6ppg EMW Max. Anticipated Surface Pressure:2,620 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:1,400 psi (6/8/2025) H2S Level (Most Recent / Highest):18ppm 11/10/2025, 20ppm 04/14/2019 History J-01B was originally completed in 1979, side tracked in 1994 and again most recently in 2002. The well required a rig work over in 2006 to replace the tubing. The original 2002 perforations remained competitive until July of 2021. A plug was set and Z4 rich gas was shot from 8,577 8,597 MD. After the rich gas became uncompetitive, a plug was set and the Sag was perforated from 8,436 8,460 MD on 6/25/2022. This remained competitive until 2024. A cement squeeze was performed on the Sag and Z4 perforations, CIBPs were milled out on 4/2/2024. This was done as an intermediate step to gain some flush production from the original perforations in 2002. On 11/25/24, these perforations were again set behind a CIBP and an extended add perf was performed from 9,900 10,100 MD in Z2A. In June of 2025, the CIBP was milled out to preemptively remove it, a new one was set and 88 of perforations were added. These perforations were expected to last 4-8 months and have performed as expected, lasting about 6 months before becoming marginal. Objective Isolate existing perforations behind a CIBP and shoot the next intervals of extended perforations. Attachments Current Wellbore Schematic Proposed Wellbore Schematic Tie In Log BOP Schematic Extended Perforating Standing Orders Equipment Layout Sundry Change Form Page 2 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Procedure (Page 1 of 2) Coil Tubing 1. Make up motor and mill. Mill out 2-7/8 CIBP at 9,800 MD and push to TD. a. Attempt to get plug to below 10,717 MD perforations. b. Plug is pre-emptively being milled to ensure highest chance of success of returning to bottom most perforations for future flush production opportunities. 2. Perform GR/CCL logging run from 9,800 to 8,000 MD. Flag pipe for plug and perf runs. a. Send field print to OE, brenden.swensen@hilcorp.com 3. Set 2-7/8 CIBP at ±9,480 MD. a. Tie in log shows collars at 9,471 and 9,502 MD. CoilTubing Extended Perforating Notes: Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations 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. 4. 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. 5. Bullhead 1.2x wellbore volume ~165 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 = 134 bbls b. 4-1/2 tubing 8,061 X .0152 bpf = 123 bbls c. 3-1/2 liner 577 x 0.0081 bpf = 5 bbls d. 3-3/16 Liner 99 X .0076 bpf = 1 bbl e. 2-7/8 Liner 843 X .0058 bpf = 5 bbls 6. At surface, prepare for deployment of TCP guns. 7. 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. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Page 3 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Procedure (Page 2 of 2) Coil Tubing Extended Perforating 8.*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 spacedout, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.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. 9. 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 Millenium guns or similar Run Sand TOP MD BOT MD Total Order to Shoot Gross Interval Net Guns Weight of Gun (lbs) 1 Z2A 9,111 9,19685 1 254 196 ± 1,422 lbs (5.6 ppf) Z2A 9,216 9,25034 Z2A 9,268 9,28012 Z2A 9,300 9,36565 10. 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. 11. After perforating, PUH to top of liner or into tubing tail to ensure debris doesnt fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 12. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 13. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 14. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. If ops is not ready to POP well, freeze protect to 2,100 MD with 32 bbls of diesel. 16. RDMO CTU. 17. Turn well over to Operations POP. Page 4 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 5 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 6 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 7 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 8 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 BOP Schematic Page 9 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 10 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 11 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 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 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 J-01B Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-201 50-029-20020-02-00 10758 Conductor Surface Intermediate Liner Liner 9026 932 4220 3521 469 2697 9800 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9002 39 - 950 38 - 4258 37 - 8558 8089 - 8558 8061 - 10758 39 - 950 38 - 4258 37 - 8846 8088 - 8557 8060 - 9026 10724 520 1540 4760 6820 10530 9800 1530 3090 6870 7740 10160 9580 - 10717 4-1/2" 12.6# 13cr, L-80 35 - 8084 9005 - 9024 Structural 26 30" 40 - 66 40 - 66 4-1/2" Baker S3 Packer 8019, 8018 7857, 8019 7856, 8018 Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 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 0028281 35 - 8083 IC Void in Wellhead at Surface Pump 3-cups of Greenstick. Final Pressure = 0-psi. 346 367 18320 17967 18 25 450 500 260 280 N/A 13b. Pools active after work:Prudhoe Oil 4-1/2" TIW HBBP-R Packer 7857, 7856 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 8:17 am, Aug 21, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.21 05:52:13 - 08'00' Torin Roschinger (4662) RBDMS JSB 082825 DSR-9/11/25J.Lau 11/4/25 ACTIVITY DATE SUMMARY 8/6/2025 T/I/O = 240/5500/540. Temp = 81°. Liquid Greenstick IC-test void/retreat. No AL. RU packing gun to 1/2" Hoke valve and pumped ~1-1/2 of a guns of Semi-liquid greenstick. Held pressure for 1 hr for a good pack. Bled OAP to BT to 0 psi in <1 min (gas). Monitored for 30 min. OAP increased 0+ psi. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:30 Daily Report of Well Operations PBU J-01B 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 J-01B Mill CIBP, Ext Add Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-201 50-029-20020-02-00 10758 Conductor Surface Intermediate Liner Liner 9026 932 4220 3521 469 2697 9800 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9002 39 - 950 38 - 4258 37 - 8558 8089 - 8558 8061 - 10758 39 - 950 38 - 4258 37 - 8846 8088 - 8557 8060 - 9026 10724 520 1540 4760 6820 10530 9800 1530 3090 6870 7740 10160 9580 - 10717 4-1/2" 12.6# 13cr, L-80 35 - 8084 9005 - 9024 Structural 26 30" 40 - 66 40 - 66 4-1/2" Baker S3 Packer 8019, 8018 7857, 8019 7856, 8018 Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 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 0028281 35 - 8083 N/A N/A 375 502 37464 11366 46 18 300 425 920 220 325-214 13b. Pools active after work:Prudhoe Oil 4-1/2" TIW HBBP-R Packer 7857, 7856 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 9:44 am, Jun 11, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.11 09:31:34 - 08'00' Torin Roschinger (4662) RBDMS JSB 061825 JJL 6/13/25 DSR=/18/25 ACTIVITY DATE SUMMARY 5/30/2025 LRS CTU 1, 1.5" x .134" HT-110. Job Objective: Mill, Log, Ext Adperf Travel to J-01. Lay rig mats . Spot CTU start R/U **Continued to WSR on 5/31/25 5/31/2025 LRS CTU 1, 1.5" x .134" HT-110. Job Objective: Mill, Log, Ext Adperf R/U CTU. Function BOPs upon installation. M/U baker 1.69" milling BHA with 2.300" reverse clutch mill. Tag CIBP at 10230CTM and begin milling. Mill CIBP and push to 10704 CTM (based on correction at tag would be 10724MD). PUH, bullhead 100bbl of KCL and dry drift liner down to 10315. POOH for caliper tools. M/U HES GR/CCL/Caliper. RIH, log from 10,200-8,000'. POOH **Continued to WSR on 6/1/25** ***CTC bumped up against the brass. Safety joint pressure tested to 4257psi. Day crew held a well control drill simulating a kick while tripping and deploying the safety joint along with the contingency of dropping the BHA.*** 6/1/2025 LRS CTU 1, 1.5" x .134" HT-110. Job Objective: Mill, Log, Ext Adperf Cont POOH with HES GR/CCL/Caliper. Log from ~10300 to 8000. POOH, L/D HES logging tool, +9.5' correction Tied into SLB CNL log final print dated 11/23/2002. M/U BOT CIBP. Load well with 205bbls KCL capped with 5 bbls 60/40. RIH. Correct depth at flag. Set plug at 9,800 mid element. Pressure tested plug to 500psi. CIrc out well with 1% KCL and flow check - no flow. POOH pumping pipe displacement. FLow check at surface - no flow. Deploy 85' of HES 2" Maxforce 6 spf, 60 degree phased perf guns. Correct depth at CIBP. Perforate 9580- 9665. Bullhead until caught pressure - 2 bbl. Increase WHP to 1000psi and allow it to bleed off to formation. Flowcheck on bottom - no flow. POOH pumping pipe displacement + .25bpm. L/D spent HES guns, recover 1/2" ball. M/U JSN. RIH circulate well over to diesel **Continued to WSR on 6/2/25** ***Day and Night crew held a well control drill simulating a kick while tripping and deploying the safety joint along with the contingency of dropping the BHA. Confirmed fit up of XO from safety joint to perf guns*** 6/2/2025 LRS CTU 1, 1.5" x .134" HT-110. Job Objective: Mill, Log, Ext Adperf Tag up after rolling well to diesel. Attempt to flow to tanks. RIH to 4,000' to displace fluid and swab well. Unable to flow to tanks, RDMO. Turn well over to ops to back flow **Job Complete** 6/5/2025 T/I/O = 1320/330/10. Temp = SI. T FL (Ops request). No AL. T FL @ 3850' (578' blelow sta #4, Dummy, 58.5 bbls) SV, WV = C. SSV, MV = O. IA, OA = OTG. 13:00 6/7/2025 ***WELL S/I ON ARRIVAL*** RIG UP POLLARD UNIT 63 ***WSR CONT. ON 06-08-2025*** 6/8/2025 ***WSR CONT. FROM 06-07-2025*** RAN 4-1/2'' BRUSH, 3.78'' G. RING TO XN NIP @ 7945' MD (No Issues) SET 4-1/2" WHIDDON @ 7945' MD PULLED RK-DGLV FROM ST# 3 @ 5400' MD PULLED RK-DGLV FROM ST# 4 @ 3272' MD SET RK-LGLV (16/64" port, tro 1500 psi) IN STA #4 @ 3272' MD SET RK-OGLV (20/64" orifice) IN STA #3 @ 5400' MD PULLED 4-1/2" WHIDDON FROM XN @ 7945' MD (empty) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU J-01B 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 this 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 J-01B Mill CIBP, Ext Add Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-201 50-029-20020-02-00 341J ADL 0028281 10758 Conductor Surface Intermediate Production Liner 9026 932 4220 3521 469 2697 10250 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9017 39 - 950 38 - 4258 37 - 8558 8089 - 8558 8061 - 10758 2620 39 - 950 38 - 4258 37 - 8846 8088 - 8557 8060 - 9026 10724 520 1540 4760 6820 10530 10250 1530 3090 6870 7740 10160 9900 - 10717 4-1/2" 12.6# 13cr, L-80 35 - 80849008 - 9024 Structural 26 30" 40 - 66 40 - 66 4-1/2" Baker S3 Packer 4-1/2" TIW HBBP-R Packer 7857, 7856 8019, 8018 Date: Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 PRUDHOE BAY 4/22/2025 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 No SSSV Installed By Grace Christianson at 11:24 am, Apr 08, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.04.08 10:43:44 - 08'00' Torin Roschinger (4662) 325-214 Perforating gun 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 beforebreakingcontainment 10-404 JJL 4/8/25 DSR-4/11/25 Perforate SFD 4/10/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.14 16:47:06 -08'00'04/14/25 RBDMS JSB 041525 Page 1 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Well Name:J-01B API Number:50-029-20020-02 Current Status:Ivishak Producer PTD #202-201 Estimated Start Date:5/10/2025 Rig:Service Coil Tubing Reg.Approval Req’std?10-403, 10-404 Estimated Duration:2 days Regulatory Contact:Abbie Barker 907-564-4915 (O) First Call Engineer:Brenden Swensen 907-748-8581 (M) Second Call Engineer:Finn Oestgaard 907-350-8420 (M) Current Bottom Hole Pressure:3,200 psi @ 8,800’ TVD (7.0 ppge, based on offsets) Maximum Expected BHP:3,500 psi @ 8,800’ TVD (est.) 7.6ppg EMW Max. Anticipated Surface Pressure:2,620 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:1,860 psi (3/19/2025) H2S Level (Most Recent / Highest):16ppm 01/15/2025, 20ppm 04/14/2019 History J-01B was originally completed in 1979, side tracked in 1994 and again most recently in 2002. The well required a rig work over in 2006 to replace the tubing. The original 2002 perforations remained competitive until July of 2021. A plug was set and Z4 rich gas was shot from 8,577 – 8,597’ MD. After the rich gas became uncompetitive, a plug was set, and the Sag was perforated from 8,436 – 8,460’ MD on 6/25/2022. This remained competitive until 2024. A cement squeeze was performed on the Sag and Z4 perforations, CIBP’s were milled out on 4/2/2024. This was done as an intermediate step to gain some flush production from the original perforations in 2002. On 11/25/24, these perforations were again set behind a CIBP and an extended add perf was performed from 9,900 – 10,100’ MD in Z2A. Objective Isolate existing perforations behind a CIBP and shoot the next intervals of extended perforations. Procedure: Coil Tubing 1. Make up motor and mill. Mill out CIBP at 10,250’ MD and push to TD. a. Attempt to get plug to below 10,717’ MD perforations. b. Plug is pre-emptively being milled to ensure highest chance of success of returning to bottom most perforations for future flush production opportunities. 2. Perform GR/CCL/Caliper logging run from new TD to 8,000’ MD. Flag pipe. a. Liner is L80 ran in 2002 with moderate water production. Ensure liner is in reasonable shape. b. Send field print to OE, brenden.swensen@hilcorp.com 3. Set CIBP at ±9,800’ MD. a. Tie in log shows collars at 9,780’ and 9,812’ MD. b. May adjust depths as necessary based on caliper data. CoilTubing – 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 Page 2 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 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. 4. 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. 5. Bullhead 1.2x wellbore volume ~165 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 = 137 bbls b. 4-1/2” tubing – 8,061’ X .0152 bpf = 123 bbls c. 3-1/2” liner – 577’ x 0.0081 bpf = 5 bbls d. 3-3/16” Liner – 99’ X .0076 bpf = 1 bbl e. 2-7/8” Liner – 1,363’ X .0058 bpf = 8 bbls 6. At surface, prepare for deployment of TCP guns. 7. 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. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 8.*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. a.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. 9. 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” Millenium guns or similar Run Sand TOP MD BOT MD Total Order to Shoot Gross Interval Net Guns Weight of Gun (lbs) 2*** Z2A 9,111’9,196’85 Contingent on first perf performance 254 196 ± 1,422 lbs (5.6 ppf)Z2A 9,216’9,250’34 Z2A 9,268’9,280’12 Z2A 9,300’9,365’65 1 Z2A 9,580’9,665’85 1 85 85 ± 476 lbs (5.6 ppf) ***Run #2***will be performed as a second rig up after flow testing the first set of perforations if perforations are not competitive. The first set of perforations are expected to gas out in 4-8 months, similar to the November 2024 perforations. If the first set of perforations is competitive, the 10-403 will be closed out and a new one submitted at a future date for the contingent perfs. 10. 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. Page 3 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 11. 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. 12. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 13. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 14. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. RDMO CTU. 16. Turn well over to Operations POP. Slickline 17. Set generic gas lift design for kick off. Attachments: x Current Wellbore Schematic x Proposed Wellbore Schematic x Tie in Log x BOPE Schematic x Standing Orders x Equipment Layout Diagram x Sundry Change Form Page 4 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 5 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 6 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 7 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 8 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 BOP Schematic Page 9 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 10 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 Page 11 of 11 Extended Add Perforation Well: J-01B PTD: 202-201 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 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 J-01B Ext Add Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-201 50-029-20020-02-00 10758 Conductor Surface Intermediate Production Liner 9026 932 4220 3521 469 2697 10250 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9017 39 - 950 38 - 4258 37 - 8558 8089 - 8558 8061 - 10758 39 - 950 38 - 4258 37 - 8846 8088 - 8557 8060 - 9026 10724 520 1540 4760 6820 10530 10250 1530 3090 6870 7740 10160 9900 - 10717 4-1/2" 13cr, L-80 35 - 8084 9008 - 9024 Structural 26 30" 40 - 66 40 - 66 4-1/2" Baker S3 Packer 8019, 8018 7857, 8019 7856, 8018 Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 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 0028281 35 - 8083 N/A N/A 412 1242 41252 15783 65 61 100 150 1000 900 324-601 13b. Pools active after work:Prudhoe Oil 4-1/2" TIW HBBP-R Packer 7857, 7856 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 9:52 am, Dec 05, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.12.04 19:41:27 - 09'00' Torin Roschinger (4662) DSR-12/16/24WCB 2-12-2025 RBDMS JSB 121224 ACTIVITY DATE SUMMARY 11/25/2024 LRS CTU #1 w/1.5" .134" WT Job Scope: Drift/Log, Set CIBP, & Ext Adperfs Mobilize & MIRU CTU #1. Make up NS/HES logging tools, RIH and drift to 13,360'. Log out of hole from 13,360 to 7,900'. Paint white flag at 10,260' for plug set. Lay down logging tools and confirm +18' Corr w/ GEO. MU NS 2-7/8" CIBP. RIH corr depth off white flag. Set TOP CIBP 10,250' MD. PT CIBP 550 psi - passed. POOH. BD NS settign tool. PT MHA. Deploy HES 1.56" Millennium guns. ***Continue on WSR 11/26/24*** 11/26/2024 LRS CTU #1 w/1.5" .134" WT Job Scope: Drift/Log, Set CIBP, & Ext Adperfs Deploy 200' HES 1.56" Millennium Perf Guns. RIH. Tag CIBP corr depth. Perf 9900' - 10,100' per reference log with HES 1.56" Millennium guns 6spf 60 degree phasing (9903-10,103 per tie-in log). POOH while pumping pipe displacement. PJSM and WC drill with crew on undeploying guns. Undeploy guns, and pump remaining FP into TBG. Blow down CT reel for pipe swap. RDMO CTU. ***Job Complete*** Daily Report of Well Operations PBU J-01B Perf 9900'y - 10,100' ggy MU NS 2-7/8" CIBP. RIH corrgg g depth off white flag. Set TOP CIBP 10,250' MD. PT CIBP 550 psi - passed. POOH 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 J-01B Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-201 50-029-20020-02-00 10758 Conductor Surface Intermediate Production Liner 9026 932 4220 3521 469 2697 10725 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9024 39 - 950 38 - 4258 37 - 8558 8089 - 8558 8061 - 10758 39 - 950 38 - 4258 37 - 8846 8088 - 8557 8060 - 9026 10724 520 1540 4760 6820 10530 None 1530 3090 6870 7740 10160 10367- 10717 4-1/2" 13cr, L-80 35 - 8084 9020 - 9024 Structural 26 30" 40 - 66 40 - 66 4-1/2" Baker S3 Packer 7857, 7856 7857, 8019 7856, 8018 Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 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 0028281 35 - 8083 IC Test Void on Wellhead at Surface Pump 1 cup of Greenstick Packing. Final pressure = 0-psi 469 Well Test Not Available 42280 74 500 450 960 780 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" TIW HBBP-R Packer 8019, 8018 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 9:34 am, Jun 13, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.06.12 19:12:56 - 08'00' Torin Roschinger (4662) RBDMS JSB 061924 WCB 8-30-2024 DSR-6/13/24 ACTIVITY DATE SUMMARY 6/8/2024 T/I/O = SSV/470/380. Temp = SI. Greenstick IC test void/ retreat. No AL. RU packing gun to 1/2" hoke valve and pumped 1/4 of a gun of greenstick. Held pressure for 1 hr for a good pack. OA FL @ surface. Bled OAP to BT to 0 psi in <1 min. Monitored for 30 min. OAP increased 10 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 Daily Report of Well Operations PBU J-01B Greenstick IC test void/ retreat. No AL. RU packing gun to 1/2" hoke valve and pumped 1/4 of a gun of greenstick. Held gg pressure for 1 hr for a good pack. OA FL @ surface 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 this 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 J-01B Ext Add Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-201 50-029-20020-02-00 341J ADL 0028281 10758 Conductor Surface Intermediate Production Liner 9026 932 4220 3521 469 2697 10725 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9024 39 - 950 38 - 4258 37 - 8558 8089 - 8558 8061 - 10758 2490 39 - 950 38 - 4258 37 - 8846 8088 - 8557 8060 - 9026 10724 520 1540 4760 6820 10530 None 1530 3090 6870 7740 10160 10367- 10717 4-1/2" 13cr, L-80 35 - 80849020 - 9024 Structural 26 30" 40 - 66 40 - 66 4-1/2" Baker S3 Packer 4-1/2" TIW HBBP-R Packer 7857, 7856 8019, 8018 Date: Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 PRUDHOE BAY 11/5/2024 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 1:00 pm, Oct 16, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.10.16 10:45:07 - 08'00' Torin Roschinger (4662) 324-601 Contact AOGCC Engineer if PT on CIBP fails. Perforate MGR08NOV24 x SFD 10/26/2024 10-404 AOGCC Witnessed BOP Test to 2500 psi prior to deployment of extended perf guns 1.5 x WBV of KWF on location for open hole operations DSR-10/23/24JLC 11/12/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.11.12 15:42:20 -09'00'11/12/24 RBDMS JSB 111424 CIBP & Perf Procedure J-01B PTD: 202-201 Well Name:J-01B API Number:50-029-20020-02 Current Status:Operable Rig:CTU Estimated Start Date:11/05/2024 Estimated Duration:2days Regulatory Contact:Abbie Barker First Call Engineer:Aras Worthington (907) 440-7692 (c)(907) 564-4763 Second Call Engineer:Tyson Shriver (406) 690-6385 (c) Current Bottom Hole Pressure:2,985 psi @ 8,306’ TVD 6.9 PPGE (SBHPS on 3/22/24) Max. Anticipated Surface Pressure:2490 psi (Based on SIWHP 8/13/24) Min ID:2.372” ID of 3-3/16”x2-7/8” XO at 8,737’ MD Max Angle:95 deg @ 9,393’ MD Tie-in Log:Schlumberger MCNL 11/23/02 Brief Well Summary: 2002 CTD sidetrack. Objective: Set CIBP over Z2A toe perfs. Adperfs in Z2A. Notes: x Chrome tubing x Perfs 8419’ – 8597’ MD squeezed off w/ cement x GLVs are dummied Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x Note: The well will be killed and monitored before making up the initial perfs guns. 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. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. After MU MHA and pull testing the CTC, tag-up on the CT stripper toensure BHA cannot pull through the brass upon POOH with guns. 3. MU 2.3”drift nozzle & logging tools. a. Last tag was ~10,725’ MD with 2.30” mill (4/2/24) b. Flag pipe at appropriate depth for CIBP set and adperfs. 4. Bullhead kill the well with 205 bbls SW or 1% KCL (1.5 x the WBV to top perf). This must be performed before setting the CIBP because the perfs in the heel have been squeezed off. As an alternative, the well can be loaded with CT from the bottom-up after setting the CIBP at WSS discretion. a.Wellbore volume to top of perfs = ~137 bbls b. 4-1/2” Tubing – 8061’ x .0152bpf = 122 bbls c. 3-1/2” Liner - 577’ x .0081bpf = 5 bbls d. 3-3/16” Liner – 99’ x 0.0076 bpf = 1 bbls e. 2-7/8 Liner to top of perfs – 1630’ x 0.0055= 9 bbls CIBP & Perf Procedure J-01B PTD: 202-201 5. MU 2-7/8” CIBP and set @ ~10,250’ MD. 6. PT the CIBP to 500 psi for five minutes. Less than 10% pressure loss in 5 minutes is a pass. Contact OE if PT fails. 7. At surface, prepare for deployment of TCP guns. 8. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man- watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps 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. 10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per sundry is 500ft.Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule *HES 1.75” Geo Razor guns were used to estimate for this job. 1.91” gun swell 11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 12. 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. 13. Pump pipe displacement while POOH. Stop at surface to reconfirm well dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. FP well to 2000’ MD. 16. RDMO CTU. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Standing Orders for Open Hole Well Control during Perf Gun Deployment 5. Equipment Layout Diagram 6. Sundry Change Form Perf Interval Perf Length Gun Length Weight of Gun (lbs) 9,900’ - 10,100’ MD (Zone 1A)200’200’920lbs (4.6ppf) CIBP & Perf Procedure J-01B PTD: 202-201 Current Wellbore Schematic CIBP & Perf Procedure J-01B PTD: 202-201 Proposed Schematic CIBP & Perf Procedure J-01B PTD: 202-201 Coiled Tubing BOPs CIBP & Perf Procedure J-01B PTD: 202-201 Standing Orders for Open Hole Well Control during Perf Gun Deployment CIBP & Perf Procedure J-01B PTD: 202-201 Equipment Layout Diagram CIBP & Perf Procedure J-01B PTD: 202-201 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 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 J-01B Mill CIBPs, Squeeze Perforations Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-201 50-029-20020-02-00 10758 Conductor Surface Intermediate Production Liner 9026 932 4220 3521 469 2697 10725 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9024 39 - 950 38 - 4258 37 - 8558 8089 - 8558 8061 - 10758 39 - 950 38 - 4258 37 - 8846 8088 - 8557 8060 - 9026 10724 520 1540 4760 6820 10530 None 1530 3090 6870 7740 10160 10367- 10717 4-1/2" 13cr, L-80 35 - 8084 9020 - 9024 Structural 26 30" 40 - 66 40 - 66 4-1/2" Baker S3 Packer 7857, 7856 7857, 8019 7856, 8018 Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 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 0028281 35 - 8083 Perforations at 8419' - 8443'MD and 8577' - 8597'MD Squeeze 20-bbls 15.8-ppg Class G cement with Final pressure = 3000-psi 114 1392 15770 31563 47 133 350 425 208 925 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" TIW HBBP-R Packer 8019, 8018 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 9:54 am, Apr 08, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.04.05 13:00:43 -08'00' Torin Roschinger (4662) RBDMS JSB 041024 WCB 2024-07-09 DSR-4/12/24 ACTIVITY DATE SUMMARY 3/31/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Mill CIBP, Cement Squeeze, Mill Out Cement 2nd CIBP MIRU. MU YJ milling assembly and 2.7" venturi/burn shoe. Load the well with KCL/SL. RIH. Tag the CIBP 8498 ctmd. MIll the plug and push to 8587 ctmd. Freeze protect coil while POOH. BD YJ Burnshoe/Venturi (NO core recovered, about 1/4 cup slip & plug parts). MU SLB 2" BDJSN BHA. Snow Removal. MIRU Slb Cementers. RIH. Kill Well & load w/ Diesel. ***Continue on WSR 4/1/24*** 4/1/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Mill CIBP, Cement Squeeze, Mill Out Cement 2nd CIBP At 8000' Waiting on Contaim & PowerVis. PJSM. PT Cmt pump line. RIH tag CIBP @ 8581' CTM/ 8586' Mech. Batch up CMT (wet @ 2:35 am). Pump 5 bbl FW, 20 bbls 15.8 ppg Class G, 10 bbls FW, 2 bbls 60/40, 22.7 bbl diesel. (sqz 1 bbls into perfs above LNR) PUH to safety @ 6800'. Down Sqz working up 3K psi total 3 bbls squeezed away. Contaminate down to top of CIBP remnants at 8,582', case OOH washing Jewelry. Good pressure test to ~700 psi against cement sqz, MU & RIH w/ YJ 2.73" 3 blade Junk Mill. RIH. Start milling @ 8594' ctm. Mill ~ 3 hours slight motor work and no stalls. POOH. BD 2.73" 3 blade junk mill. Replace motor and MU 2.70" Venturi/Burnshoe. RIH. ***Continue on WSR 4/2/24*** 4/2/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Mill CIBP, Cement Squeeze, Mill Out Cement 2nd CIBP RIH w/ YJ 2.70" Venturi/Burnshoe BHA. Tagged CIBP @ 8595' cmt / 8610' Mech. Start milling @ 8594' ctm. Mill ~ 3 hours slight motor work and no stalls. POOH. BD 2.73¿ 3 blade junk mill. Replace motor and MU & RIH w/ 2.70¿ Venturi/Burnshoe. Tagged CIBP @ 8595' cmt / 8610' Mech. 5 stalls ~ 2 hours push CIBP to 3-3/16" XO @ 8615' ctm / 8626 Mech (still have 1:1 returns). 10 mins thru 3-3/16" XO. Push down dry to 2-7/8" XO @ 8719' ctm / 8730' Mech. Tagged 3 times. POOH. Recovered upper CIBP core & giblets, RIH w/ YJ 2.30" Venturi/Burnshoe BHA, tagged 2nd CIBP in 2-7/8" XO @ 8,712' ctm, mill through and push down to PBTD at 10,700' ctm (10,725' md), estimated ~8' rathole, POOH PF coil. FP tubing 5 bbls 60/50 meth and 35 bbls diesel. Plug #2 core recovered. RDMO ***Job Complete*** Daily Report of Well Operations PBU J-01B Down Sqz working up 3K psi total 3 bblsg squeezed away. Contaminate down to top of CIBP remnants at 8,582', case OOHy washing Jewelry g tagged 2nd CIBP in 2-7/8" XO @ 8,712' ctm, mill through and push down to PBTD atgg 10,700' ctm (10,725' md), PT Cmt pump line. RIH tag CIBPgg @ 8581' CTM/ 8586' Mech. Batch up CMT (wet @ 2:35 am). Pump 5 bbl FW, 20 @ (@ ) bbls 15.8 ppg Class G, 10 bbls FW, 2 bbls 60/40, 22.7 bbl diesel. (sqz 1 bbls into(g perfs above LNR) PUH to safety @ 6800'.)y@ gy Tag the CIBP 8498 ctmd. MIll the plug and push to 8587 ctmd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y Samantha Carlisle at 10:26 am, Mar 11, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV $&7,9,7<'$7(6800$5< :(//)/2:,1*21$55,9$/ 35(381,7)2558,1$0 &21721:65 &217)520:65 (48$/,=((92$7 (/0'6+($5('*575<,1*7238// &21721:65 &217)520:65 38//('(92)520 (/0' 6(716&,%3$7 0' :(///()76,21'(3$5785(3$'23127,),('2)67$786 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8-% 1Carlisle, Samantha J (OGC)From:Regg, James B (OGC)Sent:Thursday, January 27, 2022 12:13 PMTo:AOGCC Records (CED sponsored)Subject:FW: [EXTERNAL] RE: OPERABLE: Producer J-01B (PTD #2022010) Re-energize wellhead sealsJim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 27, 2022 6:01 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: OPERABLE: Producer J‐01B (PTD #2022010) Re‐energize wellhead seals Mr. Regg, Answers to your questions in red. Let me know if you need any further clarification. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 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. 2From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Wednesday, January 26, 2022 10:58 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: [EXTERNAL] RE: OPERABLE: Producer J‐01B (PTD #2022010) Re‐energize wellhead seals A couple questions: What was the test pressure when subsequent pack‐off test failed? The test pressure was 3500 psi. Have you considered other steps to achieve integrity of the pack‐offs? It is suspected the primary seals have failed, but the secondary seals now have integrity after being re‐energized with plastic packing. This particular wellhead does not have the ability to re‐energize the primary seals (which would usually be done by torquing the Lock‐Down Screws). The only option to restore the primary seal is through a RWO. Since the seals are redundant and the secondary seal now has integrity, no further action is planned. However, if the secondary seal were to fail in the future, it is possible we would attempt to restore integrity by pumping a wellhead sealant, or as I mentioned earlier, through a RWO. What is Hilcorp’s acceptance criteria for allowing the well to be put back online if not a successful pack‐off test? For the well to remain Operable with a failing pack‐off test, one of the redundant wellhead seals must have integrity. Integrity was proven by applying ~1500 psi to the IA and no pressure response on the OA. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 25, 2022 7:58 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer J‐01B (PTD #2022010) Re‐energize wellhead seals Mr. Regg, 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. 3 Producer J‐01B (PTD #2022010) secondary inner casing wellhead seals were re‐energized on 01/12/22. A subsequent pack‐off test failed however IA casing pressure was increased to ~1500 psi on 01/13/22 and no IAxOA or OA re‐pressurization has been observed. The well is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, January 8, 2022 4:25 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer J‐01B (PTD #2022010) OA casing pressure above MOASP Mr. Regg, Producer J‐01B (PTD #2022010) has a cemented outer annulus that was called in for an unmanageable number of bleeds and exceeding MOASP on 01/07/22. The reported OA pressure was 1008 psi. DHD bled the IAP and OAP and the OA re‐pressurization subsided. A follow up PPPOT‐IC failed indicating the OA re‐pressurization was due to IAxOA communication through the wellhead seals. The well will now be classified as UNDER EVALUATION and is on the 28‐day clock for diagnostics. Plan forward: 1. DHD: Bleed IAP to 0 psi. 2. DHD: Re‐energize IC‐wellhead seals 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 4M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer J-01B (PTD #2022010) OA casing pressure above MOASP Date:Monday, January 10, 2022 9:39:07 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, January 8, 2022 4:25 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer J-01B (PTD #2022010) OA casing pressure above MOASP Mr. Regg, Producer J-01B (PTD #2022010) has a cemented outer annulus that was called in for an unmanageable number of bleeds and exceeding MOASP on 01/07/22. The reported OA pressure was 1008 psi. DHD bled the IAP and OAP and the OA re-pressurization subsided. A follow up PPPOT-IC failed indicating the OA re-pressurization was due to IAxOA communication through the wellhead seals. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: Bleed IAP to 0 psi. 2. DHD: Re-energize IC-wellhead seals 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:202-201 6.50-029-20020-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10758 8624 8623 7857, 8019 None 8624 7856, 8018 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural 26 30" 40- 66 40 - 66 Conductor 932 20" 39 - 950 39 - 950 1530 520 Surface 4220 13-3/8" 38 - 4258 38 - 4258 3090 1540 Intermediate 3521 9-5/8" 37 - 8558 37 - 8846 6870 4760 Production 469 5-1/2" 8089 - 8558 8088 - 8846 7740 6820 Perforation Depth: Measured depth: 8577 - 10717 feet True vertical depth:8576 - 9024 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L80 35 - 8084 35 - 8083 7857 7856Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S3 Packer Liner 2697 8061 - 10758 8060 - 9026 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 134995076461 10831032 1150 42688 471 844 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen Brian.Glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5277 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9026 Sundry Number or N/A if C.O. Exempt: N/A 4-1/2" TIW HBBP-R Packer 8019 8018 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028281 PBU J-01B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" x 3-3/16" x 2-7/8" By Meredith Guhl at 10:31 am, Aug 06, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.06 10:17:15 -08'00' Stan Golis (880) SFD 8/13/2021MGR10AUG2021RBDMS HEW 8/9/2021 DSR-8/6/21 ACTIVITY DATE SUMMARY 7/8/2021 ***WELL S/I ON ARRIVAL***(perforating) RAN 2.71" WRP DRIFT TO 2-7/8" XO @ 8,737' MD. RAN 10' x 2.0" BAILER TO 9,050' SLM. (drift for cbl) LRS LOADS TBG w/ 165 bbls OF 1% KCL RAN READ CBL PER PROGRAM. (good data) RAN 20' x 2.0" DUMMY GUNS (2.29" Max OD) TO 9,050' SLM. ***JOB COMPLETE, WELL LEFT S/I*** 7/8/2021 Assist Slickline (PERFORATING) Pumped 2 bbls 60/40 meth and 165 bbls 1% KCL down Tbg for load. Pumped 35 bbls 1% KCL while SL logged. Flushed Tbg w/ 50 bbls 1% KCL and 38 bbls crude for freeze protect. Slickline in control of well per LRS departure. IA,OA=OTG 7/22/2021 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(perf/evo plug) RIH & PERFORATE @ 8577'-8597' USING 2", 6 SPF, 60 DEGREE PHASING LOADED W/ MAXFORCE CHARGES. CCL TO TOP SHOT OFFSET: 7.5'. CCL STOP DEPTH: 8569.5'. PRE-PERF T/IA/OA: 0/1000/0, POST PERF T/IA/OA: 0/1000/0. SET HES 3-1/2" EVO PLUG MID-ELEMENT AT 8626'. TOP OF PLUG @ 8624'. CCL TO MID-ELEMENT OFFSET: 17.7'. CCL STOP DEPTH: 8608.3'. OAL = 5.75'. EVO SN: P105103967-3. CORRELATED TO SLB CNL DATED 23-NOV-2002. ***JOB COMPLETE / TURN OVER TO PAD-OP TO POP*** Daily Report of Well Operations PBU J-01B David Dempsey Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: David.Dempsey@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: DATE: 07/13/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU J-01% (PTD 202-201) RCBL Radial Cement Bond Log 07/8/2021 Please include current contact information if different from above. Received By: 07/14/2021 37' (6HW By Abby Bell at 1:02 pm, Jul 14, 2021 PTLD °CD2 Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent Monday,April 30, 2018 1:37 PM To: Loepp,Victoria T(DOA) Subject FW: Producer J-01B (PTD#2022010) Similar Construction Geometry to 02-03 Follow Up Flag: Follow up Flag Status: Flagged Jim Regg Supervisor, Inspections same AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From:AK,GWO SUPT Well Integrity<AKDCWellIntegrityCoordinator@bp.com> Sent: Monday,April 30, 2018 1:35 PM To: Regg,James B(DOA)<jim.regg@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Foerster,Catherine P (DOA)<cathy.foerster@alaska.gov>; Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Rixse, Melvin G (DOA)<melvin.rixse@alaska.gov>; Daniel, Ryan <Ryan.Daniel@bp.com>; Cismoski, Doug A<CismosDA@BP.com>; Romo, Louis A<Louis.Romo@bp.com>;AK,GWO Well Integrity Engineer<AKGWOWellSiteEnginee@bp.com> Subject: RE: Producer J-01B(PTD#2022010)Similar Construction Geometry to 02-03 Jim, Per my voicemail,we will reclassify the wells with gravel protection strings Not Operable: • Producer S-122(PTD 2050810) • Injector W-209(PTD 2031280) • Injector W-214(PTD 2071420) • Injector W-216(PTD 2071680) Our surface casing depth verification project identified 2 other wells with surface casing set in the permafrost(both Long Term Shut Ins): • Producer E-28A(PTD 1990610)—will reclassify Not Operable • Injector M-01(PTD 1690780)—already Not Operable due to remaining shut in past its 4-year witnessed test date BPXA's Tubular Design Advisor will review all of these wells. Upon completion,we'll present the findings to the AOGCC. In the meantime,all will remain Not Operable and shut in. 1 • Thanks, • Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 From: Regg,James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, April 27, 2018 2:18 PM To: AK, GWO SUPT Well Integrity Cc: Loepp, Victoria T(DOA); Foerster, Catherine P (DOA); Schwartz, Guy L(DOA); Rixse, Melvin G (DOA) Subject: RE: Producer 3-01B(PTD #2022010) Similar Construction Geometry to 02-03 Thank you for the follow-up email. Just to be clear,are the S-pad and W-pad wells with gravel protection strings also going to be reclassified as"not operable"to verify they are not at risk for failure like PBU 02-03B? When BP is finished with the reviews of the wells, please arrange for a meeting to present your findings to the AOGCC. That can be coordinated with Victoria. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 90/- 793-1236 or jim.reggPalaska.gov. From:AK,GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com> Sent: Friday,April 27, 2018 1:51 PM To: Regg,James B(DOA)<jim.regg@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Cismoski, Doug A<CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>;AK, GWO Well Integrity Engineer<AKGWOWellSiteEnginee@bp.com> Subject: Producer J-01B(PTD#2022010)Similar Construction Geometry to 02-03 Jim, To summarize our phone conversation today: • After the 02-03 incident,we reported to the AOGCC 14 wells with similar construction geometry; i.e. a 3-string casing design,and the surface casing shoe set in the permafrost. • Yesterday,we identified one additional well with similar construction geometry:J-01. • We do not believe that J-01 is at risk of an event similar to 02-03, because, unlike 02-03,all three strings of casing are anchored together with cement.We believe this eliminates the potential for differential force loading at the wellhead. 2 • However,we are going'eclassify J-01 Not Operable,shut it in,and secure it, until we can perform modeling, to verify. • We also identified 4 wells on S-Pad and W-Pad that have 13-3/8"gravel protection strings set in the permafrost, and 2 casing strings within. I'm investigating the details now, but I do not believe these wells present a risk.The 13-3/8" is a second conductor,and not coupled to the inner casing strings at the wellhead. In the event the 13- 3/8"were to subside, it would not impart a load to the inner casing strings via the wellhead. I will follow up on these wells as soon as possible. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 3 • 110 1110 Pit a 1-2010 Regg, James B (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, April 27, 2018 5:05 PM �e j� 4I3o/I o To: Regg, James B (DOA) t` Subject: RE: Producer J-01 B (PTD#2022010) Similar Construction Geometry to 02-03 Jim, I've completed a review of the S-Pad and W-Pad wells with 13-3/8" gravel protection strings. I've confirmed that none of the gravel protection strings are coupled to the 9-5/8" and 7" casings at surface.Therefore, basedtupon BPXA's knowledge of the PBU 02-03B failure mechanism,these wells are not at risk for a similar failure, and can be safely operated. Well PTD 13-3/8" Shoe Coupled to 9-5/8"and 7" Details (TVD Subsea) at surface? S-122 2050810 497' No; wellhead is installed Unplanned gravel protection string due to hole on 9-5/8" casing problems.After cementing 13-3/8", cut it below the 9-5/8" landing ring in conductor. W-209 2031280 1549' No; wellhead is installed Unplanned gravel protection string due to hole on 9-5/8" casing problems.After cementing 13-3/8", cut off the casing hanger, and welded on 9-5/8" landing ring. W-214 2071420 1218' No; wellhead is installed Planned gravel protection string. 13-3/8" hung on 9-5/8" casing off on butt weld sub inside conductor. W-216 2071680 1210' No; wellhead is installed Planned gravel protection string. 13-3/8" hung on 9-5/8" casing off on butt weld sub inside conductor. Please let me know if it's acceptable for these wells to remain Operable,and whether you'd like us to arrange a meeting to discuss them in more detail. We will arrange a meeting to present the J-01 modeling results when they are complete. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate: Jack Lau) 0:(907)659-5102 C:(907)943-0296 H: 2376 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, April 27, 2018 2:18 PM To: AK, GWO SUPT Well Integrity Cc: Loepp, Victoria T(DOA); Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Rixse, Melvin G (DOA) Subject: RE: Producer J-01B (PTD #2022010) Similar Construction Geometry to 02-03 Thank you for the follow-up email. Just to be clear, are the S-pad and W-pad wells with gravel protection strings also going to be reclassified as"not operable" to verify they are not at risk for failure like PBU 02-03B? 1 • • When BP is finished with the reviews of the wells, please arrange for a meeting to present your findings to the AOGCC. That can be coordinated with Victoria. Jim Regg Supervisor, Inspections AOGCC 333 With Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From:AK, GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, April 27, 2018 1:51 PM To: Regg,James B (DOA) <jim.regg@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Cismoski, Doug A<CismosDA r- I P.com>; Daniel, Ryan <Ryan.DanleI b .com>• AK, GWO Well Integrity Engineer<AKGWOWellSiteEnine- bp.com> Subject: Producer J-01B (PTD#2022010) Similar Construction Geometry to 02-0 Jim, To summarize our phone conversation today: • After the 02-03 incident, we reported to the AOGCC 1, ells with similar construction geometry; i.e. a 3-string casing design, and the surface casing shoe set in th- •ermafrost. • Yesterday, we identified one additional well wit imilar construction geometry:J-01. • We do not believe that J-01 is at risk of an ev: t similar to 02-03, because, unlike 02-03, all three strings of casing are anchored together with cemen e believe this eliminates the potential for differential force loading at the wellhead. • However, we are going to reclassify 111 Not Operable, shut it in, and secure it, until we can perform modeling to verify. • We also identified 4 wells on S •ad and W-Pad that have 13-3/8"gravel protection strings set in the permafrost, and 2 casing strings within. 'm investigating the details now, but I do not believe these wells present a risk.The 13-3/8" is a second con ctor, and not coupled to the inner casing strings at the wellhead. In the event the 13- 3/8" were to subside ' would not impart a load to the inner casing strings via the wellhead. I will follow up on these wells as soo s possible. Thanks, ,// Adrienne McVey/ Well Integrity'Superintendent—GWO Alaska (Alternate:/,lack Lau) 0:(907)659-5102 C: (907)943-0296 H: 2376 2 • P8i.,c. Tat g • • Pr6 -zo zoo Regg, James B (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, April 27, 2018 1:51 PM 124 1(6 To: Regg,James B (DOA) Cc: Loepp, Victoria T (DOA); Cismoski, Doug A; Daniel, Ryan;AK, GWO Well Integrity Engineer Subject: Producer J-01 B (PTD#2022010) Similar Construction Geometry to 02-03 Jim, To summarize our phone conversation today: • After the 02-03 incident, we reported to the AOGCC 14 wells with similar construction geometry; i.e. a 3-string casing design, and the surface casing shoe set in the permafrost. • Yesterday, we identified one additional well with similar construction geometry:J-01. • We do not believe that J-01 is at risk of an event similar to 02-03, because, unlike 02-03, all three strings of casing are anchored together with cement. We believe this eliminates the potential for differential force loading at the wellhead. • However, we are going to reclassify J-01 Not Operable, shut it in,and secure it, until we can perform modeling to verify. • We also identified 4 wells on S-Pad and W-Pad that have 13-3/8" gravel protection strings set in the permafrost, anc12. 5.ing strings within. I'm investigating the details now, but I do not believe these wells present a risk.The 13-3/8" is a second conductor, and not coupled to the inner casing strings at the wellhead. In the event the 13- 3/8" were to subside, it would not impart a load to the inner casing strings via the wellhead. I will follow up on these wells as soon as possible. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate: Jack Lau) 0: (907)659-5102 C:(907)943-0296 H: 2376 1 r Pm 202ZDt0 Regg, James B (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> 1`�'C 41-7-_41,5 Sent: Friday, April 27, 2018 4:31 PM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOp5ProdEOCTL; Frankenburg, Amy;Wellman,Julie; Regg, James B (DOA) AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Cc: p Well Integrity;AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington, Aras J;Wallace, Chris D (DOA) Subject: NOT OPERABLE: Producer J-01 B (PTD #2022010) for completion evaluation All, Producer J-01B (PTD#2022010)was recently identified as having a 3-string casing design with the 20" surface casing shoe set in the permafrost, similar to 02-03. It is believed that J-01 does not present the same risk as 02-03 due to the casing strings being cemented together, thus eliminating the potential for differential force loading at the well head. However, in order to verify this,further modeling will be conducted. Until the modeling is complete,the well will be classified as NOT OPERABLE and will be secured with a downhole plug. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday,April 27, 2018 4:31 PM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK,OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W; AK, OPS Well Pad Z;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Frankenburg,Amy;Wellman,Julie; Regg, James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: NOT OPERABLE: Producer J-01 B (PTD#2022010)for completion evaluation All, Producer J-01B (PTD#2022010)was recently identified as having a 3-string casing design with the 20" surface casing shoe set in the permafrost,similar to 02-03. It is believed that J-01 does not present the same risk as 02-03 due to the casing strings being cemented together,thus eliminating the potential for differential force loading at the well head. However, in order to verify this,further modeling will be conducted. Until the modeling is complete,the well will be classified as NOT OPERABLE and will be secured with a downhole plug. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 SCANNED 1 (.;OF Ty',1�j,s, THE STATE Alaska Oil and Gas s��, of Conservation Commission -: ____ , ALASI�;A f ilEi ittz u^__, 333 West Seventh Avenue " .° , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALAS/1'P- Fax: 907.276.7542 www.aogcc.alaska.gov Jessica SayersNNED ),. r 7: , SCAEngineering Team Leader BP Exploration(Alaska), Inc. (9`.- P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-01B Sundry Number: 315-178 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, '(-Vel Cathy P. oerster J Chair DATED this d of April, 2015 i Encl. RECEIVED STATE OF ALASKA MAR 3 1 201 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well Change Approved Program Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ TimO�FeE�m�Zroensionn L Operations ShutdownEl Re-enter Susp.Well❑ Stimulate ID Alter Casing: Other. Well Lock Teshpele�r�Cl��f'Lr gr 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development 0• 202-201-0 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20020-02-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU J-01 B - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL0028281 ' PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10758 • 9026 • 7945 7944 7945 None Casing Length Size MD TVD Burst Collapse Structural ' Conductor 932 20"94#H-40 40.82-972.86 40.82-972.85 Surface 1553 13-3/8"68#J-55 39.82-1592.35 39.82-1592.32 3450 1950 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10367-10717 9020.46-9024 See Attachment See Attachment See Attachment Packers and SSSV Type. See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development El • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/7/15 Commencing Operations: Oil El • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jessica Sayers Email Jessica.Sayers@BP.Com Printed Name Jessica Sayers Title Well Intervetions Engineer Signature 564-4281 Date 3/30/1 Prepared by Garry Catron 564-4424 OMMISSION USE ONLY Conditions of approval: Notify Commi n so that a representative may witness Sundry Number: 51 - ( y Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: /b — 4 b 4- APPROVED BY Approved by: / 914_4_,_ COMMISSIONER THE COMMISSION Date: 4- -2—/) /: 3/1-5/1j , -- RILoN A Lex y-z-i.� , 5 . 3 Form 10-403 Revised 10/2012 Approved application is valor 1Z mos from the d of approval. Submit Form and Attachments in ...soli6te RBDMS APR - 6 2015 Si//1 0 -0 0 0 0 o o 0 0 in a @vaoa? aoc000cocc? Uao 0 = J Z J J J J _, J a) co CD • o O O 0 0 0 0 00 N 0 0 coN Co in O O 1--- N M O 0 LO 0 0 Ln D o CCO COCv v v Ca ,- CO CO I� CO CO co a) (B N. N. .- M Ln N N 0 CO M O 0 N 0 No.) 00 0o f*--- M 0 0 CO O ...o O O O Co co 00 07 1- t` CO I- 0_ O 1- MCO 1"-- N I- O ON V CO 1- O Ln CO p v Ms' CO O O f- M CA >, > 0o 0o 0o 0o f"- L F- CU N- E co Eco 0 co co M O Cp O N r N N I- m Ln N N CO , CA CO CO O ❑ O 00 co 000 .O .- CO CY) p 2 J — • o 0 N H rn °) Nv000 (NoLncXo 0 ovM � COOCDNvMO) 00ao00CO ti L CD O O co O O O In 00 O co O 00 co . 00 co 0i In U Nr J J . J c N _ *k *k N .- (0 oho 4 co N *k r r- 0 co .- CO 0 i-0 N OO M ' .-- b N 1 i M � i M N O � . Ln 1 CO M N T L M p) N O = OO CO 0 N Ln N1• o Q) O 01 co Lo Lo O 1.0 0 0 J W W r, _Q Q CI- 00 W .( U W W U 0 p( CC cC CL u- Z Z Z W W W W W Wcr m m Q , Z_ Z_ Z_ Z_ j D D 0 Z Z J J J J U) F- F- Packers and SSV's Attachment ADL0028281 Well Facility Type MD Top Description TVD Top J-01 B PACKER 7871 4-1/2" Baker S-3 Perm Packer 7870 J-01 B ' PACKER 8022 4-1/2"TIW HBBP Packer 8021 J-01 B PACKER 8089 5-1/2"TIW Packer 8088 bp 1?“) To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 03-16-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: J-01 WellLock MicroOA Treatment Objective This program is for treating the micro-annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. The liquid leak rate has been established at 0.05 gallons per minute at 3000 psi. WellLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use the small diaphragm, suitcase, pump to squeeze the WellLock into the micro-annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A followed by diesel, should be flushed across the OA valves to keep WellLock from setting up. Well Detail Current Status: Not Operable — PAL Previous Test: 03-17-14 CMIT-IA passed to 3000psi 07-03-13 OA Shell test @ 2000 psi, LLR 0.08 gpm Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas), highest observable pressure 1400 psi; Last H2S Reading: 05-24-2013 110 ppm Well Operation Detail Fluid Density: WellLock: 9.1-9.3 ppg (keep WellLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: See rig-up diagram Temperature: Maintain 750-800 F throughout the entire job Relevant History: > 09/2006: RWO completed cement OA to surface > 07/03/13: OA LLR 0.081 gpm @ 2000 psi > 12/01/13: OA LLR .1268 gpm @ 2400 psi Well Program: 1 D Pump 870 bbls hot, 180° F, crude down IA to heat up the OA. 2 D Over flush diesel out of OA void with several gallons of 2% KCI, 120° F, using the triplex. Purge void with nitrogen, displacing as much KCI as possible. 3 D *** Switch to diaphragm pump. Pump 1.5 gallon WellLock pill. Take returns 1:1 in grounded bucket. 4 D Maintain 3,000 psi for two hours by pumping KCI at signs of pressure fall off. This is to squeeze the WellLock into the microannulus. Record pressure and temperature readings on casing every hour. Do not exceed 3,500 psi. 5 D Swap to Musol A in suitcase pump, crack needle valve on returns line to grounded bucket. Maintain 3,000 psi on returns line. Pump 1 gallon of Musol A through pump, across valves to returns. 6 D Shut-in suitcase pump and returns. 7 D Swap to Musol A through triplex. Pump 1 bbl of Musol A across well to returns to durms, maintaining 3,000 psi. Swap to neat meth in triplex. Overflush Musol A with neat meth, maintaining 3,000 psi. 8 D Shut down triplex with 3,000 psi on well for one week. 9 D Leave crystal gauge on well and take pressure and temperature readings on casing, twice daily. Record in AWGS. 10 D After seven days, MIT-OA *** Collect approximately one cup sample of WellLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period. 2 of 3 . . TRH= 4-1,'6'CPAI VVELLI-EAD= MCEVOYI SAFETY NOTE: --4-1fr CHROME TEIG— ACTLATOR-• BAKER C X 0 1 1 KB ELEV- 74' BF S.EV= 40 07 i i 511- 9- V FXR J KOP 3207 __-,- 1698' 19-ss•fr•Fs.7-FNEN-FR Max Angle= IS'al 3600' Dattrn MD= 8935' I 7, Dish"TV3- 88010'SS , 2104' 1 15.1"D9-818 TEBACX CSG,408 L-80 Mt ID=8.8351 —1. 1706' j LI 3-318"CSO,720,L-10 ID 4,2 347j—f ?GOO' 1.—Al OAS LET MANDRELS Sr AC) 71/0 my TYPE VI,V LA,CH PORT1 L1R TE N S 37SS 32W 11 'MG CxD R4 16 11104/CE 4 4789 4739 11 MOO DONE RK 18 I1 AINIC6 3 6069 6C09 7 INVG DOW RI( 16 I16X/E6 ---,,-----„, 2 7035 7004 1 WC DOW Pl< 16 01,154/C6 Minimum ID=2.313" @8172 1 7850 77891 1 AVG SO RX 26 (11/134/05 .-_. 2-718 REDUCING NIPPLE I I I 7----.TCY _14-1.70TI5XNP,0=3813' 7941' H0:541-7K 4-1 ?"'BKR 9-3 PKR,C 4 3 890- Will 7141, A4 I G'016 X NIP 0. 813_1 7965' 1.44-1/2-XX PLUG 0Y21 1) A 6031' H Tao srue cow 8410 1, 4-1 n•"MG 1768,1:IGIR VAN TOP --I 9028' _.----- 0157 1:0,10 i R 3 95EF r -1,- inner t—j 8-5/8"x 4-12-LINQUEDVERSIT LJ L. 8071 _I ' _Vir1T PAR CFA i A SSYJ - [ 809T 49-51-it 4-117"BOT PKR 0 . ,. I t_843w 1_4 1/7"011S 4 NP.0=3 813- 4-1a.reci,t 2 60,L-80..0152 501.1D=ISM' 818r -------\-- 1119L 1—IJET CUT TBG TAIL( 2/03108) I Tap or-P' oxi —I Erincr 9-543'CSG,470,L-I30,,ID.•8 6131" H 8890' 1" PERECRATICN SIAM Fl" REF LOG SINS BI-ICS ON 10125/79 I ANGLE A r r0P%Pic T a 8812 Note Ref er to Precticton CO for nstoncal parr data 1 8S33 Hw,,,,,ER Jor,-, I SIZE SPF IN I EriVA L OpnrSoz DATE 3 Ur 4 8992 9905 0 09(24699 3-318" 10 8988-9004 0 12/2C090 3-38' 10 SCX8-9CrA) 0 12/20/90 I [U NKNOW N1--1F8FI-4-1/7'TEIG TAIL(C1:7". 12/3/06) I 3-38 4 9025-9045 0 102289 r------) 2-117 4 0045-9(101) 5 09/1989 I I I I ,.., lir'T411I I I I I [ Pa TD I-4 9929' 1" Sae/WM jr•LNR 298 L-B0 0.3(' 581 ID,6.184" I--I 9976' 1.4.1.4.0A1.0.1 CATE REV BY COARJENFTS DATE REV B., COMMENTS fIRLDHOE aeoe INT 11103179 ORIGINAL COMPLETION 11/17106 KSII,I 0,,GI V C/0',11 4.106) WL,L X-01 11103/04 RHO ' 121C3OS JNIFIPJ-1 TBG TAIL CUT OFF nEnnirr No I7sotao 09119/08 0-14 %NO 06/23,07 PJC OW Tr CORRECTIONS API ND 50-029-20393-00 I 0/130.5 l'NS/PJC XX PLLO IN NIP REDUCER 03/27/1i MSS/PJC SET XX PLUG(3/23111 SEC.8,Ti ON,RI4E 274'FNL&491'RM. I 16114.05 PJC CORWCT IONS 02/0912 DIV RIC'TREF COPSIE-CTUN 02'23o€ FR/PC DRLG DRAFTCORRECTON _ BP Exploration(Alas Ma) 3 of 3 RE: PBU 1-01 Cellar Bubbling . . ?i1)d:LZo 07 Jim, J-01B (PTD #2022010) was reported on 04/01/07 with fluid in the cellar and slow bubbling. A cellar fluid sample was taken and determined to be fresh water. We have continuous monitoring in place on this well to ensure the fresh water does not overflow the cellar. At this point we are uncertain of the source of the bubbles in the cellar; further diagnostic work will be completed. The well has been shut-in and secured with a tubing plug. <Ç- The plan forward is as follows: 1. WIC: Shut-in well - DONE 2. SL: Set TTP - DONE 3. FB: MITT and MITIA to 3000 psi 4. DHD: MITOA w/N2 to 500 psi A wellbore schematic and TIO plot have been included for reference. Please call with any questions. Thank you, Andrea Hughes iCANNED APR 0 5 2007 Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 xl154 - - - - -Original Message - - - - - . ._.., ."...... ..." From: James Regg [mailto:jim regg@adrnin.state.ak.us] Sent: Tuesday, April 03, 2007 10:07 AM To: NSU, ADW Well Integrity Engineer; Tom Maunder Cc: Admin AOGCC Prudhoe Bay Subject: PBU J-01 Any thoughts on what is going on with J-01? Received a spill report for this on 4/3 via fax noting fresh water flow from gravel in cellar of the well; report says "Well Engineer is working on diagnosing the leak." Apparently the water was discovered 4/1 based on spill report. Jim Regg AOGCC Content-Description: J-OlB.pdf J-OIB.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of? 4/3/2007 1 :26 PM RE: PBU 1-0] Cellar Bubbling . . Content-Description: J-Ol no Plot.ZIP J-Ol TIO Plot.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 20f2 4/3/20071:26 PM TREE= 4-1/16" CAMERON ELLHEA D = CA MERON OR = BAKER 77.25' 38.4' 8558' ~~x Angle - 95 @ 9393' Datum MD - 8894' Datum ND = 8800' SS ! 9/5/8" TIEBK CSG, 47#, L-80 TC-II, ID = 8.681" 113-3/8" CSG, 68#, ID= 12.415" J-01 B 4-1/2" TBG, 12,6#, 13-CR VAM TOP, 7956' .0152 bpf, ID = 3,958" 14-1/2" X NIP, ID= 3,813" GAS LlFf MANDRELS ST MD ND DEV TYPE VLV LATCH 4 3272 3272 0 MMG DOME RK 3 5400 5400 1 MMG SO RK 2 6855 6854 2 MMG DMY RK 1 7766 7765 1 MMG OMY RK PORT DATE 16 08/12/06 20 08/12/06 o 07/31/06 o 07/31/06 Minimum ID :::: 2.372" @ 8720' 3-3/16" X 2-7/8" XO 7837' 7857' 7882' 7945' 4-1/2" X NIP, 10 - 3.813" t.-9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3,870" 14-1/2" X NIP, ID = 3,813" 1 14-1/2" XN NIP, ID = 3.725" I ITBG STUB (TAGGED 07/22/06) I UNIQUE MACHINE OVERSHOT 19-518" X 4-112" TIW HBBP-R PKR. 10 = 4.0" 13-1/2" BAKER DEPlOY SLY, ID = 3.000" I 14-112" OTIS X NIP. 10 = 3.813" (BEHIND LNR) 13-1/2" HES XNNIP, ID=2,75" I 14-1/2" OTIS XN NIP, ID = 3.725" (BEHIND LNR) 1 14-1/2" WLEG, ID = 3.958" (BEHIND LNR) I H ELMD TT LOGGED 03/09/95 (BEHIND LNR) 14-112" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I I TOP OF 5-112" LNR I 8084' 8089' PERFORA TION SUMMARY REF LOG: SWS MEI\.4 CNL/GR!CCL ON 11/23/02 ANGLEATTOPÆRF: 88 @ 10367' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL OA TE 2" 4 10367 - 10717 0 11/23/02 MILLOUTWINDOW (J-01B) 8664' - 8672' 13-1/2"LNR,8.81#,L-80,.0081 bpf,10=2.880" H 8622' 3-1/2" X 3-3/16" XO, 10 = 2.800" COMMENTS ORIGINAL COM PLETION SIDETRACK (J-01A) RACK (J-01 B) 3-3/16" X 2-7/8" XO, 10 = 2.372 I WHIPSTOCK, 3RDSET(11/13/02) I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10" 2.800" 19-5/8" CSG, 47#, L-80, 10" 8.681" 1 I 5-112" LNR, 17#, L-80, .0232 bpf, 10 = 4.892" 2-7/8" LNR, 6.16#, L-80, .0055 bpf, 10 = 2.372" 1 OA TE REV BY COMMENTS 08/23106 OCR! PJC DRLG DRAFT CORRECTIONS PRUDHOE SAY UNff WELL: J-01B PERMff No: '3023390 API No: 50-029-20020-02 SEC 9, T11 N, R13E, 750' SNL & 1245' WEL N4ES RWO CO/DTM ÆRFlTREE CORRECT (6113/0 RCT/PJC GL V ClO BP Exploration (Alaska) . . Production History PBU J-01 B ~ - !8 0 ceo I 'I 556 17955 8 I 8 i=~ ~ 01 64 I 23 I I 287 30 Ol-A I 2 10 Ol-Ju I o C 0 01 I 0 C 0 01- 6401 I 0 C 0 01- 6401 I 0 C 0 '~_H^"~Y=Y~~__ 01- 6401 I 0 C 0 0 6401 I 0 C 0 0 01- v",v'Jv¡1 0 C 0 0 Ol-D I 0 01 0 I 0 C 0 0 OI- 1 0 C 0 0 I 0 C 0 I 0 C 0 0 Ol-J I 0 C 0 0 0 0 0 0 Ol-May-( 64 I 8 0 C 0 0 _u;:.;~~ 64 8 0 C 0 0 Ol-Mar-( 64 I 8 0 0 0 0 Ol-Feb-( 640 I 8 0 C 0' 0 OJ -Jan-051 640 I 8 0 C 0 0 01- 640 8 0 0 0 0 I 8 0 0 0 0 8 0 C 0 C 01-8 I 8 I 0 0 0 C _,wwW=~H._' I- I 8 0 0 0 C OI- 1 I 10 78 -----~i~ Ol-J I I 169 3 31 I J 39 3 I I I 2 I 1 171 39 Ol-F I I 7475931 I I ""Lo31 0 31 I I 2 82 31 I I 7~ 3 OI- I I 309 3 I I 2 8 0 31 I 1 26 8 ~ 3 Ol-J I I 3 64 I 2 770 31 I I 262 10 3 Ol-A I I 29 ~.~.~ 3C I I 3 8 C 31 01_ I 2 10:¡ 28 01-Jan-03 I 2 13841 31 o I-Dec-O I 2 :=~~~l 25991 31 o I-Nov-021 64015011 2 4734 241 Jim Regg :jV Page 1 4/3/2007 04-03-2007 07:09am From-BPX WOAS~ 9076594174 . T-963 Generated on: POO)/001 F-691 03/0412007 Obp North Slope Spíll Report BP Exploration(Alaska),INC. 900 East Benson Blvd. Anchorage, AK 99519-6612 þ _.~ í. . i 6:)X Spill ~pt#: i I Date of Spill (DD/MMIYYYY) ! Time (HI-!:MM): Report Status: í I.ocatlon 1 ; i ¡ll.ocation2: N~C Rpt#: I Company: I ¡ I Materia~ Name L 07 -oao Total In Contalnmen!(GÖlllons): o 01/04/2007 Total Outside CQntall'lment(Gal): 1260 07:02:00 AM Recycled/ReusEid (Gal): o Water Affected? 49 Interim Disposed (Ga): o West Surface Area Impacted (Sq.Ft): Well 12ad J All Secondary Containment? Tundra Affected? Fresh Water Amount (Gal): ~ 1260 'iJ""~· . i' - P J flr¡/fL'1;¡p ~J "-ê¡ ""·!J8 ] I N BPX(A) N ! Cause: Fresh water wea alscoverea WillI \I <òuflli"'.......... flow ..f !r..o" wool.., ..,..nino "I" fMm th.. 0....",,1 In the cellar of J-1. rhe Wells Ënglneer ie working on diagnosing the IliIak. Initially 17 barrels were recovered using a Vac truck, Over me next Z4 hours an additional 13 barrelS of flllid were recollered, .. Clean-U p: The watet Inside of the well cellar is baing remolled with.. va<: true\( and monitored by mè Oownhole IJlagnoetic iechnicililns. The gravel inside the wellhOl1se was removed using iii $Upe!' su¡;{er assiPõted by approxlmatlilly 13 barrels of hot water ftom a water truck to tMw frQzen gravel. Oispo&al: The grave! frOm the wall cellar W'IS taken to the Grind & Inject Facility. TtIe vac truC{ is still on site mQnitoring the wliIll and the mat~rlal on the vae truck will be taken to Pad·3 once the true\< 15 rlilleased. - Einvironmental Impact: None Bxpected, material is frash water contained wltt'tln a gravel well cellar with a wooden sida box. . PreventativliI Action: The Wells Integrlty Engineer will diagnose the leak and dellelop an action plan. Additional Information: This report satisfies the notification requirements of 18 AAC 075.300 -~.. Submitted 8f ...-....' ('10=; )roS1- '-ßlS Telephone Page 1 of 1 · . STATE OF ALASKA _ ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & G RECEIVi::.D as ons. omrns: I 1. Operations Performed: Anchorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 202-201 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20020-02-00 7. KB Elevation (ft): 77.25' 9. Well Name and Number: PBU J-01 B 8. Property Designation: 10. Field / Pool(s): ADL 028281 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10758 feet true vertical 9026 feet Plugs (measured) None Effective depth: measured 10725 feet Junk (measured) None true vertical 9024 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 100' 30" 100' 100' Surface 933' 20" 950' 950' 1530 520 Intermediate 4241' 13-3/8" 4258' 4258' 3090 1540 Production 8541' 9-5/8" 8558' 8557' 6870 4760 Liner 575' 5-1/2" 8089' - 8664' 8088' - 8663' 7740 6280 Liner 2697' 3-3/16" x 2-7/8" 8061' - 10758' 8060' - 9026' SCANNED AUG 2 8 2006 Perforation Depth MD (ft): 10367' - 10717' Perforation Depth TVD (ft): 9020' - 9024' 4-1/2", 12.6# 13Cr80 / L-80 8084' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker 'S-3' packer 7857' 9-5/8" x 4-112" TIW 'HBBP-R' packer 8019' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled tubing from 7969'. Cut and pull 9-5/8" casing from -126'. Run 9-518" tieback to surface. Perform top job cementing oDerations with 7.5 Bbls Arcticset I (42 cu ft, 45 sx, Yield .93). Ran new Chrome tubinç¡. 13. ReDresentative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 306-214 Printed Name Terrie Hubble Title Technical Assistant Signatur~A!I; 0 &~ Phone 564-4628 08 /Í 0 Prepared By Name/Number: Date rZ DC:, Terrie Hubble, 564-4628 AUG 1 7 2006 c c 'on Form 10-404 Revised 04/2006 r<lGINAL RBDMS BFl AUG 2 4 2006 Submit Original Only . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 Complete Rig move from J-28 to J-01. Spot Sub over J-01 Well. Spot Pipe Shed and Pits. Raise and scope Derrick. Accept Rig at 02:00 hrs. Spot Tiger Tank. Rig-up Lines. Take on 1% KCK Water. Test Lines to 3,500 psi. Pick-up Lubricator and pull BPV. Lay down same. Hold pre-Job Safety and Operations meeting with all. Reverse out Diesel Freeze Protect. Circulate Well down to Jet Cut at 3,850'. Shut in Well and allow gas and oil to migrate to surface. Circulate out migrated gas and oil. Shut-in and repeat several times. Finally got Tubing to go on Vac. Still building pressure an back-side due to fluid migration. Install and test TWC. Nipple down Tree and Adopter Flange. Inspect Hanger Threads. Lift threads are "dog-chewed". Order out 4 1/2" Spear. Nipple-up BOP Stack. Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Chuck Scheve w/ AOGCC witnessing test. Tested choke manifold valves. Pipe & blind rams. Annular preventor. HCR choke & kill. Manual Choke & kill. TIW & dart valves. DFAL DECOMP Had accident on rig floor. As preparing to test Koomey unit. the TWC failed & well bore pressure blew bushings out of rotary table & struck floorman. Floorman named Lyrr Hamilton suffered broken tibia bone in his left leg. No other injuries reported. Well was shut in w/ blind rams. All emergency personnel were notified & injuried man was taken to infirmery in ambulance. Incident deemed to be a HIPO. All operations were ceased pending full investigation as to cause. SIP = 130 psi. Con't to Monitor well. Con't to monitor well pending HIPO accident investigation. SIP = 150 psi. Continue to monitor Well. Wellhead pressure at TP = 160 psi. Casing = 300 psi. Discuss Plan Forward with Anchorage. Receive permission to weight up to 9.0 Brine for circulating and loading up Well as discussed eariler. Weight up 1% KCL Water in Pits to 9.0 Ib/gal Brine. Hold PJSM before pumping. TP = 160 psi. CP = 300 psi. Bleed gas through Choke from Casing and Tubing to zeros (-8 minutes). Not much volume. Ease Pump on line down tubing side (under closed Blind Rams) no pressure (TWC not in Hanger profile). Increase pump rate to 3 bpm. Caught fluid after pumping 20 bbls (this volume replaces the approx amount of pit gain before the Well was shut in). Crack Choke and take returns to Tiger Tank. Continue circulating Well at 3 bpm/500 psi through Choke. Circulated Wellbore volume down to the Jet-Cut at 3,850' (305 bbls). Shut down Pump and close Choke. Zeros. Open bleeder on Casing side. Clean fluid, slight flow, spitting gas. Open bleeder on Tubing side. Slight flow. Close Choke and 7/14/2006 00:00 - 00:30 0.50 MOB P PRE 00:30 - 02:00 1.50 RIGU P PRE 02:00 - 03:30 1.50 RIGU P PRE 03:30 - 04:00 0.50 KILL P DECOMP 04:00 - 05:00 1.00 WHSUR P DECOMP 05:00 - 05:30 0.50 KILL P DECOMP 05:30 - 12:30 7.00 KILL P DECOMP 12:30 - 13:00 0.50 WHSUR P DECOMP 13:00 - 14:30 1.50 WHSUR P DECOMP 14:30 - 16:00 1.50 BOPSU DECOMP 16:00 - 20:30 4.50 BOPSU DECOMP 20:30 - 00:00 3.50 BOPSU N 7/15/2006 00:00 - 06:00 6.00 BOPSU DFAL DECOMP 06:00 - 10:00 4.00 BOPSU DFAL DECOMP 10:00 -11:00 1.00 BOPSU DFAL DECOMP 11 :00 - 14:00 3.00 KILL N DFAL DECOMP 14:00 - 16:00 2.00 KILL N DPRB DECOMP Printed: 7/31/2006 11 :00:41 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 7/15/2006 14:00 - 16:00 2.00 KILL N DPRB DECOMP pump down Tubing side. Bring pressure up to 2,000/5 min psi and test Packer and PXX Plug (Note: Plug tested only if tubing joint is not totally collapsed). Close in Well and monitor pressures. 16:00 - 21 :30 5.50 KILL N DPRB DECOMP Continue to monitor Well. Pressure at 17:00 hrs. TP = 20. CP = 40 psi. 21 :30 - 22:30 1.00 KILL N DPRB DECOMP SITP 10 psi, Annular pressure 40 psi. Circulate well start @ 1 BPM, 60 psi. Getting oil & some gas. pumped 15 bbls & estimate recovered 4 bbbls of oil. Con't to circulate 1 BPM, 60 psi. Pumped tubing volume getting 8.9 ppg brine back w/ very slight amount of oil. SID & monitor well. Well flowing slightly. 22:30 - 23:00 0.50 KILL N DPRB DECOMP P/U kelly & test same. LP 250 psi. HP 3500 psi. Charted test. Blow down & set back kelly. 23:00 - 00:00 1.00 KILL N DPRB DECOMP Monitor well & allow oil to rise. Guages showing no SI pressures. When opening sample valve well flows. 7/16/2006 00:00 - 01 :00 1.00 KILL N DPRB DECOMP Con't to monitor well. SITP = 0 psi. SI annular pressure = 0 psi. Well flows slightly when opened. Out of balance. 01 :00 - 03:00 2.00 KILL N DPRB DECOMP Circulate well. Pump 3 BPM @ 180 psi. Circulated all the way around from 3850'. SID, well breathing, then stopped. Monitor well. 03:00 - 03:30 0.50 FISH N DPRB DECOMP M/U 7" magnet on single jt of DP. Open blind rams. Drain BOP stack. Located TWC laying between hanger neck & side of spool. RIH w/ magnet & fish TWC. UD magnet & inspect TWC. Bottom 2 threads appear rough & have some damage. 03:30 - 04:00 0.50 BOPSU N DPRB DECOMP P/U test jt & RIH. Perform Koomey function test. Chuck Scheve w/ AOGCC declined to witness Koomey & Kelly tests. This completes the BOP test. 04:00 - 06:00 2.00 KILL N DPRB DECOMP Monitor well. Mobilize spooling unit, Cameron personnel & fisherman. Prepare to pull hanger. 06:00 - 06:30 0.50 PULL P DECOMP Lub Rig and inspect Derrick. 06:30 - 07:00 0.50 PULL P DECOMP Bring 4 1/2" Spear to Floor. Rig-up Control Line Spooling Unit. 07:00 - 08:00 1.00 PULL P DECOMP Pick-up 1 Joint of 3 1/2" Drill Pipe. Make-up BHA #1 as follows: Bull Nose, Pack-off, lower Spear Grapple, upper Spear Grapple. BOLDS. Pull Tubing Hanger to Floor at 49K with no problems. Release Spear. Lay down Hanger. Inspect BPVITWC profile threads. VERY BAD. Rough, nicked, and one section where running in and out of the Well with Coiled Tubing, S-Line, E-Line over the years has cut a groove and completly worn the threads away. (See Photos). NORM Tubing Hanger. Send the Hanger and TWC to Tool Services for inspection by the Investigation Team and others. 08:00 - 09:30 1.50 PULL P DECOMP Circulate bottoms-up from the Jet-Cut at -3,850' at 4 bpm/150 psi. Monitor Well dead. 09:30 - 11 :30 2.00 PULL P DECOMP Single down 4 1/2" L-80 Tubing in Pipe Shed. Spool Control Line. Recovered Control Line and Bands complete. Stop to rig-down Spooling Unit. 11 :30 - 13:00 1.50 PULL P DECOMP Continue to lay down remaining 4 1/2" Tubing. Recovered a total of 96 Joints, SSSV assembly, 3 ea 4 1/2" Pup Joints, 20.51' Jet-Cut Stub. Jet-Cut = normal flare. 13:00 - 14:00 1.00 FISH P DECOMP Rig-down 4 1/2" handling equipment. Rig-up to handle BHA #2 and 3 1/2" Drill Pipe. 14:00 - 16:00 2.00 FISH P DECOMP Make-up BHA #2 as follows: 8.50 x 6.63" Rotary Shoe, WP, WP, WP, WP, Drive Sub, XO, Bumper Sub, Oil Jar, 9 ea Drill Printed: 7/31/2006 11:00:41 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 7/16/2006 14:00 - 16:00 2.00 FISH P DECOMP Collars, Intensifier. 16:00 - 21 :00 5.00 FISH P DECOMP RIH with BHA #2. Single in with 31/2" Drill Pipe from Pipe shed. tagged top of tubing stub @ 3846'. 106 jts + BHA + 25' of jt 107. Wash pipe when over stub wI no prpblem. Con't to P/U & single in hole. Bottomed out @ 3976'. 110 jts + BHA + 28' of jt #111. P/U Wt = 70K, SIO Wt = 70K. P/U retag & confirm bottoming on drive sub. 21 :00 - 22:30 1 .50 FISH P DECOMP Circulate bottoms up. Pumped 5 BPM @ 650 psi. Pumped approx 300 bbls. Had some gas to surface, not enough to have to close in bag. SID & monitor well, Well dead. 22:30 - 00:00 1.50 FISH P DECOMP POOH WI BHA #2. Stand back 31/2" DP. 7/17/2006 00:00 - 02:00 2.00 FISH P DECOMP Break out & UD BHA #2. 02:00 - 03:00 1.00 FISH P DECOMP P/U & M/U BHA #3 to cut tubing from the outside. BHA is as follows: Outside cutter, 4 jts of wash pipe, Drive Sub, XO, 9 * 4 3/4" DCs, PxP Sub, Bit Sub wI float. TL = 414.32'. 03:00 - 04:00 1.00 FISH P DECOMP RIH wI BHA #3 on 4stands of 3 1/2" DP. 04:00 - 05:00 1.00 FISH P DECOMP Cut & slip 84' of drilling line. Adjust brakes. 05:00 - 07:00 2.00 FISH P DECOMP Con't to RIH wI BHA #3. 07:00 - 09:30 2.50 FISH P DECOMP Swallow Flare on top of Jet-Cut stump (3,850') and collasped section( -3,907') with no problems (saw nothing). PUW = 74K. SOW - 74K. Pick-up Kelly. Locate collar on first full joint below collasped joint at 3,947'. RTW = 84K. Attempted to perform out-side cut at 3,950'. Did not see any evidence the a cut was made. Prep to POOH. 09:30 - 10:30 1.00 FISH P DECOMP Set back Kelly. Pulled 11 Stands. Stop operations. Attempte to get relief for the BFT Hand. No relief available. Everybody out in the Field on other jobs. Instructed BFT Hand to take a Safety Nap. Leave BHA and Drill Pipe at present depth for a kill string. 10:30 - 15:30 5.00 FISH N WAIT DECOMP Service, clean, and maintain Rig while BFT Hands gets some rest. 15:30 - 17:00 1.50 FISH P DECOMP Resume Ops. Finish out with 3 1/2" Drill Pipe and BHA #3. 17:00 - 20:00 3.00 FISH P DECOMP Lay down BHA. Fish recovered as follows: Jet-Cut Stump = 18.60' and the Collasped Joint = 39.15'. Pin-end collasped - 2 1/2'. Clear & clean rig floor. 20:00 - 21 :00 1.00 FISH P DECOMP Wait on 2 7/8" PAC DP. 21 :00 - 23:00 2.00 FISH P DECOMP P/U & M/U BHA #4 as follows: 33/4" Mill, Shear Guide, 6 Jts 2 7/8" PAC DP, XO, Bumper Sub, Jars, 9 * 4 3/4" DCs, Accelerator. TL = 501.86' 23:00 - 00:00 1.00 FISH P DECOMP RIH wI BHA #4 on 31/2" DP. 7/18/2006 00:00 - 00:30 0.50 FISH P DECOMP Con't to RIH wI BHA #4. Tagged up on tbg stub @ 3904'.35 Stands + 2 singles +8'. P/U Wt = 66K, SIO Wt = 66K. 00:30 - 01 :00 0.50 FISH P DECOMP Rotate string & Slack off. Guide sheared out & mill entered 4 1/2" tubing. Con't to RIH & drift tubing w/3 3/4" mill. Bottomed out @ 4096'. 26 stands + 2 singles + 10'. No drag or tight spots noted. 01 :00 - 02:30 1.50 FISH P DECOMP P/U 2' & break circulation. Pumped 5 BPM @ 1220 psi. Had some gas to surface. Not necessary to close bag. Pumped 350 bbls. Monitor well. Well static. 02:30 - 04:00 1.50 FISH P DECOMP Break out head pin & POOH wI BHA #4. Stand back 3 1/2" DP. 04:00 - 06:00 2.00 FISH P DECOMP Break out & UD BHA #4. Clear & clean rig floor. 06:00 - 06:30 0.50 FISH P DECOMP Lube Rig and inspect Derrick. 06:30 - 07:00 0.50 FISH P DECOMP Rig-up to handle and pick-up 41/2" Tubing. Printed: 7/31/2006 11 :00:41 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 7/18/2006 07:00 - 08:00 1.00 FISH P DECOMP Make-up BHA #5 as follows: 8 1/8" Overshot dressed to catch 41/2" BT box, XO, XO. 08:00 - 11 :00 3.00 FISH P DECOMP Run in hole with BHA #5. Single in with 4 1/2" NSCT Workstring from Pipe Shed. 94 jts & 6.87' of pup. 11 :00 - 11 :30 0.50 FISH P DECOMP PJSM. 52K up wt, 52K down wt. Latch tubing stub @ 3904'. Overpull 53K to final up wt of 105K. Workstring spaced out to rig up just above rig floor, slips set wI dog collar. 11 :30 - 15:00 3.50 FISH P DECOMP Wait on Schlumberger slickline. 15:00 - 21 :00 6.00 FISH P DECOMP PJSM. Rig up Schlumberger slickline. Pressure tested lubricator 2000 psi for 5 min. charted same. 21 :00 - 22:00 1.00 DHB P DECOMP RIH & make gauge ring I junk run to 2325'. 3.85" centralizer, 3.80" gauge ring. Work up & down several times. No go. Got sticky. POOH. 22:00 - 23:30 1.50 DHB P DECOMP Change out tools. RIH wI 3.79" gauge ring & tagged up on prong @ 7953'. POOH. Recovered 1 cup full of scale & debris. 23:30 - 00:00 0.50 DHB P DECOMP Change out tools for a 3.83" swage. OD of PXX plug is 3.81" . RIH. 7/19/2006 00:00 - 01 :30 1.50 DHB P DECOMP Con't to RIH wI 3.83" swage. Had to work thru 2329' several times. Tight spot cleaned up. Con't in hole. Bottomed out @ 7956'. POOH. 01 :30 - 03:00 1.50 DHB P DECOMP Change tools for 3.55" bell guide & 2 1/2" JDC to pull prong in "PXX" plug. RIH to 7958'. Engauge & Jar on prong. Pin sheared. POH. 03:00 - 04:30 1.50 DHB P DECOMP Redress, re-pin JDC tool & re-run in hole. RIH to 7958' Could not grab fishing head. POOH. 04:30 - 06:00 1.50 DHB P DECOMP Change out tools for a, 3" pump bailer. RIH & clean out to prong. 06:00 - 07:00 1.00 DHB P DECOMP OOH, empty bailer, approximately 1/2 gallon recovered. Marks on inside of bailer indicating made contact wI fish neck on prong. 07:00 - 10:30 3.50 DHB P DECOMP M/U & RIH w/2 1/2" JDC in a 3.60" bell guide to 7953' WLM. Unable to latch prong. POOH. 10:30 - 11 :30 1.00 DHB P DECOMP Swap stem for 5' x 2 518" .., will add 5' to the bailer. JD came back sheared, skirt, pawls & core were beat up. RBIH wI 10' x 3" pump bailer wI clean mule shoe flapper bottom to 7953' WLM. Work bailer for 1/2 hour. POOH wI 1/2 gallon of same substance as before, (pipe dope, scale & grit). marks on inside of bailer bottom. 11 :30 - 15:30 4.00 DHB P DECOMP PJSM. CUt 100' of slickline & re tie knot. RIH wI bailer, recovered 1 cup. RIH w/1 3/4" KJ, 2 1/2" JDC in a 3 1/2" bell guide to 7953'. Stab around, got a small friction bite, unable to latch up. OOH. JD sheared. RIH wI same set up but w/2 1/2" JUS, (steel), gently tap around, latch prong, got (8) jar licks, POOH. 15:30 - 18:00 2.50 DHB P DECOMP OOH wI sheared JUS, discuss options, run baited guttered J pulling tool on a GR. 18:00 - 19:30 1.50 DHB P DECOMP Con't to jar on prong. Change out crews. Jar on prong. Wire parted between drum & counter while jarring wI 1800 Ibs. Line did not go down hole. 19:30 - 20:30 1.00 DHB P DECOMP Hold PJSM & discussed procedure to resume operation. Untangle line. Tie on & pull line down to floor. Make temporary splice. 20:30 - 22:00 1.50 DHB P DECOMP Jar down & Shear off from PXX prong & POOH. Printed: 7/3112006 11 :00:41 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 7/19/2006 22:00 - 23:00 1.00 DHB P DECOMP UD lubricator & Wireline tools. RID unit. 23:00 - 00:00 1.00 DHB P DECOMP Change out equip wI 2nd unit. Spot in & set new unit. 7/20/2006 00:00 - 01 :00 1.00 DHB P DECOMP Finish swapping & RlU unit. Install new pack off. 01 :00 - 01 :30 0.50 DHB P DECOMP M/U on 2 518" stem, Spangs, oil jar & 3 1/4" GS retrieving tool. Pressure test lubiricator to 2000 psi for 5 min. Charted same. 01 :30 - 04:00 2.50 DHB P DECOMP RIH to 7955' & latch onto PXX Prong. Attempt to jar free wI 1600-1800 Ib licks for 1 hr. No movement. Shear off & POOH. 04:00 - 04:30 0.50 DHB P DECOMP UD & re-dress GS tool. Cut & slip 150' of .125" wireline. P/U 8' of 3" stem, 2 1/8" Oil Jars, 2 1/8" Spangs & 4.5" GS tool. 04:30 - 09:00 4.50 DHB P DECOMP RIH to 7955' & latch onto PXX Prong. Jar on Prong. Unable to jar equalizing prong free, shear off & POOH. 09:00 - 12:00 3.00 DHB P DECOMP PJSM. Rig down Schlumberger slickline. 12:00 - 14:00 2.00 PULL P DECOMP PJSM. Rig up Schlumberger E line wI full BOP. Pressure test to 2000 psi, OK. 14:00 - 15:30 1.50 PULL P DECOMP RIH wI centralized 4 1/2" tbg jet cutter on E line, tag "X" Nipple & correlate. Position cutter @ 7924' in 1 st full joint above "X" Nipple. Detonate jet cutter, good indication on rig floor. 15:30 - 16:00 0.50 PULL P DECOMP PJSM. POOH wI cutter to 200'. 16:00 - 16:30 0.50 PULL P DECOMP PJSM. Line up & circulate @ 4 bpm 150 psi, down tubing w/9 ppg brine, (2) tubing volumes. 16:30 - 17:00 0.50 PULL P DECOMP PJSM. Rig down Eline BOPE & E line sheaves. Latch up & pull on tubing to verify free. Up wt = 95K, pipe is free. 17:00 - 17:30 0.50 PULL P DECOMP PJSM. Finish rigging down Schlumberger Eline. 17:30 - 19:30 2.00 PULL P DECOMP Circulate bottoms up wI 8.9 ppg brine. Start 6 BPM @ 240 psi. Had gas to surface @ 1900 stks (112 bbls) Slow pump to 3 BPM @ 60 psi. Con't to circulate thru gas buster. Gas died out & was completely gone @ 5500 stks. (324 bbls) Con't to circulate. Fluid returns had light spots of 8.4 ppg wI some small amounts of gas. ( original 1 % KCI Brine). Circulated to 10100 stks (594 bbls). No more gas. SID & monitor well. Well Dead. 19:30 - 23:30 4.00 PULL P DECOMP RID head pin. POOH & UD work string. UD 7' pup, 94 jts of 4 1/2" work string & Overshot Assy. 23:30 - 00:00 0.50 PULL P DECOMP M/U head pin & begin circulating bottoms up wI 8.9 ppg brine. 5 BPM @ 150 psi. Change out crews. 7/21/2006 00:00 - 01 :30 1.50 PULL P DECOMP Con't to circulate bottoms up Pump 5 BPM @ 160 psi. Had gas to surface in 1200 stks (71 bbls). Slow pump to 3 BPM & continue to circulate. Gas quit @ 2600 stks ( 153 bbls) Had some light spots of fluid. Weighting all fluid returns up to uniform 8.9+ ppg. Con't to circulate. Pumped 294 bbls. SID & monitor well, well dead. Also check OAP wI new gauge, read 15 psi. 01 :30 - 06:00 4.50 PULL P DECOMP RID head pin. Pull 1 jt of tbg, on the 2nd jt 27" below the collar, saw evidence of attempted outside tbg cut. unifrom groove evenly all the way around the tbg. ( did not cut thru at any spot). Con't to POOH & UD 4 1/2" completion string. Pins are very badly corroded. 06:00 - 07:30 1.50 PULL P DECOMP Clear I clean rig floor. Prep to run DP. 07:30 - 09:00 1.50 PULL P DECOMP PJSM. M/U baker outside cutter BHA. 09:00 - 17:00 8.00 PULL P DECOMP PJSM. RIH w/3 1/2" DP, (stands from derrick). Pick up singles. 200 jts in the hole. 17:00 - 18:30 1.50 PULL P DECOMP Notice a little bubbling on the IIA side. (Float installed in BHA). Circulate bottoms up, 5 bpm I 925 psi. Pumped 460 bbls. SID Printed: 7/31/2006 11:00:41 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 7/21/2006 17:00 - 18:30 1.50 PULL P DECOMP monitor well. Well static. 18:30 - 20:00 1.50 PULL P DECOMP P/U 35 additional jts & RIH. 235 jts + BHA = 7801'. M/U head pin. Noticed small bubbles in annulus. 20:00 - 21 :30 1.50 PULL P DECOMP Circulate bottoms up 5 BPM @ 1000 psi. No gas to surface during entire circulation. Pumped 470 bbls. Checked OAP, had 15 psi on it. Bled down to 0 psi. Did not smell like gas. Air? SI. Monitor well, well static, no bubbles. break of circulating pin. checked DP FL approx. 20' down in pipe. 21 :30 - 22:30 1.00 PULL P DECOMP Con't to monitor well while P/U Storm Packer. M/U storm Packer, RIH to 33' & set same. P/U wt = 124K, SIO wt =124K. Pressure up & test storm packer from below. wI 500 psi, held for 5 min. Back out running tool, POOH & UD same. Close in rams & pressure test from top wI 500 psi for 5 min. Charted both tests. 22:30 - 00:00 1.50 WHSUR P DECOMP P/U test plug RIH & set in tubing hanger. RILDS. RlU test equip. Fill lines Open annulus valve. 7/22/2006 00:00 - 05:30 5.50 BOPSU P DECOMP Perform weekly test on BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. John Crisp wI AOGCC waived witnessing test. Had 2 failures, Valve #13 on choke manifold. Bled off Cucled valve open & closed several times. Re-pressure & valve tested. Dart valve failed, Re-placed "0" ring & re-tested good. 05:30 - 06:00 0.50 BOPSU P DECOMP RID test equip. Clear & clean rig floor. 06:00 - 07:00 1.00 BOPSU P DECOMP PJSM. Run in wI running tool & screw into Halliburton Storm Packer, no pressure, pick up & release packer, monitor well, well stable, UD packer & running tool. 07:00 - 09:00 2.00 PULL P DECOMP PJSM. RIH w/3 1/2" DP. 239 jts + 23.85' pup. See top of stub @ 7925' DPM. Kelly up & run in 27' on kelly = 7979' DPM. (Collar @ 7965'). 122K down wt, 125K up wt, 128K rotating wt. 09:00 - 11 :00 2.00 PULL P DECOMP PJSM. Pick up slowly, see up wt increase @ 7969'. Slack off 6". Kick in rotarey table @ 30 RPM. Torque is 1000 - 1500 ftllbs. Bring on charge pump for continuous hole fill to allow us to watch for loss of returns, indicating good cut. Rotate @ 30 RPM for 10 minutes & pick up 1/2". Repeat process. After 4 1/2" see torque increase to 3000 ftllbs & gradually drop on back down. Rotate @ 30 RPm for 10 minutes as before. Pick up another 1/2" & repeat. After 6" total pick up, see torque increase again, as before & gradually drop off. Note loss of returns at this point. Pick up another 1/2" & rotate for 5 minutes, no torque increase. Kick out rotary table & pick up with no overpull. Loss rate is 30 -40 bph. Filling hole wI seawater. Break off & stand back kelly. 11 :00 - 14:30 3.50 PULL P DECOMP PJSM. POOH wI 3 1/2" DP & outside cutter assembly. 14:30 - 16:00 1.50 PULL P DECOMP PJSM. Stand back 4 3/4" DCs. Break down & lay down outside cutter BHA. Recovered 43.69' fish including, from top down, cut off jt, 10' pup, "x" nipple, 10' pup & collar plus 2' of next full jt. Cut made approximately 2' below collar, good looking cut, no burrs or flaring. 16:00 - 17:30 1.50 PULL P DECOMP PJSM. Pick up 4 1/2" tubing stub dress off BHA. 17:30 - 23:00 5.50 PULL P DECOMP PJSM. RIH wI tubing dress off BHA & 3 1/2" DP. Loss rate 18 -25 bph, (seawater). 23:00 - 00:00 1.00 PULL P DECOMP RIH with 241 jts of 31/2" DP. Tag tbg stub at 7970'. 129K up wt, 128K down wt, 130 rotating wt. Kick in rotary table at 30 Printed: 7/31/2006 11:00:41 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 7/22/2006 23:00 - 00:00 1.00 PULL P DECOMP RPM and pump 3.0 bpm at 470 psi. Dress tbg stub down to 7971'. Loss rate 12 bph. 7/23/2006 00:00 - 03:00 3.00 PULL DECOMP Reverse circulate 30 bbls hi-vis sweep around to clean tbg stub followed by 582 bbls at a rate of 4.0 bpm I 700 psi until sweep cleaned up. Loss rate 36-72 bph. 03:00 - 06:30 3.50 PULL DECOMP POOH with 3 1/2" DP and dress off BHA. 06:30 - 07:30 1.00 PULL DECOMP PJSM. UD tubing dress off BHA. 07:30 - 09:30 2.00 DHB DECOMP PJSM. Pick up 9 518" Halliburton retrievable bridge plug on (9) 43/4" DCs. Total BHA length = 293.71' to middle of element in bridge plug. 09:30 - 14:00 4.50 DHB DECOMP RIH w/9 518" RBP on 3 1/2" DP. 80 stands. 112K up wt, 122K down. 14:00 - 15:00 1.00 DHB DECOMP PJSM. Pick up 6', rotate (2) turns to the right, set down 15K, bridge plug set @ 7884'. Pick up & UD (1) jt DP. MIU headpin & close pipe rams. Pressure test 9 5/8" casing fropm 7884' to surface @ 3500 psi, 30 minutes, charted. Good test. OIA monitored, no indication of communication to O/A. Bleed off all pressure, open pipe rams. 15:00 - 19:30 4.50 DHB DECOMP PJSM. POOH w/3 1/2" DP & Halliburton running tool. 19:30 - 23:30 4.00 EVAL DECOMP PJSM. LD riser and MU shooting flange. Rig up Schlumberger E-Line with lubricator and pressure test to 500 psi, OK. 23:30 - 00:00 0.50 EVAL DECOMP RIH with US IT on E-Line down to 7800' and log up at 50 fpm to determine cement top in 9-5/8" x 13-3/8" annulus. 7/24/2006 00:00 - 07:00 7.00 EVAL DECOMP Con't logging with USIT to determine cement top in 9-5/8" x 13-3/8" annulus. 07:00 - 08:00 1.00 EVAL DECOMP PJSM. Rig down Eline. 08:00 - 10:30 2.50 FISH DECOMP PJSM. Rig up Eline & shooting flange. Safety meeting regarding firing string shot @ shallow depth. 10:30 - 12:00 1.50 FISH DECOMP RIH wI string shot. Pressure test lubricator to 500 psi, OK. Arm tool. Correlate depth to fire string shot. Close annular preventor wI 500 psi close in pressure. Fire string shot, (12' - 3 strands), f/114' - 126'. 12:00 - 13:30 1.50 FISH DECOMP PJSM. POOH & RID Eline. 13:30 - 14:30 1.00 DHB DECOMP PJSM. NID shooting flange, NIU flow nipple. 14:30 - 15:00 0.50 DHB DECOMP PJSM. Pick up Halliburton 9 5/8" Retrievable bridge plug & (9) 4 3/4" DCs. OAL = 293.71' to middle of element. 15:00 - 16:00 1.00 DHB DECOMP PJSM. RIH w/18 stands 3 1/2" DP. 16:00 - 17:00 1.00 DHB DECOMP PJSM. Pick up 6', rotate (2) turns to the right, set down 15K, bridge plug is set. UD (1) jt pressure test bridge plug wI 2000 psi 115 minutes, good test. Top of bridge plug @ 1987'. 17:00 - 18:00 1.00 DHB DECOMP PJSM. Dump 1500# river sand on bridge plug. 18:00 - 19:00 1.00 FISH DECOMP Let sand settle and tag top of sand at 1961' (17 stands, 1 single, 18') 19:00 - 20:30 1.50 FISH DECOMP Empty pits and circ 9.8 brine at 4 bpm I 240 psi. 20:30 - 22:00 1.50 FISH DECOMP PJSM. POOH with 3 1/2" DP and LD Halliburton setting tool. 22:00 - 00:00 2.00 FISH DECOMP PJSM. PU Baker 8 1/4" Multi-String cutter, stabilizer, and (2) 4 3/4" DCs. OAL = 72.12'. 7/25/2006 00:00 - 01 :00 1.00 FISH DECOMP PJSM. RIH with 1 jt of 31/2" DP. Pressure up workstring to 300 psi to extend cutters and locate 9 5/8" csg collar at 126' (22' in on kelly). PUH 19' to 107' and establish parameters for making csg cut. Up Wt = 19K. Down Wt = 19K. Freespin at 60 rpm is 1000 ft Ibs. Kick on pump and gradually ramp up pressure to 500 psi; averaged 2000 ft Ibs during cut. Lost 7.1 Printed: 7/31/2006 11:00:41 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 7/25/2006 00:00 - 01 :00 1.00 FISH DECOMP bbls (Annular vol to 107') indicating pipe was cut. Con't circulating. 01 :00 - 03:00 2.00 FISH DECOMP PJSM. RIU LRS and pump 50 bbls of hot diesel down workstring up 9 5/8" x 13 3/8" annulus taking returns to tiger tank. Let diesel soak for 15 min. Pump additional 50 bbls the same. Flush diesel with 9.8 brine and let well stabilize of 30 min monitoring pressure. 03:00 - 04:00 1.00 FISH DECOMP PJSM. POOH 1 jt of 3 1/2" DP. LD Baker Multi String cutter. Clear floor. 04:00 - 06:00 2.00 FISH DECOMP PJSM. ND BOPE and TBG spool. 06:00 - 08:00 2.00 FISH DECOMP Continue to N/D. Remove old tubing spool. Remove test spool. OIA open & dead throughout operation. 08:00 - 11 :00 3.00 FISH DECOMP PJSM. NIU spacer spool & double studded adapter flange to bottom of BOP. 11 :00 - 13:30 2.50 FISH DECOMP PJSM. M/U 95/8" spear on (1) jt DP. Attempt to pull casing slips, pull eventually to 55K, (35 - 40K over), no movement at slips. UD joint of DP & pick up (1) 4 3/4" drill collar & jars. Work pipe to 75K & set off jars at 75K - 80K wI no visible movement at slips. 13:30 - 16:00 2.50 FISH DECOMP PJSM. Rig up containment around wellhead and apply steam to wellhead. 16:00 - 17:30 1.50 FISH DECOMP PJSM. Pull (1) time to 75K after heating wellhead wI steam, no discernable movement. UD 4 3/4" DC & jars, pick up (2) 6 1/4" DCs & 6 1/4" jars. RIH & engage spear. Also apply Kroil liberally to emergency slips. Attempt to jar loose w/6 1/4" jars, jars not re cocking, opt to go back to smaller jars. 17:30 - 19:00 1.50 FISH DECOMP PJSM. Break out & UD jars, pick up necessary X/Os and make up smaller jars wI (2) 6 1/4" DCs on top. Engage spear & pull to 80 -90K, set off jars. Recock jars & pull to 125K & set jars, no movement for (6) hits & came free on the 7th hit. 19:00 - 19:30 0.50 FISH DECOMP PJSM. Remove slips from 95/8" casing. 19:30 - 20:30 1.00 FISH DECOMP PJSM. Lower BOPE & NIU to wellhead. 20:30 - 22:30 2.00 FISH DECOMP Set casing down and release Spear from 9 5/8". Lay down 6 1/4" DC's and re-make up Spear Assembly. 22:30 - 00:00 1.50 FISH DECOMP PJSM. Re-engage Spear into 9 5/8" and pull to Rig Floor. Begin laying down joints of 9 5/8" into Pipe Shed. Recovered 2 cut joints and one full joint of 9 5/8" Casing. Lengths were: 22.22',40.45',20.30'. 7/26/2006 00:00 - 01 :30 1.50 FISH DECOMP PJSM. MU BHA #10 as follows: 13 3/8" Casing Scraper, Bit Sub, XO, Bumper Sub, (3) 43/4" DCs. OAL = 111.26'. RIH with Scraper and tag hard at 12' in on the third DC. This puts the BHA at 91'. Continue to work Scraper and tagging at same depth. May be some cement. Attempt to rotate down through it - no joy. Will attempt to clean out with wash pipe BHA. POH with Scraper and break down BHA. 01 :30 - 04:30 3.00 FISH DECOMP PJSM. Clear and clean Rig Floor. RU to handle BHA components. PU and MU BHA #11 as follows: 12 118" Dragtooth Shoe, (1) joint of 11 3/4" Washpipe, Drive Sub, XO, Boot Basket, Bit Sub, XO, (1) 61/4" DC, XO. OAL = 70.36'. 04:30 - 05:30 1.00 FISH N DPRB DECOMP RIH with BHA #11. PU and MU Kelly. Line up to pump down workstring. UW = 18K. Break circulation at a rate of 3.5 bpm I 20 psi. Kick in rotary table at 60 RPM with 50 Amps (1,000 ft-Ib) of torque. RW = 15K. Taking weight with 20' Kelly in the Printed: 7/31/2006 11 :00:41 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 7/26/2006 04:30 - 05:30 1.00 FISH N DPRB DECOMP hole = 90' in the hole. Torque increasing to 150 Amps (3,000 ft-Ib). Maintaining about 4K and very solid. Not wanting to clean up. Decision made to run string mill. 05:30 - 07:00 1.50 FISH N DPRB DECOMP POH with BHA #11. Break down BHA components and prepare to run string mill. Recovered 1/2 - 1 cup metal in junk sub & some cement. 07:00 - 08:30 1.50 FISH N DPRB DECOMP PJSM. UD washpipe, pick up 11 3/4" cut lip guide shoe. 08:30 - 09:30 1.00 FISH N DPRB DECOMP RIH, tag @ 91', POOH. 09:30 - 11 :00 1.50 FISH N DPRB DECOMP UD BHA. Clear I clean rig floor. 11 :00 - 11 :30 0.50 FISH N DPRB DECOMP PJSM. Fill hole, close blind rams, pressure test 9 5/8" & 133/8" casing to 1100 psi, bled 200 psi in 15 minutes. NOTE: Previous MIT/OA bled from 2000 psi to 600 psi in 15 minutes ... pre work over... ,so no significant indication of hole in 133/8". 11 :30 - 14:30 3.00 FISH N DPRB DECOMP PJSM. MIU 103/4" swedge, hang off (6) DCs below swedge, oil jars, bumper sub & RIH on (2) 6 1/4" DCs. MIU (1) jt of 3 112" DP. Tag @ 91'. 14:30 - 20:00 5.50 FISH N DPRB DECOMP PJSM. Work swedge, dropping on tight spot @ 91'. Made l' in 1 st (2) hours. @ 17:00 hrs, dropped through & made another 5' - 6' to 97' - 98'. Pulled back up through wI usual overpull of 20 - 25K. Continue to work swedge, made it down to top of stub @ 106'. Work tight spot. Cleaned out and had no overpull going into or out of tight spot around 19:00 hrs. Then began to stick again in both directions. Attempt to circulate any junk that may be catching swedge but still sticking with about 15K. Discuss with Anchrorage Engineering and decision made to go in and backoff. 20:00 - 20:30 0.50 FISH N DPRB DECOMP POH with BHA to inspect swedge. Lay down DCs below swedge. 20:30 - 22:30 2.00 FISH N DPRB DECOMP PJSM. Begin breaking down BHA components and laying down what will not be used on next run. Clear and clean rig floor. 22:30 - 00:00 1.50 FISH P DECOMP PJSM. PU and MU BHA #12 as follows: Bullnose, XO, (7) DCs, XO, XO, Blanking Sub, Lower Anchor Assembly, Back-off Power Section, Upper Anchor Assembly, XO, (2) DCs, XO, 1 Joint of DP, 1 Pup Joint of DP. OAL = 375.44'. 7/27/2006 00:00 - 00:30 0.50 FISH P DECOMP Continue MU BHA #12 - 9 5/8" Casing Backoff Assembly. 00:30 - 02:00 1.50 FISH P DECOMP RIH with BHA #12. PU single joint of DP and 23.95' pup joint of DP. Fill workstring with diesel and monitor for any losses - good. MU Headpin. PJSM. Position workstring at 18.5' in on pup joint at the Rotary Table. Pressure up to 1,500 psi to set lower anchor assembly. Bleed pressure off. Set upper anchor assembly with 3,500 psi. 02:00 - 02:30 0.50 FISH P DECOMP Begin backing off on the 9 518" Casing. List of turns and associated pressure as follows: 1/4 turn, 3500 psi; 1/2 turn, 1700 psi; 1/2 turn, 1000 psi; 1/2 turn, 600 psi; 3/4 turn, 550 psi; 1/2 turn, 350 psi; 1/2 turn, 150 psi; 3/4 turn, 350 psi; 1/2 turn, 500 psi; 1/2 turn, 550 psi; 1/2 turn, 500 psi; 1/2 turn, 575 psi; 1/2 turn, 600 psi. Total amount of turns achieved = 6 3/4 turns. 02:30 - 03:00 0.50 FISH P DECOMP PJSM. Bleed lines and pressures off. Break off Headpin. POH with BHA #12. 03:00 - 05:30 2.50 FISH P DECOMP Break down BHA #12 components and lay down 6 1/4" Drill Collars. Clear and clean Rig Floor. 05:30 - 07:00 1.50 FISH P DECOMP PJSM. PU tool components and begin MU BHA #13 to displace Printed: 7/31/2006 11:00:41 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 7/27/2006 05:30 - 07:00 1.50 FISH P DECOMP fluid in the 9 5/8". BHA consists of (9) 6 1/4" DCs & (9) 43/4" DCs with a bullnose plug and closed valve on the bottom. 07:00 - 08:30 1.50 FISH P DECOMP RIH w/11 stands 31/2" DP to 1603'. Drain stack, (3 bbls). 08:30 - 10:00 1.50 FISH P DECOMP PJSM. POOH, stand back DP & 4 3/4" DCs, UD 6 1/4" DCs. 10:00 - 12:00 2.00 FISH P DECOMP PJSM. M/U spear dressed for 9 5/8" 47# casing, tag up @ 91' w/10 3/4" stop ring. POOH, remove stop ring. RBIH, engage tubing stub @ 135'. Pull 3k over & rotate to the left, (6) turns, not free, repeat one more time & free. POOH. Pulled tight for 1 -2',5 - 8K overpull required. 12:00 - 13:00 1.00 FISH P DECOMP Break off & UD spear. Recovered 18.70' of 9 5/8" w/10 5/8" OD collar. 13:00 - 15:30 2.50 FISH P DECOMP PJSM. Send in crossover jt & BTC collar to Baker Machine to turn down collar to 10 1/2" OD. Rig up floor to run 9 5/8" casing. 15:30 - 17:30 2.00 CASE P TIEB1 PJSM. Pick up crossover joint, 95/8" BTCM 47# L-80 x TCII wI BTCM collar made up on the bottom. Collar turned down to 10 1/2" OD. RIH wI (2) joints 9 5/8" L-80 47# TCII, torque turning connections to 18,500 ftIlbs, using Jet Lube Seal Guard pipe dope. See tight spot @ 91' & work thru same, OK. 17:30 - 18:00 0.50 CASE P TIEB1 Pre-tour safety meeting with night crew. Discuss plan forward and prepare to screw-in the 9 5/8". 18:00 - 19:30 1.50 CASE P TIEB1 PU 20' pup joint of 9 5/8" 47# L-80 TC-II and MU. Begin screwing in to existing 9 5/8" BTC. Weight = 16K. Achieved 10 turns and torqued to 12,000 ft-Ibs. Pull tested to 150K per Cameron - good. Maintain 150K on the Hook. RD Torque Turn Equipment and RU to pressure test the 9 5/8" Casing. Pressure test to 1,000 psi for 15 minutes, charted - OK. 19:30 - 22:00 2.50 CASE P TIEB1 PJSM. Split BOPE Stack in preparation for cement top job. Drain Stack to have ready for Wachs cutter. Waiting on vac trucks to commence cement job. 22:00 - 23:30 1.50 CASE P TIEB1 Continue to wait on dirty vac truck to arrive. 23:30 - 00:00 0.50 REMCM P TIEB1 Hold PJSM with Nabors and Schlumberger Cementers. Discuss top job procedure and associated hazards/risks. 7/28/2006 00:00 - 00:30 0.50 REMCM P TIEB1 Batch up -5 bbls and begin pumping 15.7 ppg Arctic 1 cement at a rate of 3/4 bpm. Pump a total of 5.5 bbls and shut down to batch up more. Inspect void and cannot see top of fluid yet. Begin pumping again at a rate of 1/4 bpm until fluid level seen at surface. Stop pumping after a total of 7.5 bbls pumped. Cement returns to surface. No well bore fluids (i.e. diesel) on top of cement. 00:30 - 02:00 1.50 WHSUR P TIEB1 Flush all lines and begin RD Schlumburger Cementers. Install 12" x 9 5/8" Emergency Slips with Cameron representatives. Slack off weight on pipe to fully energize slips. 02:00 - 04:00 2.00 WHSUR P TIEB1 Finish draining the 9 5/8" in preparation for cutting. PU and cut the 9 5/8" Casing with the Wachs Cutter per Cameron representative. Good cut. RD Wachs Cutter and clean Base Flange area. Lay down excess 9 5/8" in Pipe Shed. Cut off jt laid down = 20.50'. 04:00 - 07:00 3.00 WHSUR P TIEB1 PJSM. Set BOPE Stack back. Remove Double-Studded Adapter. NU new McEvoy 13 5/8" 3M x 13 5/8" 5M Tubing Spool with secondary YB Packoff. 07:00 - 08:00 1.00 WHSUR P TIEB1 Pressure test the Packoff to 3,000 psi for 30 minutes. 08:00 - 11 :00 3.00 BOPSU P DECOMP PJSM. NIU 13 5/8" x 5M BOPE & riser. Printed: 7/31/2006 11:00:41 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 PJSM. Close blind rams & pressure test BOPE connections & 9 5/8" casing from surface to RBP @ 1987' to 3500 psi I 30 minutes I charted, good test. Monitor OIA , no flow or pressure build from O/A. Bleed all pressure, open blind rams. 12:00 - 13:30 1.50 CLEAN P DECOMP PJSM. Install wear ring, P/U Halliburton retrieving tool on (9) 4 3/4" DCs. 13:00 - 14:00 1.00 CLEAN P DECOMP RIH wI Halliburton retrieving tool on 3 1/2" DP, 17 stands & 20' in on 2nd single picked up. Tag up top of sand @ 1961'. 14:00 - 17:00 3.00 CLEAN P DECOMP PJSM. Rig up to reverse circulate sand out. Plugged off a few times, suspect cement chunks from outside of 9 5/8" casing we pulled. Continue reversing @ 5 bpm 1625 psi, changing out 9.8 ppg brine in well bore to seawater. 17:00 - 18:00 1.00 CLEAN P DECOMP Latch onto RBP @ 1987' and begin releasing procedure. Successfully release RBP with 20K over. 18:00 - 19:30 1.50 CLEAN P DECOMP Pre-tour safety meeting with night crew. Review TOH with Drill Pipe Procedure. Begin TOH with RBP standing back DP. 19:30 - 20:00 0.50 CLEAN P DECOMP On surface with RBP. Break off RBP from Retrieving Tool and inspect - looks good. 20:00 - 21 :00 1.00 BOPSU P DECOMP PJSM. Pull Wear Bushing. RU Test Spool and Equipment. Install Test Plug. RILDS. 21 :00 - 00:00 3.00 BOPSU P DECOMP PJSM. Test BOPE per BP/AOGCC Regulations to a low pressure of 350 psi and high pressure of 3,500 psi. The state's right to witness the test was waived by John Crisp at 18:30 hrs on 7/29/2006.24 hour and 2 hour short notice were given. 7/29/2006 00:00 - 02:00 2.00 BOPSU P DECOMP Continue testing BOPE per BP/AOGCC Regulations to 350 psi 13,500 psi. Tested VBRs against both 3.5" and 4.5" Test Joints. Tested Annular to same pressures. Charted and all tests passed. 02:00 - 03:00 1.00 BOPSU P DECOMP PJSM. Rig down Testing Equipment and pull Test Plug. Install Wear Ring. 03:00 - 03:30 0.50 CLEAN P DECOMP Clear and clean the Rig Floor. PU and MU Halliburton RBP Retrieving Tool. 03:30 - 05:30 2.00 CLEAN P DECOMP Begin TIH with Halliburton RBP Retrieving Tool on 3.5" DP from the Derrick. 05:30 - 06:00 0.50 CLEAN P DECOMP Latch onto RBP @ 7884' and begin releasing procedure. Released with no problems at 15K overpull. 06:00 - 07:00 1.00 CLEAN P DECOMP PJSM. CBU. Pump 500 bbls @ 5 bpm 1975 psi. Lost 20 bbls while circulating. 07:00 - 15:30 8.50 CLEAN P DECOMP PJSM. POOH LDDP. 15:30 - 20:00 4.50 RUNCO RUNCMP PJSM. Pull wear bushing, RIU to run 41/2" completion. Pre-tour safety meeting with night crew. 20:00 - 20:30 0.50 RUNCMP PJSM with Nabors, Baker and Casing representatives. Discuss procedure and associated hazards. Assigned responsibilites to crew members. 20:30 - 00:00 RUNCMP Begin RIH with 4.5" 12.6# 13Cr Vam Top Tubing Completion. Jewelry ran in following order: Unique Overshot, XN Nipple with RHC-M Plug Assembly, 1 jt of Tubing, X Nipple Assembly, Baker S-3 Packer Assembly, X Nipple Assembly, 1 jt of Tubing and first GLM wI Dummy Assembly. Baker Lok'd all connections below the Packer. Continue RIH with 4.5" 12.6# 13Cr Vam Top Tubing. Torque Turning all connections to 4440 ft-Ibs. Utilizing a stabbing guide and jet lube on all threads. 7/30/2006 00:00 - 06:00 6.00 RUNCO RUNCMP Continue RIH with 4.5" 12.6# 13Cr Vam Top Tubing Printed: 7/31/2006 11 :00:41 AM , . . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/13/2006 Rig Release: 7/31/2006 Rig Number: Spud Date: 5/14/1969 End: 7/31/2006 Completion. (4) GLM's being ran in the well with Dummies in the bottom (3) and a DCR-1 Shear Valve in the upper one. Torque all connections to 4440 ft-Ibs and utilizing Jet Lube Seal Guard on all threads. 170 jts in the hole. RUNCMP Continue picking up 4.5" 12.6# 13cr Vam Top Tubing, 183 jts total. 90K up wt, 90K down. Tag up top of stub 15' in on Jt # 185. Observe pins shear on Unique Overshot wI 5 - 1 OK setting down. Locate out 19' in. UD Jts 185, 184 & 183. Install space out pups. 31.35' of space out pups. RBIH wI jt #183. MIU hanger & landing joint. Land hanger, saw top of stub @ 17' - 18' in on hanger ...RKB = 22.15'. RILDs. UD landing joint. PJSM. Line up & reverse circulate 100 bbls of 125 degree seawater followed by 480 bbls of 125 degree seawater wI corrosion inhibitor @ 3 bpm I 550 psi. PJSM. Drop rod I ball assembly, allow to fall. Line up on tubing, pressure tubing slowly to 3500 psi to set packer & test tubing, monitoring IIA. No pressure build on IIA, no surface leaks, 30 minutes, charted, good test. Bleed tubing to 1500 psi & pressure up slowly on IIA to test packer. Pressure up to 3500 psi, 30 minutes, charted, good test. Bleed tubing & observe DCR valve shear wI 350 psi on tubing. Bleed off all pressure. PJSM. Set two way check & test from bottom & top @ 1000 psi, OK. PJSM. ND BOPE. Call out Little Red and Drill Site Maintenance. Set Stack back. NU Adapter Flange and test to 5,000 psi for 30 minutes per Cameron. NU 41/16" x 5M Tree and test to 5,000 psi -good. PJSM. PU Lubricator and pull TWC. RD Drill Site Maintenance. RU Little Red Services to IA. Pump 150 bbls of diesel down the IA at a rate of 2 bpm I 650 psi. Shut down and U-tube freeze protect into Tubing. Install BPV with Cameron and test to 1000 psi with Little Red - good. Rig down Little Red. Secure cellar and Tree. Rig Released at 06:00 hrs on 7/31/2006. 06:00 - 08:00 08:00 - 09:00 1.00 RUNCMP 09:00 - 13:30 4.50 RUNCO RUNCMP 13:30 - 16:00 2.50 RUNCO RUNCMP 16:00 - 16:30 0.50 RUNCO RUNCMP 16:30 - 19:00 2.50 BOPSU P RUNCMP 19:00 - 22:30 3.50 WHSUR P RUNCMP 22:30 - 00:00 1.50 WHSUR P RUNCMP 7/31/2006 00:00 - 04:30 4.50 WHSUR P RUNCMP 04:30 - 06:00 1.50 WHSUR P RUNCMP Printed: 7/31/2006 11 :00:41 AM R~~c~ \Ì L.Ù AUG 0 8 Z006 Schlumberger .~ Oil.& Gas Cons. Co~ NO. 3883 Ancl10rage Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth de) ~J - cI{)( SCANNED . ')r,r.(:' flUe í 4. (..uUU n Ü .L Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Loa Descriction Date BL Color CD NK-43 11211388 R /DEFT 04/02/06 1 NK-22A 10568415 FILE W/DEFT 0272671f3 1 L4-12 N/A WFULDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20/04 1 13..Q6A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09·25 11296703 INJECTION PROFILE 07/19/06 1 04..09 11211398 INJECTION PROFILE 04/28/06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17-21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18..Q3B 11057071 SBHP 12102/05 1 X-15A 11212877 USIT 07/18/06 1 J..Q1 B 11511430 USIT 07/24/06 1 15-12A 11221595 US IT 07/25/06 1 Z-14B 11217268 US IT 07/29/06 1 S-400 10987564 CH EDIT PDC-GR OF USIT 01/26/06 1 D-03A 11217269 USIT 07/31/06 1 05-28A 11217267 USIT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth 08/01/06 . . RE: Sundry # 306-214 2-- ()\2. - 7- () i Subject: RE: Sundry # 306-214 From: "Reem, David C" <ReemDC@BP.com> Date: Wed, 28 Jun 2006 11 :02:42 -0800 To: Winton· Aubert<wihton_aubert@admin.state.aKus> Winton, it's somewhat impossible to predict footage of 9-5/8" to remove until we run a cement bond log inside the 9-5/8" casing and ascertain where the 2nd stage cement top is within the 9-5/8" x 13-3/8" annulus. Our records from this 1969 operation are sketchy at best. There appears to be a DV tool with the 9-5/8" string at -5800'md. Not sure if the 2nd stage was fully circulated in or exactly how it was placed. We will certainly cut the 9-5/8" no deeper than 4200' md (13-3/8" shoe is at 4258'md). Cement volume will be calculated based on 9-5/8" x 13-3/8" annular capacity plus -20 bbls to ensure competent cement to surface. Hope this information will suffice until we get actual cement bond log information which will drive our cut depth decision. Thanks. ---~~"-'.·,".-,<==c_·.,.,~~,·"..·.-^~~.,,,,,~~-,,,,·_,o_==~=,_·,._~~=""~",,=-==-_==~_~.e-c=~---=="=_~-==""',~==-~"".'-===",.~=,,,,=,,"=_-_=..__~~..,.w==,-,,<.= From: Winton Aubert [mailto:winton_aubert@admin.state.ak.us] Sent: Wednesday, June 28, 2006 10:43 AM To: Reem, David C Subject: Re: Sundry # 306-214 Dave, Please E-mail details of the proposed change, Le., length of 9-5/8" replaced, cement volume, etc. No need to submit another application. Thanks, Winton Aubert AOGCC 793-1231 1.;.;./'.. '1I.'NI:.:\' 'iP'H ,J"<... ~,.;<' ,) 200ß r~eem, David C wrote: Winton, please be informed that BP would like to expand the workover scope of Prudhoe well J-01 B slightly. The increased scope would result in a greater portion of the 9-5/8" being cut and removed from the well. New casing would be installed and fully cemented. There are no plans to expand the scope beyond this increase. Does the AOGCC require an additional Sundry application or can we proceed with the workover using the approved Sundry #306-214? Please advise. Thanks Dave Reem WellslWorkover Engineer 564-5743 (w) 632-2128 (c) 1 of 1 6/28/2006 11 :08 AM (Q:ì'~ f"\\ l7 'fF \ '\, I i./ \ .'1 ï ,:::J [1))!: ¡r~,\lj !L ,,=>;,,' ..-..-., "'~. -""-, ...,.". ..",,,,,=,,,, e ,·I"-¡·,'n·j~" I j;::;J j ·1, ' j' \.)1 1,1 ~", ,,,.I e '-' ! i\ \ //=~1 ! FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-01B Sundry Number: 306-214 n i".> b.1I\.l1'~¡¡:;;r 'Ji\;4'~n'!~ ,~~¿' ') ~> I..~' '.;"'j Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ¡6day of June, 2006 Encl. 6b~-aó( ~,ft"/¡ ffc 6116/~ (rr.~'I& ð~ ~Ei~Etr°(p 'j "" STATE OF ALASKA ALASKA L AND GAS CONSERVATION CO ISSION JUN 1 5 2006 ,/ APPLICATION FOR SUNDRY APPRO~~~&Ga'ton'.tornnis'ion f) /j t¡ / ~ I (. 20 MC 25.280 Anchorage 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program 1m Repair Well / 0 Plug Perforations 0 Stimulate 1m Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Time Extension o Other o Re-Enter Suspended W 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Well Class Before Work: / 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 202~201 /" 6. API Number: 50-029-20020-02-00 ,/ 99519-6612 77.25' 9, Well Name and Number: PBU J-01 B /' 8. Property Designation: 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool , ~ , , ' Effective Depth TVD (ft), Plugs (measured): Junk (measured): 9024 None None /' TVD Burst Collapse ADL 028281 t1Ò??>~/Y/~/.> /'Y'l'll::t;;t;; Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 10758 9026 I 10725 Casinq Length Size MD Structural Conductor Sllrface Intermediate Production Liner Liner 100' 30" 100' 100' 933' 20" 950' 950' 1530 520 4241' 13-3/8" 4258' 4258' 3090 1540 8541' 9-5/8" 8558' 8557' 6870 4760 575' 5-1/2" 8089' - 8664' 8088' - 8663' 7740 6280 2697' 3-3/16" x 2-7/8" 8061' - 10758' 8060' - 9026' Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 10367' -10717' / 9020' - 9024' Packers and SSSV Type: 9-5/8" x 4~1/2" TIW 'HBBP-R' packer Tubing Size: 4-1/2", 12.6# /~ Tubing MD (ft): 8084' 12. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14, Estimated Date for Commencing Operations: Tubing Grade: L-80 I Packers and SSSV MD (ft): 8019' ~ 13. Well Class after proposed work: / o Exploratory 181 Development 0 Service 16. Verbal Approval: Commission Re presentative: 17. I hereby certify t~t the foregoing is true and correct to the best of my knowledge. Printed Name pa id Reem 1'1 Title Drilling Engineer Siqnature h-l'1:~ ~ J) (~J.¿..po-,,,,,- Phone 564-5743 Commission Use Only JUIÇ;) 2006 oote: 15. Well Status after proposed work: 181 Oil 0 Gas o WAG 0 GINJ o Plugged OWINJ o Abandoned o WDSPL Contact David Reem, 564-5743 Date ,115/6(; Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance I Sundry Number:~ ~Ð -....'J ,A Other: T l.-l;> ;- IS 0 r E to ~ SO 0 P t<' . S"'''',,"OO' Fo~ R",";,.., I 0 _ ) Approved By' . ~~ Ç¡)MMISSIONER Form 10-403 Revised 07/2005 ~I Y - OR} o1f~AL RBDMS BFL jut{ 2 0 1""6 APPROVED BY THE COMMISSION Date b,/t·ðp Submit In Duplicate . . J-01 BRig Workover Scope of Work: Pull collapsed 4-%" L-80 completion, cut and pull top two joints of 9-5/8" casing, tie-back /' w/new 9-5/8" casing, replace 9-5/8" emergency slips and primary pack-off, and run 4-1'2" 13Cr80 stacker packer completion. /,,'"- MASP: ;1350ß~i Well TyP9',Producer Estimated Start Date: July 20, 2006 Pre-Ri o 1 E 2 F 3 o 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well is secured w/TTP in the "X" nipple at 7954'md. PPPOT-T & IC. DONE - tbg hanger passed, IC failed ~ primary pack-off. Well has assin CMIT TxlA to 3500 si. Jet cut 4-1'2" tubin in middle of 1 full joint above the collapse. Done Circulate well with seawater and diesel thru the cut. Done Remove the well house & flow line, Level the ad as needed for the ri , Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 3500 psi. /Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2, Pull and LD 4-1'2" tubing string to the cut. 3. Run outside cutter past the collapse at -3882'md, cut 1 sl full joint below collapsed joint. 4. Run 4-1/2" L-80 workstring w/over-shot. Latch onto 4-1/2" tubing stub.. 5. RU e-line and cut 4-1/2" tubing in middle of 1 sl full joint above the packer set at 8019'md. 6. Recover remaining 4-1/2" L-80 tubing down to the cut. /' 7. Run dress-off BHA over the 4-1/2" tubing stub. 8. Run 9-5/8" RBP and set at -1500'md, Stack -30 ft of sand on RBP. PT RBP to 1500 psi to prove up /' barrier, 9. Mechanically cut 9-5/8" casing in 2nd joint below the casing hanger. Pull casing thru stack. 10. Back-off 9-5/8" stub and pull same. 11, Screw back in with new 9-5/8",47#, L-80 c~jng and land on new emergency slips with new primary pack-off. PT 9-5/8" pack-off to 3500 psi. 12. Run 4-1'2" 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -7900' MD.___ 13. Displace the IA to packer fluid and set the packer. 14. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD, 15. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = . 4" CAMERON ~OTES: I WB..LHEAD = CAMERON J-01 B ACTUATOR = BAKER KB. ELEV = 77 .25' BF. ELEV = 38.4' KOP= 8558' Max Angle = . I 2102' 4-1/2" OTIS HXO SSSV NIP, ID = 3.813" I 95 @ 9393' Datum MO = 8894' Datum TVD = 8800' SS I HJETCUTTBG (04/26/05) I ^'^ 3850' ..,~~ I 3907' ICOLLAPSEDTBG (04/26/05) I ,/ GAS LIFT IvIANDRELS I 13-3/8" CSG, 68#, ID = 12.415" I 425S' ~ ~ ST MO TVO DE\! TYÆ VLV LATCH PORT DATE L 4 4191 4114 1 OTIS DMY RM 0 07/10/04 3 6821 6743 2 OTIS DMY RM 0 07/10/04 Minimum ID = 2.372" @ 8720' 2 7780 7723 1 OTIS DMY RA 0 3-3/16" X 2-7/8" XO 1 7886 7829 1 OTIS DMY RA 0 I 7954' 4-1/2" OTIS X NIP, ID = 3.813" I . 18 Ið 8019' 9-5/8" x 4-1/2" TIW HBBP-R PKR, ID = 4.0" I . I I S061 , 3-1/2" BAKER DEPLOY SLV, ID = 3.000" I S055' 4-1/2" OTIS X NIP, ID - 3.813" (BEHIND LNR) I . . SOSO' 3-1/2" HES XN NIP, ID = 2.75" I S072' 4-1/2" OTIS XN NIP. ID = 3.725" (BEHIND LNR) I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I S084' I S084' 4-1/2" WLEG, ID = 3.958" (BEHIND LNR) I I TOP OF 5-1/2" LNR I SOS9' . . I S1oo' H ELMO TT LOGGED 03/09/95 (BEHIND LNR) I 13-1/2" LNR. 8.81#, L-80, .0081 bpf, ID = 2.880" I S622' I 8622' 3-1/2" X 3-3/16" XO. ID = 2.800" I PERFORA TION SUMMARY I MUOVT WINDOW - 8664' - 8672' I REF LOG: SWS MEM CNUGRlCCL ON 11/23/02 ANGLE AT TOP PERF: 88@ 10367' Note: Refer to Production DB for historical perf data I 8720' 3-3/16" X 2-7/8" XO, ID - 2.372 I SIZE SPF INTERVAL Opn/Sqz DATE ~1 2" 4 10367 - 10717 0 11/23/02 / . II I SET WHIPSTOCK, 3RD SET (11/13/02) I S664' r II ~ 13-3/16" LNR, 6.2#, L-80, S720' I .0076 bpf, ID = 2.800" , I PBTD I 10725' J I 9-5/8" CSG, 47#, L-80, ID = 8.681" I j ~ 9304' I 12-7/8" LNR, 6.16#, L-80, .0055 bpf, 10 = 2.372" I 1075S' I I 5-1/2" LNR, 17#. L-80. .0232 bpf, ID = 4.892" I 9900' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/79 ORIGINAL COMPLETION 07/10/04 RWLlKAK GL V C/O WELL: J-01 B 10/03/94 MOO SIDETRACK (.1-o1A) 05/08/05 JRAITLH COLLAPSETBG/JET CUT ÆRMIT No: "3023390 11/24/02 DCRlTLH CrD SIDETRACK (~1B) 06/05105 DRSITLH CORRECTIONS API No: 50-029-20020-02 11/29/02 JMltlh GLV C/O 06/29/06 CO/OTM ÆRF/TREE CORRECT (6/13/04) SEe 9, T11 N, R13E. 750' SNL & 1245' WEL 01/21/03 TLHlTP DEPTH CORRECTIONS 07/15/03 CMO/TLP IvIAX ANGLE CORRECTION BP E:xp!.oratitm (Alaska) TREE = ~ 4" CAMERON W8.LHEAD = CAMERON ACTUATOR = BAKER KB. B.EV = 77.25' BF, B.EV = 38.4' KOP = 8558' Max Angle = 95 @ 9393' DatumMD= 8871' Datum TVD = 8800' SS J-01 B PROPOSED COM LETION / 14,112" TBG, 12.6#, 13Cr, .0152 bpf, ID = 3.958" I I 13·3/8" CSG, 68#, D = 12.415" I Minimum ID = 2.372" @ 8720' 3-3/16" X 2·7/8" XO 14-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I I TOP OF 5-1/2" LNR I 13-1/2" LNR, 8,81#, L-80, .0081 bpf, ID = 2,880" I 4258' ~ 8084' 8089' 8622' PERFORA TION SU~RY REF LOG: SWS MEM CNUGRlCCL ON 11/23/02 ANGLE AT TOP PERF: 89 @ 10350' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10367 - 10717 0 11/23/02 I 1 SET WHIPSTOCK, 3RD SET (11/13/02) I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8664' 9304' I · · · u · · ~. ...... ~ · · r '" I ~ lS I I . . 11II /r'Ii r 18 I 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" DA TE REV BY COt4t1ENTS 12179 ORIGINAL COMPLEI'ION 10/03/94 MOO SIDETRACK (J-G1A) 11/24/02 DCRlTLH CTD SIDETRACK (J-01B) 11129102 JWtlh GLV C/O 01/21/03 TLHITP DEPTH CORRECTIONS 07/15/03 CMOITlP MAX ANGLE CORRECTION I 2100' 1-14-112" X NIP, ID = 3,813" GAS LIFT MANDRB.S ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3300 3300 0 3 5400 5400 1 2 6851 6850 2 ~ 1 7783 7782 1 I 7853' 1- 4-1/2" X NP, D = 3.813" I 7873' 1- 9-5/8" x 4-112" BAKER S-3 PKR 7903' H 4-1/2" X Nfl, D = 3.813" I I 7923' H 4-1/2" XN Nfl, D = 3,725" I I 7983' H UNIQUE MACHINE OVERSHOT I I 7985' ¡-CHEM CUT TBG I 8019' 8061' 8055' 8080' 8072' 8084' 8100' 8639' t- 9-5/8" X 4-1/2" TIIN HBBP-R PKR, ID = 4.0" I t- 3-1/2" BAKER DEPLOY SLV, D = 3.000" I I- 4-1/2" OTIS X NP, ID = 3,813" (BEHIND LNR) I- 3-1/2"HES XNNP,D=2.75" I I- 4-1/2" OTIS XN NIP, I) = 3,725" (BEHIND LNR) I t- 4-112" WLEG, ID = 3.958" (BEHIND LNR) I H B.MD TT LOGGED 03/09/95 (BEHIND LNR) I 3-1/2" X 3-3/16" XO, ID = 2.800" I I MILLOUT WINDOW - 8664' - 8672' I 8738' DATE REV BY COfIfMENTS 07/10/04 RWL/KAI< GLV C/O 05/08/05 JRAITlH COLLAPSE TBG/JET CUT 13-3116" LNR, 6.2#, L-80, ,0076 bpf, ID = 2.800" "rl'§ I PBTD 1 10725' I ~ ~-7/8" LNR, 6.16#, L-80, .0055 bpf, D= 2,372"1 9900' I 3-3/16" X 2· 7/8" XO, D = 2,372 I 1 8720' I 10758' I PRUDHOE BA Y UNrr W8.L: J-01 B PERMrT No: ~022010 API No: 50-029-20020-01 SEC 9, T11 N, R13E. 750' SNL & 1245' W8. BP exploration (Alaska) . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ;t 1;) ~<- ~ vl DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Permit to Drill 2022010 Well Name/No. PRUDHOE BAY UNIT J-01 B / MD 10758 / ." TVD 9026 ~~ Completion Date 11/24/2002./ ~~---_._-~ REQUIRED INFORMATION Mud log No ~~-- ~------------- DATA INFORMATION Types Electric or Other Logs Run: MWD, DGR, Memory CNl, GR, CCl Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ---~-~ ~J9g. .N'êutron L~~~..... vf(pt :/ i(og ...-éément Evaluation Directional Survey Gamma Ray ~ó C yg>. .~ ~/ D trf548 Neutron --é';sing collar locator ~ Directional Survey Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01l Current Status 1-01l API No. 50-029-20020-02-00 UIC N Samples No Directional Survey Yes (data taken from logs Portion of Master Well Data Maint) ~ Log Log Run Scale Media No 25 Blu 1 Interval OH / Start Stop CH Received Comments 7886 10701 Case 2/28/2003 A Directional Survey log is required to be submitted, This record automatically created from Permit to Drill Module on: 10/2/2002, 8755 Case 11/29/2002 U j "If 10758 Open 12/13/2002 ~ An H2S Measurement is required to be submitted, This record automatically created from Permit to Drill Module on: 10/2/2002, 0 0 / " ~D D L.11698 LIS Verification 8484 10731 Open 4/17/2003 JWt".. LIS Verification 8484 1 0731 Open 4/17/2003 ~.... C Lis 1-26'14 Gamma Ray 84840 10731 Open 8/5/2004 STS LIS Writing Library, MWD ---_._~._-------,~~---- 5 Col 8064 8755 Case 11/29/2002 8662 10758 Open 12/13/2002 7886 10701 Case 2/28/2003 25 Blu 25 Blu 5 Col 7886 7886 8064 8662 10701 Case 2/28/2003 10701 Case 2/28/2003 Permit to Drill 2022010 MD 10758 TVD 9026 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Y/~ Chips Received? ~ Well Cored? Analysis Received? .x:.L.bJ-,-"" . ~-~--------- -~-------~-~._- Comments: --~._---------------~--'----- ~--------~---~- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Well Name/No. PRUDHOE BAY UNIT J-01B OperâtorBP EXPLORATION (ALASKA) INC Completion Date 11/24/2002 Completion Status 1-01L Interval Start Stop Sent Received Daily History Received? Formation Tops :J-e Current Status 1-01L Sample Set Number Comments (Y)/N &>/N Date: API No. 50-029-20020-02-00 UIC N ~ to ~~. ~"-{) S- '~ ') ) It FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 25,2003 ~t)z - ;20( ~ ,2.(,('1 Sperry-Sun Drilling Services ATTN: Rob Kalish 6900 Arctic Blvd. Anchorage, AK 99518 RE: Damaged CD - Well J-01B Rob, Enclosed is a CD for API# 50-029-20020-02-00. The folders are there when you open the disk but there is no infonnation in the folders. Please send a new disk to my attention at your earliest convenience. If you have any questions, please do not hesitate to contact me at #793-1223. Thank you. Sincerely, '-"''-''-. ,," ~ \\a~ \~~~ Robin Deason Ene. /; /" , : .. öb t1'\ S~("ï Le.+ ~. kV\oW +~.~ +ððk ~-t' +Co +'ntre\ l~.\ 1 ~~1 th.'J ~!2/fi{ ~~~. 'f 0 0... V\ eeJ. \<ó6 t(~ l~~ ) p,oo--OO\ '1 / ( , WELL LOG TRANSMITTAL October 14, 2003 State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 To: RE: MWD Fonnation Evaluation Logs: J-O IB, AK-MW-22 1 81 J-OIB: Digital Log Images 50-029-20020-02 1 CD Rom .". , 1r.lcf PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ f ~(o ~ OCT ;2 7 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~~~ A0~'-~ d!~c'~W:~~ ") ) 9CÐ-ÔO\ WELL LOG TRANSl\1ITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Q£!Q~,?003 RE: MWD Fonnation Evaluation Logs: J-01B, AK-MW-22181 J-OIB: Digital Log Images 50-029-20020-02 1 CD Rom 18/95 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~~~ /'{'.~ '-~ OCT 27 ') ) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm, Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs J-O IB, 1 LDWG formatted Disc with verification listing. API#: 50-029-20020-02 April 07, 2003 AK-MW-22181 q(B~o } Ilto9« PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~- (/~.. Date: Signed: RECEIVED APR 1 7 2003 Alaska œ & Gas Cons. Commï-ï- Anc:ltorage 'nn~u Schlumbepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well F-08A ~. D;:} ~ rl ~ ( J-01 B -~ WGI-01 ~-O~-!.I W-17 J - oq~ F-44 J 1- 00 sr F-21 J 'i{q- 0 54J F-21 .J¡ D.S.9-01 /7 b,.. 0 7lc Job# Log Description 23017 MCNL 23015 MCNL LDL TEMPERATURE PROFILE 23055 RST -SIGMA LDL PRODUCTION PROFILE PRODUCTION PROFILE/DEFT 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: RECEIVED FEB 28 2003 AJa!k1J Œ¡ & Gas Cons. l.'.ort'~T.~~:1 A:,cl;,-~ ase NO. 2684 Company: 02/26/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date BlueJine Sepia Prints CD 12/19/02 1 11/23/02 1 02/04/03 1 02/14/03 1 01/21/03 1 02/18/03 1 02/18/03 1 02/24/03 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATT4: Beth, ',- Rec ived by: . ~~ u OO<2(LJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') ') 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 750' SNL, 1245' WEL, SEC. 09, T11N, R13E, UM At top of productive interval 741' SNL, 4082' EWL, SEC. 09, T11N, R13E, UM At total depth 1485' SNL, 333' EWL, SEC. 10, T11N, R13E, UM X=644700. Y=5969890 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 77.25' ADL028281 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/17/2002 ' 11/21/2002 p 11/24/2002 ' 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10758 9026 FT 10725 9024 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, DGR, Memory CNL, GR, CCL Classification of Service Well rŒ~t ~ I ¡ .~~1~. i~,:. i r ..., .,.. :~ '~j )n ,.,' .;: ~~~'~~;;¡'" ,'.' ,-',,< ,- ~> .::L'~")~\~'~Íì\ri,~~~:}ì~''!''':_~'"''~''i''_':''' ~':j,. x = 643107. Y = 5970596 7. Permit Number 202-201 302-339 8. API Number 50- 029-20020-02 9. Unit or Lease Name Prudhoe Bay Unit x = 643154. Y = 5970605 10. Well Number J-01B 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (NiP~e1: 2102~ MD .1900' (Approx.) 7 tr./,.#~ ?f01ø'l ' n-J J:> 1(~~r'.trÞ 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 30" Stove Pipe Surface 100' 36" 280 sx Permafrost .. 20" 94# H-40 17' 950' 26" 1800 sx Fondu 13-3/8" 68# 1 61# K-55 / J-55 17' 4258' 17-1/2" 1600 sx Class 'G' 9-5/8" 47# N-80 17' 8558' 12-1/4" 2155 sx Class 'G' 5-112" 17#' L-80 8089' 8664" 6-3/4" 315 sx Class 'G' 3-3/16"x2-7/S" 6.2#/6,16# L-80 8061' 10758' 3-3/4" 123 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 10367' - 10717' 9020' - 9024' AMOUNT PULLED (3-1/2", 8.81# for top 578') SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 8084' PACKER SET (MD) 8019' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 25 Bbls MeOH 27. Date First Production December 1, 2002 Date of Test Hours Tested 1/20/2003 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD 1348 Flow Tubing Casing Pressure CALCULATED Press. 1108 24-HoUR RATE OIL-BBL GAs-McF 24,345 GAs-McF WATER-BBL 44 WATER-BBL CHOKE SIZE 96° OIL GRAVITY-API (CORR) 26.7 GAS-OIL RATIO 18,067 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core C~sr',' ~"~F ~ ~~. t~ No core samples were taken. 28. ~F Form 10-407 Rev. 07-01-80 RBDMS 8Fl ?P - '.) Submit In Duplicate ) 29. Geologic Markers Marker Name Measured Depth Top of CGL 8723' Base of CGL 8784' 25N 88821 25P 8887' 22P 8995' 21P 9038' Zone 1 B 9193' 14N 9200' 14P 92161 31. List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8721' 87791 886T 8871' 89581 8985' 9020' 90191 9019' & Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble /fO AJ\; 1 - H<~ Title Technical Assistant Date D l.;t \ . 0 ~ J-01 B 202-201 302-339 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Alistair Sherwood, 564-4378 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-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 [)ate Hóurs Task Code NPT 1 0/21/2002 10:00-11:30 1,50 MOB P PRE 11 :30 - 00:00 12.50 MOB N RREP PRE 1 0/22/2002 00:00 - 02:00 2.00 MOB N RREP PRE 02:00 - 13:00 11,00 MOB N HMAN PRE 13:00-14:00 1.00 MOB P PRE 14:00 - 15:30 1.50 RIGU P PRE 15:30 - 18:00 2,50 RIGU N RREP PRE 18:00 - 18:45 0,75 RIGU P PRE 18:45 - 23:30 4,75 RIGU N RREP PRE 23:30 - 00:00 0.50 BOPSUR P PRE 10/23/2002 00:00 - 01 :00 1.00 BOPSURN SFAL PRE 01 :00 - 03:30 2,50 BOPSUR P PRE 03:30 - 08:00 4,50 BOPSUR P PRE 08:00 - 09: 15 1.25 BOPSUR N SFAL PRE 09:15 - 09:30 0,25 BOPSUR P PRE 09:30 - 10:15 0,75 STWHIP P WEXIT 10:15 - 12:00 1.75 STWHIP P WEXIT 12:00 - 12:45 0.75 STWHIP N SFAL WEXIT 12:45 - 13:00 0.25 STWHIP P WEXIT 13:00 - 14:45 1,75 STWHIP P WEXIT 14:45 - 16:15 1,50 STWHIP P WEXIT 16:15 - 18:00 1,75 STWHIP N SFAL WEXIT 18:00 - 20:00 2.00 STWHIP P WEXIT 20:00 - 20:30 0,50 STWHIP P WEXIT 20:30 - 21 :30 1.00 STWHIP P WEXIT 21 :30 - 00:00 2,50 STWHIP P WEXIT 10/24/2002 00:00 - 02:30 2,50 STWHIP P WEXIT 02:30 - 04:30 2,00 STWHIP P WEXIT 04:30 - 05:00 0,50 STWHIP P WEXIT 05:00 - 05:30 0,50 STWHIP P WEXIT 05:30 - 08:30 3,00 STWHIP N STUC WEXIT Back rig off of J-20b, move across pad, park on pad near J-01, Continuing to modify Nordic 2. Rig Mods in Progress: Install articulating gooseneck, tweak hydraulic pump on CT side, Modify cellar doors to close w/ S-riser attached. Continue modifying cellar doors (zero rig rate), Unable to bleed flowline between J-01 and manifold building. Several leaking valves, Rig on standby, Position rig over well. NU BOPE. Attempt BOP test. Test hose blew, No backup, Decide to install new gooseneck (back on zero rig rate until pipe is stabbed), Crew change safety and TL meeting, Stab pipe. Free tugger cable from new windwall section, Agreed to accept rig at 20,15 hrs, As we were simultaneously completing contractor modifications and RU on well. Safety meeting for BOP test. Perform initial BOP test. Witness waived by AOGCC's Chuck Scheve, Tree valves leak. Call greasers. Test choke manifold while greasing tree valves, Resume test on stack, HCR failed test. Grease it. Retest OK. RD test equip. SafetylTL meeting. PU inj. Install CTC. Pull test. Circulate coil and PT. Attempt to open tree valves, Grease locked. Get grease crew back here. Bleed well (40 psi). Fill hole (1 bbl) MU milling BHA. RIH taking returns to cuttings tank. Did not see XN, Continue RIH. Did not see whipstock, Stop at 8950' CTM, Mechanical shows minus 850' (yes, 9800' discrepancy). Up wt indicates maybe 5000' of coil in the hole, Switch encoders. 3400' popped up. Use this for now, Continue RIH slowly, Ftlmin about twice the actual speed, E-depth looking OK. Mechanical acting like meters (but backward), RIH tag XN 8084' CTM. Correct to 8088' ELMD, NPT for RIH counter trouble MillXN Dress nipple and make dry passes, RIH slow while adjusting hydraulic pressure on power pack, RIH tag whipstock 8849', Flag pipe. Correct depth -3',Half hour attributable to power pack issue, Mill window 2.4 /2.4bpm 1780 psi on, 1670psi off 1 K wob, Mill from 8846 to 8848.2. Mill window from 8848.2 @2.4/2.4bpm, 1670 psi off, 1860 psi on,3-4K WOB, UP 39K, DN 29K, to 8849,3, Continue milling from 8849.3 to 8850', Stall. PU and ream back to bottom, Continue milling at 8850 @ 2.4/2.4 bpm, 2128 psi on, 1670 psi off, WOB 3K, Up wt 39K, Dn wt 29K. Stall. Bit stuck, Work pipe with and without pump, Pull to 90 K without pump. Printed: 12/6/2002 1:55:38 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 Date Frö'll-' To Hours Task Code. NPT Descri ptionofQperë;3tiöns 10/24/2002 08:30 - 09:30 1,00 STWHIP N STUC WEXIT 09:30 - 14:30 5,00 STWHIP N STUC WEXIT 14:30 - 15:15 0,75 STWHIP N STUC WEXIT 15:15 - 16:00 0.75 STWHIP N STUC WEXIT 16:00 - 16:30 0,50 STWHIP N STUC WEXIT 16:30 - 16:45 0,25 STWHIP N STUC WEXIT 16:45 - 17:15 0.50 STWHIP N STUC WEXIT 17:15 -17:30 0,25 STWHIP N STUC WEXIT 17:30 - 19:00 1.50 STWHIP N STUC WEXIT 1 0/25/2002 19:00 - 20:00 1.00 STWHIP N STUC WEXIT 20:00 - 21 :30 1.50 STWHIP N STUC WEXIT 21 :30 - 00:00 2,50 STWHIP N STUC WEXIT 00:00 - 02:30 2,50 STWHIP N STUC WEXIT 02:30 - 04:30 2,00 STWHIP N STUC WEXIT 04:30 - 05:15 0,75 STWHIP N STUC WEXIT 05:15 - 07:45 2.50 STWHIP N STUC WEXIT 07:45 - 08:15 0.50 STWHIP N STUC WEXIT 08: 15 - 08:45 0.50 STWHIP N STUC WEXIT 08:45 - 09: 15 0.50 STWHIP N STUC WEXIT 09:15 -10:00 0.75 STWHIP N STUC WEXIT 10:00 - 10:30 0.50 STWHIP N STUC WEXIT 10:30 - 12:30 2,00 STWHIP N STUC WEXIT 12:30 - 13:45 1,25 STWHIP N STUC WEXIT 13:45 - 14:30 0,75 STWHIP N STUC WEXIT 14:30 - 15:00 0,50 STWHIP N STUC WEXIT 15:00 - 23:00 8.00 STWHIP N STUC WEXIT 23:00 - 00:00 1,00 STWHIP N STUC WEXIT 00:00 - 02:20 2,33 STWHIP N STUC WEXIT 02:20 - 03:15 0,92 STWHIP N STUC WEXIT 03:15 - 04:00 0.75 STWHIP N STUC WEXIT 04:00 - 04:30 0.50 STWHIP N STUC WEXIT 04:30 - 05:15 0.75 STWHIP N STUC WEXIT 05:15 - 06:00 0,75 STWHIP N STUC WEXIT 06:00 - 06:45 0,75 STWHIP N STUC WEXIT 06:45 - 07:30 0.75 STWHIP N SFAL WEXIT 07:30 - 08:30 1,00 ì STWHIP N STUC WEXIT I 10/26/2002 Pressure BS to 1600 psi. Little to no bleed-off. Workpipe. lAP = 177 psi. Dump pressure while working, No movement. repeat. Nope, Circulate. Note that circ conditions changed 1,5/1400 initial; 1.2/1900 current. Concerned about damaging motor and plugging bit. Circ at minimum rate, Wait on acid crew, flowback tank, etc. RU iron for acid job. Safety meeting. PT line to divert tank, Put 40 bbls of soda ash water in tank, PT treating lines to 5500 psi. PVT = 388. Load 30 bbls of 12-3 HCL-HF acid at 1.0 BPM 1700 psi into coil. Zero MM on lead. Chase with 10 bbls of cleanup water. Chase acid with rig pumps, Blew pop-off at 1000 psi. Switch to pump 2, Pump at 2,1 BPM; 2800 psi. At 56 bbls, 2,1 BPM 3250 psi. At 60 bbls (6 bbls out mill), SD pump and let soak while working pipe to 90k, Let soak for 20 minutes, Pump another 5 bbls, let soak 20 mintues -- working pipe, Pump one bbl at a time, soak 5 minutes -- working pipe, With 15 bbls acid out and 90k, pulled free, Circulate out acid to divert tank. 2,2bpm @ 1170 PSI. POH to surface, Pulled out of coil connector. Wait on fishing tools, While waiting had to order additional soda ash solution to neutralize acid, PH still in the 1-2 range after initial attempt to neutralize. Wait on fishing tools, PU fishing BHA (2-3/8" spear) Stab injector. RIH with fishing BHA. Latch fish, Jar 12 times up, WOO, Jar 15 times down to max down (-1 Ok), Jar 23 times up, to 80k. No movement Drop a 7/8" ball to disconnect. Circulate to seat. Shear disconnect. POOH, LD fishing BHA. Wait on E-line. Safety meeting with E-line crew RU E-line for USIT log, Log the interval 8050' - 8760', MU Whipstock install pip tag. MU Eline BHA RIH with whipstock,Depth correct +6', Log into position and set with Top of Whipstock at 8681' 15 right of high side, RA tag 8690'. Tag to confirm, POH to surface. LD whipstock running tools, MU milling BHA for second attempt. Change out CTC and pull test to 30,000#, Stab injector RIH, SafetylTL meeting, Chicksan connection backed off inside reel. Tighten, secure, clean-up bio water in reel house, RIH. Tag pinch pOint dry 8677' CTM, PU, Come up on Printed: 12/6/2002 1:55:38 PM ) ) Bp..EXPLORATION Qp~ration$ SllmnlaIjR~p~rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 Date FrOni-To Hours Task Code NPT 10/26/2002 07:30 - 08:30 08:30 - 15:15 STUC WEXIT STUC WEXIT 1,00 STWHIP N 6.75 STWHIP N 15:15 - 16:30 STUC WEXIT 1,25 STWHIP N 16:30 - 19:00 2.50 STWHIP N STUC WEXIT 19:00 - 20:00 1,00 STWHIP N STUC WEXIT 20:00 - 21 :50 1,83 STWHIP N STUC WEXIT 21 :50 - 22:20 0.50 STWHIP N STUC WEXIT 22:20 - 00:00 1,67 STWHIP N STUC WEXIT 1 0/27/2002 00:00 - 01 :30 1,50 STWHIP N STUC WEXIT 01 :30 - 01 :35 0,08 STWHIP N STUC WEXIT 01 :35 - 02:00 0.42 STWHIP N STUC WEXIT 02:00 - 03:40 1,67 STWHIP N STUC WEXIT 03:40 - 04: 15 0,58 STWHIP N STUC WEXIT 04: 15 - 06:00 1,75 STWHIP N STUC WEXIT 06:00 - 06: 15 0.25 STWHIP N STUC WEXIT 06:15 - 08:00 1.75 STWHIP N STUC WEXIT 08:00 - 09:30 1.50 STWHIP N STUC WEXIT 09:30 -10:00 0.50 STWHIP N STUC WEXIT 10:00 - 10:45 0,75 STWHIP N STUC WEXIT 10:45 - 12:00 1,25 STWHIP N STUC WEXIT 12:00-15:30 3,50 STWHIP N STUC WEXIT 15:30 - 16:00 0.50 STWHIP N STUC WEXIT 16:00 - 22:00 6.00 RIGD N STUC POST 11/16/2002 06:00 - 08:00 2.00 MOB P PRE 08:00 - 08:30 0,50 MOB P PRE 08:30 - 09:00 0,50 MOB P PRE 09:00 - 09:30 0.50 MOB PRE P pumps. RIH. Start milling at 8676', corrected to 8682'. Two stalls getting started, then smooth milling to 8686', Mill 2,3/1600 FS. Average motor work 500 psi. Average WOB 3500 Ibs. Pumped three 10 bbl sweeps (4 ppb biozan) while milling, Stall at 8686', PU clean. Ease into it. Couple of pressure bumps and mill off on bottom, then stall again. Stuck, Deja vu same milled footage, same # stalls, same result as last whipstock, Work pipe to 93k a couple of times, Swap well to Flo-Pro (5% lubetex). Also, order 20 bbl Flo-Pro pill with 20% lubetex. Wait on arrival of Lubtex pill, Pump 20 bbllubtex pill to mill and spot 15 bbl of pill in open hole. work pipe -15 to 93 K, NO GO. Attempt to pressure backside. NO GO. Prep to drop ball, Drop ball 15/16" and circulate to disconnect POH to surface, Set back injector. LD BHA MU fishing BHA. Time change Fall back one hour. Stab injector RIH with GS spear fishing assembly. Up WT 39K, Tag top offish 8665', Stack out 5K pull10K overpull 5 jar licks NO GO, Pull 20K over 5 licks NO GO. Pull 40K overpull 3 jar licks, Pull free. Either pull fish free or stripped the GS spear. Next fishing option 2,32" Itco Spear to catch ID of lower disconnect. POH to surface. Crew change. LD fishing BHA. Motor broke where output shaft pin screws into rotor. Rotor and motor housing recovered, TOF at 8683' (2' below top of whipstock). Discuss options, SafetylTL meeting -- swap to KCL and RDMO, RU nozzle on MHA. RIH to 8660'. Swap well to 2% KCL water. POOH. Freeze protect top 2000' with 25 bbls MeOH, LD BHA. RD equipment. Empty and clean pits. ND BOPE. NU and test tree cap, Release rig 22:00 hrs, Rig Released from J-27A @ 06:00 on 11/16/02, PJSM. Prep to move rig to J-01, Warm moving system, Roll-up tarps, Disconnect green tank & inspect rig. Held pre-move safety meeting. Review & discuss recent lifting incident & stress need to take time to double-check things before we jump into operations. Move rig from J-27 to J-01 & line up to well. WHP, lAP, OAP = Opsi. Flowline pressure = 2400psi from freeze protection. Pad operator bled flowline down to Opsi. Lateral valve is double blocked - thus no possibility of sending fluids down the flowline during operations, Carry out post-operations pad inspection on J-27 & pre-operations pad inspection on J-01. Printed: 12/6/2002 1:55:38 PM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From '"To Hours Task Code NPT Phase 11/16/2002 09:30 - 10:00 0.50 MOB P PRE 10:00 - 12:00 2.00 BOPSUB P DECOMP 12:00 - 18:30 6,50 BOPSUB P DECOMP 18:30 - 19:15 0,75 BOPSUB N RREP DECOMP 19:15-20:15 1,00 BOPSUB P DECOMP 20:15 - 21:00 0,75 BOPSUB P DECOMP 21 :00 - 21 :20 0,33 STWHIP P WEXIT 21 :20 - 22:20 1,00 STWHIP P WEXIT 22:20 ., 23:50 1.50 STWHIP P WEXIT 23:50 - 00:00 0.17 STWHIP P WEXIT 11/17/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 02:30 1,00 STWHIP P WEXIT 02:30 - 03:30 1,00 STWHIP P WEXIT 03:30 - 04:45 1,25 STWHIP P WEXIT 04:45 - 06:00 1.25 STWHIP P WEXIT 06:00 - 07:20 1.33 STWHIP P WEXIT 07:20 - 08:20 1,00 STWHIP P WEXIT 08:20 - 09:30 1,17 STWHIP P WEXIT 09:30 - 10:40 1,17 STWHIP P WEXIT 10:40 - 10:50 0,17 STWHIP P WEXIT 10:50 -12:10 1,33 STWHIP P WEXIT 12:10 - 12:20 0.17 STWHIP P WEXIT 12:20 - 12:40 0,33 STWHIP P WEXIT 12:40 - 14:30 1,83 STWHIP P WEXIT Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 Pëscription of Ç>perations Install spill dike, Remove tree cap & install X/O & spacer spool. ACCEPT RIG @ 10:00 HRS on 11/16/2002, N/U BOPE. Spot trailers & tanks. Grease-lock swab valve & perform initial BOPE pressure/function test. AOGCC test witness waived by John Crisp. Meanwhile fill rig pits with 2% KCL bio-water. Blind/shear rams not testing. Rebuild. Press test Blind / Shear rams - OK, Press test inner reel valve, Change out CT pack-off. PRE-SPUD AND SAFETY MEETING, Reviewed well plan and special considerations, Reviewed procedure, hazards and mitigation for M/U of window milling BHA. M/U window milling BHA #1 with HC 3,80" diamond speed mill, 2-7/8" straight motor, MHA, 2 jts PH6, XO and CTC. BHA total length = 82,2 ft, RIH with BHA #1, Circ 2# Biozan water at 0,2 bpm, 200 psi, take well bore returns to green tank. Wt. chk at 8610'. Up wt = 32,5K, Dwn Wt. = 25,5K, Circ, at 2,5 bpm, 1900 psi, Tag whipstock pinch point at 8668' ctd. Correct depth to 8665', Flag CT at 8665', Milling window, Flagged CT at 8665', Free spin 2000 psi, 2,5 bpm, 4 stalls to get started at top of whipstock, Started milling at 8665,0 ft, 2.5 / 2,5 bpm, 2000-2300 psi, 1 K WOB, Milled to 8665.5 ft, Milling, 2,5/2.5 bpm, 2000 - 2250 psi, 1 K WOB. Milled to 8666,5', Milling, 2,5 / 2,5 bpm, 1900 - 2150 psi, 1 K WOB, Milled to 8667.7', Steady easy milling, Milling, 2,5/2,5 bpm, 1900 - 2150 psi, 1 K WOB, Milled to 8668', Pick up easy at 29K up wt, No overpull. Free spin = 1900 psi. Dwn wt = 21,7 K. Milled to 8669', Milling, 2,5/2,5 bpm, 1900 - 2150 psi, 1 K WOB, Milled to 8670', Steady easy milling, Milling, 2,5/2,5 bpm, 1900 - 2150 psi, 1 K WOB. Milled to 8671', Milling, 2,5/2.5 bpm, 1900 - 2150 psi, 1 K WOB. Milled to 8672', Milling, 2,5/2.5 bpm, 1900 - 2050 psi, 1 K WOB. Milled to 8673.4', Observe CT pressure drop to 1900psi - mill must have popped out of window btm, Mill formation with 2,5/ 2.5bpm, 1900/2250psi, 2K WOB & increased ROP, Milled to 8683,5' . Back ream clean up to 8660', POOH window milling BHA#1, UO & inspect DSM, Mill gauge 3,79" & wear on face indicates crossing of Csg wall. M/U another good used DSM with 3,80" String Reamer. M/U same 2-7/8" straight extreme motor, MHA, 2 jts PH6, XO & CTC. BHA OAL = 83.2'. RIH with window dressing BHA #2 to 8600', Up wt check- 31.5k, Run-in wt - 23k. Bring pumps up 2,5bpm/201 Opsi. Continue RIH & tag @ 866~,~', Assume SR @ TOW & subtract 4,3' from CTD to place SR @"TOW (8665'), Printed: 12/6/2002 1 :55:38 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 Date' Frörn-To Hours Task Code NPT Phase pescriþtiörtof. Oþer~tions 11/17/2002 14:30 - 14:45 0.25 STWHIP P WEXIT Stall 1 x @ 8665,5', Ease-in from 8664' @ 0,1 '13m ins, Continue reaming window with 2.5/ 2.5bpm, 2000/2150psi & 1 k WOB, Stall1x @ 8668.6, P/U clean & ease-back into milling again. 14:45 - 15:30 0,75 STWHIP P WEXIT Continue reaming with 2,5/2.5bpm, 2000/2050psi & 1 k WOB, Milled to 8670' & observe CT pressure drop to 1900psi - string reamer is out of window btm. 15:30 - 15:40 0,17 STWHIP P WEXIT Ream formation & tag up @ 8679,9' with 2,5/2.5bpm, 1950psi. Correct CTD to 8683,5', 15:40 - 16:30 0,83 STWHIP P WEXIT Dress/drift window & make several backream passes with & without pumping, Window looks clean, TOW = 8665' & BOW = 8673,5' & TD = 8683.5', Meanwhile swap wellbore to recycled Flopro mud, 16:30 - 18:00 1,50 STWHIP P WEXIT Paint EOP flag @ 8400' & POOH window dressing BHA#2. 18:00 - 18:45 0.75 STWHIP P WEXIT LlO BHA#2 & inspect SR. SR gauge 3.80". 18:45 - 19:00 0,25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for MWD BHA M/U, 19:00 - 19:45 0,75 DRILL P PROD1 M/U BHA #3, Sperry MWD build BHA with 1.04 deg motor and used Smith 3,75" M09 bit. 19:45 - 20:20 0,58 DRILL P PROD1 Grease and check injecter head chains, OK. 20:20 - 22:00 1.67 DRILL P PROO1 RIH with MWD BHA #3, Shallow hole test OK, RIH, 22:00 - 22:30 0,50 DRILL P PROD1 Orient TF to high side, RIH thru window clean, Orient to 70R. 22:30 - 00:00 1.50 DRILL P PROD1 Tagged TD at 8,687' CTD, correct to TO of 8683,5' BKB [-3,5' CTD), Drilling, 2,5/2,5 bpm, 3170 - 4000 psi, TF = 70R. Several stalls, ROP = 30 FPH Drilled to 8,720 ft, 11/18/2002 00:00 - 02:30 2.50 DRILL P PROD1 Drilling Zone 3, 2,5 / 2.5 bpm, 3200 - 4100 psi, 60R, many stalls, 15 fph, Drilled into Zone 3 at about 8722'. Drilled to 8749', 02:30 - 04:15 1,75 DRILL P PROD1 Drilling Zone 3, 2,5/2.5 bpm, 3200 - 4100 psi, 30R, many stalls, 10 fph, Drilled to 8762', 04:15 - 05:30 1,25 DRILL P PROD1 Drilling Zone 3, 2.8/2,8 bpm, 3700 - 4100 psi, 20R, many stalls, 10 fph, Drilled to 8775', 05:30 - 06:00 0,50 DRILL P PROD1 Drilling Zone 3, 2,8 / 2.8 bpm, 3700 - 4100 psi, 20R, many stalls, 10 fph, Drilled to 8783', 06:00 - 07:00 1,00 DRILL P PROD1 Drilling, 2,7/2.7 bpm, 3300 - 4000 psi, 20R, 10 fph, Drilled to 8789' 07:00 - 08:30 1,50 DRILL P PROD1 Continue drilling to 8795' with 36R TF, 2,7/2,7bpm, 3300/3600psi. Decide to pull for BHA change, 08:30 - 09:00 0.50 DRILL P PROD1 Wipe clean to 8510', 09:00 -10:15 1,25 DRILL P PROD1 Log down @ 60fph & tie-into PDC log GR marker. Add 18' to CTD, 10:15 -10:40 0.42 DRILL P PROD1 RBIH, Kill pumps & RIH thru window to 8700', 10:40 - 11: 10 0,50 DRILL P PROD1 Log down @ 60fph & see RA pip tag depth @ 8691' (18' deeper). 11:10 -12:30 1,33 DRILL P PROD1 POOH drilling BHA#3, 12:30 - 13:00 0,50 DRILL P PROD1 LlO used M09 Bit (grades 4,6,1) 13:00 - 13:30 0,50 DRILL P PROD1 Adjust motor bend to 1,69degs & M/U drilling BHA #4 with new design Smith M09 bit. M/U injector. 13:30 - 15:15 1.75 DRILL P PROD1 RIH with BHA #4, SHT MWD & orienter - OK, Continue RIH to 8700', 15:15 -16:00 0,75 DRILL P PROD1 Tie-into RA pip tag & add 12' to CTD, 16:00 -16:15 0,25 DRILL P PROD1 RIH & tag TD @ 8810', Printed: 12/6/2002 1 :55:38 PM ) ") Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 Date Fronl'- Tö Höurs Task Code NPT Phase Descriþtion öf Operations 11/18/2002 16:15 -16:25 0,17 DRILL P PROD1 Orient TF to 90R. Up wt = 31 k, Run-in wt = 21 k, Freespin @ 2,5bpm = 3150psi. 16:25-17:15 0,83 DRILL P PROD1 Drill to 8837' with 85R TF, 2.6/2.6bpm, 3150/3450psi, 25fph ave ROP. 17:15 -18:00 0,75 DRILL N HMAN PROD1 Geologist & MWD Engr confirm that original tie-in should have been -18' instead of +18'CTD, i.e, we are 36' deep to actual. Wipe hole & review tie-ins & depths. Whipstock had been set 18 ft high, Subtract 36' from CTD & correct depths as follows: TOWS = 8646', TOW = 8647', RA PIP = 8655' & BOW = 8655'. Tag TD @ 8801', Likely exiting zone 3 now, 18:00 - 18:30 0.50 DRILL P PROD1 PUH to obtain directional surveys, 18:30 - 18:45 0,25 DRILL P PROD1 Orient TF to 80R. 18:45 - 19:30 0.75 DRILL P PROD1 Drilling build sec, 2,5 I 2.5 bpm, 3200 - 3700 psi, 80R, 50 FPH, Drilled to 8832 ft. 19:30 - 20:45 1.25 DRILL P PROD1 Drilling, 2.5/2,5 bpm, 3200 - 3800 psi, 80R, 40 FPH. Drilled to 8870 ft, 20:45 - 21 :00 0.25 DRILL P PROD1 Orient TF to 60R. 21:00 - 23:15 2.25 DRILL P PROD1 Drilling, 2.5/2,5 bpm, 3200 - 3800 psi, 60R, 40 FPH, Drilled to 8950', 23: 15 - 23:30 0.25 DRILL P PROD1 Wiper trip to window, Clean hole. RIH. 23:30 - 23:45 0,25 DRILL P PROD1 Orient TF to 25R. 23:45 - 00:00 0,25 DRILL P PROD1 Drilling, 2,5/2,5 bpm, 3200 - 3900 psi, 20R, 60 FPH, Drilled to 8,965'. 11/19/2002 00:00 - 01 :30 1,50 DRILL P PROD1 Drilling build section. 2.5/2.5 bpm, 3200 - 4000 psi, 30R, 80 FPH, Drilled to 9,044' 01 :30 - 01 :45 0,25 DRILL P PROD1 Wiper trip to window, Clean hole. Geologist determined that 14N shale may come in high at 8925' SS, Unable to land above 14N shale with present 1,69 deg, motor. POH for 3,0 deg motor to land well above 14N. 01 :45 - 03:00 1,25 DRILL P PROD1 POH for higher bend motor. Flag CT at 8500' EOP, POH. 03:00 - 04:10 1.17 DRILL P PROD1 Adjust motor to 3,0 deg, C/O Sperry WMD tools to get recorded data for Geo, Re-run M09X bit. New condition. 04:10 - 05:50 1,67 DRILL P PROD1 RIH with BHA #5, 3,0 deg motor and M09X bit. Check depth at flag. No correction. 05:50 - 06: 15 0.42 DRILL P PROD1 Orient TF to high side. 06: 15 - 06:45 0.50 DRILL P PROD1 RIH to TD. Clean hole. 06:45 - 07:25 0.67 DRILL P PROD1 Orient TF to HS, 07:25 - 08: 15 0.83 DRILL P PROD1 Drill to 9100' with HS-10R TF, 2,5/2,5bpm, 3200 - 3800psi & 100fph ave ROP, Drilling ratty, stacking & stalling, 08:15 - 09:30 1,25 DRILL P PROD1 Drill to 9123' with HS-10R TF, 2.5/2,5bpm, 3200 - 3800psi & 15fph ave ROP, Drilling ratty, 09:30 - 10:30 1.00 DRILL P PROD1 Drill to 9139' with HS-10R TF, 2,5/2.5bpm, 3200 - 3800psi & 30fph ave ROP, Project 93degs @ the bit. Discover 20' difference between J-01 & J-01A surveys. Whipstock setting & current J-01 B were tied-into J-01A which has a -20'vd error from J-01, Thus we're actually ca, +1-20'vd deeper & this places TD (9139') @ ca, 8946,5'vd & the 14N @ ca. +/-8947'vd, 10:30 - 10:45 0,25 DRILL P PROD1 Short 200' wiper trip. RBIH to btm. Review situation with town. Lay-in 8ppb klagard mud in OH, Printed: 12/6/2002 1 :55:38 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 Date From.'" To Hours Task Code NPT Desçripti9p.ofQperé]tions 11/19/2002 10:45 -12:35 12:35 - 12:50 12:50 - 13:20 13:20 - 15:00 15:00 - 16:00 16:00 - 17:20 17:20 - 17:50 17:50 - 19:00 19:00 - 19:20 19:20 - 20:20 20:20 - 20:40 20:40 - 21 :00 21 :00 - 21 :20 21 :20 - 22:00 22:00 - 22:15 22: 15 - 23:45 23:45 - 00:00 11/20/2002 00:00 - 00:40 00:40 - 02:30 02:30 - 02:45 02:45 - 03:10 03: 1 0 - 04:00 04:00 - 04:30 04:30 - 04:45 04:45 - 06:30 06:30 - 07:30 07:30 - 07:40 07:40 - 08:30 08:30 - 09:55 09:55 - 10:40 10:40 -11:10 11:10 -11:55 11:55-12:10 12:10 - 12:50 12:50 - 12:52 12:52 - 14:50 14:50 - 15:10 15:10 -15:40 15:40 - 16:50 1,83 DRill P 0,25 DRill P 0,50 DRill P 1.67 DRill 1.00 DRill 1.33 DRill 0.50 DRill 1.17 DRill P P P P P 0.33 DRill P 1.00 DRill P 0,33 DRill P 0.33 DRill P 0.33 DRill P 0.67 DRill P 0,25 DRill P 1.50 DRill P 0,25 DRill P 0,67 DRill P 1.83 DRill P 0.25 DRill P 0.42 DRill P 0,83 DRill P 0.50 DRill P 0,25 DRill P 1,75 DRill P 1.00 DRill P 0.17 DRill P 0.83 DRill P 1.42 DRill P 0,75 DRill 0.50 DRill 0,75 DRill 0,25 DRill 0,67 DRill P P P P P 0,03 DRill P 1,97 DRill P 0,33 DRill P 0.50 DRill P 1.17 DRill P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 POOH BHA#5. LlO M09 Bit (grades 1,1,1'" still looking new) Adjust motor bend to 1,04degs & M/U drilling BHA #6 with new Hycalog DS49 bit. M/U injector. RIH with BHA #6, long orienting in big dogleg interval. 9139', Resume drilling. 9184', Orient to 60R, trying to maintain 91 deg as per geo, Resume drilling. 2,5/2,5/3290 psi. Pit vol 296 bbls, ROP=50 fph, Drilled to 9217'. Orient TF to 40R. Drilling, 2.5/2.5 bpm, 2300 - 4000 psi, 92 deg inc. Stacking wt, Drilled to 9269 ft, Wiper trip to window, Clean hole, log tie-in with RA tag at 8655', Added 1 ft CTD. RIH clean to TD, Drilling, 2,8/2,8 bpm, 3600 - 4100 psi, 60R, 60 fph, 92 deg Inc, Drilled to 9310'. Orient to left side. Drilling, 2.8/2.8 bpm, 3600 - 4100 psi, 70l, 110 fph, 94 deg Inc, Drilled to 9,445'. Wiper trip to window, Clean hole, Wiper trip to window. RIH Clean to TD. Drilling, 2.8/2,8 bpm, 3800 - 4100 psi, 70l, 91 deg. Inc, 80 fph, Drilled to 9560', Swapped to new FloPro at 9520 ft. Orient TF to 80R. Drilling, 2,6/2.6 bpm, 3100 - 3600 psi, 70R, 94 deg inc, 100 fph, Drilled to 9600'. Wiper trip to window, Clean hole, RIH clean to TD, Drilling, 2,6/2,6 bpm, 3100 - 3600 psi, 150R, 91 deg inc, 120 fph, Drilled to 9650', Orient TF to 80R. Drilling, 2,6/2,6 bpm, 3100 - 3600 psi, 90R, 91 deg inc, 120 fph, Drilled to 9750'. Wiper trip to window, Clean hole. RIH clean to TD, Orient TF to 80l Drilling, 2,6/2,6 bpm, 3100- 3600 psi, 80l, 91 deg inc, 80 fph, Drilled to 9830 Drilling, 2.6/2,6 bpm, 3100-3600 psi, 70l, 84 deg inc, 91 fph, Drilled to 9900 Wiper trip to window Tie-in at 8690, add 4 feet Continue wiper trip to bottom Orient to 90l Drilling, 2,6/2,6 bpm, 3100-3600 psi, 90l, 89.4 deg inc, 106fph, Drilled to 9955 Kick while drilling drill- only a drill Cont. Drilling, 2.6/2,6 bpm, 3100-3600 psi, 90l, 89.4 deg inc, 100 fph, Drilled to 10034 Orient to 70l Drilling, 2,5/2,6 bpm, 3100-3600 psi, 70l, 89,25 deg inc, 48 fph, Drilled to 10054', Wiper trip to shoe. Clean PU off bottom at 28 klbs, Pit Printed: 12/6/2002 1 :55:38 PM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/20/2002 11/21/2002 J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 Froll1- To Hours Task Code NPT Phase Description ofOperatiQns 15:40 - 16:50 1,17 DRILL P PROD1 volume=247 bbls, 16:50 - 17:20 0,50 DRILL P PROD1 Orient to 135L. Back on bottom, pit vol=241 bbls. Lost 6 bbls of mud during wiper trip, Possibly at fault at 9970'. 17:20 - 17:45 0.42 DRILL P PROD1 Resume drilling. 17:45 - 17:55 0,17 DRILL P PROD1 Orient to 80R. Pit vol=237 bbls. 17:55 - 19:45 1,83 DRILL P PROD1 Resume drilling. 2.7/2.6/3960, Pit vol=235 bbls. Continuing to loose fluid, 19:45 - 20:20 0.58 DRILL P PROD1 10170', Pit Vol=229 bbls. Lost 5 bbls in last hour. Drilled to 10,187'. 20:20 - 21 :30 1,17 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to TD, 21 :30 - 21:45 0,25 DRILL P PROD1 Orient to 70L. 21 :45 - 00:00 2,25 DRILL P PROD1 Drilling, ROP slowed to 10 fph at 10,195 ft, 2.7 I 2.7 bpm, 3600 - 4200 psi, Drilled to 10,215', 00:00 - 01 :30 1.50 DRILL P PROD1 Drilling, 2,6 / 2,6 bpm, 3200 - 3900 psi, 60L, 92 deg inc, 20 FPH. Drilled to 10,238'. 01 :30 - 01 :40 0.17 DRILL P PROD1 POH for bit. Slow ROP. 01 :40 - 02:00 0,33 DRILL P PROD1 Log tie-in with RA tag at 8655'. Added 2.5 ft to CTD, Present TD = 10,240', 02:00 - 03:50 1.83 DRILL P PROD1 POH for Bit. 03:50 - 04:05 0,25 DRILL P PROD1 SAFETY MEETING, Review procedure, hazards and mitigation for BHA C/O. 04:05 - 05:00 0,92 DRILL P PROD1 C/O Bit [ 4,4,1 ], motor and Sperry MWD tools. M/U Bit #7 - New DS49 and new 1.04 deg HP motor. BHA = 65,34 ft. 05:00 - 07: 15 2.25 DRILL P PROD1 RIH with BHA #7, 1.04 deg motor Lateral BHA. Shallow test tools, RIH. 07: 15 - 07:40 0.42 DRILL P PROD1 Tag bottom, make -26' correction. Set depth to 10240'. Free spin 2,6/2.4/3220 psi. Pit vol=295 bbls, Current IAP=22 psi, OAP=51 psi. Orient to 80R. 07:40 - 08:45 1,08 DRILL P PROD1 10240', Resume drilling, 2,6/2,5/3430 psi. TF=70R. 08:45 - 09:15 0,50 DRILL P PROD1 10315', Orient to 80R. Pit Vol=293 bbls. Losses have virtually stopped, 09:15 -10:20 1,08 DRILL P PROD1 Resume drilling. Pit Vol=291 bbls, 2,7/2,5/3520, ROP=89 fph, 10:20-12:15 1,92 DRILL P PROD1 10410', Clean PU off bottom. Pit volume=288 bbls. Wiper trip to shoe clean up and back in hole. 12:15 - 12:20 0,08 DRILL P PROD1 Orient to 80R. 12:20 - 13:20 1,00 DRILL P PROD1 Resume drilling, Pit Vol=282 bbls, Lost 6 bbls during trip, 2,7/2,5/3600 psi. ROP=75 fph. 13:20 - 13:30 0.17 DRILL P PROD1 10540', orient 13:30 - 13:55 0.42 DRILL P PROD1 Resume drilling. Pit Vol=278 bbls. 13:55 - 15:40 1,75 DRILL P PROD1 10575', Wiper trip to shoe. Clean PU off bottom at 30klbs, 15:40 - 16:05 0.42 DRILL P PROD1 Resume drilling, Pit Vol=273 bbls, Lost 5 bbls on wiper trip, 2,5/2,3/3550 psi. Drilling at 71 L Tool face, ROP=100 fph. 16:05 - 16:10 0.08 DRILL P PROD1 Orient to 90R. 16:10 - 17:30 1,33 DRILL P PROD1 11640', Resume drilling, Pit Vol=273 bbls, 17:30 - 18:30 1.00 DRILL P PROD1 TD well at 10740'. Wiper trip to shoe. Clean PU off bottom at 29 klbs. 18:30 - 18:45 0,25 DRILL P PROD1 Log tie in pass over RA tag in whipstock, Added 2 ft CTD, 18:45 - 20:30 1.75 DRILL P PROD1 RIH clean to TD, Tag TD at final corrected depth of 10,741 ft BKB, POH clean to window, 20:30 - 21 :00 , 0,50 DRILL P PROD1 Log GR tie-in record for Geology from 8660-8500 ft, 21 :00 - 22:30 1.50 DRILL P PROD1 POH with MWD BHA. Printed: 12/6/2002 1 :55:38 PM ) ') BP EXPLORATION OpØrêltions$umlJ1~ry ..Repqr1 Page 9 . of 1.1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From-To. Hours Task Code NPT Phase 11/21/2002 22:30 - 23:30 1,00 DRILL P PROD1 23:30 - 00:00 0,50 CASE P COMP 11/22/2002 00:00 - 00: 15 0.25 CASE P COMP 00:15 - 02:30 2.25 CASE P COMP 02:30 - 04:00 1.50 CASE P COMP 04:00 - 05:15 1.25 CASE P COMP 05:15 - 06:15 1,00 CASE P COMP 06: 15 - 06:50 0,58 CASE P COMP 06:50 - 07:30 0,67 CASE P COMP 07:30 -10:40 3,17 CEMT P COMP 10:40 -11:05 0.42 CEMT P COMP 11 :05 - 11 :25 0,33 CEMT P COMP 11 :25 - 13:00 1.58 CEMT P COMP 13:00 - 14:40 1,67 CEMT P COMP 14:40 - 15:40 1.00 CEMT P COMP Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 LlO Drilling BHA. Prepare rig floor and pipe shed to run liner. SAFETY MEETING, Review procedure, hazards and mitigation for running liner. M/U BKR Fit Equip on 1 Jt, 2-7/8", M/U 39 jts, 2-7/8", 6,16#, L-80, STL Liner. Fill Liner. STL Turbos run on all JTs. M/U 2 pup jts, 2-7/8" with Turbos, M/U 25 jts, 2-7/8" STL Tubing with Turbos, XO, 3 jts, 3-3/16", TCII, XO and 19 jts, 3.5", STL Tubing. M/U HOWCO 3.5" XN Nipple, 2 pups 3-1/2" STL and 3.75" Baker Deployment Sleeve, M/U BKR CTLRT. M/U CTC, Pull I Press Test. RIH with Liner. Circ. 0,2 bpm at 1500 psi. Liner Length = 2,696,79'. Up WT. = 34,5 Kat 8640', Dwn WT. = 24K, Run in open hole Tag up at 10765'. PU at 40klbs, Retag again same place: Make -24' correction, which is consistent with previous runs, PU 3', drop 5/8" steel ball. Chase with KCL. Coil vol=57,6 bbls, Pumping at 2.6, returns 2.5. Pit vol at 07:20=247 bbls, Ball on seat at 48.4 bbls away, Good indication of release at 4500 psi. PU 2', at 20klbs, confirm free from liner. OAP=39, IAP=14, Swap to KCL, start circulating well to KCL. Clean pits. Mud going to MI for recycle, Slight fluid loss with Flopro in hole, When well swapped to KCL, pumping 2.2 bpm at 1025 psi, getting 1,9 back, 85% returns with KCL, Safety meeting prior to mixing cement. Attended by SWS cementers, SWS and Nordic rig personnel, Peak Vac truck driver, BP Co. Man, and Baker tool hand. Circulate while cementers are coming up to weight. Cement up to weight at 11 :20, PT cementers hardlines to 4000 psi. Pump 4 bbls of fresh water as preflush. On line with cementers pumping cement. Pump 25 bbls cement thru MM, Suck back lines, fill with bio, drop dart, Displace dart with rig pumps pumping 20 bbls bio pill, followed by KCL. 3.0/2,7 while pumping cement down coil. Rate to 1,75 bpm with cement at shoe, 1.7/1,5 Land dart at 56,2 bbls (Coil Vol=57.7 bbls), good indication of shear. Displace cement at 1 bpm. Returns 1,0 in, 0,8 out. Landed plug on 16.9 bbls, liner volume=17,1 bbls. Bumped plug to 2000 psi. 21 bbls behind pipe, 4 bbls lost to formation. Unstung from liner clean, Wash top of liner ok, CIP @ 12:55, Cement Data: Class g, 15,8 ppg, Additives; D-600G @ 2,0 gps, D-047 @O.2 gps, C-359 @ 0,02% BWOC, D-800 @ 0,25% BWOC, D-065 @ 0,62% BWOC, POOH with CTLRT. ***** Note, no POOH, or POH code in CEMT task, Another problem for DeWayne Pratt ********** Lay down CTLRT, recovered in proper order. Jet stack with Printed: 12/6/2002 1:55:38 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 Date From- TO Hours Task Code NPT Phase DescriptiOn of Operations 11/22/2002 14:40 - 15:40 1,00 CEMT P COMP nozzle, 15:40 - 16:00 0.33 EVAL P COMP Safety meeting prior to picking up CNL tool and cleanout motor. 16:00 - 16:40 0,67 EVAL P COMP Make up cleanout motor and memory CNL carrior housing, Well full of KCL, did not take any fluid, 16:40 - 17:45 1,08 EVAL P COMP Make up 88 joints of CSH work string. 17:45 - 18:20 0.58 EVAL P COMP Crewchange and pretour safety meeting re-running CSH/Memory CNL log. 18:20 -19:15 0,92 EVAL P COMP Continue running CSH in hole, 19:15 - 20:15 1,00 EVAL P COMP RIH with motor I mill and SWS Memory CNLlGR/CCL tools, BHA = 2, 785'. Circ at 0,5 bpm while RIH. Stop at 7900 ft. 20:15 - 22:30 2.25 EVAL P COMP Wait on Cement. Cmt in place at 12:55 hrs. DS Cmt UCA sample at 0 PSI CS at 20:15 hrs, 22:30 - 00:00 1.50 EVAL P COMP Log down at 30 FPM from 7,900', circ, at 0.4 bpm, 1700 psi. Tag PBTD of 10,706' at 10,718' CTD, Log up at 30 FPM, circ. 0.4 bpm. 11/23/2002 00:00 - 01 :30 1.50 EVAL P COMP Log up with Memory CNLlGR/CCL while laying in high viscosity new FloPro perf pill. 01 :30 - 02:45 1,25 EVAL P COMP POH with logging tools, motor and mill. 02:45 - 04:45 2.00 EVAL P COMP Stand back 44 stds of CSH workstring, Wet string, 04:45 - 05:00 0.25 EVAL P COMP SAFETY MEETING. Reviewed procedure, hazards and mitigation for LlO of memory CNLlGR/CCL tools and motor / mill. 05:00 - 05:30 0.50 EVAL P COMP LlO logging I cleanout BHA. 05:30 - 06:00 0.50 EVAL P COMP Pressure test 3,5" liner lap with 2000 psi for 30 min. Chart test. Good test. Starting press =2050 psi, End Pressure at 30 min. = 2020 psi. Bleed off WHP, lAP = 20 psi, OAP = 30 psi, during test. 06:00 - 07: 15 1,25 EVAL P COMP Fax CNL log to town. Communicate with Town Geo/Roger Sels. No changes to perf interval. PU perf guns into pipe shed, prep to run. 07:15 - 07:35 0.33 PERF P COMP Safety meeting prior to picking up perf guns, 07:35 - 08:30 0,92 PERF P COMP Make up perf guns. 08:30 - 09:45 1.25 PERF P COMP Pick up 88 joints of 1-1/4" CS hydril work string, 09:45 - 10:05 0.33 PERF P COMP MU MHA and injector. 10:05 - 11 :35 1.50 PERF P COMP RIH with perforating guns conveyed on CS hydrill work string and coil. Observed Bio/contaminated cement returns from displacement while RIH, 11:35 -14:20 2.75 PERF P COMP Tag bottom at 10718', same uncorrected depth as MCNLlCleanout run. Retag to confirm, Make -9' correction, to MCNL correlated PBTD of 10708', Pull up to ball drop depth and pump 20 bbls of flopro mud, Chase with KCL, 2 bpm @ 3132 psi. Ball on seat at 58.8 bbls away, (Coil + CSH vol = 60.8 bbls), Good indication of fire at 3000 Ibs over. All indications are good. Perforation Information: Shot interval 1 0350'-1 0700' with 2" Powerjet charges at 4 spf, 60 deg phasing, 14:20 - 15:50 1,50 PERF P COMP POH with coil, circulating accross the top to keep the well full. 15:50 - 16:20 0,50 PERF P COMP PJSM prior to laying down CSH, and perf guns, 16:20 - 17:30 1.17 PERF P COMP Lay down CS hydril work string for prep to move to DS14-08. 17:30 - 18:00 0,50 PERF N RREP COMP Problem with SCR room, shut down tripping pipe to make Printed: 12/6/2002 1 :55:38 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-01 J-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/25/2002 Rig Release: 10/27/2002 Rig Number: N2 Spud Date: 5/14/1969 End: 11/24/2002 Date From-To Hours Täsk CodèNPT Phase Descri ptionof Operc¡tions 11/23/2002 17:30 - 18:00 0,50 PERF N RREP COMP repairs, 18:00 - 18:25 0.42 PERF P COMP PJSM with night tour crew, 18:25 - 19:45 1,33 PERF P COMP Continue coming out sideways with CS hydrill work string, 19:45 - 20:00 0,25 PERF P COMP SAFETY MEETING, Review procedure, hazards and mitigation for laying out perf guns. 20:00 - 22:00 2,00 PERF P COMP Recover all perf guns, All shots fired. Load out guns from pipe shed. 22:00 - 23:45 1,75 RIGD P COMP RIH and freeze protect 4.5" tubing to 2000 ft with MEOH, Pump 1,2 bpm, pull at 120 fpm. Stop at 200' and circ until MEOH seen at surface, POH, Pumped 25 bbls MEOH, Closed Master and Swab valves, 23:45 - 00:00 0.25 RIGD P COMP Displace CT with N2, Pump 20,000 FT3, Bleed down coil to tiger tank, 11/24/2002 00:00 - 02:00 2.00 RIGD P COMP Blow down N2 from coil. Change out CT pack-off, clean rig pits, 02:00 - 03:00 1.00 RIGD P COMP Secure CT. Remove guide arch, Set injecter head in pipe bay. 03:00 - 05:00 2.00 RIGD P COMP Nipple down BOPE, N/U tree cap and pressure test with 4000 psi. RELEASED RIG AT 0500 HRS, 11-24-2002, TOTAL OF 7 DAYS, 19 HRS ON WELL. Start rig Wait on Weather at 0500 hrs, Wind at 14-24 MPH, To high to lay down wind walls. 05:00 - 06:30 1.50 RIGD N WAIT COMP Wind moderating, begin prepping for rig down, 06:30 - 07:15 0,75 RIGD N WAIT COMP Safety meeting prior to rigging down wind walls and derrick. 2 new hands involved in the operation for first time. Review SWS/Nordic procedures line by line, Total of 2,25 hours WOW, Billed as standby for rig move to DS 14-08AL 1 07:15 - 11 :30 4.25 RIGD P COMP Rig down wind walls and derrick, 11 :30 - 12:00 0.50 MOB P PRE Safety meeting with tool service, security, CPS, rig hands re moving to DS 14-08, 12:00 - 18:30 6.50 MOB P PRE Move Nordic 1 rig from J Pad on the WOA to DS14 on the EOA.Nordic 1 on DS 14 at 18:30 hrs, Sevice CTU still on well. Further events captured on DS14-08 DIMS report. Printed: 12/6/2002 1 :55:38 PM Well: Field: API: Permit: ) ') J-01 B Prudhoe Bay Unit 50-029-20020-02 202-201 Rig Accept: 11/16/02 Rig Spud: 11/17/02 Rig Release: 11/24/02 Drilling Rig: Nordic #1 POST-RIG COMMENT 01/21/03 AFTER NORDIC #1 MOVED OFF OF THIS WELL THE GEOLOGIST DETERMINED THAT AN ERROR HAD BEEN MADE IN DETERMINING THE TIE-IN POINT. SINCE THIS WAS IDENTIFIED POST RIG, THE DEPTH NOTATIONS IN THE "OPERATIONS SUMMARY REPORT" ARE OFF BY 17 FEET. THESE CORRECTIONS HAVE BEEN MADE HOWEVER IN THE FINAL SURVEY AND ON THE 10-407. TOP OF WHIPSTOCK = 8664' TOP OF WINDOW = 8664' (BOTTOM = 8672') TOP OF LINER (DEPLOYMENT SUB) = 8061' (WITH XO AT 8639 TO 3-1/2" AND XO AT 8738' TO 2-7/8") TD & BOTTOM OF LINER = 10758' PBTD = 10725' PERF'S = 10367' TO 10717' ) ) 06-Dec-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well J-01 B Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 8,662.00' MD Window / Kickoff Survey 8,664.00' MD (if applicable) Projected Survey: 10,758.10' MD Please call me at 273-3545 if you have any questions or concerns. Regards, RECEIVED William T. Allen Survey Manager DEC 1 3 2002 Attachment(s) ,Alaska O¡1 & Gas ColiS. Commission Anchorage ÕlOd-dO) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU _WOA J Pad J-01 B Job No. AKMW22181, Surveyed: 21 November, 2002 Survey Report 5 December, 2002 Your Ref: API 500292002002 Surface Coordinates: 5970595.20 N, 643106.70 E (70° 19' 37.7976" N, 148050' 21.8455" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 970595.20 N, 143106.70 E (Grid) Surface Coordinates relative to Structure Reference: 2332.52 N, 1997.30 E (True) Kelly Bushing: 77.25ft above Mean Sea Level Elevation relative to Project V Reference: 77.25ft Elevation relative to Structure Reference: 77.25ft 5pe""'''y-5UI''1 CAILI-.NG SERVU:::es A Halliburton Company ):t: ,--VE -~' "-,,, Survey Ref: svy11382 Sperry-Sun Drilling Services Survey Report for PBU_WOA J Pad - J-01B Your Ref: API 500292002002 Job No. AKMW22181, Surveyed: 21 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8662.00 9.300 0,000 8583.49 8660.74 56.758 54.62 W 5970537.42 N 643053.17 E -30,65 Tie On pOint .. 8664.00 9.560 359.730 8585.46 8662.71 - 56.42 8 54.62 W 5970537,75 N 643053.17 E 13: 187 -30,77 Widow Point 8706,70 11 .270 11,550 8627.46 8704.71 48.79 8 53.80 W 5970545.40 N 643053.84 E 6.390 -32,74 8736.70 13,750 20,260 8656,75 8734.00 42.57 8 51.98 W 5970551,65 N 643055.54 E 10,365 -33.27 8766.70 19,690 25,880 8685.47 8762.72 34.67 8 48.53 W 5970559.61 N 643058.84 E 20.498 -32.89 8796,70 23.900 29,770 8713,32 8790.57 24.84 8 43.31 W 5970569.54 N 643063.87 E 14.829 -31,53 .--- 8827,27 26,080 32,670 8741,03 8818.28 13.81 8 36.61 W 5970580.70 N 643070.36 E 8.178 -29.23 8863,50 28,130 54,380 8773,36 8850.61 2.108 25.33 W 5970592.62 N 643081.41 E 27.738 -22.90 8891,50 29.780 69,680 8797,89 8875.14 4.17N 13.43 W 5970599,11 N 643093,19 E 27.034 -14,03 8919,23 34.360 77.61 0 8821.39 8898,64 8.24N 0.68E 5970603.46 N 643107,23 E 22.406 -2.32 8949,60 37,360 87,120 8846.02 8923.27 10.55 N 18.27 E 5970606.09 N 643124.77 E 20,810 13.28 8994.60 44.41 0 98,050 8880,07 8957.32 9.03N 47.58 E 5970605.13 N 643154.10 E 22.275 41,18 9022.82 49.960 102,810 8899.25 8976.50 5.24N 67.91 E 5970601.74 N 643174,50 E 23.225 61,52 9060.55 60,790 103,160 8920.65 8997.90 1.738 98.12 E 5970595.34 N 643204.83 E 28.714 92,22 9091.57 69,870 104.210 8933,59 9010.84 8.40 8 125.47 E 5970589.20 N 643232.31 E 29.432 120.15 9119.82 80.260 105.620 8940.86 9018.11 15.42 8 151.81 E 5970582.68 N 643258.78 E 37.093 147.25 9149.05 90.660 104.570 8943.17 9020.42 23.00 8 179.90 E 5970575.64 N 643287.01 E 35.759 176.20 9180,75 91,080 108.830 8942.69 9019.94 32.108 210.26 E 5970567.11 N 643317,53 E 13.502 207,80 9209.35 92,070 113.200 8941,90 9019.15 42.35 8 236.94 E 5970557.37 N 643344.40 E 15,661 236.38 9243,35 93,740 117.960 8940,18 9017.43 57,01 8 267.56 E 5970543.30 N 643375,29 E 14.819 270.22 9274.50 91.890 120,600 8938.65 9015.90 72.23 8 294.69 E 5970528.61 N 643402.71 E 10.340 301,00 9331.65 91.370 125,890 8937.02 9014,27 103,53 8 342.45 E 5970498.22 N 643451.06 E 9.297 356,81 9359.55 92,600 122,360 8936.05 9013.30 119.178 365.53 E 5970483.02 N 643474.43 E 13,391 383.96 9393,20 94,71 0 120,960 8933.91 9011.16 136,80 8 394.11 E 5970465.94 N 643503,35 E 7,520 416.96 --' 9443,10 91,320 114.240 8931.28 9008,53 159.868 438.24 E 5970443.72 N 643547.91 E 15.065 466.42 9474.52 90.660 111,620 8930.74 9007,99 172,108 467.17 E 5970432.04 N 643577.07 E 8.598 497,82 9504,60 90.930 108,800 8930,32 9007.57 182.498 495.39 E 5970422.19 N 643605.48 E 9.417 527,89 9534.57 91.100 105.980 8929,79 9007,04 191.458 523.98 E 5970413.78 N 643634.24 E 9.425 557,79 9562.98 92.600 105.980 8928.87 9006.12 199,268 551.28 E 5970406.49 N 643661.68 E 5.280 586,08 9606,52 94.360 108.440 8926.23 9003.48 212,128 592.79 E 5970394.43 N 643703.43 E 6,938 629.43 9638,18 93.570 111.970 8924.04 9001,29 223,03 8 622.43 E 5970384.09 N 643733.27 E 11,399 661.01 9667,00 90.400 110,560 8923.04 9000,29 233.478 649.26 E 5970374.16 N 643760.30 E 12,037 689.81 9697,75 90.520 115.720 8922.79 9000,04 245.55 8 677.53 E 5970362.62 N 643788.79 E 16,784 720.53 9728.75 92.330 120,250 8922.02 8999.27 260,098 704.89 E 5970348.60 N 643816.42 E 15,731 751,28 9763,68 87.400 120,960 8922,10 8999,35 277.87 8 734.94 E 5970331.40 N 643846,81 E 14.259 785.71 5 December, 2002 - 16:31 Page 2 0'4 DríllQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA J Pad - J-01B Your Ref: API 500292002002 Job No. AKMW22181, Surveyed: 21 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9806.45 84.930 117.080 8924,97 9002.22 298.56 S 772.25 E 5970311.42 N 643884.50 E 10.736 827,95 9841,00 84,930 112.670 8928,02 9005.27 313.04 S 803.46 E 5970297.55 N 643915.99 E 12.714 862.28 9874.23 87,840 112,320 8930.12 9007,37 325.72 S 834.10 E 5970285.44 N 643946,86 E 8,820 895.43 9911 .15 89.430 108.970 8930.99 9008,24 338.73 S 868.63 E 5970273.10 N 643981.64 E 10,041 932,33 9943.27 89,690 107,390 8931 .24 9008.49 348.75 S 899.15 E 5970263.66 N 644012.34 E 4,985 964.41 9968.35 90,310 104.040 8931 .24 9008.49 355.55 S 923.29 E 5970257.33 N 644036,60 E 13.584 989,38 ~/ 10003.68 89,780 101,570 8931,21 9008.46 363.38 S 957.74 E 5970250.16 N 644071.19 E 7.150 1024.35 10028,32 88.990 99.460 8931.48 9008.73 367.87 S 981.96 E 5970246.12 N 644095.50 E 9.143 1048.57 10070,05 87,840 93,640 8932,63 9009.88 372.63 S 1023.38 E 5970242.16 N 644137.00 E 14.211 1088,95 10108,00 86,520 97.520 8934,50 9011.75 376.31 S 1061.10 E 5970239.19 N 644174.78 E 10.788 1125.48 10136.60 88,110 103.690 8935,84 9013.09 381.57 S 1089.16 E 5970234.47 N 644202.94 E 22.255 1153,56 10170.43 88,190 107.210 8936.93 9014.18 390.58 S 1121.75 E 5970226.09 N 644235.70 E 10.402 1187,21 10200.45 88,550 112.140 8937,79 9015.04 400.68 S 1150.00 E 5970216.53 N 644264.13 E 16.459 1217.20 10233.68 88,110 108,090 8938,76 9016.01 412.10 S 1181.18 E 5970205.71 N 644295.53 E 12,254 1250.41 10271,62 87.930 107.030 8940.07 9017.32 423.54 S 1217.33 E 5970194.96 N 644331.89 E 2,832 1288.26 10301,90 88,020 108.970 8941,14 9018,39 432.89 S 1246.11 E 5970186.16 N 644360.84 E 6.410 1318.48 10342.43 88,190 117,080 8942.48 9019.73 448.72 S 1283.36 E 5970171.04 N 644398.38 E 20,003 1358.92 10375.87 88.460 122.190 8943.46 9020,71 465.24 S 1312.40 E 5970155,08 N 644427.74 E 15.296 1391.96 10406.43 89.250 127,120 8944.07 9021.32 482,61 S 1337.53 E 5970138.19 N 644453.19 E 16,335 1421.64 10439,52 90,570 131.880 8944.12 9021.37 503.65 S 1363.05 E 5970117.64 N 644479.11 E 14.928 1453.01 10478,15 89,870 136.110 8943,97 9021.22 530.48 S 1390.84 E 5970091.35 N 644507.40 E 11.099 1488.56 10514.27 90.840 143.690 8943,75 9021.00 558.08 S 1414.08 E 5970064.19 N 644531.17 E 21.156 1520.16 10548,85 90.220 142.450 8943.43 9020.68 585.72 S 1434.86 E 5970036.95 N 644552.47 E 4.009 1549.46 10578,15 89.160 139,630 8943,59 9020.84 608.50 S 1453.28 E 5970014.52 N 644571,32 E 10,282 1574,82 --~ 10611,90 89.780 133.990 8943.90 9021.15 633.10 S 1476.37 E 5969990.37 N 644594.88 E 16,811 1605,19 10650.75 88,720 128.710 8944.41 9021.66 658.76 S 1505.52 E 5969965,28 N 644624.51 E 13.861 1641,60 10701.43 87.490 135,930 8946,09 9023.34 692.83 S 1542.95 E 5969931,92 N 644662.58 E 14.444 1688,76 10729,30 87,670 140,160 8947.27 9024,52 713.54 S 1561.56 E 5969911.58 N 644681,58 E 15,178 1713,55 10758.10 87,670 140.160 8948.44 9025,69 735.63 S 1579.99 E 5969889.84 N 644700.44 E 0,000 1738.68 Projected Survey 5 December, 2002 - 16:31 Page 3 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA J Pad - J-01B Your Ref: API 500292002002 Job No. AKMW22181, Surveyed: 21 November, 2002 BPXA North Slope Alaska All data is in Feet (US) unless otherwise stated, Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference, Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 111.000° (True). Magnetic Declination at Surface is 25.971 0(22-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 10758.1 Oft., The Bottom Hole Displacement is 17 42,85ft.. in the Direction of 114.966° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8662.00 8664.00 10758.10 8660,74 8662.71 9025,69 56,75 S 56.42 S 735.63 S 54.62 W 54.62 W 1579.99 E Tie On Point Widow Point Projected Survey Survey too/program for J-01 B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) ~ Survey Tool Description 0,00 8520.35 0.00 8519.50 8520,35 10758.10 8519.50 AK-1 BP _HG - BP High Accuracy Gyro(J-01) 9025.69 MWD Magnetic(J-01A) 5 December, 2002 - 16:31 Page 4 of4 DrillQuest 3.03.02.004 Se_lombepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 11/26/02 NO. 2567 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job# Log Description Date Blueline Sepia Prints J-10B 1o...a.-.O I 22494 USIT 10/25/02 2 MPI-02 '10-~cy 22495 US IT 10/16/02 2 D.S.1-12 I ~"7- )( 22460 RST 09/02/02 1 H-23A J 5,,0 S 22488 MCNL 10/12/02 1 D.S.11-33 I iJ"'Q~ t) 22441 RST 09/13/02 1 H-08 I 7 7...~ '5 22479 RST 10/15/02 1 E-31A ~f6 ï&; 22409 MCNL 08/08/02 1 H-20 I -... 0 "1 22478 RST 10/09/02 1 N-15 I -D1C¡ 22507 RST 11/13/02 1 C-31A ~~"'OOltJ 22335 MCNL 07/13/02 1 D.S.11-17A~-O~~ 22418 PERF/JEWELRY (PDC) 08/22/02 1-01/J-19 I ~. D. '1 22504 RST 11/02/02 -~--- 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 RECEIVED Date Delivered: NOV 2 9 2002 Alaska Oi~ & Gas Cons. Cornmis3ion Anchorage CD 1 1 1 1 1 1 1 1 1 1 -,." Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN Beth Received ~ ~p"..J 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. ) STATE OF ALASKA' ') ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 0 Suspend . 0 Plugging 0 Time Extension 0 Perforate 0 Repair Well I 0 Pull Tubing 0 Variance 0 Other II Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate yJG*" 1°1'1)0/°'- .Þ't £-f!, /~/Jð/ð 2..- pC1S /0/3/ 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) KBE = 77.25' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 750' SNL, 1245'WEL, SEC. 09, T11N, R13E, UM At top of productive interval 4740' NSL, 1390' WEL, SEC. 09, T11 N, R13E, UM At effective depth 802' SNL, 1300' WEL, SEC, 09, T11 N, R13E, UM (Whipstock) At total depth 3382' NSL, 4954' WEL, SEC. 10, T11 N, R13E, UM (As Planned) 12. Present well condition summary Total depth: measured 8. Well Number / J-01 B 9. Permit Number 202-201 10. API Number 50- 029-20020-02 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool true vertical 9900 feet 9056 feet 8681 feet 8680 feet Plugs (measured) Set whipstock and P&A existing perfs, TOC at approx. 8845' (1 0/02); Set 2nd whipstock at 8681' (10102) Junk (measured) Fish: Stuck window milling assembly at approx. 8686' (10102) true vertical Effective depth: measured Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 280 sx Permafrost 100' 100' 1800 sx Fondu 950' 950' 1600 sx Class 'G' 4258' 4258' 2155 sx Class 'G' 8682' (TOW) 8680' 100' 933' 4241' 9287' 30" 20" 13-3/8" 9-518" true vertical None RECEIVED OCT 30 2002 Perforation depth: measured None Tubing (size, grade, and measured depth) 4-1/2'" 12.6#, L-80 tubing to 8084'. Alaska Oil & Gas Gons. Commission Anchorage Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" TIW HBBP Packer at 8019' and a 4-1/2" SSSV Landing Nipple at 2102'. 13. Attachments 181 Description Summary of Proposal 0 Detailed Operations Program 15. Status of well classifications as: 181 Oil 0 Gas 0 Suspended 0 BOP Sketch 14. Estimated date for commencing operation October 27,2002 16. If proposal was verbally approved Winton Aubert / 10/28/2002 Name of approver Date Approved Contact Engineer Name/Number: Alistair Sherwood, 564-4378 17. ~:n~~Y :~:s::::f~5:=:;(~:::r.. Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test _On $AA~M1:tiæ..form required 10- t.fO ~ . glO81 ~ DJ ~~~O~~4~~ o~~ o~~~~~mmiSSion Camrr Õ Is! Service Prepared By Name/Number. Terrie Hubble, 564-4628 Date ~/~æ I Approval No.3 0 Z. - ~ ~c¡ {c ~~~~lIt ~~') ;" <SCt~ "Btv ~ t Com~îssl~ner Date' D (~I / O~ Submit In t~iplicate ) Page 1 of 1 Hubble, Terrie L r-"- .... -"'-'.._.."._._--,-_._-~_..__.."...._._- From: Sherwood, Alistair Sent: Tuesday, October 29, 2002 4:04 PM To: Hubble, Terrie L Cc: Sels, Roger A.; Hyatt, Paul G Subject: J-01 A Operations Shutdown Terrie, find attached details for the AOGCC required operations shutdown report. On Tue 22nd Oct 02, Nordic 2 CTD rig moved over J-01 A with the objective of drilling a 2,OOOft sidetrack, J- 01 B. J-01A had previously been prepared by the Wells group. Pressure & mechanical integrity had been verified, a thru-tbg mechanical whipstock was set in the 5.5" liner and the original perforations below the whipstock were P&A'd with cement. While RIH with the first milling BHA, (a 3.8" od diamond speed mill with l' long x 3.8" od cutrite string reamer, 18 inches behind) the well was circulated to a 2% KCI/ 2ppb biozan milling fluid. An Otis 3.725" XN was milled with ease on route to the whipstock tray. After verifying the WS pinch point, milling / operations proceeded as per CTD team recommended practice. 4' into the 7-8' long window the milling BHA stalled and became stuck. Attempts were made to release the BHA with straight pull, annulus pressure fluctuation and a 30bbls HCUHCF acid pill. After pumping the acid the coil was pulled free, however at surface it was discovered that the coil had been pulled from the dimple coil connector:-One fishing attempt was made to recover the 75' long BHA, using a 2-3/8" spear stabbed into the connector. After failing to move or break the milling BHA a ball was dropped to release the coil. It was decided to set another, same type mechanical whipstock further up the liner and start a fresh. It had been surmised that a lack of cement behind liner had caused instability and the first mill to stick. To check this theory a cement bond, (USIT) log was run across the new setting depth. With good coment behind liner '" verified the whipstock was set. After RIH with the second milling BHA, (the same except for the position of the disconnect) and verifying the WS pinch point, milling operations commenced again. 4' ,into the 7-8' long window the milling BHA stalled and became stuck yet again - a carbon copy of the first event. Attempts were made to release the BHA with straight pull, pumping around Flo-Pro mud, pumping around a lubricant pill & fluctuating the annulus pressure without success. After working the coil to it's fatigue limit a ball was dropped to release from the BHA. One fishing attempt was made to recover the 15' long BHA, using a GS spear stabbed into the disconnects fishing .neck. A portion, (13') of the milling BHA was recovered to surface. It turned out the motor was broken off at 7' the output shaft. It was decided to rig Nordic 2 off of the well at this point, and spend some time evaluating the incidents. It is / planned to return to the well with either Nordic 1 or 2 before the year end, with a revised & tested window milling strategy. Alistair Sherwood Coil Tubing Drilling Engineer Greater Prudhoe Bay BP Exploration (Alaska) 900 E. Benson Blvd. Anchorage, +(907) 564 4378 +(907) 440 8301 10/30/2002 ) ~1T~1T TONY KNOWLES, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 w. -¡m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit J-OIB BP Exploration (Alaska), Inc. Permit No: 202-201 Surface Location: 750' SNL, 1245' WEL, Sec. 09, T11N, R13E, UM Bottomhole Location: 3382' NSL, 4954' WEL, Sec. 10, T1IN, R13E, UM Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above development well. . This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations unt il a 11 0 ther required permits a nd approvals ha ve been is sued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF~E COMMISSION DATED thisÆ day of October, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 750' SNL, 1245' WEL, SEC. 09, T11 N, R13E, UM At top of productive interval 4740' NSL, 1390' WEL, SEC. 09, T11N, R13E, UM At total depth 3382' NSL, 4954' WEL, SEC. 10, T11 N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ;/ ADL028284, 3382' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8830' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade Couolina 3-3/4" 3-1/2"x3-3I1S" 8.81#/S.2# L-80 ST-L/TCII ALASKA. 012 AND ~:A;~g~S~;:;;ON COMMI~JION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 77.25' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL028281 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number J-01 B 9. Approximate spud date 10105/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10875' MD I 8950' TVD 0 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 94 Maximum surface 2094 psig, At total depth (TVD) 8800' I 3150 psig Setting Depth Too Bottom Quantitvof Cement Lenath MD TVD MD TVD (include staae data) 2845' 8030' 8030' 10875' 8950' 93 sx Class 'G' W'6A- '/3"/0'"L ~ C¡/~(o2-- 11. Type Bond (See 20 AAC 25.025) / Number 2S100302630-277 x 2-7/8" 6,16# 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Su rface Intermediate Production Liner 9900 feet 9056 feet 9300 feet 9037 feet Length Plugs (measured) 3-3/8" IBP PLUG AT 9300' MD (05/96) Junk (measured) Size Cemented MD TVD 100' 933' 4241' 9287' 1811' 30" 20" 13-3/8" 9-518" 5-1/2" 280 sx Permafrost 1800 sx Fondu 1600 sx Class 'G' 2155 sx Class 'G' 315 sx Class 'G' RI€EI'VED ~~~: 4258' SEP 2 4 2002942~~0;~30' AlasKa 01' GasOans. GDIDDIISSlon , AucltGtIs)a 100' 950' 4258' 9037' 8088' - 9056' 20. Attachments Above Bridge Plug: 9135' - 9150', 9214'; Below Bridge Plug: 9380',9420' - 9630' , 9660' - 9810' Sqzd: 9150' - 9170' true vertical Above Bridge Plug: 9016' - 9020',9033'; Below Bridge Plug: 9036',9036' - 9044' , 9046' - 9054' Sqzd: 9020' - 9025' III Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Alistair Sherwood, 564-4378 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the for7o/:in;!. .is. tr~and corre9 to the best of my kn~~ledge . Q h i..1ø Signed Alistair Sherwood f{V¡~'(" ßO: V~..x;{ Title CT Dnlllng Engineer Date. .J .~~ e 2- ." , '" -,.:..-'~:;/-~'.::r";:r:.,~-,r;-~o'~I~."~:.QníY>'. . .. ' Permit Number API Number Appr°'RI' qz:t~rJ See cover letter -< 0 .<.. - 2. C> / 50- 029-20020-02 \ U ~ \) ~ for other reQuirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required l 0 Yes tit No Hydrogen Sulfide Measures t8 Yes 0 No Directional Survey Required BYes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: Tëst- BoPE i-o ~5q§Rð~AL GIG,""-'" r'.,v ¡-; , )'-'IG':'-JAl :~!~~'1¥Ð nv 0 T I '......lJ LJ by order of ~::~~~~ Rev. 12-01-85 '-" ~~ S!;;'¡;ov.:t' ' 0 Frf 'WÃ L the commission Date sulQ¡L ~t Perforation depth: measured ) ) BP J-01 a CTD Sidetrack Summary of Operations: / On or about the 5th October Nordic 2 CTO rig is scheduled to rig up on J-01. It will drill a thru-tubing sidetrack, J-01 B from an exit in the 5%" liner to a new Z2A Ivishak reservoir target. Phase 1: Prep work. Planned ASAP. 1. Run caliper survey to check the mechanical condition of the production tubing & liner. 2. Perform mechanical integrity tests (MIT) on the inner, (IA) & outer annulus, (OA) 3. Run & set 4% x 5%" thru tUbingæ~PJtock @8,830'/ 4. P&A perfs below whipstock with ~Is of 15.8ppg cement, (assume that 250/0 squeezed away) 5. Isolate & vent production flowlin , remove the well house & level the surrounding pad. Phase 2: Mill window, Drill and Complete sidetrack: Planned to start October 5th, 2002. . CTO will to mill the window then drill and complete the sidetrack as per attached plan. Mud Program: . , . Phase 2: Mill with seawater/2ppb biozan, drill with Flo-Pro (8.6 - 8.7 ppg) / Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: /' . A solid & tapered liner (2*" ST-L x 33/16" TCII x 3%" ST-L) will be run from TO at 1 0,875'md (-8,950'tvdss) to 8,030'md (- 8030'tvdss). .,'~/) . The liner will be cemented in place witÞf1 ~b6ls of 15.8ppg cement, with the objective of placing the cement top, 300' above the window exit to ensure h.¥ãraulic isolation. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. /' . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is 94°. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . MWO directional & GR data will be logged while drilling. A memory CNUGR/CCL log will be acquired after running & cementing the liner. Hazards . J-01 a last test was 5ppm H2S. J pad has no production over 100ppm H2S. . Two fault will be crossed making the risk of lost circulation moderate. . The 2nd fault may also throw the sidetrack into the reactive 14N shale. This has a tendency to stick our drilling assy & liner. Reservoir Pressure . Res. press. is estimated to be 3150 psi at 8800'ss (6.9 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2094 psi. / TREE ~ 4" CAMffiON WELLHEAD = CAMffiON ÄëTüÃ To"Fr;~~^"--~-BAKER 'KS. ELE\T;_w'-'""~'-j7:25; '"BF.'f~[EV''';;;'''''-''''''.'''''''''''''''''-38'':4'''. . KOP ~---------Š66i 'Max"A^ñglê;;; """'''gÕ'''C{f9386i #Bãium MÕ;;;#w'''''#M,,---_w~ã894"î' 'oatûffi"ïVo';"" """"""'-ããõõ'î"ss ) 13-3/8" CSG, 68#, ID = 12.415" l-i 4258' Minimum ID = 3.725" @ 8072' 4-1/2" OTIS XN NIPPLE 14-1/2" TBG, 12,6#, L-80, 0.0152 bpf, ID = 3.958" l-i 8084' I TOP OF 5-1/2" LNR l-i 8089' ÆRFORA TION SUMMARY REF LOG: GRlCCL ON 03/09/95 ANGLEATTOPÆRF: 73 @ 9135' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9135 - 9150 0 07/20/97 3-1/2" 4 9155 - 9170 0 04/19/97 3-3/8" 4 9214 - 9380 OIC 05/28/96 3-3/8" 4 9420 - 9630 C 05/28/96 3-3/8" 4 9660 - 9810 C 05/28/96 I TOP OF CEMENT 1'1 8563' [ 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9304' DATE 12/79 10/03/94 03/14/01 03/15/01 07/20/01 J-01A ~ SAFL ')OTES: 8 2102' r4-1I2" OTIS HXO SSSV NIP, ID = 3.813" I ~ l ST MD lVD 4 4191 4114 3 6821 6743 2 7780 7723 1 7886 7829 GAS LIFT MANDRELS DEV ïYÆ VLV LATCH 1 OTIS RA 2 OTIS RA 1 OTIS RA 1 OTIS RA PORT DATE I I 7954' rI4-1/2" OTIS X NIP, ID = 3.813" 1 Z ~ 8019' rI9-5/8" x 4-1/2" TWV HBBP-R PKR, ID = 4.0" I ~ ~ 8055' rI4-1/2" OTIS X NIP, ID = 3.813" I 8072' rI4-1/2" OTIS XN NIP, ID = 3,725"1 8084' rI4-1/2" WLEG, ID = 3.958" I .. I 8100' 1-1 ELMD TI 03/09/951 MILLOUT WINDOW - 8558' - 8618' ~ 1'13-3/8" BAKER IBP PLUG I PBTD l-i 9817' 1 5-1/2" LNR, 17#. L-80, 0,0232 bpf, ID = 4.892" l-i 9900' REV BY DA TE REV BY COMMENTS ORIGINAL COMPLETION MOO SIDETRACK COMPLETION SIS-QAA CONVERTED TO CANVAS SIS-MD FINAL RN/TP CORRECTIONS COMMENTS PRUDHOE BAY UNIT WELL: J-01A PERMIT No: 1941110 API No: 50-029-20020-01 SEC9, T11N, R13E BP Exploration (Alaska) TREÈ = 4" CAMERON WELLHEAD = CAMERON 'Ã-êTüATÕRN;--'^W~"'-ãAKER Kif ELer;;;-_'m_'___^''"77~2-5; 'B"i=:"Ëléi;;""'"'''''' '3a:';f "KOP = ---~'---ã66'2" Max Angle = 90 @ 9386' Datum MD = -'.""'-"-8894' "õãtüñî'wI5";""',o...... ¿söÖö'SS ) 13-3/8" CSG, 68#,10 = 12.415" 1-1 4258' ~ Minimum ID = 3.725" @ 8072' 4-1/2" OTIS XN NIPPLE (Nipple Milled to 3.8"ID) 1 3.5" XN Nip - 2.75" 10 1-1 8040' 14-1/2" TBG, 12,6#, L-80, 0.0152 bpf,lO = 3,958" 1-1 8084' 1 1 TOP OF 5-1/2" LNR 1-1 8089' 1 1 TOP OF CEMENT 1-1 8563' 1 I 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9304' PERFORATION SUMMARY REF LOG: GRlCCL ON 03/09/95 ANGLE AT TOP PERF: 73 @ 9135' Note: Refer to Production DB for historical perf data - SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9135 - 9150 isolated proposed 3-1/2" 4 9155 - 9170 isolated proposed 3-3/8" 4 9214 - 9380 isolated proposed 3-3/8" 4 9420 - 9630 isolated proposed 3-3/8" 4 9660 - 9810 Isolated proposed I 5-1/2" LNR, 17#, L-80, 0.0232 bpf, Ð = 4.892" H 9900' 1 DATE 12/79 10/03/94 03/14/01 03/15/01 07120/01 COMtÆNTS ORIGINAL COMR.ETION MOO SIDETRACK COM'lETlON SIS-QAA CONVERTED TO CANVAS SJS..MD FINAL RN/TP CORRECTIONS DATE REV BY REV BY J-01 B Proposed cro Sidetrack 8 ~ l 1 1 r~ri I :8: I ~ .. I L--- SAF ') ')TES: 2102' 1-14-1/2" OTIS HXO SSSV NIP, 10 = 3,813" 1 ST MO TVO 4 4191 4114 3 6821 6743 2 7780 7723 1 7886 7829 GAS LIFT MANDRELS OEV TYPE VLV LATCH 1 OTIS RA 2 OTIS RA 1 OTIS RA 1 OTIS RA PORT OA TE 7954' 1-14-1/2" OTIS X NIP, 10 = 3.813" 1 ) 8019' 1-19-5/8" x 4-1/2" TIN HBBP-R PKR, 10 = 4.0" 1 8030' 1-1 Top of 3-3/16" Liner 8055' 1-14-1/2" OTIS X NIP, 10 = 3.813" 1 8072' 1-14-1/2" OTIS XN NIP, ID = 3.725"1 8084' 1-14-1/2" WLEG, ID = 3.958" 1 8100' 1-1 ELMO TT 03/09/951 MILLOUT WINOOW - 8558' - 8618' $CO'/" ~ 8J8r 1-1 Top of Cement I 9200' 1-13-3/16 x 2-7/8 X-over II' .----. ",----, ) I r ! i.', ..:, ~ 3-3116' X 2-718' crrfed and perfed H 10875' I . Pt ~ 8830' 1-1 Mechanical Whipstock 1 ~ 9300' H 3-318" BAKER BP PLUG I - COMMENTS I PBTD 1-1 9817' PRUDHOE BAY UNIT WELL: J-01A PERMIT No: 1941110 API No: 50-029-20020-01 SEC9, T11N, R13E BP Exploration (Alaska) BP Amoco p.,.nt Wellp.thl T" Oft MOl ft.' R.f. OIItumt WIILLPATH I18TAlLS PIa.1I4 J.cI1. .002.2002002 .I.o1A ..22.00 2 .01 .12311884 00100 77.2lft V~o,: ~11~ ~~ 111.00' 0,00 0.00 ::::I;t.o 0,00 REFERENCE INFORMATION Co-ordinate ~E¡ Reference: Well Centre: J-Q1, True North V~c¡f~n (Vg¡ ~:¡:~:~~: ~r~t~~; roeg8rJ.~~)el Measured Depth Reference: 2: 01 9/23/1994 00:00 77.25 Calculation Method: Minimum Curvature 8.CTlON DITAIU 8M MD Inc All TVD 1 8822.00 21.78 :Me.'" 87H.II 2 8810.00 22.10 348.18 .7a.H " ..10.00 24.40 351.3. "82.21 .. noo.oo M.. 8.27 Mos.H . 8188.10 eo.OO D.:tO 8N8.7t 8 83U.JO 80.00 "411.80 ''''''71 7 ""3.10 80.00 1n.10 """'" . Ml8.1O 80.00 '.,10 "".11 . 8808.10...28 "17.71 ......08 10 80.00 ".70 88..08 11 .1'." ....00 8818.88 1. 80.00 112.07 "4e1.18 U 80.00 88.t7 --11 ... 1043 80.00 t""7 -..0.1. 'II 10111.70 ...41 108.". aNt... if U""'OO 11-78 .....07 n401.00 ANHOTATIOHS 1'VD MD AIt.outioll sn.... "22,00 TIP 87.2,88 ..20AO KOP 87.1.2. .810.00 1 "01.21 '100.00 2 ,"'.71 "",20 3 '''',71 '212,20 . '''',71 ..13.20 . '''',71 '''',20 . ''"-0' .101.20 7 '82'.0' ,....,2 . 1t2'''' "",12 . ,"'.18 10Ot',70 10 :~.:: ::!t::~: :: 11 ,,,,... 10"'.70 13 ,. ......0 '!..7..00 TO +IIJ.W DLe. TF8ce vsec Tar.et ~1.24 ,".23 0.00 0.00 -51.27 ...28 ....82 17.70 340.18 -12.88 -0.32 -81.24 ..00 41.00 .87.08 24.70 .eG.40 30.00 45.00 ..5.24 tn.72 1M.02 30.00 85.20 84.01 H.H aa.. 30.00 10.00 H1.15 .3.43 313.20 12.00 -10.00 283.82 48.12 340.88 12.00 10.00 331.88 -1U.I. "'-.to 12.00 ....00 484.'11 .2<11.07 817.10 12.00 282,00 "'.8' ::~: =::: ~::: 28'::: ~: -3U.17 101...40 12.00 270.00 1058.28 .H2.87 121T.M 12.00 80.00 1277.31 ....,.85 1328.18 12.00 284&.00 1401.21 '''''12 "'7f.M faGO Mr."" tf9(\.I1 TARGET DETAILS Name TVD +N/-S +EJ.W Shap$ ~~!~.1 :~.: i~:~ m:H ær J.{)1B T43 8950.00 -644.68 1~1.38 POint 7700--¡--- - 91 O()-~ S i ¡ 920(}--- j . - - 1 -III! I I II -700 -600 -500 bp LEGEND - J-01 (J-01) J-01 (J-01A) - J-25 (J-25) - Plan#4 J-01B - Plan #4 T ^M ¿ Direct: (907) 267-6613 E-mail: brij.potnis@inteq.com Baker Hughes INTEQ: (907) 267-6600 Plan: Plan #4 (J-01/Plan#4 J-01B) Created By: Brij Potnis Date: 9/19/2002 Azimuths to True North Magnetic North: 26.02° Stre~~~~~~~~}~~ Dip Angle: 80.81° Date: 9/19/2002 Model: BGGM2002 Contact Information: INXEQ - c i 0 t:a.100 - - + --200 ! 0 -300 - ~ - "i"-400 - - .c ~ -500 0 en -600 -- -- , II~ I I 0 I -11-- 1 - -l--I-- ! I ) I I I - -- - - J ------ --- --- '-I ~tl I I I I , I ,t~11 ~-t.n: ! ~,-,l ~I~-, I~ ll~ ,~~1, I I ,~I'I I I 200 400 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 West(-)/East(+) [100ft/in] 9/19/2002 11 :22 AM '-.......,,/ ........,-' ) ) . l~tJtéa BP Baker Hughes INTEQ Planning Report D.te::~11912Q02. '. .. Tim~:>t1:22:27 . Ç~~'diliat~)R*~e~: ..W~lk.J~01..T~N()rth . Yø~~.(l':VP)::R~~~çê: .' . ;~~rn:~?~~~~evel . . ~QIl(V.~)~efe,!n~:,. ,'\'V~t(~~90N~O~OOIE~t11;oOAzO.. : SnrveyçalçuljítìoBl\<ie~b94:. . MiriimûmCurvature '. Db: COR:lpany: Fiêld: Sitê:. . WeD: Wellpatb: . Field: BP Amoco Pl'\Jdh~.~y PBJ ;Pad 'J~01 . PlaO#4J;;01B Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level PB J Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0,00 ft Ground Level: 0.00 ft Site: J-01 J-01 Well Position: Well: p~~: 1 Oracfe Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 5968224.22 ft 641155,79 ft Latitude: Longitude: North Reference: Grid Convergence: 70 19 14.845 N 148 51 20.092 W True 1,08 deg Slot Name: 01 70 19 37.789 N 148 50 21.844 W +N/-S 2333.20 ft Northing: 5970594.35 ft Latitude: +E/-W 1995.35 ft Easting: 643106.75 ft Longitude: Position Uncertainty: 0,00 ft Wellpath: Plan#4 J-01B 500292002002 Current Datum: 2 : 01 9/23/199400:00 Magnetic Data: 9/19/2002 Field Strength: 57527 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Name Description Dip. Dir. J-O 1 B Polygon4.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 J-01 B T 4.2 TVD ft 0,00 0,00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 8935,00 J-01 B T4.1 J-01B T4,3 8950.00 8950.00 Annotation Height 77.25 ft Drilled From: Tie-on Depth: Above System Datum: Dedination: Mag Dip Angle: +E/-W ft 0.00 J-01A 8822,00 ft Mean Sea Level 26.02 deg 80.81 deg Direction deg 111.00 +N/-S ft 0.00 Ma:p.. Map.. <:~~ ..Latitude. --?'. . h:LOngitgde--> +Nj..S +Ef-W Nort~i~g E~sting ,Degl\iin ..' ...~. DegMÎll .Sec ft ft ft ft -249,25 253.56 5970350.00 643365.00 70 19 35.338 N 148 50 14,443 W -249.25 253.56 5970350.00 643365.00 70 19 35.338 N 148 50 14.443 W -351.16 876.78 5970260.00 643990.00 70 19 34,335 N 148 49 56.251 W -432.35 1200.31 5970185.00 644315.00 70 19 33.536 N 148 49 46,807 W -799.76 1583.40 5969824.99 644705.00 70 19 29,922 N 148 49 35,627 W -534.50 1573.46 5970090.00 644690.00 70 19 32,531 N 148 49 35,916 W -328,32 1252.31 5970290.00 644365,00 70 19 34.559 N 148 49 45.289 W -242.41 943.87 5970370.00 644055.00 70 19 35.405 N 148 49 54,292 W 5.34 278,42 5970605.00 643385,00 70 19 37,842 N 148 50 13,717 W -230.93 604,00 5970375.00 643715.00 70 19 35.518 N 148 50 4,213 W 123,38 120.63 5970720.00 643225,00 70 19 39.003 N 148 50 18,323 W -644.68 1581,36 5969980.00 644700,00 70 19 31,447 N 148 49 35.686 W 8822,00 8830.00 8850,00 8900,00 9188.20 9363.20 9413,20 9458,20 9608,20 9844,12 9919,12 8736.55 8743.95 8762.25 8805.36 8949.71 8949,71 8949.71 8949.71 8944,06 8935.05 8936.58 TIP KOP 1 2 3 4 5 6 7 8 9 ) ") BP Baker Hughes INTEQ Planning Report '~"J'i(i Company: BP AmoCo ',Date: < 9/19/2002 Tune: 11:22:27 Page: 2 FreId: ptu(jhoeBay ~f'''nåte(NE)Rerereltçei W~I';',J-01.Trt)~N<>rth Site: PRJ Pad ,Ve""~'(l'~D).~efer~~œ: " ;Sy~erntM~nS~kÌlevel'. Wen: J-01 Stiçtjol1(v~l R~~r~~; . , .VVelt(9.0QN~P1905..111.QOAii) Wellpath: Plan#4J.-01B SÙrVeyCåí~.ulåtion::M~od:: .Minimum,Curvafure' Db: Oracle Annotation MD TVD. ft ft 10095,70 8940.19 10 10210,70 8940.19 11 10430,70 8940.19 12 10555.70 8941.89 13 10875.00 8949.90 TD Plan: Plan #4 Date Composed: 9/19/2002 Identical to Lamar's Plan #4 Version: 4 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Aziin TVD' +N/-S +El.W DLS' Build' TJlI'Ø T.FO' Target ft deg d~ ft, ft ft cteijl10,OftdegI100~.ctegl~OOft. d~ 8822,00 21.76 349.46 8736.55 -11.24 -59.23 0.00 0.00 0.00 0,00 8830,00 23.10 348.26 8743,95 -8.25 -59.82 17.70 16.75 -15.00 340.58 8850.00 24.40 351,34 8762.25 -0.32 -61,24 9.00 6,52 15.41 45,00 8900,00 36.49 9.27 8805.36 24.70 -60.40 30.00 24,16 35.85 45.00 9188,20 90.00 93,30 8949.71 119.72 136.02 30.00 18.57 29.16 85.20 9363,20 90.00 145.80 8949.71 36.38 282.98 30.00 0.00 30.00 90.00 9413,20 90,00 139.80 8949,71 -3,43 313.20 12.00 0,00 -12.00 -90,00 9458.20 90,00 145,20 8949.71 -39,12 340,58 12.00 0,00 12.00 90,00 9608.20 94.29 127.71 8944.06 -147.34 443.40 12.00 2.86 -11.67 284.00 9844,12 90.00 99.70 8935.05 -241.07 657.10 12.00 -1.82 -11.87 262.00 9919.12 87.68 91.00 8936.58 -248.05 731.68 12.00 -3.09 -11.60 255,00 10095,70 90,00 112.07 8940.19 -283.15 903.68 12.00 1.31 11.93 84.00 10210,70 90,00 98,27 8940.19 -313,17 1014.40 12.00 0.00 -12.00 270.00 10430.70 90.00 124.67 8940.19 -392.97 1217.34 12,00 0.00 12.00 90.00 10555.70 88,45 109.74 8941,89 -449.95 1328,18 12.00 -1.24 -11.94 264,00 10875.00 88.78 148,07 8949.90 -646.72 1571.96 12.00 0,10 12,00 90,00 Survey MD Ind Azim SSTVD N/S. E/W MapN M~pE VS DLS TFO Tool ft deg deg ft ft ft ft .ft ft deg/' OOft deg 8822.00 21.76 349,46 8736,55 -11.24 -59,23 5970581.98 643047.75 -51.27 0.00 0,00 TIP 8825.00 22,26 348.99 8739.33 -10,14 -59.44 5970583.08 643047.52 -51.86 17.70 340.58 MWD 8830,00 23.10 348.26 8743.95 -8.25 -59.82 5970584,96 643047,10 -52,89 17.70 341,01 KOP 8850.00 24.40 351.34 8762,25 -0.32 -61,24 5970592.86 643045.53 -57,06 9,00 45,00 1 8875.00 30.15 1,93 8784.48 11,08 -61.81 5970604.24 643044.75 -61,67 30,00 45.00 MWD 8900.00 36.49 9.27 8805,36 24.70 -60.40 5970617,90 643045,90 -65,24 ~O.OO 35.57 2 8925,00 37,76 21,53 8825.33 39.18 -56,39 5970632.45 643049.63 -66,68 30.00 85.20 MWD 8950.00 40.21 32.82 8844.78 53.10 -49,20 5970646.50 643056.56 -64.96 30,00 75.41 MWD 8975,00 43.63 42.81 8863.40 66.23 -38.95 5970659,82 643066,56 -60,09 30.00 66,62 MWD 9000,00 47.82 51.51 8880,87 78.34 -25,81 5970672,18 643079.45 -52,17 30.00 59,17 MWD 9025.00 52,59 59.06 8896.88 89.22 -10.02 5970683.36 643095.03 -41.33 30,00 53,09 MWD 9050.00 57,77 65.67 8911.16 98.70 8.15 5970693,18 643113,02 -27,76 30.00 48,25 MWD 9075,00 63.26 71.55 8923.47 106.60 28.41 5970701,46 643133.12 -11.68 30,00 44.47 MWD 9100.00 68.97 76,87 8933.60 112.79 50.39 5970708.07 643154.98 6.62 30,00 41,57 MWD 9104.00 69.90 77.69 8935.00 113.61 54.04 5970708,96 643158.61 9,74 30.00 39,41 J-01B T4 9125,00 74.83 81,80 8941.36 117.16 73.73 5970712.89 643178.23 26,84 30,00 39.12 MWD 9150.00 80,79 86.46 8946.64 119.65 98.02 5970715.84 643202.46 48.63 30.00 37.87 MWD 9175.00 86.81 90.96 8949.34 120.21 122,85 5970716.87 643227.28 71.61 30,00 36.89 MWD 9188,20 90.00 93.30 8949.71 119.72 136.02 5970716.63 643240.46 84.09 30.00 36,40 3 9200.00 90,00 96.85 8949.71 118.67 147.78 5970715.81 643252.23 95.44 30.00 90,00 MWD 9225,00 90.00 104,35 8949.71 114.08 172.34 5970711.69 643276.87 120.01 30.00 90.00 MWD 9250.00 90,00 111.85 8949.71 106.32 196.08 5970704,38 643300,76 144,96 30.00 90,00 MWD 9275.00 90.00 119.35 8949.71 95.53 218.61 5970694.02 643323.49 169.86 30.00 90.00 MWD 9300,00 90.00 126.85 8949.71 81.88 239.54 5970680.78 643344.67 194.29 30.00 90.00 MWD 9325.00 90.00 134.35 8949.71 65,63 258.51 5970664.89 643363,95 217.82 30.00 90.00 MWD ) BP ..'8 .~ Baker Hughes INTEQ Planning Report .''''.~---'''.''---''--'--- IN'fEQ Co¡npâny: BPAmoCQ , Date::~l19/2002 , " . 'riilte:;1i:~2:21 ' Pågê: FÏèld: PrQ(lhQE!!:eay . 'P~~~4~~)r<~~~.æêi. ' '~~lhJ~Ol;Tru~:.Nþt'th Site; P6'J.Pad - VerticáJ:(T\fPlltêfe~~œ: ' '. - Sÿ~~Ørn:.Mean~~~\l~t' . ' Wen: J-O.l ~~oß(V~)~efeœttte: " .. WØlI,,(O:QQN;g~QQE;111~()()~i) Wellpat..: Plan#4 J-018 S.urVeyCalçu~tiønl\f~4: ' MiriimurnCurvature' 'Db: Oracle Survey MD loCI Aiiln SSTVD N/S EIW l\fapN MapE vs DLS TFO Tool ft deg deg ft It ft ,'ft ft ft , d~gf100ft deg 9350.00 90.00 141.85 8949.71 47.03 275.20 5970646.62 643380.98 240.06 30.00 90.00 MWD 9363.20 90,00 145.80 8949.71 36.38 282.98 5970636.12 643388.97 251,15 30.00 90.00 4 9375.00 90.00 144.39 8949.71 26.70 289.74 5970626,57 643395.91 260.92 12,00 270.00 MWD 9400.00 90.00 141.39 8949.71 6.77 304.82 5970606.93 643411,37 282.15 12.00 270.00 MWD 9413.20 90,00 139.80 8949.71 -3.43 313.20 5970596.90 643419,94 293.62 12,00 270,00 5 9425.00 90.00 141.22 8949.71 -12.54 320.70 5970587.93 643427.61 303.90 12,00 90.00 MWD 9450.00 90,00 144.22 8949.71 -32.43 335.84 5970568.34 643443.13 325.16 12,00 90.00 MWD 9458.20 90.00 145.20 8949.71 -39,12 340.58 5970561,74 643447.99 331,98 12.00 90.00 6 9475.00 90.49 143.25 8949,64 -52.75 350.40 5970548,30 643458,07 346.03 12.00 284,00 MWD 9500,00 91.21 140.34 8949.27 -72.39 365,86 5970528.96 643473,90 367.50 12,00 283,99 MWD 9525.00 91,93 137.42 8948.58 -91,21 382.29 5970510.45 643490.69 389.59 12,00 283.95 MWD 9550.00 92,65 134.51 8947.58 -109.17 399.66 5970492.83 643508.39 412.23 12.00 283.87 MWD 9575,00 93.36 131,59 8946.27 -126,21 417.90 5970476.14 643526,95 435.37 12.00 283.75 MWD 9600,00 94.06 128.67 8944.65 -142.29 436,97 5970460.43 643546,33 458.94 12,00 283,60 MWD 9608.20 94.29 127.71 8944.06 -147.34 443.40 5970455.51 643552.85 466,75 12.00 283,41 7 9625.00 94,00 125.70 8942.84 -157,36 456.83 5970445.75 643566.47 482.88 12.00 262.00 MWD 9650.00 93.57 122.73 8941.19 -171.38 477.46 5970432.12 643587,36 507.16 12,00 261,86 MWD 9675,00 93.13 119.76 8939,73 -184.33 498.79 5970419.59 643608,93 531.72 12,00 261,66 MWD 9700.00 92.69 116.79 8938.46 -196.15 520.78 5970408.18 643631.14 556.48 12,00 261.48 MWD 9725.00 92.23 113.82 8937.38 -206.82 543.36 5970397.94 643653.92 581,39 12,00 261.33 MWD 9750,00 91.77 110.85 8936.51 -216,32 566.47 5970388.89 643677,20 606.36 12,00 261.21 MWD 9775,00 91.30 107.89 8935.84 -224.60 590.04 5970381.06 643700.92 631.34 12,00 261.10 MWD 9800.00 90,83 104.92 8935.38 -231.66 614.01 5970374.46 643725.03 656.25 12.00 261.02 MWD 9825.00 90,36 101.96 8935.11 -237.47 638,33 5970369,11 643749.44 681.03 12.00 260.97 MWD 9844,12 90.00 99.70 8935,05 -241.07 657,10 5970365.88 643768,28 699.85 12,00 260,94 8 9850.00 89.82 99.01 8935.06 -242,02 662.91 5970365.03 643774.10 705,61 12.00 255.00 MWD 9875.00 89,04 96,12 8935.31 -245.31 687.68 5970362.22 643798.94 729.92 12.00 255.00 MWD 9900.00 88.27 93.22 8935,90 -247.35 712.59 5970360,66 643823.88 753.90 12,00 255,03 MWD 9919,12 87.68 91.00 8936,58 -248.05 731.68 5970360,32 643842.98 771,98 12,00 255,10 9 9925.00 87.75 91.70 8936.81 -248,19 737.56 5970360.30 643848.86 777.51 12.00 84.00 MWD 9950,00 88.07 94.69 8937.72 -249.58 762.50 5970359,38 643873,82 801,30 12.00 83,97 MWD 9975,00 88.39 97.67 8938.49 -252.27 787.34 5970357.17 643898.70 825.45 12,00 83,86 MWD 10000,00 88.72 100.65 8939.12 -256.25 812,01 5970353.66 643923.44 849.91 12.00 83.77 MWD 10025.00 89,05 103.63 8939.61 -261.50 836.44 5970348.87 643947.97 874.60 12.00 83.70 MWD 10050.00 89.39 106.62 8939,95 -268.02 860.57 5970342,81 643972.22 899,47 12.00 83,64 MWD 10075.00 89.72 109.60 8940.14 -275,79 884,33 5970335.49 643996.12 924.43 12.00 83,60 MWD 10095.70 90.00 112.07 8940,19 -283.15 903.68 5970328.50 644015.60 945,13 12.00 83.57 10 10100.00 90.00 111.55 8940,19 -284.75 907.67 5970326,98 644019,62 949.43 12.00 270.00 MWD 10125,00 90.00 108,55 8940,19 -293,32 931.15 5970318.86 644043.26 974.42 12,00 270,00 MWD 10150.00 90.00 105,55 8940.19 -300,65 955,05 5970311.99 644067.29 999.36 12.00 270,00 MWD 10175.00 90.00 102,55 8940,19 -306.72 979.30 5970306.39 644091,65 1024,17 12,00 270.00 MWD 10200,00 90.00 99,55 8940.19 -311,51 1003,83 5970302.07 644116.27 1048,79 12.00 270.00 MWD 10210,70 90.00 98.27 8940.19 -313.17 1014.40 5970300,61 644126,87 1059.26 12.00 270,00 11 10225.00 90.00 99.98 8940,19 -315.44 1028.52 5970298.61 644141.03 1073.25 12.00 90.00 MWD 10250,00 90,00 102,98 8940,19 -320.41 1053.02 5970294.11 644165.61 1097,90 12,00 90.00 MWD 10275.00 90.00 105.98 8940,19 -326.66 1077,22 5970288.32 644189.93 1122.74 12.00 90.00 MWD 10300.00 90.00 108,98 8940.19 -334,17 1101.06 5970281.27 644213.91 1147.69 12.00 90.00 MWD 10325.00 90,00 111,98 8940.19 -342.92 1124.48 5970272.97 644237.49 1172.68 12.00 90.00 MWD 10350.00 90.00 114.98 8940,19 -352.88 1147,41 5970263.45 644260.60 1197.66 12.00 90.00 MWD 10375,00 90.00 117 ,98 8940.19 -364.03 1169.78 5970252.73 644283.18 1222.54 12.00 90.00 MWD 10400.00 90.00 120.98 8940,19 -376.33 1191.54 5970240,85 644305.17 1247,27 12,00 90.00 MWD 10425.00 90.00 123.98 8940.19 -389,75 1212.63 5970227.83 644326.50 1271.76 12.00 90,00 MWD ') BP ') Baker Hughes INTEQ Planning Report I~~~d BP Arnoco . . Ti....,:":.11.;22:27 COJDpany: J>â~; ..... .' 9/1:9/2002 Fièld: Prudhoe Bay .' ,Ç();or.dinåu(NE)~êf~Ii~:.. WøJ;.J~l,T(UêN()rth . Site: PBJPad Yertical{rY~)ae~erèQ~::: S~~~m:.f\I1èé1n Sea. Lêvel WèD: J:'01 $eetioíf(VS)Rerè~nce: Well(Q;O()N~O.OOE, 111 :OO~i) WeDpatb: Plan#4J"Ù1 B Survey Calcidation.~~thOd:' Minhnun'i Curvaturê Db:. Graefe Survey MD loel Azini SSTYD N/S EIW MapN Ma¡í~. ys ])JjS TFO ft deg deg. ft ft It ft ft ;. It d~g/100ft : <leg 10430.70 90,00 124.67 8940.19 -392,97 1217.34 5970224.70 644331.27 1277.31 12,00 90.00 12 10450,00 89.76 122,36 8940.23 -403.62 1233.43 5970214.36 644347.56 1296.15 12.00 264.00 MWD 10475.00 89.45 119.38 8940.41 -416.45 1254.88 5970201,94 644369.25 1320.78 12.00 264.00 MWD 10500.00 89.13 116.39 8940,72 -428.14 1276.97 5970190,68 644391.56 1345.59 12,00 264.03 MWD 10525.00 88.82 113.41 8941.16 -438.66 1299.64 5970180.59 644414.43 1370,53 12.00 264.06 MWD 10550,00 88,52 110,43 8941.74 -447.99 1322.83 5970171.70 644437,78 1395.51 12.00 264.12 MWD 10555.70 88.45 109.74 8941.89 -449.95 1328.18 5970169.85 644443.17 1401.21 12,00 264,19 13 10575.00 88.45 112.06 8942.41 -456.83 1346.20 5970163.31 644461.32 1420.50 12,00 90,00 MWD 10600.00 88.46 115.06 8943.09 -466.82 1369.11 5970153,76 644484.41 1445.46 12.00 89.94 MWD 10625.00 88.47 118.06 8943.76 -477,99 1391.46 5970143.02 644506,97 1470,33 12.00 89.86 MWD 10650,00 88,48 121,06 8944.43 -490.32 1413.19 5970131.11 644528.93 1495.04 12,00 89.78 MWD 10675.00 88,50 124.07 8945.09 -503.77 1434.25 5970118.06 644550.24 1519.53 12,00 89,70 MWD 10700.00 88,52 127.07 8945.74 -518.31 1454,58 5970103,92 644570.84 1543.71 12,00 89,62 MWD 10725,00 88.55 130.07 8946.38 -533.89 1474.12 5970088,72 644590.67 1567,53 12.00 89.54 MWD 10750.00 88.58 133,07 8947.01 -550.47 1492.81 5970072.50 644609.68 1590,93 12,00 89.46 MWD 10775.00 88,61 136,07 8947.62 -568,00 1510.62 5970055.30 644627.81 1613.84 12,00 89,39 MWD 10800.00 88,65 139.07 8948.22 -586.45 1527.48 5970037.18 644645.02 1636.19 12.00 89.31 MWD 10825.00 88.69 142.07 8948.80 -605,75 1543.35 5970018,19 644661.26 1657.92 12,00 89,24 MWD 10850.00 88.74 145,07 8949.36 -625,86 1558.19 5969998.37 644676.48 1678.98 12,00 89,17 MWD 10875.00 88,78 148,07 8949.90 -646.72 1571,96 5969977.78 644690.64 1699,31 12,00 89,10 TD ) ) All Measurements are from top of Riser 6/6/2002 ~ Q) C/) .- ~ top of bag BAG bttm of bag middle of slips Blind/Shears ~, TOTs ~~ middle of pipes 2 3/8" combi ram/slips ............... .... -...... ~ ,--,. middle of flow cross Mud Cross Mud Cross -- '--' middle of pipe/slips 2 3/8" combi ram/slips '" ........ '... ,.... .... TOTs / ...."" ...... .... -... middle of blind/shears variable bore pipe 3 1/2".2 7/8" Flow Tee ~. ",-....., H DATE CHECK NO. 8/01/02 H207051 VENDOR DISCOUNT NET H $100.00 207051 DATE GROSS INVOICE I CREDIT MEMO DESCRIPTION 8/01/02 CK073102R Permit To Dri:1 Fee R!£E 'V ED J-Olß PIs contact SondraStewman X4750 for check pickup SEP 24'2002 Alaska OB& GasGors. GommIsSIon Anchor2ge THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ $100.00 FIRST NATIONAL BANK OF ASHLAND AN AI=FlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 ~***Au~. 1, 2002** *****$100.00**~**** TO THE ORDER OF Alaska Oil & Gas Conservation Corom ,333 W 7th Ave, Ste 100 Anchorage, AK 99501 C\::. ~'\':::::'::::::\~:::{;:)X.~.~~~.~t: ~.i~:~:: ~ ~.t~~\ " .:. :"; .:.:::.¿¡£~~.. ::..;:.....(\...~: .....: ~.....::..... ~{i.t:'t¿{~~Ú~;;.~~:;;;~~~7(,~ . NOT VALID AFTER 12Ò DAYS ~, 118 20 ?O 5 ~II' ':0 it ~ 20 ~8 q 51: 008 it... ~ qll8 ) ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME h/4 PTD# 2oz--.2o) CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) paOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates v: 0/.8 "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original.API number. stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (SO 70/80) from records, data and logs acquired for well (name on permit). . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuànce of a conservation order approving a spacing . exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. PROGRAM: Exp - Dev~ Redrll X Re-Enter - Serv - Wellbore seg - GEOLAREA ~?A UNIT# /(b.~t1 ON/OFF SHORE aN ,... Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N U ~-'.¡;:¡. '¥-N- -Y N Y N' AlIA-- --¥--N- ~~ CID¿{ ¥þ~ Y N ¡.tIlt ~ N ~ P1 ¡J :g, 7 PM . a2 ~ MSr ?l) Cjf.{ fk. æN Œ/N ~~~~. y@ ~~ /IJ,A. J~ WELL PERMIT CHECKLIST COMPANY A;P X WELL NAME.lifq V- 0 I ¡f FIELD & POOL 6~¿)/ ..5' ó INIT CLASS ~II>..i / -~.: / 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.. . . . . . . . . APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . dh~ 0./ - .¿<> 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . /JlC-- ~~ 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.. . . . . (Service Well Only) 13. Well located w/in area & strata authorized by injection order#-- (Service Well Only) 14. All wells w/in X mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE \"-' 4 ~ "I ~ol 0 L. (Service Well Only) GEOLOGY APPR DATE J</f' ~~ (Exploratory Only) 15. Conductor string provided. . . . . . . . . . . . -. . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol ádequate to circulate on conductor & surf csg. . . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . .. . 20~ Casing designs adequate for C, T, B & permafrost. . .. . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . . . . ; . . . 24. If diverter required, does it meet regulations. . . . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to '3500 psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable... . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . > GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Commentsllnstructions: RP£- TEM JDH~ JBR COT DTS WGA W~k MJW ~H r~//ø2.- Rev: 07/12/02 SFD- G:\geology\perm its\checklist.doc ) ) 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 simpltfy finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ,- ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 02 09:00:45 2003 Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/04/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS ) aœ-aOI / / b9r:( Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22181 D. RICHARDSO EGBEJIMBA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 AK-MW-22181 D. RICHARDSO EGBEJIMBA # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: MSL 0) Library. Scientific Technical Services J-01B 500292002002 BP Exploration Sperry Sun 02-APR-03 MWDRUN 2 AK-MW-22181 D. RICHARDSO EGBEJIMBA MWDRUN 5 AK-MW-22181 M. ALLEN SARBER 9 11N 13E 750 1245 56.90 .00 (Alaska) Inc. MWDRUN 3 AK-MW-22181 D. RICHARDSO EGBEJIMBA ) ) GROUND LEVEL: .00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.760 5.500 8647.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE J-01A WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT ABOUT 8646' MD / 8588' TVDSS. 4. MWD RUNS 1 - 5 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. UPHOLE TIE-IN DATA (SGRC) ARE INCLUDED WITH RUN 1 DATA. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN J-01B ON 15 SEPTEMBER 2002. LOG HEADER AND RUN INFORMATION DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 03 MARCH 2003. 9. MWD RUNS 1 - 5 REPRESENT WELL J-01B WITH API#: 50-029-20020-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10741'MD / 8952'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 clipped curves¡ all bit runs merged. .5000 START DEPTH 8484.5 8688.0 STOP DEPTH 10731.0 10758.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8484.5 8498.0 8501.0 GR 8464.5 8478.0 8480.5 ) 8507.5 8515.0 8518.0 8522.5 8545.0 8558.0 8561.5 8565.0 8576.0 8585.5 8588.5 8604.0 8621.5 8623.5 8626.5 8631.5 8639.5 8641.0 8643.0 8646.0 8671.5 8681.0 8696.5 8704.0 8711.0 8721.0 8755.0 8764.5 8783.5 8810.5 8819.5 8827.0 8831.5 8846.5 8850.0 8854.0 8864.5 8880.5 8882.0 8889.0 8893.0 8897.5 8912.0 8914.0 8920.0 8926.0 8929.0 8934.0 8937.5 8955.0 8959.5 8966.0 8971.5 8983.0 8991.0 9001.0 9013.0 9024.0 9028.0 9029.5 9042.0 9043.5 9058.0 9069.0 8487.5 8495.0 8498.0 8501.5 8524.0 8537.0 8542.0 8545.5 8556.0 8565.0 8568.5 8583.5 8601.5 8604.0 8608.0 8612.5 8620.0 8622.0 8625.0 8627.5 8655.0 8663.5 8679.5 8686.5 8693.5 8703.5 8738.0 8747.0 8764.5 8791.5 8799.5 8806.5 8811.5 8827.5 8830.5 8835.0 8845.0 8861.0 8862.0 8869.0 8873.0 8876.5 8890.5 8893.5 8900.0 8906.0 8908.5 8913.5 8917.5 8935.0 8940.0 8946.5 8952.0 8962.0 8971.0 8980.0 8992.5 9003.5 9006.5 9008.5 9022.0 9024.0 9038.5 9049.0 ) ) 9074.0 9055.0 9109.0 9090.5 9123.5 9104.5 9142.5 9125.0 9146.0 9127.5 9148.0 9128.5 9155.0 9135.0 9176.0 9156.5 9189.5 9169.5 9202.0 9180.5 9219.5 9200.0 9236.5 9218.5 9250.5 9231.5 9251.5 9233.0 9256.0 9237.0 9258.0 9239.0 9274.0 9252.5 9287.5 9268.0 9304.0 9285.5 9313.5 9294.5 9317.5 9299.0 9348.0 9329.5 9371.0 9351.5 9373.0 9354.0 9387.0 9367.5 9402.5 9383.0 9404.0 9385.5 9417.0 9398.0 9420.5 9401.0 9430.5 9412.0 9442.0 9422.5 9445.5 9427.0 9454.0 9435.5 9460.0 9441.0 9478.5 9459.5 9509.5 9491.0 9517.0 9498.0 9530.5 9510.5 9534.5 9513.5 9538.5 9518.0 9543.0 9523.0 9547.5 9528.0 9556.5 9535.5 9560.5 9540.5 9562.5 9542.0 9566.0 9548.5 9570.0 9552.0 9572.5 9554.0 9581.5 9563.0 9596.0 9576.5 9603.0 9583.5 9606.0 9586.5 9608.0 9589.5 9610.0 9592.0 9618.5 9599.0 9621.5 9602.5 9624.5 9605.5 9626.0 9608.0 9627.0 9610.0 9631.0 9614.0 9637.0 9619.0 9644.0 9626.0 9663.0 9645.5 9665.0 9647.0 ) ) 9673.0 9654.5 9683.5 9664.5 9691.0 9672.5 9711.5 9692.0 9724.5 9706.5 9733.5 9716.0 9750.5 9734.0 9759.5 9742.5 9773.0 9755.5 9786.0 9767.5 9796.0 9777.0 9819.5 9800.0 9860.5 9842.5 9870.0 9852.0 9876.0 9857.5 9882.5 9865.5 9899.5 9882.0 9921.0 9902.5 9937.5 9919.0 9950.0 9932.5 9956.0 9938.0 9959.5 9943.5 9964.0 9947.5 9974.5 9956.5 9987.5 9970.5 9992.0 9974.0 9994.5 9976.0 9998.5 9981.5 10004.0 9987.5 10044.0 10026.5 10076.0 10058.5 10083.0 10066.0 10103.0 10086.5 10112.5 10096.5 10115.5 10099.5 10121.0 10104.0 10147.0 10130.0 10159.5 10143.0 10174.0 10157.5 10175.0 10159.0 10213.0 10199.0 10216.5 10201.5 10249.5 10235.0 10257.0 10242.0 10265.5 10251.0 10274.0 10259.0 10280.0 10266.0 10299.0 10284.5 10302.5 10287.5 10312.5 10297.5 10321.0 10304.5 10330.5 10315.0 10332.0 10316.0 10339.0 10324.0 10344.5 10329.0 10349.0 10333.0 10367.0 10351.5 10376.5 10360.5 10380.0 10365.0 10388.5 10372.5 10393.5 10378.0 10407.5 10391.0 10411.0 10394.0 10414.0 10397.5 ) ") 10421.5 10439.5 10446.5 10453.0 10467.0 10488.5 10515.5 10518.5 10525.0 10530.0 10535.0 10549.0 10555.0 10575.5 10579.5 10598.5 10602.0 10620.0 10628.5 10641.0 10685.5 10691.5 10698.0 10699.0 10758.5 $ 10404.0 10420.0 10429.0 10436.5 10449.5 10471.0 10498.0 10501.0 10508.5 10513.0 10517.0 10533.0 10540.0 10560.0 10564.5 10583.5 10587.0 10603.0 10613.0 10625.0 10666.5 10672.5 10679.5 10681.0 10740.5 # MERGED DATA PBU TOOL MWD MWD MWD MWD MWD $ SOURCE CODE BIT RUN NO 1 2 3 4 5 MERGE TOP 8464.5 8747.0 9016.5 9111.5 10212.0 MERGE BASE 8774.0 9044.5 9139.0 10240.0 10740.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point........ .... ..Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8484.5 10758.5 9621.5 4549 8484.5 10758.5 ROP MWD FT/H 0.02 1984.85 90.4149 4142 8688 10758.5 GR MWD API 15.63 202.12 33.1571 4494 8484.5 10731 ) ') First Reading For Entire File......... .8484.5 Last Reading For Entire File.......... .10758.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/02 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. ..... .03/04/02 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR Rap $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 8464.5 8670.5 STOP DEPTH 8746.5 8774.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 18-NOV-02 Insite 4.3 Memory 8795.0 8470.0 8795.0 9.0 11.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.760 8647.0 # ') 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.....O Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point............. . Undefined Frame Spacing.... .... ...,........ .60 .1IN Max frames per record.. .......... . Undefined Absen t value. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') Flo Pro 9.00 65.0 9.0 18000 1.0 .000 .000 .000 .000 .0 141.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FTIH 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8464.5 8774 8619.25 620 8464.5 8774 ROP MWD010 FTIH 0.02 67.92 12.7901 208 8670.5 8774 GR MWD010 API 17.17 126.11 36.1767 565 8464.5 8746.5 First Reading For Entire File....... ...8464.5 Last Reading For Entire File......... ..8774 File Trailer Service name......... ... .STSLIB.002 Service Sub Level Name. . . Version Number. . . . . . .-. . . .1.0.0 Date of Generation. ..... .03/04/02 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...... .03/04/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 8747.0 8774.5 STOP DEPTH 9016.0 9044.5 # 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 GM Dual GR $ # 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: 19-NOV-02 Insite 4.3 Memory 9045.0 8795.0 9045.0 11.3 44.4 TOOL NUMBER 82758 3.760 8647.0 Flo Pro 8.70 65.0 7.4 24000 1.0 .000 .000 .000 .000 .0 141.4 .0 .0 ') ) MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units. ... ...... .Feet Data Reference Point......... .... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8747 9044.5 8895.75 596 8747 9044.5 ROP MWD020 FT/H 0.29 322.54 62.6844 541 8774.5 9044.5 GR MWD020 API 15.63 100.9 28.97 539 8747 9016 First Reading For Entire File......... .8747 Last Reading For Entire File.......... .9044.5 File Trailer Service name. ..... ...... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/02 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...... .03/04/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 ) RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ ) header data for each bit run in separate files. 3 .5000 START DEPTH 9016.5 9045.0 STOP DEPTH 9111.0 9139.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. .......... ......0 Data Specification Block Type.....O Logging Direction.. .............. . Down Optical log depth units.......... .Feet Data Reference Point....... ...... . Undefined 19-NOV-02 Insite 4.3 Memory 9139.0 9045.0 9139.0 60.8 81.3 TOOL NUMBER 69706 3.760 8647.0 Flo Pro 8.70 65.0 7.4 24000 1.0 .000 .000 .000 .000 .0 141.9 .0 .0 ) ) Frame Spacing............... ..... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9016.5 9139 9077.75 246 9016.5 9139 ROP MWD030 FT/H 0.12 138.99 77.7802 189 9045 9139 GR MWD030 API 20.83 67.53 28.4428 190 9016.5 9111 First Reading For Entire File......... .9016.5 Last Reading For Entire File......... ..9139 File Trailer Service name...... ...... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/02 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...... .03/04/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9111.5 ROP 9139.5 $ 5 header data for each bit run in separate files. 4 .5000 STOP DEPTH 10212.0 10240.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE 21-NOV-02 VERSION: Insite ') 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 GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER1S 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..................O Data Specification Block Type.....O Logging Direction...... .......... . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing..... ..... ..... ..... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 4.3 Memory 10240.0 9139.0 10240.0 84.9 94.7 TOOL NUMBER 69706 3.760 8647.0 Flo Pro 8.80 65.0 9.0 24000 8.6 .000 .000 .000 .000 .0 159.5 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam First Reading Last Reading ') DEPT FT ROP MWD040 FT/H GR MWD040 API 9111.5 0.32 17.87 10240 1984.85 202.12 9675.75 2258 94.9457 2202 36.2512 2202 9111.5 9139.5 9111.5 10240 10240 10212 First Reading For Entire File........ ..9111.5 Last Reading For Entire File.......... .10240 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/04/02 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...... .03/04/02 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 10212.0 10240.5 STOP DEPTH 10713.0 10740.5 # 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: 21-NOV-02 Insite 4.3 Memory 10741.0 10240.0 10741.0 87.5 90.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 # ) 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..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 3.760 8647.0 Flo Pro 8.80 65.0 8.5 23000 8.2 .000 .000 .000 .000 .0 166.1 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10212 10740.5 10476.3 1058 10212 10740.5 ROP MWD050 FT/H 7.74 520.58 118.14 1001 10240.5 10740.5 GR MWD050 API 17.62 73.82 28.0667 1003 10212 10713 First Reading For Entire File........ ..10212 Last Reading For Entire File.......... .10740.5 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... 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