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197-254
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 Q-03A Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-254 50-029-20322-01-00 10952 Conductor Surface Intermediate w/ tieb Liner Liner 9016 80 2646 8504 738 2353 9684 20" x 30" 13-3/8" 9-5/8" x 7-5/8" 7" 4-1/2" 9025 31 - 111 30 - 2676 28 - 8532 8004 - 8742 8597 - 10950 31 - 111 30 - 2673 28 - 8320 7792 - 8530 8385 - 9016 10210 470 2670 4760 7020 7500 9684 1490 4930 6870 8160 8430 9300 - 10850 4-1/2" 12.6# 13Cr80, L80 27 - 8604 9019 - 9011 Structural 4-1/2" Baker S3 Packer 8547, 8335 8407, 8547 8195, 8335 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 27 - 8392 N/A N/A 611 Well Not Online 69534 79 1400 650 1150 650 325-382 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S3 Packer 8407, 8195 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 8:57 am, Sep 10, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.10 08:09:22 - 08'00' Torin Roschinger (4662) RBDMS JSB 091625 DSR-9/11/25J.Lau 11/6/25 ACTIVITY DATE SUMMARY 8/6/2025 ***WELL SI ON ARRIVAL*** PULLED ROCK SCREEN FROM X NIPPLE @ 2126' MD ( ROCK SCREEN EMPTY) ***WELL SI ON DEPARTURE*** 8/27/2025 LRS CTU#2 1.75"CT 0.156"WT HT-110 Job Objective: Caliper, Ext Perf, Set CIBP MIRU, MU NS MHA and 3.60" DJN drift bha, Function test BOP, PT PCE 345 / 4260psi, L/K well w/ 239bbls 1% KCL w/ safelube, RIH with 3.60" drift nozzle BHA. Tagged at 10213 CTM. Paint flag for caliper run and POOH. Make up and RIH with HES 40-arm caliper. Log from just above tag to 7700'CTM flagging pipe for guns. POOH and kill well with 250bbl of 1% KCL. Pump across the top at MCHFR, well on 100% losses. Confirm -11.5' correction. Deploy 2-7/8"x257' MaxForce 6sfp, 60deg phasing, 17.5gr perf guns, RIH, correct depth at white flag, Perf interval 9393-9650'. POOH, pump 30bbls at 4.0bpm, lower rate to MCHFR, cont. POOH ***Continue on 8-28-25 WSR*** ***Bump test H2S/LEL sensors and place in wellhouse, pull test CTC against stripper brass, PT safety joint / TIW to 340 / 4260psi, Day and night crew performed well control drill for deploying the safety joint as well as the contingency of dropping the BHA, Confirmed BOS XO fit from perf guns to safety joint.*** 8/28/2025 LRS CTU #2 1.75"CT 1.56"WT HT-110 Job Objective: Caliper, Ext Perf, Set CIBP POOH w/ spent perf guns, pump MCHFR down CTBS. Flow check well at surface, well on 100% losses, continue pumping MCHFR throughout retrieval. Retrieve spent perf guns, all guns in scallops. RIH w/ NS 4-1/2" CIBP, correct depth at flag to Mid element at flag and set at 9684. Stack weight on plug to confirm set. Compare pre/post injectivity after plug set. POOH circing the well to diesel. Pad operator notified of well status. RDMO. ***Job Complete*** Daily Report of Well Operations PBU Q-03A 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU Q-03A Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-254 50-029-20322-01-00 341J ADL 0028281 10952 Conductor Surface Intermediate w/ tieback Liner Liner 9016 80 2646 8504 738 2353 10867 20" x 30" 13-3/8" 9-5/8" x 7-5/8" 7" 4-1/2" 9012 31 - 111 30 - 2676 28 - 8532 8004 - 8742 8597 - 10950 2620 31 - 111 30 - 2673 28 - 8320 7792 - 8530 8385 - 9016 10210 470 2670 4760 7020 7500 None 1490 4930 6870 8160 8430 9300 - 10850 4-1/2" 12.6# 13Cr80, L80 27 - 86049019 - 9011 Structural 4-1/2" Baker S3 Packer 4-1/2" Baker S3 Packer 8407, 8195 8547, 8335 Date: Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907.748.8581 PRUDHOE BAY 7/9/2025 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 11:03 am, Jun 25, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.25 10:53:23 - 08'00' Torin Roschinger (4662) 325-382 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 10-404 JJL 6/27/25 DSR-6/30/25A.Dewhurst 07JUL25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.07 15:20:02 -08'00'07/07/25 RBDMS JSB 070925 Page 1 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Well Name:Q-03A API Number:50-029-20322-01 Current Status:Ivishak Producer PTD #197-254 Estimated Start Date:7/10/2025 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:2,150 psi (4/9/2025) H2S Level (Most Recent / Highest):20ppm 02/09/2023, 25ppm 09/15/2017 History Q-03A is a natural flow Ivishak producer. The parent well was originally completed in 1978 with the well being sidetracked to its current location in 1998. The well was worked over in 2005 to replace the tubing with chrome 4.5”. The well is currently a cycle well, but the recharge is limited even with prolonged off cycles. With the limited on-time, the well has more potential by setting a plug and shooting additional Z2 perforations. Objective Isolate existing perforations behind a CIBP and shoot the next intervals of extended perforations. Page 2 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Procedure (Page 1 of 3) Slickline 1. Pull rock screen from 2126’ MD. a. Annotate contents in well service report. 2. Drift to deviation with ±3.70” gage ring and sample bailer. a. 2/21/2022 SL drifted with 3.70” dummy WRP to deviation of 9325’ MD. 3. Drift to deviation with 30’ 2-7/8” dummy guns. Coil Tubing 4. Perform GR/CCL/Caliper logging run from new TD to 7,800’ MD. Flag pipe. a. Liner is L80 ran in 1998 with moderate water production. Ensure liner is in reasonable shape. b. Send field print to OE, brenden.swensen@hilcorp.com Coil Tubing – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 5. 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. 6. Bullhead 1.2x wellbore volume ~170 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 = 142 bbls b. 4-1/2” tubing – 9,300’ X .0152 bpf = 142 bbls 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, 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. 9.*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. Page 3 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Procedure (Page 2 of 3) Coil Tubing – Extended Perforating 10. 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 2-7/8” MaxForce guns or similar Run Sand TOP MD BOT MD Total Order to Shoot Gross Interval Net Guns Weight of Gun (lbs) 1 Z2 9,393’9,650’257 1 257 257 ±3,187 lbs (12.4 ppf) 11. 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. 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 is dead. Kill well if necessary. 14. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 15. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. Page 4 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Procedure (Page 3 of 3) Coil Tubing 16. Set CIBP at ±9,680’ MD. a. CCL from tie in shows collar at 9,674’ MD. b. May adjust depths as necessary based on caliper data. c. Due to proximity to target perfs and risk of upsetting plug when shooting perforations, set plug after perforating. 17. RDMO CTU. 18. Turn well over to Operations POP. Slickline 19. Set rock screen in nipple at 2126’ MD. 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 5 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Page 6 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Page 7 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Tie In Log (Page 1 of 2) Page 8 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Tie In Log (Page 2 of 2) Perf ± 9,393 – 9,650’ (257’) Plug set ± 9,680’ Page 9 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 BOP Schematic Page 10 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Page 11 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 Page 12 of 12 Extended Add Perforation Well: Q-03A PTD: 197-254 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 Q-03A Cement Squeeze, Mill CIBPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-254 50-029-20322-01-00 10952 Conductor Surface Intermediate w/ tieb Liner Liner 9016 80 2646 8504 738 2353 10867 20" x 30" 13-3/8" 9-5/8" x 7-5/8" 7" 4-1/2" 9012 31 - 111 30 - 2676 28 - 8532 8004 - 8742 8597 - 10950 31 - 111 30 - 2673 28 - 8320 7792 - 8530 8385 - 9016 10210 470 2670 4760 7020 7500 None 1490 4930 6870 8160 8430 9300 - 10850 4-1/2" 12.6# 13Cr80, L80 27 - 8604 9019 - 9011 Structural 4-1/2" Baker S3 Packer 8547, 8335 8407, 8547 8195, 8335 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 27 - 8392 Perforations from 9196' to 9206'MD Squeeze 3-bbls of 15.8-ppg Class G Cement with final squeeze pressure of 3000-psi. 475 736 48484 61020 145 211 1300 1550 950 950 N/A 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S3 Packer 8407, 8195 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 7:49 am, Mar 22, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.03.22 06:40:41 -08'00' Torin Roschinger (4662) WCB 2024-07-11 DSR-3/29/24 RBDMS JSB 032824 ACTIVITY DATE SUMMARY 1/8/2024 T/I/O = 2390/491/28. Temp - SI. (INJECTIVITY TEST) Pumped 260 bbls of 90* crude @ 5 BPM down IA. Pumped 140 bbls 50* Crude into TBG to load. Pumped 33 bbls Crude for injectivity test = 1.4 bpm @ 2500 psi. Pad operator notified upon depatures. Tags Hung, FWHP's = 865/453/40 3/6/2024 CTU #9 - 1.75" Coil Job Objective: Squeeze perfs, mill CIBP MIRU CTU. M/U SLB 2" BHA. RIH, kill well with 1% slick KCL w/SL. Load well with 120bbls diesel. ...Continued to WSR on 3/7/24.... 3/6/2024 T/I/O 950/1280/50 Temp S/I ( IA load and FL FP) Pumped 3 bbls of Meth followed by 268 bbls of crude down the IA to Load IA. Pumped a further 4 bbls of Meth and 300 bbls of crude down the FL for FP. Pressured FL to 1500 psi per PCC. Tags hung and DSO notified of completion of job. Final WHPS 850/523/50 3/7/2024 CTU #9 - 1.75" Coil Job Objective: Squeeze perfs, mill CIBP Continue RIH. Tag plug, at 9206E 9245M. clean out on top of plug with no more footage made. pick up above perfs and batch up 15.8ppg Class G cement. Lay in cement from 10' above plug to above perforations. Squeeze 1bbl into perfs then lay in remaining cement. Freeze protect CT down to 2000' and start hesitate squeezing from 7700'. Walk up press Squeeze Press to 3000 psi hold for 1 hour. RIH (Est TOC 8465' MD / 8416' CTM). Start Clean out w/ PowerVis. Tagged hard 9202' MD / 9153' CTM in Top perfs (53' Cmt to CIBP) and could NOT jet thru. Case Cmt OOH 80% washing Jewelry. Wash WH. RIH FP CT and Well to 1200'. WOC. 500 psi compressive strength. M/U 2-7/8" YJ milling BHA w/3.72" 5 blade junk mill. RIH ...Continued to WSR on 3/8/24.... 3/8/2024 CTU #9 - 1.75" Coil Job Objective: Squeeze perfs, mill CIBP Continue RIH. Tag top of cement, mill cement down to plug. pump gel sweep from bottom up. Perform 5 min pressure test of cement squeeze 1227psi to 1200psi. 2.2% loss. Continue milling remaining last 5 ft cement and mill plug. Push top of Blow CIBP @ 9270'. LOW FLUIDS. POOH. BD Junk Mill - worn side and face. MU 3.71" Venturi/Burnshoe. RIH. Mill @ 9263' CTM. Push plug down to 10,210CTMD. POOH freeze protect CT and load well with 142bbls diesel. LD YJ BHA, recovered 3 slip segments and apx 1/4 cup of various small debris. ...Continued to WSR on 3/9/24.... 3/9/2024 CTU #9 - 1.75" Coil Job Objective: Squeeze perfs, mill CIBP Finish L/D YJ milling BHA. RDMO ...Job Complete.... 3/13/2024 ***WELL S/I ON ARRIVAL*** FUNCTION TEST WLV DRIFT & BRUSH SSSV NIPPLE @ 2,126' MD W/ 4-1/2" BLB & 3.805" G.RING ***CONT WSR ON 03/14/2024*** Daily Report of Well Operations PBU Q-03A Continue milling remaining last 5 ft cement and mill plug. Push top of Blow CIBP gg g @ 9270'. LOW FLUIDS. POOH. BD Junk Mill - worn side and face. MU 3.71" @ Venturi/Burnshoe. RIH. Mill @ 9263' CTM. Push plug down to 10,210CTMD. Tag plug, at 9206E 9245M. clean out on top of plug with no more gg g footage made. pick up above perfs and batch up 15.8ppg Class G cement. Lay in ggy cement from 10' above plug to above perforations. Squeeze 1bbl into perfs then lay in g remaining cement. Freeze protect CT down to 2000' and start hesitate squeezing gg from 7700'. Walk up press Squeeze Press to 3000 psi hold for 1 hour. RIH (Est ( TOC 8465' MD / 8416' CTM). Start Clean out w/ PowerVis. Tagged hard 9202' MD / )gg 9153' CTM in Top perfs (53' Cmt to CIBP) and could NOT jet thru. Daily Report of Well Operations PBU Q-03A 3/14/2024 ***CONT WSR FROM 03/13/2024*** SET 4-1/2" ROCKSCREEN (202" lih, sec lockdown installed) IN SSV NIPPLE @ 2,126' MD RAN CHECK SET TO ROCKSCREEN IN SSSV NIPPLE @ 2,126' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** The milled CIBP and the squeezed perfs are correctly shown on the WBS below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y Samantha Carlisle at 9:15 am, May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a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aPLQ3XPSHGEEOVFUXGHWRWDO'62QRWLILHGXSRQ GHSDUWXUH):+3 V 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%84$ O O O O O O O O • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 March 31, 2010 " ~~`'~ ~~~ ~~`~ ~ ~ ~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad Q Dear Mr. Maunder, • by ~ECE~~E APR ~ 7 201A ~+-~ca 0iI ~ Gas C0lilsi~ rq7; ~ A Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad Q that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date: 03/31/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Q-01A 1971260 50029203010100 0.1 NA 0.1 NA 1.70 3/10/2010 Q-02A 1971470 50029203330100 0.2 NA 0.2 NA 1.70 3/10/2010 Q-03A 1972540 500 100 0.1 NA 0.1 NA 1.70 3!1012010 Q-048 2091010 50029203400200 1 NA 1 NA 3.40 3/10/2010 Q-O58 2071560 50029203440200 0.5 NA 0.5 NA 3.40 3/9/2010 Q-06A 1980900 50029203460100 0.2 NA 0.2 NA 1.70 3/9/2010 Q-076 2031570 50029203520200 0.7 NA 0.7 NA 3.40 3/9/2010 , STATE OF ALASKA ALASKA )L AND GAS CONSERVATION CO. 11SSION REPORT OF SUNDRY WELL OPERATIONS3EP 12 J~,i~1 Ir" 1. Operations Performed: D Abandon D Alter Casing D Change Approved Program "qor' ll_ J D Suspend D Operation Shutdown D Perforate D Other iii Repair Well D Plug Perforations D Stimulate D Re-Enter Suspended Well iii Pull Tubing D Perforate New Pool D Waiver D Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 70.22' 8. Property Designation: ADL 028281 11. Present well condition summary Total depth: measured 10950 feet true vertical 9016 feet Effective depth: measured 10215 feet true vertical 9011 feet Casing Length Size Structural Conductor 140' 20" x 30" Surface 2676' 13-3/8" Intermediate 8510' 9-5/8" x 7-5/8" Production Liner 738' 7" Liner 2353' 4-1/2" Perforation Depth MD (ft): Perforation Depth TVD (ft): 9300' - 10190' 9019' - 9013' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4. Current Well Class: iii Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number: 197-254 6. API Number: 50-029-20322-01-00 9. Well Name and Number: PBU Q-03A 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Plugs (measured) 10215 Junk (measured) 10215 MD TVD Burst 140' 140' 2676' 2673' 4930 8532' 8320' 6870 8004' - 8742' 7792' - 8530' 8160 8597' - 10950' 8385' - 9016' 8430 Collapse 2670 4760 7020 7500 ç\ ":: 'ì 0 DYC:. r'-'~\\ì\,I~~¡r,::ri) (,'rCI¡?;~.l ¡._,\J",~ ¡;)~¢I"\Ðl;J~\\ik,..'" 1) L .; 4-1/2", 12.6# 13Cr80 / L -80 8604' 7" x 4-1/2" Baker 'S-3' packer; 7" x 4-1/2" Baker 'S-3' packer; 4-1/2" HES 'X' Nipple 8547'; 8407'; 2126' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFL SEP 2 0 2005 Treatment description including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: D Copies of Logs and Surveys run iii Daily Report of Well Operations iii Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure 15. Well Class after proposed work: D Exploratory a Development D Service 16. Well Status after proposed work: a Oil D Gas D WAG D GINJ D WINJ D 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 N/A Printed Name Terrie Hubble Title Technical Assistant Date Oq/,CJ/OS Signature ~~ ~_ I Phone 564-4628 Form 10-404 Revised 04/2004 CJ RIG t N A L Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only ') ) Well: Q-03A Accept: 08/14/05 Field: Prudhoe Bay Unit Spud: N/A API: 50-029-20322-01-00 Release: 08/19/05 Permit: 197-254 Rig: Doyon 16 PRE-RIG WORK 08/1 0/05 PULLED 41/2" XXN TUBING TAIL PLUG AT 8570' SLM. 08/11/05 SET HES FASDRILL PLUG MID ELEMENT 8565', STRING SHOT 2 STRANDS 8497'-8509' AND TUBING PUNCH SMALL CHARGES 8479'-8481'. 08/12/05 TUBING CUT 8507' MID FULL JT ABOVE PACKER WITH 3.625" CHC (PRE RWO). CUTTER LOOKS LIKE EVEN CUT. ') ) BP EXPLORATION Operations Summary Report Page 1 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-03A Q-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 8/13/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 8/14/1978 End: 8/19/2005 Date From.. To Hours Task Code NPT Phase Description of Operations 8/12/2005 14:00 - 20:00 6.00 MOB P PRE R / D Top Drive and Rig Floor. Backed off of B-02A. Bridled Up. Laid Down Derrick. Removed BOP Stack from Cellar. Installed Front and Rear Boosters. Waited on Tool Service to Set Mats. 20:00 - 20:30 0.50 MOB P PRE Held PJSM wi Rig Crew, Toolpusher and Security. 20:30 - 00:00 3.50 MOB P PRE Moved Rig to Q Pad. 8/13/2005 00:00 - 04:00 4.00 MOB P PRE Moved Rig from B-02A to Q Pad Access Road. 04:00 - 00:00 20.00 MOB P PRE Moved Rig Down Q Pad Access Road, Laid Double and Triple Mats on Road. 8/14/2005 00:00 - 10:00 10.00 MOB P PRE Moved Rig Down Q Pad Access Road, Laid Double and Triple Mats on Road. 10:00 - 12:00 2.00 MOB P PRE Rig on Q Pad. Removed Booster Wheels. P / U and Placed BOP Stack on Cellar Pedestal. 12:00 - 13:30 1.50 MOB P PRE Raised and Pinned Derrick. R / D Bridle Lines. 13:30 - 15:00 1.50 MOB P PRE R I U Top Drive and Rig Floor. Set Herculite and Rig Mats. Spotted, Leveled and Set Rig Over Q-03A. Set Slop Tank, N / U Secondary Annulus Valve. Accepted Rig at 1500 hrs 8/14/ 2005. 15:00 - 17:30 2.50 PULL P DECOMP R I U Lines to Circulating Manifold and Tree. R I U Drill Floor. 17:30 - 19:00 1.50 PULL P DECOMP Held PJSM. R I U DSM Lubricator, Latched and Pulled BPV, Very Slight Pressure on Tubing. R / D DSM Lubricator. 19:00 - 21 :30 2.50 PULL P DECOMP Held PJSM w/ Rig Crew, Vac Truck Drivers, Tool Pusher and Drilling Supervisor. Tested Lines to 2,000 psi, OK. Displaced Wellbore wi 40 bbl Hi-Vis Detergent Sweep Followed by 700 bbls of 140 deg Seawater. 10 bpm, 800 psi. 21 :30 - 22:30 1.00 WHSUR P DECOMP Monitored Well, Static. Ran and Set TWC, Tested from Below to~,OOO psi, OK 22:30 - 00:00 1.50 WHSUR P DECOMP Held PJSM. N / D Tree and Adapter. 8/15/2005 00:00 - 00:30 0.50 WHSUR P DECOMP Held PJSM. Continued to N I D Tree and Adapter. Terminated Control Lines at Adapter. 00:30 - 04:30 4.00 BOPSUR P DECOMP N I U BOPE: 13-5/8" 5M GK Annular Preventer, 13-5/8" 5M Blind Shear Rams, Mud Cross w/ Kill Choke Lines, 13-5/8" Lower Pipe Rams with 3-1/2" x 6" Variable Rams. N / U Riser. Installed Flow Line. 04:30 - 05:00 0.50 BOPSUPP DECOMP M I U Test Joint wi XO. RIH and M I U to Tubing Hanger. R I U BOPE Test Equipment. 05:00 - 10:00 5.00 BOPSUF P DECOMP Held PJSM. Tested BOPE. Tested Annular Preventer, Pipe Rams, Choke Manifold and Valves, HCR's, Kill Line, Choke Line, Floor Valves and IBOPs to 250 psi /3,500 psi. All Tests Held f/ 5 Min. All Pressure Tests Held wi No Leaks or Pressure Loss. Blind / Shear Rams Failed, C/O Blind I Shear Rams to Blind Rams. Tested Blind Rams to 250 psi 13,500 psi. Tests Held f/ 5 Min. All Pressure Tests Held w/ No Leaks or Pressure Loss. AOGCC Rep. Chuck Scheve Waived Witness of Test. BOPSUJp Test Witnessed by Doyon Tool Pusher and BP Drilling I Supervisor. 10:00 - 11 :00 1.00 I DECOMP Blew Down and RID All Test Equipment. R I U DSM !p I Lubricator, Latched and Pulled TWC, RID DSM. 11 :00 - 12:00 ¡ 1.00 PULL ! DECOMP Held PJSM. M I U Spear BHA: Packer Bullnose - Packoff Assy i I w/ 4-1/2" Cup - Spear Assy wI Double 3.947" Grapples - 2 x Spear Extensions - XO. M I U Spear Assy to 1 Joint 4" DP. 12:00 - 14:00 2.00 PULL 'N DPRB DECOMP I RIH and Attempted to Engage Tubing. Spear Stacked Out wI ¡ Lower Grapple 1.5' Inside Tubing Hanger. Could Not Work I Printed: 8/22/2005 11 :20:25 AM ") ) BP EXPLORATION Operations Summary Report Page 2 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-03A Q-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 8/13/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 8/14/1978 End: 8/19/2005 Date From - To Hours Task Code NPT Phase Description of Operations 8/15/2005 12:00 - 14:00 2.00 PULL N DPRB DECOMP Spear Deeper. Released Spear and POOH. Lower Grapple Broke At Upper Tab. Cleaned Abundant Metal Shards Off of Grapple w/ Metal Shards Embedded in Packoff Cup. Broke Down Spear, C/O Grapple and Packoff Cup. Ran Steam Hose Inside Tubing Hanger to Steam Inside of Hanger. Flushed Hanger wi Seawater. RIH and Attempted to Engage Tubing. Spear Stacked Out w/ Lower Grapple 2.0' Inside Tubing Hanger. Could Not Work Spear Deeper. Released Spear and POOH. Cleaned Metal Shards Off of Grapple wi Metal Shards Embedded in Packoff Cup. B I 0 and L / D Spear Assy. 14:00 - 15:00 1.00 PULL P DECOMP M I U Tubing Lift Thread XO to 4" DP. RIH and M I U XO to Tubing Hanger. BOLDS. P I U on Tubing, Hanger Came Off Seat wi 145,000# Up Weight. Pulled 12" x 4-1/2" Tubing Hanger to Floor wi 140,000# String Weight Up. 15:00 - 16:00 1.00 PULL P DECOMP Circulated Bottoms Up. Pump Rate 10 bpm, 300 psi. Monitored Well, Static. Blew Down and Broke Out Top Drive. R I LJ Camco Control Line Spooling Unit. 16:00 - 16:30 0.50 PULL P DECOMP Terminated Control Lines at Tubing Hanger. B I 0 and LID Tubing Hanger. B I 0 and LID XO and 4" DP. 16:30 - 18:00 1.50 PULL P DECOMP POOH, LID 48 Jts 4-1/2" 12.6# L-80 MBT Tubing, Spooled Up Dual Control Line. 18:00 - 18:30 0.50 PULL P DECOMP B / 0 and L / D SSSV Assy. RID Camco Control Line Spooling Equipment. Recovered 53 of 53 SS Bands. 19:30 - 00:00 4.50 PULL P DECOMP POOH, LID 4-1/2" 12.6# L-80 MBT Tubing. 8/16/2005 00:00 - 02:00 2.00 PULL P DECOMP POOH and LID 4-1/2" 12.6# L-80 MBT Tubing. Total Recovery: 202 Jts + 1 Cut Joint, 2 GLM's, 1 SSSV Assy, Control Line Tubing and 53 SS Bands. Good Chem Cut on Joint #203 == 22.33'. 02:00 - 03:00 1.00 PULL P DECOMP RID Tubing Handling Equipment. Cleared and Cleaned Rig Floor. Ran Wear Bushing. 03:00 - 05:00 2.00 CLEAN P DECOMP Held PJSM. M I U Dress Off BHA. 6" x 4-1/2" Mill Shoe, 3 x 5-3/4" WP Extensions, 5-3/4" TC Boot Basket Bushing, Double Pin Sub, 7" Casing Scraper, 2 x Boot Baskets, Bit Sub, Oil Jars, XO, 9- 4-3/4" DC's. Total Length == 323.21'. Total Length over 4-1/2" Tubing before Tagging 4-3/4" Mill Section == 11.02'. 05:00 - 13:30 8.50 CLEAN P DECOMP RIH wi Dressoff BHA on 4" DP to 8,500'. PI U 4" DP 1 x 1 from Pipe Shed. Rabbitted All DP Run in Hole. 13:30 - 14:30 1.00 CLEAN P DECOMP M I U Top Drive, Engaged Pump, Established Parameters: String Weight Up 185,000#, String Weight Down 150,000#, String Weight Rotating 165,000#, 70 rpm, Torque 5,000 ft Ilbs, 6 bpm, 1,300 psi. Washed Down, Tagged Top of Tubing Stub at 8,505' DPM. Dressed Off Tubing Stub from 8,505' to 8,506', I I WOM 7,000#, rpm 70, Torque 6,000 ft Ilbs, 6 bpm, 1,300 psi. PI U to 8,500', Shut Down Pump and Rotary, RIH and Tagged I \ Top of Tubing Stub at 8,506'. Mill and Extensions Went Over I Stub. 14:30 - 17:00 2.50 I CLEAN P I DECOMP Pumped and Circulated Around 40 bbl Hi-Vis Detergent I I Sweep, 10 bpm, 2,550 psi. Blew Down Top Drive, Monitored I I Wellbore, Well Static. ; 17:00 - 18:00 1.00 I CLEAN N IRREP ¡ DECOMP ¡ Repair Rig Hydraulic Pump 18:00 - 21:30 I 3.50: CLEAN P I I DECOMP ,POOH wi 4" DP. 21 :30 - 22:30 1.00 I CLEAN P i DECOMP ¡ POH wi Dress Off BHA, Stand Back 4-3/4" Dc's, BIO and UD \ I I ! I Printed: 8/22/2005 11 :20:25 AM ) ) BP EXPLORATION Operations Summary Report Page 3 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-03A Q-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 8/13/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 8/14/1978 End: 8/19/2005 Date From - To Hours Task Code NPT Phase Description of Operations 11 :30 - 13:00 1.50 RUNCOrvP DECOMP Dress Off Tools, Junk Baskets Clean DECOMP Clear and Clean Rig Floor, Remove Excess Milling Tools from Rig Floor DECOMP R/U 2-7/8" Handling Tools DECOMP P/U and M/U Drill Out BHA; 3.7" Convex Mill, Bit Sub, 57 Joints 2-7/8" PAC DP, XO, DBL Pin Sub, 2 x 4-3/4" Junk Baskets, Bit Sub, Jars, XO, 9 x 4-3/4" DC's. Total BHA Length = 2,082.63' DECOMP RIH wi 4" DP from Derrick, Tag 7" Liner Top at 8,005'. String Weight Up 160,000#, String Weight Down 140,000#, RIH tJ 8,420' DECOMP M/U Top Drive, Established Parameters, String Weight Up 166,000#, String Weight Down 147,000#, Rotary String Weight 156,000#, Pump 5 bpm, 1,840 psi, 60 Rotary rpm, Torque 3,000 ftJlbs, Wash Down fl 8,510', Tag Fasdril at 8,562'. DECOMP Milled Fasdrill Plug from 8,562' - 8,565', WOM 2,000# - 4,000#, RPM 70, Torque 4,500 ft I Ibs, Pump 5 bpm, 2,000 psi. Lost Partial Returns at 8,564'. Fasdrill Plug Fell Down Hole at 8,565'. DECOMP Washed and Pushed Fasdrill Plug Down to 9,524'. Tagged CIBP at 9,524' DPM. String Weight Up 185,000#, String Weight Down 155,000#, Rotary String Weight 170,000#. Partial Returns While Washing Down. 5 bpm, 1,850 psi. DECOMP Milled CIBP from 9,524' - 9,530', WOM 3,000# - 4,000#, RPM 60, Torque 5,000 ft Ilbs, Pump 5 bpm, 1,800 psi. Lost Full Returns at 9,526'. CIBP Plug Fell Down Hole at 9,530'. DECOMP Washed and Pushed CIBP Down to 10,211'. Tagged Lower CIBP at 10,211' DPM. No Returns While Washing Down. 5 bpm, 1,850 psi. DECOMP Circulated at 6 bpm, 2,800 psi, Regained Partial Returns After Pumping 90 bbls. Losses While Circulating 144 bph. Shut Down Pump. DECOMP Held PJSM. POOH LID 4" DP. DECOMP POOH UD 4-3/4" Dc's, 2-7/8" PAC DP and Milling Tools DECOMP Clean and Clear Rig Floor, RID 2-7/8" Handling Equipment, Pull Wear Ring RUNCMP M/U Tbg XO to Floor Safety Valve, C/O Bails, R/U 4-1/2" Compensator, Tongs and Torque Turn Equipment RUNCMP M I U 4-1/2" 12.6# 13Cr80 Yam TOP Tail Pipe Assembly: 6" x 4.625" Unique Overshot - 1 Jt 4-1/2" 12.6# 13Cr80 Yam TOP Tubing - Lower X Nipple Assy wi RHC-M Sleeve - 7" x 4-1/2" Baker S-3 Packer Assy - Upper X Nipple Assy. Bakerlocked All Connections Below Packer. P I U All Assy's wi Compensator, Torque Turned All Connections. M I U Torque 4,450 ft I Ibs. I Doped Connections Above Packer wi Jet Lube Seal Guard. RUNCMP RIH wi 198 Joints 4-1/2" 12.6# 13Cr80 Yam TOP Tubing. PI U Joints wi Compensator, Torque Turned All Connections. M I U I Torque 4,450 ft Ilbs. Doped Connections wi Jet Lube Seal I I Guard. : RUNCMP I RID Compensator, M I U Circulating Head to Jt #199. M I U Jt I #199 to Tubing String. \ : Established Parameters: String Weight Up 145,000#, String I Weight Down 125,000#,3 bpm, 80 psi. Washed Down to 18,504', Tagged Top of Tubing Stub at 8,504' TM. Swallowed 8/16/2005 21 :30 - 22:30 1.00 CLEAN P 22:30 - 23:30 1.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 00:00 - 03:00 3.00 CLEAN P 03:00 - 05:00 2.00 CLEAN P 05:00 - 05:30 0.50 CLEAN P 8/17/2005 05:30 - 06:00 0.50 CLEAN P 06:00 - 08:00 2.00 CLEAN P 08:00 - 09:00 1.00 CLEAN P 09:00 - 10:00 1.00 CLEAN P 10:00 - 10:30 0.50 CLEAN P 10:30 - 18:00 7.50 CLEAN P 18:00 - 21 :30 3.50 CLEAN P 21 :30 - 22:30 1.00 CLEAN P 22:30 - 00:00 1.50 RUNCOMP 8/18/2005 00:00 - 00:30 0.50 RUNCOMP 00:30 - 11 :30 I 11.00 I RUNCO~ I I ! Printed: 8/22/2005 11 :20:25 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) BP EXPLORATION O.perations Summary Report Q-03A Q-03A WORKOVER DOYON DRILLING INC. DOYON 16 Page 4 of 5 Start: 8/13/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 8/14/1978 End: 8/19/2005 8/18/2005 11 :30 - 13:00 From - To Hours Task Code NPT Phase Description of Operations 13:00 - 14:30 1.50 RUNCOMP 1.50 RUNCOMP RUNCMP Tubing Stub, Shut Down Pump, Continued to RIH, Tagged Up on Top of Tubing Stub wi Shear Pins, Pins Sheared wi 7,000# Stacked on Stub, Continued to RIH, No-Goed on Top of Tubing Stub wi Inside of Overshot, Stacked 15,000# on Tubing Stub. Marked Joint, PI U and Repeated x 2 to Ensure Proper Depth. RUNCMP RID Circulating Head and Lines. LID Jt #199, #198 and #197. M I U Space Out Pup Joints, M I U Jt #197. M I U Tubing Hanger and Landing Jt. Landed Hanger in Tubing Head. Tubing Spaced Out wi Unique Overshot 5.00' Over Tubing Stub. RILDS on Tubing Hanger. Completion Equipment Set At The Following Depths: Item Length Depth Unique Overshot Assy 19.07' 8,511.90' 1 Jt 4.5" 12.6# 13Cr80 Vam TOP Tbg 42.01' 8,450.81' . X Nipple wi RHC Sleeve Assy 30.16' 8,420.65' 7" x 4-1/2" S-3 Packer Assy 33.39' 8,387.26' Upper X Nipple Assy 30.10' 8,357.17' 10 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 420.03' 7,937.14' #1 GLM Assy 26.27' 7,910.87' 28 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 1,173.73' 6,737.13' #2 GLM Assy 26.30' 6,710.83' 36 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 1,507.58' 5,202.72' #3 GLM Assy 26.28' 5,176.44' 51 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 2,135.50' 3,082.95' #4 GLM Assy wi DCR Shear Valve 25.89' 3,015.05' 21 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 878.71' 2,136.33' X Nipple Assy 30.31' 2,106.03' 48 Jts 4.5" 12.6# 13Cr80 Vam TOP Tbg 2,013.18' 92.85' 4.5" 12.6# 13Cr80 Vam TOP Pup Jt 9.86' 82.99' 14.5" 12.6# 13Cr80 Vam TOP Pup Jt 3.84' 179.15' 14.5" 12.6# 13Cr80 Vam TOP Pup Jt 9.85' ,69.30' ! 1 Jt 4.5" 12.6# 13Cr80 Vam TOP Tbg 41.98' 127.31' I I Printed: 8/22/2005 11 :20:25 AM ') ) BP EXPLORATION Operations Summary Report Tubing Hanger 3.26' 24.05' PJSM wi Rig Crew, Vac Truck Drivers, Tool Pusher and Drilling Supervisor. R I U Circulating Head and Lines to Landing Joint and 9-5/8" x 4-1/2" IA to Reverse Circulate. Pumped 450 bbls 140 deg Seawater wi Corrosion Inhibitor. Pumped Down 9-5/8" x 4-1/2" Annulus No Returns Up Tubing. Pump Rate 3 bpm, 150 psi. RUNCMP PJSM w/ Rig Crew, Baker Rep, Tool Pusher and Drilling Supervisor on Setting Packer and Testing Tubing. Broke Out Head Pin, Dropped Balli Rod Assy. Allowed Balli Rod Assy to Fall On Seat. M I U Head Pin, Pressured Up on Tubing to 2,500 psi to Set Packer, Increased Pressure to 3,500 psi, Pressure Tested Tubing f/30 minutes, OK. Bled Down Tubing Pressue to 2,000 psi. Pressure Tested IA to 3,500 psi, OK. RUNCMP Bled Down Tubing, DCK Valve Sheared at 2,800 psi Differential, Bled Down All Pressures, Lined Up to Pump Down Tubing at 3 bpm, 1,000 psi and Take Returns Up IA. B/O and LID Landing Jt. and XO. Ran and Set TWC. Tested from Below to 1,000 psi, OK. PJSM-Remove Mouse Hole and Drilling Riser, N/D BOPE and Remove Spacer Spool N/U Adapter Test Adapter Flange t/ 5,000 psi. Good Test N/U Production Tree Test Tree t/ 5,000 psi. Good Test. R/U DSM Lubricator and Pull TWC. R/D Lubricator. M/U Circulating Lines to Tree and IA for Pumping Freeze Protect. Hook Up Hot Oil to Circulating Manifold and Test Lines t/ 2,000 psi. Pump 160 bbls Diesel Down IA at 3 bpm, 900 psi. Taking Returns Up Tubing to Slop Tank U-Tube Diesel from IA to Tubing RID Circulating Lines From Tree. Install BPV and Test wi Hot Oil from Below to 1,000 psi. Install Tree Cap w/ Pressure Gauge Blew Down All Lines, R/D Hot Oil and Circulating Lines, Close All Valves on Tree. Released Rig at 0500 hrs Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-03A Q-03A WORKOVER DOYON DRILLING INC. DOYON 16 Date From - To Hours Task Code NPT Phase 8/18/2005 13:00 - 14:30 1.50 RUNCOMP RUNCMP 14:30 - 17:30 3.00 RUNCOMP RUNCMP 17:30 - 19:00 1.50 RUNCOMP 19:00 - 20:00 1.00 RUNCOMP 20:00 - 22:30 2.50 BOPSUP P OTHCMP 22:30 - 23:30 1.00 WHSUR P OTHCMP 23:30 - 00:00 0.50 WHSUR P OTHCMP 8/19/2005 00:00 - 01 :00 1.00 WHSUR P OTHCMP 01 :00 - 01 :30 0.50 WHSUR P OTHCMP 01 :30 - 02:00 0.50 WHSUR P OTHCMP 02:00 - 03:00 1.00 WHSUR P OTHCMP 03:00 - 04:00 1.00 WHSUR P OTHCMP 04:00 - 04:30 0.50 WHSUR P OTHCMP 04:30 - 05:00 0.50 WHSUR P OTHCMP Page 5 of 5 Start: 8/13/2005 Rig Release: 8/19/2005 Rig Number: Spud Date: 8/14/1978 End: 8/19/2005 Description of Operations Printed: 8/22/2005 11 :20:25 AM TREE = " I. .." WELLHEAD = 'ActuATOR ~ KB. aev = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 4-1/16" CrN McEVOY BAKER 70.22' 39.3' 2631' 97 @ 10161' 9102' 8800' SS )Q-03A Completion S~ NOTE: THE ONLY SEAL BETWEEN ORlG CSL,JrIEBACK IS CMT. 70° @ 9304' AND 90° @ 9466' 19-5/S· X 7-5/S" XO 1-1 2337' 1 TOP OF 7-5/8· CSG 1-1 2337' 17-5/S· CSG, 29.7#, L-SO, ID = 6.875· 1-1 2510' 113-3/8. CSG, 72#, L-80, ID = 12.34r 1-1 2676' TOP OF SEAL ASSY 1-1 8004' BTM OF SEAL ASSY 1-1 8027' I TOP OF 7" LNR 1-1 8032' 9-5/S· CSG, 47#, L-SO, ID = S.6S1" 1-1 8532' 14-1/2" TOO, 12.6#, 13Cr, .0152 bpf, ID= 3.958" I 1-1 8537' 1-1 8547' 1-1 8571 ' 1-1 8592' 1-1 8597' 1-1 8604' Minimum ID = 3.725" @ 8592' 4-1/2" HES XN NIPPLE 1 WHIPSTOCK 1-1 8765' I 4-1/2" HES X NIP, ID= 3.813· 17" X 4-1/2" BAKER S-3 PKR, ID= 3.875" I 4-1/2" HES X NIP, ID= 3.813· I 4-1/2· HES XN NIP, ID = 3.725" 1 TOP OF 4-112" LNR 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I TBG STUB 1-1 1 PBTD l-i 7" LNR, 29#, L-80, .0371 bpf,ID=6.184" 1-1 8762' 9351' 9550' ÆRFORA TION SUMMARY REF LOG: SÆRRY SUN MWD/GR ON 01/98 ANGLEATTOPÆRF: 66 @ 9300' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9300 - 9345 0 10/26/03 3-318" 6 9317 - 9332 0 03/24/02 2-7/8" 8 9700 - 9840 C 03/24/02 2-7/8" 8 9920 - 10110 C 03/24/02 2-7/8" 4 10170 - 10190 C 03/24/02 2-3/4" 4 10300 - 10420 C 03/24/02 2-3/4" 4 10490 - 10590 C 03/24/02 2-3/4" 4 10670 - 10720 C 03/24/02 2-3/4" 4 10780 - 10850 C 03/24/02 0' 1- 13-3/8"X9-518" ANNULUS CMT'D W/295 SX COSL SET III & 350 SX COLD SET II FROM 0-2395'1 I I 2125' 1-1 4-1/2" X NIP, ID= 3.813" 2337' 1-1 9-5/S" CSG, 47#, L-80, ID = 8.681" 2395' 1-1 TOP OF 9-5/8" CSG 1 1 GAS LIFT MANDRELS ~ ~ ST MD lVD DEV lYPE VLV LATCH PORT DATE 4 3024 3020 12 KBG-2 Shea BEl< L 3 5185 5011 19 KBG-2 DMY BK ~ 2 6720 6524 7 KBG-2 DMY BK b 1 7920 7719 5 KBG-2 DMY BK . t 8JTI' 1-14-112" X NIP, ID = 3.813· 1 g 8407' 1-17" x 4-1/2" BAKER S-3 PKR 1 I - 8440' 1--14-1/2" X NIP, ID = 3.813" 1 8502' 1-1 UNIQUE MACHINE OVERSHOT 1 1 8507' 1-1 CHEM CUT TBG 1 1 1 1 1 8597' 1-1 TOP OF 7· X 5" BAKER HYD LNRlHGR 1 8604' 1--1 4-112" TTL WLEG I -I . 8603' 1-1 ELMD TT LOGGED 06/29/98 1 7" SIDETRACK WINDOW 8742' - 8754' I 10215' 1-1 BAKERCIBP, ELMD@ 10215' 1 I PBTD 1-1 10867' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 1-1 10950' 1 DATE REV BY COMMENTS DA TE REV BY COMMENTS 1978 ORIGINAL COMPLETION 06/07/05 M\NfT1.H SAFETY & CSG CORRECTIONS 02/19/98 SIDETRACK COM PLETION 02/27102 RN/TP CORRECTIONS 03/24/02 A TD/KK ADPERFS & SET CIBP 10/26/03 PNElTLP ADD ÆRFS/ANGLElLOCATION 07102/04 RWUKAK GLV C/O PRUDHOE BAY UNIT WELL: Q-03A ÆRMIT No: '1972540 API No: 50-029-20322-01 SEC 16, T11 N, R13E, 4833' FSL & 947' FEL BP Exploration (Alaska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y Samantha Carlisle at 1:47 pm, Mar 24, 2022 Name: BP Exploration (Alaska), Inc. STATE OF ALASKA ~~'ECE'\lE~[) ALASKA Oil AND GAS CONSERVATION COMMISSION FEB 252004 REPORT OF SUNDRY WELL OPERJ\!lP)N,~~~ Crn.~, C'lr~f:"~~lar. Perforate ŒJ Wa~Öèr~r3Q'-:: Stimulate 0 Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 197-2540 Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown D Plug PerforationsD Perforate New Pool 0 4. Current Well Class: OtherD 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator 70.22 8. Property Designation: ADL-0028281 11. Present Well Condition Summary: Development [&] Stratigraphic 0 9. Well Name and Number: Q-03A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Exploratory 0 Service 0 6. API Number 50-029-20322-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 10950 feet true vertical 9016.2 feet Effective Depth measured 9525 feet Plugs (measured) Junk (measured) 9525,10225 None true vertical 9036.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 31 111 31.0 - 111.0 1490 470 Liner 6032 9-5/8" 47# L-80 2500 - 8532 2498.6 - 8319.6 6870 4760 Liner 738 7" 29# L-80 8004 - 8742 7792.5 - 8529.5 8160 7020 Liner 2353 4-1/2" 12.6# L-80 8597 - 10950 8384.6 - 9016.2 8430 7500 Production 2308 9-5/8" 47# L-80 29 - 2337 29.0 - 2336.5 6870 4760 Production 173 7-5/8" 29.7# L-80 2337 - 2510 2336.5 - 2508.6 6890 4790 Surface 2646 13-3/8" 72# L-80 30 - 2676 30.0 - 2672.7 4930 2670 Perforation decth: Measured depth: 9300 - 9317, 9317 - 9332, 9332 - 9345 True vertical depth: 9019.26 - 9025.63,9025.63 - 9029.96,9029.96 - 9032.73 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 27 8604 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 8547 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Recresentative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 57 360 1050 13 Prior to well operation: Subsequent to operation: Oil-Bbl 1510 1282 50.3 293 1050 Tubing Pressure 887 1091 14. Attachments: 15. Well Class after proposed work: Exploratory D DevelopmentŒ) Service D Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D Oil[&] GasO WAG 0 GINJO WINJD WDSPLO Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations - ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron S~f~~Et, M~\n 1 Œj 2004, Title Production Technical Assistant S¡Qnatur:orm 1 0-4~:~2~~ 0 RIG I Nt\" L6~465~ 'BH Date 2/24/04 fn). 9"); II~' (~.~~~. -.~:~ rw 11W~' Lij~"1 Q-O3A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/25/03 MIRU CTU #9. RIH WITH 3-3/8" DG, DRIFT TO 9475', NO TAG. RIH WITH MEM GR/CCL. LOG INTERVAL 9150' TO 9475' CTMD. FLAGGED PIPE AT 9299' CTMD. POOH. MU GUN #1 (25' - 3 3/8" PJ3406 - HMX, 6 SPF, 60 DEG PHASE). 10/26/03 Perforate 93001-9345' 6 SPF FLUIDS PUMPED BBLS 195 195 60/40 Methanal TOTAL Page 1 TREE = WELLHEAD = ."""'" . ............. . A Cfl.LA. TOR = KB. ElEV = BF. ELEV = KOP= Max Angle = Datum MD = . .. .. .. ..... Datum TVD = 4-1/16" aN MeEV OY .... """"'" . .... BA KER 7022' 39.3' 2631' 97 @ 1Ò161' 9102' 8800' SS 1 9-518" CSG, 47#, L-80, [) = 8.681" H 1 TOP OF 7-5/8" CSG H 1 TOP OF 9-5/8" CSG H 1 7-5/8" CSG, 29.7#, L-80, [) = 6.875" H 113-3/8" CSG, 72#, L-80, ID = 12.347" H 1 TOP OF 7' LNR H 9-5/8" CSG, 47#, L-80, ID = 8.681" H Minimum ID = 3.725" @ 8592' 4-1/2" HES XN NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 1 TOPOF4-1/2"LNR H 1 WHPSTOO< 1-1 I1BG STLB 1-1 1 AHD 1-1 7' LNR, 29#, L-80, .0371 bpf, ID = 6.184" H ÆRFORA TION SUMMARY REF LOG: SPERRY SUN MWD/GR ON 01/98 ANGLE AT TOP PERF: 66 @ 9300' Note: Refer to Produetion DB for historcalyerf data SIZE SPF INTER\! AL Opn/Sqz DATE 3-3/8" 6 9300 - 9345 0 10/26/03 3-3/8" 6 9317 - 9332 0 03/24/02 2- 7/8" 8 9700 - 9840 C 03/24/02 2-7/8" 8 9920-10110 C 03/24/02 2-7/8" 4 10170- 10190 C 03/24/02 2-3/4" 4 10300 - 10420 C 03/24/02 2-3/4" 4 10490 - 10590 C 03/24/02 2-3/4" 4 10670 - 10720 C 03/24/02 2-3/4" 4 10780 - 10850 C 03/24/02 DATE 1978 02119/98 02/27/02 03/24/02 10/26/03 COMMENTS ORIGINAL COMPLETION SIDETRACK COM PLETION RN/TP CORRECllO NS A TO/KK A [PERFS & SET CIBP PWElfLP A DO ÆRFS/ANGL6'LOCA llON REV BY 2337' 2337' 2500' 2510' 2676' 8032' 8532' 8604' 8597' 8765' 8762' 9357 9550' Q-O3A fa I' ¡- SAÆTY NOTE: 00 NOT EXCEED 2500 psi ON 9-5/8" CSG. THE ONLY SEAL BElWEENORlGCSG & 11EBACK IS CMT. 70° @ 9304' AND 90° @ 9466' I 0' t-- 13-3I8"X9-5I8" ANNULUS CMT'D W/295 SX COSL SET 1\1 & 350 SX COLD SET II FROM 0-2395'? 1978' 2337' H 4-1/2" HES HXO SLVN NIP, ID = 3.813" 1 H 9-5/8" X 7-5/8" XO I 8004' 8027' 8537' 8547' GAS LIFT rv\A.NDRI3..S DBi TYÆ VLV LATa; FORT DATE 15 KGB-2LS DOME BL 16 02/21/98 14 KGB-2LS SlO BL 20 02/21/98 H TOP OF SEAL ASSY 1 H BTM OF SEAL ASSY I H 4-1/2" HES X NIP, ID = 3.813" I H 7" X 4-1/2" BAKER &3 PKR, 10 = 3.875" I H 4-1/2" HES X NIP, ID = 3.813" I H H 1-1 H H TOP OF 7' X 5" BAKER HYD LNR/I-k3R I H asp (03/24/02) I L ~ ST MD TVD 2 3185 3101 1 5512 5258 i L ! ~ .. 1 1 1 1 ¡ I . 1 ~ :8: I ~ ~ .. 1 PBTD 1-1 10867 8571' 8592' 8597' 4-1/2" HES XN NIP, [) = 3.725" I TOP OF 7' X 5" BAKER HYD LNRlHGR I 4-1/2"TTL WLEG 1 ELMD TT LOGGED 06/29/98 I 8604' 8603' 8597' 9525' 7' SIDETRACK WINDOW 8742' - 8754' 10215' 1-1 BAKER CBP, EUvD @ 10215' I 14-112" LNR, 12.6#, L-80, .0152 bpf, ID =3.953" 1-1 10950' I DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: Q-03A ÆRMT I\b: 1972540 APII\b: 50-029-20322-01 SEe 16, T11 N, R13E, 4833' FSL & 947 FEl BP Exploration (Alaska) 1\ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: clap I ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - Stimulate - Alter casing - 5. Type of Well: Development _X Exploratory - Stratigraphic- Service- 446JFNL,947IFEl,Sec.16,T11N,R13E,UM At top of productive interval 913' FNl, 5101' FEL, Sec. 15, T11 N, R13E, UM At effective depth 683' FNL, 28' FEL, Sec. 16, T11 N, R13E, UM At total depth 49391FNL, 1004IFEl,Sec.09,T11N, R13E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 643511, 5965626) Plugging - Perforate _X Repair well - Other _X CIBP 6. Datum elevation (DF or KB feet) R KB 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Q-03A 9. Permit number I approval number 197 -254 10. API number (asp's 644434, 5965406)' 50-029-20322-01 , 11. Field / Pool (asp's 643437, 5966411) Prudhoe Bay Oil Pool (asp's 644646, 5965180) 1 0950 feet 9018 feet Plugs (measured) clap set @ 95251 (03/25/2002). clap set @ 102151 (04/20/1998). measured 9525 feet Junk (measured) true vertical 9037 feet Length Size Cemented Measured Depth True Vertical Depth 1401 2011 650 sx PF II (Approx) 170' 170' 2646' 13-3/8" 3448 sx ArcticSet II 2676' 2673' 61371 9-5/8" 990 sx Class IG', 430 sx 2395' - 85321 2394' - 83191 ArcticSet I 738' 7" 340 sx Class IG' 8004' - 87421 77921 - 85291 25181 9-5/8" x 7-5/8" 295 sx ColdSet III, 350 22' - 25401 221 - 2538' sx ColdSet II 23531 4-1/2" 277 sx Class IGI 8597' - 109501 8384' - 90161 measured Open Perfs 9317'-93321, Open Perfs below clap 97001-9840',99201-10110',101701-101901, Open Perfs below CIBP 10300' - 104201, 104901 - 105901, 106701 - 10720', 107801 - 108501 true vertical Open Perfs 90251-90301, Open Perfs below CIBP 90231-9019\ 9024'-90211, 90151-9013' Open Perfs below clap 9006' - 90061,90041 - 89991,8999' - 9003',9008' - 90111 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Tubing @ 8547'. 4-1/2"Tubing Tail @ 8603'~ ~ C ~ ~ V -: ) Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker 8-3 Packer @ 85471. 4-1/2" HES HXO Sl VN Nipple @ 1978'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or I njection Data Oil-Bbl Gas-Mcf Water-Bbl Effective depth: Casing Cond uctor Surface Intermediate Liner Tieback Liner Sidetrack Liner Perforation depth: Prior to well operation Welf Shut-In Subsequent to operation Well Shut-In 15. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations - Oil _X Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~q¿~ )J.!i\¡n 4' ';Joq? 'l. d!. ',LJ . (- U Imo. l~!a~)t\.a o¡ ~ 11,1 U~'I ~ ':~ Gü¥ fS,. t;O~HffHfw.il(I..f~ t\n("'hr¡rr1qn ., t .Æ", r CasinÇJ Pressure TubinÇJ Pressure 16. Status of well classification as: Title: T echical Assistant Form 10-404 Rev 06/15/88 . , ' , , Suspended - Service , , Date May 211 2002 SCA~NFn ..JIJN 2+pfiOOGDewayne R. Schnorr 564-~1.74 l. l.. \,~---.... ,\"--, - J , S.::> SUBMIT IN DUPLICA TE-----;-:> Q-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/20/2002 PACKERS / BRIDGE PLUGS' DRIFT/TAG 03/23/2002 PACKERS / BRIDGE PLUGS' CAST IRON BRIDGE PLUG; PERFORATING 03/24/2002 PACKERS / BRIDGE PLUGS' CAST IRON BRIDGE PLUG; PERFORATING EVENT SUMMARY 03/20/02 DRIFT 3.70" SWAGE TO 9308' SLM (STOP DUE TO DEVIATION - HAW). ****LEFT WELL SHUT IN**** 03/23/02 MIRU CTU #3, RIH W/WFD MHA, 3-5/8" WT BAR & 3.5" NZL FOR DRIFT. 03/24/O2 DRIFT TO 9550' CTMD. POOH. RIH W/BAKER 4.5" MODEL "K-I" CIBP. SET CIBP AT 9525' CTMD, TAG TO CONFIRM. POOH. RIH W/15' 3-3/8" PERF GUN (PJ3406 HMX CHARGES, 6 SPF, 60 DEG PHASE, RANDOM ORIENT), REALTIME CCL. RIH AND TAG ClBP AT 9522' CTM. ATTEMPT TO LOG UP W/CCL TOOL. COULD NOT GET TOOL TO FUNCTION. POOH. C/O CCL TOOLS AND RBIH. 2ND TOOL FUNCTIONED OK. TIE IN. SHOT 3-3/8" GUN FROM 9317-9332' MD. POOH. ***LEFT WELL FP W/DIESEL AND SI. NOTIFIED PAD OP OK TO POP AFTER SAFE OUT COMPLETE*** FLUIDS PUMPED BBLS , 17 60/40 METHANOL WATER 16 1% KCL WATER , 33 TOTAL ADD PERFS 03/24/2O02 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 3-3/8" PJ 6SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 9317' - 9332' Page I fCC~NED JUN ~ 4 2002 THE MATERIAL UNDER THIS COVER HAS ON OR BEFORE BEEN PL C :LOP.~VlFILM. DOC W M ATE IA L U N D ER TH IS M ARK ER ---- OIl:Ill_lING S I~: I::t U~ I I-- I::: S WELL LOG TRANSMITTAL To: State of Alaska March 18, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Form&tic~n Evaluation Logs - Q-03A, AK-MM-80106 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 Q-03A: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-20322-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20322-01 2" x 5" MD Neutron & Density Logs: 50-029-20322-01 2" x 5" TVD Neutron & Density Logs: 50-029-20322-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company OFt I I--LI IM G S I:: F:t ~ I I-- I::: S To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.. Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formati6n Evaluation Logs March 11, 1998 Q-03A, AK-MM-80106 The technical data listed below is being submit~xl herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-20322-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [~ Gas [~ Suspended [~ Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 97-254 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 !' i!~i~,i~¥~_~T::~.::!-! 50-029-20322-01 4. Location ofwel, at surface ' L~./~/~:/ ~-i 1~: 9. Unit or Lease Name 446' SNL, 947' WEL, SEC. 16, T11N, R13E, UM ¢. Prudhoe Bay Unit At t°P °f pr°ductive interval! .... '?~'~i~'~i ! 914' SNL, 178' EWL, SEC 15, 111 N, R13E, UM -.. Q-03A At total depth .... ~ ....... ,.- 7.r:~ ~,! 11. Field and Pool 340' NSL, 1007' WEL, SEC 09, T11N, R13E, UM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 70.22'I ADL 028281 12. Date Spudded 113. DateT. D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, ifoffshore 116. Nc. of Completions 1/28/98 2/6/98 2/12/98 N/A MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)119. DirectionalSurvey120. Depth where SSSV set f21. Thickness of Permafrost 10950 9018 FT 10867 9014 FTI [~Yes [~No (Nipple) 1998' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIP, GR, 4-Phase RES, NEU DEN 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORDl AMOUNT PULLED 20"x 30" Insulated Conductor Surface 140' 36" 850 sx PF II (Approx.) 13-3/8" 72# L-80 Surface 2676' 17-1/2" 3448 sx ArcticSet II 9-5/8" 47# L-80 2395' 8532' 12-1/4" 990 sx Class 'G', 430 sx ArcticSet I 7" 29# L-80 8004' 8742' 8-1/2" 340 sx Class 'G' ~-5/8" x 7-5/8' Casing Tieback 22' 2540' __.95 sx Cold Set III, 350 sx Cold Set II 4-1/2" 12.6# L-80 8597' 10950' 6" 277 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8604' 8547' MD TVD MD TVD 9700' - 9840' 9025' - 9021' 9920' - 10080' 9026' - 9025' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10300' - 10420' 9007' - 9008' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10490' - 10590' 9006' - 9001' 10670' - 10720' 9001' - 9005' Freeze Protect with 151 Bbls of Diesel 10780' - 10850' 9009' - 9013' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) February 22, 1998 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Shublik 'A' 8769' 8588' Shublik 'B' 8813' 8602' Shublik 'C' 8827' 8616' Sadlerochit 8852' 8640' Zone 4A 8964' 8747' Zone 3 9034' 8811' Zone 2C 9118' 8886' Zone 2B 9177' 8937' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32.1 hereby certi~.thatthe(,~/~__,~, foregoing is true,~,/~ and correct to the best of my knowledge Signed ~' -~0~'~ ~-~ Jam /' ' Title Engineering Supervisor Date 97-254 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IT£M 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. IT£M 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Il.EM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Il'EM 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 Facility Date/Time 22 Jan 98 23 Jan 98 24 Jan 98 25 Jan 98 26 Jan 98 27 Jan 98 28 Jan 98 29 Jan 98 Progress Report PB Q Pad Well Q-03A Page 1 Rig Nabors 2ES Date 11 February 98 18:00-06:00 06:00-09:00 09:00-12:00 12:00-13:00 13:00-18:00 18:00-19:00 19:00-21:00 21:00-23:30 23:30-04:00 04:00-06:00 06:00-09:30 09:30-12:00 12:00-13:30 13:30-15:00 15:00-23:00 23:00-00:00 00:00-03:30 03:30-06:00 06:00-07:00 07:00-07:30 07:30-10:00 10:00-13:30 13:30-14:30 14:30-16:30 16:30-18:30 18:30-19:00 19:00-21:30 21:30-23:00 23:00-00:00 00:00-01:30 O1:30-06:00 06:00-09:30 09:30-10:30 10:30-14:00 14:00-15:30 15:30-19:00 19:00-19:30 19:30-06:00 06:00-08:30 08:30-12:30 12:30-13:30 13:30-17:00 17:00-20:30 20:30-00:30 00:30-01:30 01:30-05:00 05:00-06:00 06:00-12:00 12:00-16:30 16:30-21:30 21:30-23:30 23:30-00:00 00:00-00:30 00:30-02:30 Duration 12hr 3 hr 3 hr 1 hr 5hr 1 hr 2 hr 2-1/2 hr 4-1/2 hr 2 hr 3-1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 8 hr 1 hr 3-1/2 hr 2-1/2 hr 1 hr 1/2 hr 2-1/2 hr 3-1/2 hr 1 hr 2 hr 2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 4-1/2 hr 3-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 10-1/2 hr 2-1/2 hr 4 hr 1 hr 3-1/2 hr 3-1/2 hr 4hr 1 hr 3-1/2 hr 1 hr 6 hr 4-1/2 hr 5 hr 2 hr 1/2 hr 1/2 hr 2 hr Activity Rig moved 100.00 % Rig moved 100.00 % Fill pits with Seawater Serviced Tubing hanger Freeze protect well - 200.000 bbl of Seawater Tested Casing Installed Hanger plug Removed All tree annulus valves Rigged up All rams Tested BOP stack Tested BOP stack Retrieved Hanger plug Retrieved Tubing hanger Circulated at 8762.0 ft Pulled Tubing on retrieval string to 8762.0 ft Rigged down Tubing handling equipment Rigged down BOP stack Installed Tubing head spool Installed Tubing head spool Tested Seal assembly Rigged up BOP stack Tested BOP stack Rigged up sub-surface equipment - Other sub-surface equipment Conducted electric cable operations Conducted electric cable operations Rigged down sub-surface equipment - Other sub-surface equipment Made up BHA no. 1 Singled in drill pipe to 550.0 ft Serviced Block line Repaired Drillstring handling equipment Singled in drill pipe to 3800.0 ft Singled in drill pipe to 5300.0 ft Installed Kelly Singled in drill pipe to 8748.0 ft Circulated at 8748.0 ft Conducted electric cable operations Cut Casing at 8742.0 ft Cut Casing at 8742.0 ft Circulated at 8771.0 ft Pulled Drillpipe in stands to 750.0 fl Pulled BHA Made up BHA no. 2 R.I.H. to 8771.0 fl Conducted electric cable operations Washed to 8771.0 ft Conducted electric cable operations Drilled to 8774.0 ft Drilled to 8800.0 ft Pulled out of hole to 8800.0 ft Pulled BHA R.I.H. to 5100.0 ft Serviced Block line Functioned downhole tools at 5100.0 ft R.I.H. to 8781.0 ft Facility Date/Time 30 Jan 98 31 Jan 98 01 Feb 98 02 Feb 98 03 Feb 98 04 Feb 98 05 Feb 98 Progress Report PB Q Pad Well Q-03A Page 2 Rig Nabors 2ES Date 11 February 98 02:30-06:00 06:00-00:00 00:00-01:00 01:00-04:00 04:00-05:00 05:00-06:00 06:00-10:30 10:30-11:30 11:30-13:00 13:00-15:30 15:30-16:30 16:30-17:30 17:30-00:00 00:00-03:00 03:00-04:00 04:00-06:00 06:00-10:00 10:00-15:00 15:00-15:30 15:30-17:30 17:30-21:00 21:00-01:00 01:00-02:30 02:30-06:00 06:00-10:30 10:30-15:30 15:30-16:00 16:00-16:30 16:30-18:00 18:00-23:00 23:00-03:00 03:00-06:00 06:00-09:30 09:30-00:00 00:00-06:00 06:00-07:00 07:00-13:00 13:00-16:30 16:30-19:00 19:00-21:00 21:00-01:30 O1:30-02:30 02:30-03:00 03:00-06:00 06:00-09:00 09:00-11:00 11:00-11:15 11:15-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-15:00 15:00-15:15 Duration 3-1/2 hr 18 hr 1 hr 3 hr 1 hr 1 hr 4-1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 1 hr 1 hr 6-1/2 hr 3 hr 1 hr 2 hr 4 hr 5 hr 1/2 hr 2 hr 3-1/2 hr 4 hr 1-1/2 hr 3-1/2 hr 4-1/2 hr 5 hr 1/2 hr 1/2 hr 1-1/2 hr 5 hr 4 hr 3 hr 3-1/2 hr 14-1/2 hr 6 hr 1 hr 6 hr 3-1/2 hr 2-1/2 hr 2 hr 4-1/2 hr 1 hr 1/2 hr 3 hr 3 hr 2 hr 1/4 hr 12-3/4 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr 2-1/2 hr 1/4 hr Activity Conducted electric cable operations Drilled to 9174.0 ft Circulated at 9174.0 ft Pulled out of hole to 850.0 ft Laid down 640.0 ft of 4in OD drill pipe Pulled BHA Downloaded MWD tool Made up BHA no. 4 Singled in drill pipe to 935.0 ft R.I.H. to 8700.0 ft Serviced Block line R.I.H. to 9174.0 ft Drilled to 9192.0 ft Drilled to 9197.0 ft Circulated at 9197.0 ft Pulled out of hole to 6500.0 ft Pulled out of hole to 0.0 fl Tested BOP stack Worked on BOP - BOP stack Made up BHA no. 5 R.I.H. to 9197.0 ft Drilled to 9372.0 ft Circulated at 9372.0 ft Pulled out of hole to 1580.0 ft Pulled BHA R.I.H. to 8740.0 ft Serviced Block line R.I.H. to 9268.0 ft Circulated at 9259.0 ft Pulled out of hole to 195.0 ft Pulled BHA R.I.H. to 8740.0 fi R.I.H. to 9372.0 ft Drilled to 9780.0 ft Drilled to 9835.0 ft Drilled to 9835.0 ft Logged hole with LWD: DIR/FE/DD from 9835.0 ft to 9067.0 ft Pulled out of hole to 0.0 ft Downloaded MWD tool Made up BHA no. 8 R.I.H. to 8700.0 ft Serviced Block line R.I.H. to 9471.0 fl Underreamed to 9495.0 ft Reamed to 9835.0 fl Drilled to 9884.0 ft Held drill (Kick while drilling) Drilled to 10189.0 fi Held safety meeting Drilled to 10347.0 ft Drilled to 10480.0 ft (cont...) Held safety meeting Drilled to 10570.0 fi Held drill (Kick while drilling) Facility Date/Time 06 Feb 98 07 Feb 98 08 Feb 98 09 Feb 98 Progress Report PB Q Pad Well Q-03A Page Rig Nabors 2ES Date 15:15-19:00 19:00-21:00 21:00-02:00 02:00-04:00 04:00-06:00 06:00-10:00 10:00-10:15 10:15-11:00 11:00-12:00 12:00-18:00 18:00-18:15 18:15-21:00 21:00-22:30 22:30-00:00 00:00-00:30 00:30-01:30 01:30-04:30 04:30-06:00 06:00-09:30 09:30-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-18:00 18:00-19:30 19:30-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-01:45 06:00-06:30 06:30-07:00 07:00-08:00 08:00-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-14:30 14:30-14:45 14:45-15:00 15:00-17:00 17:00-18:00 18:00-19:30 19:30-00:00 00:00-00:30 00:30-02:30 02:30-03:00 03:00-04:00 04:00-06:00 06:00-07:30 07:30-12:00 12:00-12:30 12:30-13:15 13:15-13:45 Duration 3-3/4 hr 2 hr 5 hr 2hr 2 hr 4 hr 1/4 hr 3/4 hr 1 hr 6 hr 1/4 hr 2-3/4 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1 hr 3 hr 1-1/2 hr 3-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1 hr 4 hr 1-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/2 hr 1/2 hr 1 hr 4hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 2 hr 1 hr 1-1/2 hr 4-1/2 hr 1/2 hr 2 hr 1/2 hr 1 hr 2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 3/4 hr 1/2 hr Activity Drilled to 10658.0 ft Circulated at 10658.0 ft Pulled out of hole to 2000.0 ft Pulled BHA Made up BHA no. 9 R.I.H. to 8700.0 ft Circulated at 8750.0 ft R.I.H. to 10600.0 ft Washed to 10658.0 ft Drilled to 10850.0 ft Held drill (Kick while drilling) Drilled to 10950.0 ft Circulated at 10950.0 ft Pulled out of hole to 8700.0 ft Held safety meeting R.I.H. to 10950.0 ft Circulated at 10950.0 ft Pulled out of hole to 8000.0 ft Pulled out of hole to 2000.0 ft (cont...) Pulled BHA Held safety meeting Pulled BHA Rigged up Casing handling equipment Ran Liner to 2300.0 ft (4-1/2in OD) Rigged up Tubing handling equipment Ran Tubing to 2200.0 ft (2-7/8in OD) Held safety meeting Installed Setting tools Circulated at 2300.0 ft Held drill (Kick while tripping) Held safety meeting Circulated at 8700.0 ft Ran Liner on landing string to 10950.0 ft Circulated at 10950.0 ft Held safety meeting Circulated at 10950.0 ft Batch mixed slurry - 62.000 bbl Pumped Water spacers - volume 55.000 bbl Mixed and pumped slurry - 62.000 bbl Displaced slurry - 96.000 bbl Circulated at 10860.0 ft Cleared Sand traps Circulated at 10860.0 ft Pulled Drillpipe in stands to 0.0 ft Held safety meeting Pulled Drillpipe in stands to 0.0 ft Rigged up Drillstring handling equipment Laid down 1000.0 ft of 2-7/8in OD drill pipe Laid down 2000.0 ft of 3-1/2in OD drill pipe Laid down 2000.0 ft of 3-1/2in OD drill pipe (cont...) Tested BOP stack Held safety meeting Tested Liner - Via string Held safety meeting 3 11 February 98 Facility Date/Time 10 Feb 98 11 Feb 98 PB Q Pad 13:45-17:00 17:00-18:30 18:30-00:00 00:00-00:30 00:30-02:00 02:00-02:15 02:15-03:00 03:00-03:30 03:30-04:30 04:30-04:45 04:45-06:00 06:00-12:00 12:00-12:30 12:30-13:30 13:30-16:00 16:00-19:00 19:00-19:30 19:30-21:30 21:30-00:00 00:00-00:30 00:30-06:00 Duration 3-1/4 hr 1-1/2 hr 5-1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 3/4 hr 1/2 hr 1 hr 1/4 hr 1-1/4 hr 6 hr 1/2 hr 1 hr 2-1/2 hr 3 hr 1/2hr 2 hr 2-1/2 hr 1/2 hr 5-1/2 hr Progress Report Well Q-03A Rig Nabors 2ES Page Date Activity Installed TCP Installed Retrievable packer Ran Drillpipe in stands to 10867.0 fi Held safety meeting Set packer at 8423.0 ft with 0.0 psi Perforated Reverse circulated at 8431.0 ft Retrieved Retrievable packer Laid down 1000.0 ft of Drillpipe Held drill (Kick while tripping) Laid down Drillpipe of 2000.0 ft Laid down 8500.0 ft of Drillpipe (cont...) Held safety meeting Retrieved Retrievable packer Laid down 2000.0 fi of Tubing Retrieved TCP Retrieved Wear bushing Rigged up Tubing handling equipment Ran Tubing to 1200.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 6500.0 fi (4-1/2in OD) 4 11 February 98 SPERRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE i SHARED SERVICES DRILLING PBU / Q-03A 500292032201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 020798 MWD SURVEY ~O~--NU~~-AKMM80106 KELLY BUSHING ELEV. = 70.22 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES VERT. DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 8729.02 8518.06 8447.84 1 19 8754.0~ 8543.03 8472.81 2 5 8767.87 8556.88 8486.66 3 12 8799.13 8587.99 8517.77 7 54 8830.60 8619.11 8548.89 9 8 S 26.70 E .00 505.02S 1247.44E -1205.34 S 40.64 W 8.02 505.62S 1247.27E -1205.68 S 50.08 W 8.57 506.07S 1246.81E -1205.70 S 58.28 W 15.21 507.76S 1244.31E -1205.31 S 61.53 W 4.20 510.09S t240.27E -1204.38 8863 . 39 8651 . 23 8581 . 01 8895 . 28 8681 . 96 8611 . 74 8927.40 8712.49 8642.27 8959.61 8742.68 8672.46 8991 . 63 8772.13 8701.91 13 48 17 10 19 16 21 48 24 32 S 63.31 W 14.28 513.09S S 64.39 W 10.61 516.84S S 81.87 W 18.14 519.64S N 81.48 W 19.70 519.50S N 66.59 W 20.14 515.98S 1234.48E -1202.78 1226.83E -1200.51 1217.29E -1196.29 1206.10E -1188.76 1194.10E -1178.16 9024.20 8801.65 8731.43 9055.59 8830.03 8759.81 9087.61 8858.93 8788.71 9118.73 8886.57 8816.35 9144.83 8909.28 8839.06 25 34 N 58.14 W 11.43 509.57S 24 57 N 58.67 W 2.10 502.55S 26 1 N 58.14 W 3.39 495.33S 28 44 N 51.11 W 13.56 487.03S 30 18 N 49.23 W 6.98 478.79S 1181.92E -1165.29 1170.51E -1152.47 1158.77E -1139.28 1147.14E -1125.35 1137.27E -1112.64 9177.44 8937.38 8867.16 9208.01 8962.88 8892.66 9240.42 8987.26 8917.04 9271.57 9006.83 8936.61 9303.81 9022.32 8952.10 30 39 N 47.36 W 3.10 467.78S 36 15 N 45.92 W 18.47 456.21S 46 1 N 44.84 W 30.22 441.24S 56 1 N 44.10 W 32.15 423.97S 66 27 N 43.48 W 32.43 403.59S 1124.92E -1096.21 1112.69E -1079.43 1097.54E -1058.18 1080.61E -1034.03 1061.08E -1005.83 9331.07 9031.22 8961.00 9369.20 9037.01 8966.79 9401.14 9038.11 8967.89 9432.98 9038.81 8968.59 9465.98 9039.21 8968.99 75 22 N 44.53 W 32.89 385.08S 87 8 N 41.97 W 31.57 357.68S 88 55 N 39.74 W 8.93 333.53S 88 33 N 39.74 W 1.16 309.06S 90 5 N 39.14 W 5.01 283.58S 1043.20E -980.12 1017.44E -942.51 996.56E -910.60 976.21E -878.78 955.25E -845.81 9497.45 9038.98 8968.76 9529.77 9038.01 8967.79 9562.22 9036.02 8965.80 9593.38 9033.53 8963.31 9624.19 9030.88 8960.66 90 44 N 39.20 W 2.07 259.18S 92 40 N 39.40 W 6.03 234.18S 94 21 N 37.88 W 6.98 208.89S 94 48 N 38.46 W 2.35 184.47S 95 3 N 38.70 W 1.12 160.48S 935.37E -814.37 914.91E -782.09 894.69E -749.75 875.50E -718.75 856.35E -688.09 9656.55 9028.15 8957.93 9688.41 9025.86 8955.64 9720.48 9023.96 8953.74 9752.70 9022.16 8951.94 9778.30 9020.80 8950.58 94 36 N 38.57 W 1.45 135.29S 93 39 N 38.63 W 2.99 110.45S 93 7 N 38.85 W 1.79 85.48S 93 16 N 39.34 W 1.58 60.52S 92 48 N 39.20 W 1.91 40.73S 836.22E -655.89 816.40E -624.16 796.36E -592.18 776.08E -560.04 759.90E -534.50 SPERRY-SUN DRILLING SERVICES ANCHOraGE ALASKA. PAGE 2 SHARED SERVICES DRiLLiNG PBU / Q-03A 500292032201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 020798 MWD SURVEY JOB NUMBER: AKMM80106 KELLY BUSHING ELEV. = 70.22 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9810.47 9020.07 8949.85 89 49 N 38.21 W 9.76 9842.20 9021.04 8950.82 86 40 N 38.57 W 9.99 9874.36 9023.20 8952.98 85 37 N 38.64 W 3.24 9906.66 9025.34 8955.12 86 45 N 39.31 W 4.06 9937.23 9026.34 8956.12 89 30 N 38.49 W 9.39 15.63S 739.79E -502.38 9.22N 720.09E -470.72 34.30N 700.07E -438.67 59.35N 679.80E -406.48 83.13N 660.62E -375.96 9969.78 9026.40 8956.18 90 16 N 37.52 W 3.80 10001.79 9026.10 8955.88 90 46 N 36.58 W 3.31 10032.68 9025.80 8955.58 90 20 N 36.97 W 1.88 10065.03 9025.51 8955.29 90 42 N 36.82 W 1.23 10097.39 9024.14 8953.92 94 7 N 37.63 W 10.86 108.77N 640.58E -343.48 134.32N 621.29E -311.57 159.06N 602.80E -280.79 184.93N 583.38E -248.54 210.67N 563.83E -216.31 10129.63 9021.22 8951.00 96 15 N 36.92 W 6.96 10160.55 9017.74 8947.52 96 39 N 37.03 W 1.34 10192.35 9014.56 8944.34 94 50 N 39.35 W 9.24 10224.33 9011.98 8941.76 94 24 N 43.07 W 11.67 10256.22 9009.66 8939.44 93 56 N 44.03 W 3.34 236.21N 544.38E -184.30 260.76N 525.91E -153.67 285.62N 506.35E -122.09 309.60N 485.35E -90.22 332.65N 463.44E -58.44 10287.96 9007.76 8937.54 92 54 N 43.80 W 3.36 10319.89 9006.73 8936.51 90 48 N 44.65 W 7.09 10352.33 9006.59 8936.37 89 41 N 44.58 W 3.43 10383.56 9006.99 8936.77 88 51 N 45.44 W 3.83 10415.75 9007.56 8937.34 89 6 N 46.69 W 3.96 355.47N 441.46E -26.78 378.34N 419.21E 5.09 401.43N 396.42E 37.48 423.50N 374.34E 68.65 445.84N 351.16E 100.74 10447.80 9007.46 8937.24 91 15 N 48.64 W 9.06 10479.42 9006.20 8935.98 93 18 N 48.77 W 6.46 10511.53 9004.47 8934.25 92 51 N 48.48 W 1.64 10543.19 9002.97 8932.75 92 33 N 48.69 W 1.16 10575.13 9001.60 8931.38 92 22 N 49.02 W 1.19 467.42N 327.47E 132.60 488.26N 303.74E 163.94 509.46N 279.68E 195.76 530.38N 255.96E 227.15 551.37N 231.93E 258.80 10608.26 9000.44 8930.22 91 37 N 48.64 W 2.51 10640.47 9000.32 8930.10 88 48 N 50.75 W 10.96 10671.89 9001.25 8931.03 87 48 N 51.62 W 4.19 10703.68 9003.15 8932.93 85 20 N 51.95 W 7.81 10735.76 9005.84 8935.62 85 1 N 52.78 W 2.78 573.17N 207.01E 291.64 594.00N 182.45E 323.52 613.69N 157.98E 354.48 633.3!N 133.06E 385.70 652.83N 107.74E 417.10 10767.58 9008.51 8938.29 85 20 N 52.74 W 1.05 ~0799.23 9010.60 8940.38 87 4 N 52.24 W 5.66 10831.33 9012.14 8941.92 87 26 N 51.34 W 3.04 10863.54 9013.56 8943.34 87 30 N 51.01 W 1.04 10888.41 9014.71 8944.49 87 11 N 50.97 W 1.22 672.02N 691.25N 711.08N 731.25N 746.89N 82.50E 448.20 57.45E 479.21 32.26E 510.76 7.19E 542.48 12.12W 566.99 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA ~PAGE 3 SHARED SERVICES DRILLING PBU / Q-03A 500292032201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 020798 MWD SURVEY JOB NUMBER: AKMM80106 KELLY BUSHING ELEV. = 70.22 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10952.00 9017.81 8947.59 87 11 N 50.97 W .03 786.89N 61.46W 629.65 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 789.28 FEET AT NORTH 4 DEG. 27 MIN. WEST AT MD = 10952 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 318.45 DEG. TIE-IN SURVEY AT 8,729.02' MD WINDOW POINT AT 8,754.00' MD PROJECTED SURVEY AT 10,952.00' MD SPERRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA · PAGE 4 SHARED SERVICES DRILLING PBU / Q-03A 500292032201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 020798 JOB NUMBER: A~M80106 KELLY BUSHING ELEV. = 70.22 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8729.02 8518.06 8447.84 9729.02 9023.49 8953.27 10729.02 9005.26 8935.04 10952.00 9017.81 8947.59 505.02 S 1247.44 E 210.96 78.84 S 791.02 E 705.53 494.57 648.77 N 113.09 E 1723.76 1018.23 786.89 N 61.46 W 1934.19 210.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -PAGE 5 SHARED SERVICES DRILLING PBU / Q-03A 500292032201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 020798 JOB NUMBER: AKMM80106 KELLY BUSHING ELEV. = 70.22 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8729.02 8518.06 8447.84 8781.25 8570.22 8500.00 8883.05 8670.22 8600.00 8989.53 8770.22 8700.00 505.02 S 1247.44 E 506.71 S 1245.91 E 515.35 S 1229.89 E 516.30 S 1194.91 E 210.96 211.03 .07 212.83 1.80 219.31 6.47 9100.26 8870.22 8800.00 9217.49 8970.22 8900.00 10952.00 9017.81 8947.59 492.11 S 1154.05 E 452.01 S 1108.41 E 786.89 N 61.46 W 230.04 10.73 247.27 17.23 1934.19 1686.91 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TONY KNOWLE$, GOVEF~NOF~ ALASI~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 30, 1997 Dan Stoltz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit Q-03A BP Exploration (Alaska) Inc. Permit No. 97-254 Sur. Loc. 446'SNL, 947'WEL, Sec. 16, TllN, R13E. UM Btmnhole Loc. 129'NSL, 796'WEL, Sec. 09, T11N. R13E. UM 'Dear Mr. Stoltz: Enclosed is the approved application for permit to rcdrill thc above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice mav be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. " STATE OF ALASKA ALASf~,~ OIL AND GAS CONSERVATION C~-~vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 68.7' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028281 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 446' SNL, 947' WEL, SEC. 16, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 4506' NSL, 5277' WEL, SEC 15, T11N, R13E, UM Q-03A At total depth 9. Approximate spud date Amount $200,000.00 129' NSL, 796' WEL, SEC 09, T11N, R13E, UM 01/03/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028284, 129'I No Close Approach 2560 10656' MD / 8910' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8750 Maximum Hole Angle 104° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# 1-80 BTC-Mod 2056' 8600' 8319' 10656' 8910' 200 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. B ~ ,... ',,,. f,,,.,, . .- ,.,,. Present well condition summary Total depth: measured 9550 feet Plugs (measured) DEC 2 ~1997 true vertical 9337 feet Effective depth: measured 9036 feet Junk (measured) fill at 9036' (12/89) AJaska 0il & Gas Cons. Commission true vertical 8823 feet Anchorage Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 650 sx PF II (Approx) 140' 140' Surface 2645' 13-3/8" 3448 sx ArcticSet II 2676' 2676' Intermediate 8493' 9-5/8" 990 sx Class 'G', 430 sx ArcticSet I 2395' - 8532' 2395' - 8319' Production Liner 1546' 7" 340 sx Class 'G' :. 8004' - 9550' 7792' - 9337' Casing Tieback 2518' 9-5/8" x 7-5/8" 295 sx Cold Set III, 350 sx CS II 22' - 2540' 22' - 2540' . :: Perforation depth: measured 8955' - 8960', 9220' - 9246' Squeezed but leaking: 9101' - 9220'0RIGJNAL true vertical subsea 8678' - 8969' (two intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Winton Auberf, 564-4825 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that th~"~egoing i.~¢tru,,e ar~/correct to the best of my knowledge Signed Dan Stoltz ~[ -/./r~-~-...~/'~.¢~ ~:;r~., Title Senior Drilling Engineer Date /Z - ~ "Z -¢"~ Commission Use Only Permit Number I APl Number AppJ;~)val Date ~;~,~ I See cover letter ~/~ %2. ~' .~ 50-029-20322-01 /_/~ -'.,...~ for other requirements Conditions of Approval: Samples Required []Yes [] No Mud Log Required []Yes .[~ No Hydrogen Sulfide Measures ,~Yes [] No Directional Survey Required ~Yes'[] No Required Working Pressure for BOPE []2M; [] 3M; [~..5M; [] 10M; [] 15M Other: by order of Approved By '0i'i(liF, al Si¢ined ~¥ Commissioner the commission Date Form 10-401 Rev. 12-01-85 Oa~;id W. johnston Submit In Triplicate I Well Name: ]Q-3A HAW Sidetrack Summary I Type of Well: IPr°ducer I ISurface Location: Target Location: Bottom Hole Location: 4833' FSL, 947' FEL, S16, TllN, R13E, UM 4506' FSL, 5277' FEL, S15, TllN, R13E 129' FSL, 796' FEL, S09, TI iN, R13E, UM I AFE Number: 14P1053.0 J · Alaska 0il & Gas Cor~, Commissi~ I Rig: I Nabors 2ES ~.c~ra~ I Estimated Start Date: 1/3/98 Operating days to complete: [ 19 IMD: 110,656' I I TVD: 18910' ss I Elev.168.7'I [Well Design: I HAW Sidetrack Objective: Q-3A is a horizontal sidetrack with an inverted tail targeting mid Zone 2 reserves in an 83 acre drainage area west of the Q-03 location. NLOC is 65'. The target lies in a regional Iow downthrown to an extensive northwest/southeast-trending down-to-the south fault. The proposed Q-3A will optimize Zone 2 oil production by placing a 600' horizontal well section in the 24P reservoir immediately above the HOT. Formation Markers Formation Tops Sag River Shublik MD Pilot 8741' 8771' TVD (ss) 8460' 8490' TSAD 9029' 8740' TD 10,656 8910' I KOP: [8750' MD Directional Maximum Hole Angle: Rig Move Close Approaches: Drilling Close Approaches: 104° through targets None None Casing/Tubing Program Hole Size Tubular Wt/Ft Grade Conn Length Top Btm O.D. M DFFVD M D/TVD 6" 4-1/2" 12.6# L-80 BTC-M O D 2056 860078319' 10656'/8910' Production Tubing I I I I NA I 4-1/2,, 12.6# L-80 BTC-MO D 8574' 26'/26' 8600'/8319' Mud Program Milling Interval: Gel-free 6% KCl Biozan I Density, ppg I Funnel Vis, sec I YPI Gels i pH I^.,..,ool 9.8 - 10.0 50 - 65 50 - 60 20-30 / 30-40 9 - 10 6 - 8 Hazards/Concerns Maintain YP 50 - 60 to insure adequate removal of metal cuttings. Insure adequate preparation to eliminate metal entering motor and MWD from mud bypassing solids control equipment. Production (6" hole) Sections: Quickdriln (viscosified SW) [ Density, ppg I Funnel Vis, sec LSRY~ I LSRV,sI pH APl FL, cc HPHTFL 8.6 - 8.8 55 - 65 14 - 20 > 50,000 8.5 - 9.0 NC < 10 cc Hazards/Concerns Potential high torque could require lubricant use. Be alert for lost circulation, differential sticking due to overbalanced MW. Maximize solids control to keep fluid as clean as possible. Max mud weight 8.8 ppg. Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments 4-1/2" N/A 200 / 15.7 / 1.19 Class G: 30% excess; Pump time = 4 hr.; TOC 150' above KOP Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Logging Program IOpen Hole Logs: 6" Hole Cased Hole Logs: I MWD Dir/GR; base Z3 to TD 4-Phase/Neutron/Density None planned Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular pre- venter will be installed and is capable of handling maximum potential surface pressures. DJ- verter, BOPE and mud fluid system schematics on file with AOGCC. Hazards · Q-Pad is a known shallow hydrocarbon area. · Stuck pipe, tight hole, and swabbing have occurred in Q-Pad wells. · Lost circulation through conductive faults is a possibility on Q-Pad. Q-3A CI II drilling wastes are to be disposed at CC-2A grind and inject facility. If Cl I wastes are generated, they will be taken to the Pad 3 disposal site. Pre-Rig Procedure 1. Operations Summary , Notify AOGCC representative prior to commencing P&A operations. 2. Kill well with sea water. If significant fluid loss is experienced (> 20 bbl/hr), inform Nabors 2ES rig representative immediately. 3. RU and establish injection using seawater. Bullhead seawater to kill well if necessary. Mix and pump 16 bbl (90 ft3) Class G cement. Displace cement until +5 bbls cement are squeezed into perforations from 9220'-9246' MD, leaving _+1.6 bbls (_+125') cement above top perforation. Proposed TOC is _+8830' MD (above upper straddle packer). Highest ac- ceptable T©C is 8800' MD due to required depth of kick-off whipstock. 4. RU electric line unit and chemical cutter for 4-1/2" tubing. RIH and chemical cut 4-1/2" tubing at _+8830' MD, avoiding collars. 5. RU and reverse circulate seawater through tubing cut until returns are clear. Monitor for fluid loss. Freeze protect well with diesel to 2,000'. 6. Have FMC wellhead services test 9-5/8" packoff to 5,000 psi and service lock down studs. Notify Rig Representative immediately of any pressure test or wellhead condition problems. 7. Bleed pressure from tubing, inner and outer annuli; zero psi is required all around. Install BPV. Remove well house and flowlines. Prepare for rig arrival. Level pad. Dig out cellar. Drilling Rig Procedure 1. MIRU drilling rig. Kill well if necessary. ND tree, NU and test BOPE. 2. Pull tubing hanger and 4-1/2" tubing. 3. Test 9-5/8" casing to 2500 psi. 4. Set whipstock and mill window through 7" liner @ _+8730' MD. 5. Kick off and directionally drill 6" wellbore to TD @ _+10,656' MD. 6. Run and cement 4-1/2" L-80 liner to TD. 7. DPC perforate 4-1/2" liner. 8. Run 4-1/2" L-80 completion with packer @ _+7750' MD. 9. Freeze protect well, set packer, set BPV, ND BOPE, NU and test tree, RDMO. W Anmda-i 11 Schl ung>e rDer .......................................................................................................... ' .... ', £. _ _ ~ .'.'.-_ ,','. '_. _~LZ ' ' _ ................................................... 1111 EaSt 8Otb Avenue Anchorage, ~ 99538 (g07) 349-4511 F~ 344-216D DIRJDCTIONAL WE~L PLA~ for SEARED SERVICES DRILLI~ n,, 7- Well ......... : Q-03A (PA) Field ........ : P~udhoe Bay, Q-Pad C~utation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.31357DD8 N S~rface Long.: 148,83689371 W L4}CAT/O~ - ALASKA Zone: ~ Legal ~escription X-Coord Y-Coord S~rfRce ...... : 4533 FSL 947 PEL S16 Tll~ R13E ~4 643511.00 5965626.0~ ~T ~ St~: ~506 FSL 5277 ~BA S15 TZi~ R13E ~ 6~4467,5D 596531~.5D ~ ~wer ~d: 5027 FgL ~41 PEL S16 TllN R1BE ~ 6~4012.50 5965~40.00 TGT Uppr S~rC: 5276 ESL 653 ~L SI6 TI~ R13E ~ ~43795.00 5966075.80 T~T Upper End: 129 FSL 796 ~L S~9 TI~ RLS~ ~ 643655.08 5966205.~0 PROPOSED STATIO~ P~fl%DURED TZE-I~ SLTRVE¥ 8729.02 TOP SA~ RI~ 8941.18 TOP OF WI~W 87~5.0D KOP ~R~ 12/100 8750-00 INCZ~q DI RECT1ON VERTICAL-DEPT~S A/9~LE AZIMUT~ TVS SUB- SEA 1.32 153.30 8516.54 1.32 153.26 $528.70 8460.00 1.32 153.25 8532.52 1,3~ 153.24 85]7,52 8468.82 2.68 222.97 8558.7~ 8490.00 END Z2/~00 CURVE CURVE 58/100 8800,00 5.94 239.48 8587.42 8518.72 8857,06 12.71 246.22 8643.7D 8575.00 8878-63 15.29 247,23 866~.62 8595.92 8966.84 15.29 247.23 87~9.75 8681.01 ,(A~adrill (c)97 Q03AP4 3.0C 1:07 PM P) P~parmd ..... : O~ Oct 199~ Vert sect az.: 318,45 KB elevation.: 68.70 ft Ma~etic Dcln: +28.161 (E) S~ale Factor.: 0.99992340 Conver~mnceo,: ~1.0951{026 SECTION C~DORDINAT~S- FROM D~PART WELLHEAD -1205,38 505.02 S 1247.44 -1~05,65 505.2? S 1247.56 -~05.73 505.34 S 1247.6~ -i~DS.B~ 505.45 S Z247.66 -1206.12 506.03 S 1247.43 ANADRILL AKA~DPC FEASIBILITY PLAN ^ P OVED [OR EXECUTION 'LAN - ~ ~ Zone ~ Y 644767.77 5965L44.95 644767,90 5965144.71 644767,94 5965~.63 64R767.99 596514~.53 644767.78 5965143.9~ -L205.9L S07.28 S 12~5.68 E -1203~~3 511.32 S 1237.3~ E -1~0~.79 513.38 S 1232.59 E -1194.30 522.38 S 1211,15 E 6~766,06 59651~.66 6~4757~8~ 5965138.46 644753.09 5965L36.31 64472~,73 5D65124.6D TOOL D~/ FACE ZOO l~3R <TIE 153E O. 02 153R 0.02 12.00 LBR 52_00 6R L2.00 ~D 12.00 73R 0.00 55R 28.00 STATION MEASURED INCLN DIRECTION VERTICAL-OEP~/7{$ IDE~TIFICATI0~ DEPT~ A/~GLE AZI~T~ ~ SUB-S~ TOP ~LEROCHIT 9028.85 2L.29 277.96 8808.70 9100,DD 31.70 295.03 8872.38 ~OT 9139.52 34.82 297,99 S888.70 9200.~0 48,18 306,53 8948.89 9300.00 65-32 313.15 9003,55 8740.00 8803.68 $820.00 8880.19 8934.85 SECTION DEPART -11S3.07 -2155.98 -1146.05 -1094,91 -1012.53 [997 Page 2 COORDINATES-FROM ALASKA Zone 4 WEI/hH~ X Y 523,99 S 1192.40 E 644713.10 596~12%.93 514.25 S 1362.55 E 64~683.07 5965~34.10 509.47 S 1152,97 E 64%673.~1 5965138-70 ~80-68 S llQS.E5 E 64~628.25 5965166.63 426.98 S 1044.7& E 644563.63 5965219.10 ~gR 1~.0~ ~ ~8.00 20R 1~.00 16R [8.00 J J n~' Z <E 9~00,00 82.68 318.12 9031.02 8962.32 END 18/100 CURVE 9442.02 90.00 320,05 9033.70 8965.00 TARGET (~OWER) ~*** 9442.02 90.00 320.05 9033.70 8965.00 CURVE 15/]00 ~0134.91 90.00 320.05 3033.70 8965.00 TARGET (LOWER) #*"** ~013~,91 90.00 320.05 9033.70 8965.00 10200.08 99.74 319.43 9028,18 89~9.48 E~TD 15/100 CURVE 50227,33 103.8% 319.16 9~22.60 8953.90 C3URVE 15/L00 10360-17 103.84 319.L6 8990.83 8922.13 1O4OO-OO 98.38 316.67 8983.16 8914.46 END 15/100 CCTRVE 1046L.04 90.00 A~2.97 8978.70 8910.D0 -916.91 -875.0[ -875.01 -182.~8 -182,38 -117_63 -90.88 38.09 77.16 137.85 326.75 326.75 204-39 204_39 253.82 274.10 37[.68 400.67 443,52 TARGET (UPPER) ***## 10%61.04 90.00 312.97 8978.?~ 8950.00 137,~5 ~43.52 TD / %-1/2" LNR <1]> 1D655~80 90,00 312,97 897S.70 8910.00 3~1.72 576.28 977.94 ~ 6~95,54 5965986.37 950.50 E 6~4467.50 5965317.50 950_5~ E 644467.50 59653~7,58 505-54 E 644012.50 5965840.00 505.54 E 6~4012.50 5965~40.00 iSR 18.00 HE 18.00 85 18.00 aL O.DO 463.68 E 643969.71 5965888.62 4L 15.00 4~6.23 E 64395[.88 5965908.56 ES 15.00 361.88 E 6~3865,69 5966004.50 156L 0,00 335.69 E 6~3838.95 5966032.98 156L 15-00 ~92.55 E 643795.00 5966075,00 MS 15.00 292,55 E 6~3795.00 5966075.00 HS 15,00 150.05 E 6~3650.00 5966205.0~ 0.00 (Anadrill [c)97 Q03AP4 3.DC 1:07 P~ P) ANADR!LL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION LAN I ...... S'MA E'D i I III . __ I I II II ._ 4nadr ........... J ] ] Sch]umberger,. I ~ TVD Scale - ~ inch = 200 feet , .................. IOeP Scale ' J inch = 200 feet -- "!'" .~ k, ~mL[....F EAS lib t k I'I'Y PLAN'~A-r"",. ,mr'_ I Dra~n .... ' 01 Oct 19§7 ii ii i DLA M ~ ' C} KOP CURVE 12/100 8750 8538 .... , r[r~~ g] END ~2/tOOCURVE ~79 8665 - : ..... E] 8roVE lB/lO0 8967 8750-1~94 ~5.; F] E~ JB/IOD C~VE 9442 9034 -875 90.( ............... Gl TARGET [LO~E~ *~ 9442 go~ -875 90.( H) C~VE 15/J00 10135 9034 -J82 90.( I) [ARBEI tLOEER] ~ J0135 9034 -]82 90,( d) END 15/JO0 CURVE ]0227 ~23 -gl 103,~ " K) CURVE 15/100 10~0 BggJ 3B 103,[ ' ~ ~ ' ~ -~ ~a~ 1~-~ L) EN9 15/~00 CUR~ 10~6~ $979 138 ~0,[ h~ ~ k~-~ M} TAROT (UP~ER) ~,~ 10461 8979 13B gO.( ....... ~1 ID / ~-t/2' L~R 41> 10656 8979 33~ 90.[ ...................................... ~ [~ff -~ , I .......... - - -~ ........ ~ ~o~- ~ r -' I , .r ~z ~ ............. , ~ _. ~;~ ~ .. ~ F H d .... , ...... 1 I _. LN _J J U Z B4 I I --- -1400 -i300 -1200 -JlO0 -lO00 -900 -BOO -700 -600 -500 -400 -300 -200 -100 0 tO0 200 300 400 ~ Section Departure ~a~]l (cl97 ~3~P~ 3.OD ]: ~ ~ PI SEF 'VIC-ES "DRIELI'NG' _ i mm I _ Q-OBA (P4) VERTICAL SECTION im i . mlmll i i Section at: 3~8.45 VIEW · iit ~"~' Hlrker Identification NO N/S £/~ /,/ TIE-IN SURVEY 8729 505S BJ TOP OF WINDOW 8745 505 J248 C:J KOP CURVE 12/100 8750 505 S t248 E hJ END ~2/100 CURVE 8879 513 ~233 E:/CURVE 18/100 8967 522 S 12tl E ['J END 18/100 CURVE 0442 327 S B§! E (;J TARGET (LOWER) ~.~ 8442 ~27 $ g§1E HJ CURV~ ~5/100 t012§ 2a4 N !J TA~G£T (LDWE~I ~ 10125 204 N §DC E dj END t5/100 CURVE t0~27 274 N 44§ E I] CURVE ~§/~00 10360 37~ N 3§2 E END 1~/100 CURVE 10461 444 N 293 E 1 4 TARGET (UPPER) ~ 10461 444 N 293 E ',J TD / 4-1/2" LNR <Ii > i065fi 576 N 150 SH/ RED SE VI CES ~r--4' INIi DRILLING ! -03A (P4) PLAN · _ CLOSURE · 595 feet at Azimuth J4,59 DECLiNATiON' +28.J6~ (E) SCALE ' ~ inch = 200 feet DRAWN ' O~ Oct ~gg7 -. /nadni l] Schlumberger Imm i (madr~11 ~ rt (Point) __ X E, XEC JTIC m m ~ ' -- ~ '" r~"' ~[X ~ .... .... ~ ,, ,~ , ........ , , mmm ,,, . .. ., ,, ~ 0 0 100 200 300 400 500 600 700 800 900 1000 1~00 i200 1300 <- ~EST' EAST -> 97 ao3~4 3,OC l~ 13 PM P) S'0 39~d Od~ 3qI~N~ 09~-~£-Z06 eS:L~ L66~/8~/~ WELLHEA 518" 5M McEvoy - ~-. ~ KB. ELEV = ' BF. ELEV = ' 9-5/8" x 13-3/8" annulus cemented with . 295 sxs Cold Set III and 350 sxs Cold Set II from 2395'. sudace . 9.518-47 L-80 ! 2366' XO g~5/8" X 7-5/8 .... 8TRS ' .... NO MD(BKB) TVOss: DEV. KOP: 2100' MAX ANGLE to Top Sag River: 25° @ 4000' '2 MAX ANGLE to below Top Sag: 104° @ 10.228' 1 : TUBING ID: 3.958" CAPACITY: .01522 BBL/FT 4-1/2" 12.6 #/ft, L-80,1BT Mod X ~ 9-5/8~ Production Packer @ 7850' MD TUBING · · 4-1/2" XN Nipple ~ 9-5/8" x/7~ Liner Top Packer @ 7900' MD , Seal Receptacle was pulled from well in 1991 workoverI Top of 7" liner @ 8031' MD L-80, BTRSTubing Cut @ 8830' MD Whipstock @ 8729' MD ~~~ 4-1/2" 12.6# L-80 @ 10,665' MD PERFORATION SUMMARY ::::"::':-'- .... 33,8" 2 ' 8955- 8960' P&A'd ~'-'-"~ ~ P&A Plug from 8850' to 9356' MD. L ~/I "'~" FISH~ ~' 9357' Otis WD packer pushed I I~Nt to bottom 12/17/91 PBTD I 9357' I --~ :..i~ THREE PRONG GRAB WITH 41/2" GS FN. DATE REV. BY COMMENTS PRUDHOE BAY UNIT 9-24-78 INITIAL COMPLETION WELL: Q-03A (9-11--13) 4-26-91 GRV E LINE STRADDLE PKR AP! NO: 50-029- 6-30-91 A. TELL REVISED 1-17-92 MJL RIGWORKOVER __SEC 16;TN 11N; PGE 13E 9/17/95 Randall WLEG added 10~9/97 Hernandez Proposed Sidetrack Well Completion BP ~ ,',l +;_xp,ora. on~^~ ~- ~v_,,as,,,a/ ,, H130619 DA~E I I O.EC~NO. / VENDOR AI_AS½AST 14 OC DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 1119?7 CK 11- 1877L 1- 00. O0 t_ 00. O0 PYMT COMMENTS: accompan§ permit, to drill app 1 ication HANDLING INST.- s/h teerie hubbie, x46~8 THE A~ACHED CHECK IS IN PAYME~ FOR ~M$ DE~fllBED ABOVE. iielf,_ll z ~ ~ ~n 1 ~. ~.~ · WELL PERMIT CHECKLIST COMPANY .,~ FIELD & POOL ~'~z'zd/'~' 0 INIT CLASS ADMINISTRATION ENGINEERING APPR ..~ WELL NAME/~ ¢-c2:)3,~ PROG, RAM: exp [] dev'"~'redrll~ serv [3 wellbore seg F_: ann. disposal para req F GEOL'AREA ~:~?0 UNIT# ' /t~5~ ON/OFF SHORE ~ N N N Y N 1. Permit tee attached ..................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7, Sufficient acreage available in drilling unit ........ 8. If deviated, is wellbore plat included ............ 9. Operator only affected party .................. 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12 Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... REMARKS 14. Conductor string provided .................. Y N 15. Surface casing protects all known LISDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ ,¢~Y N 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ('Y~N 25. BOPF's, do they meet regulation ....... .,..~ ..... 26, BOPE press rating appropriate; test to ~, ~.v v psig, 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 'Y~N GEOLOGY D T 30. Pe~:mit can be issued w/o hydrogen sulfide measures ..... Y N ' 31. Data presented on potential overpressure zones ...... 32. Seismic analysis of shallow gas zones ............. Y//.N 33. Seabed condition survey (if off-shore) ............. /Y N 34. Contact name/phone for we.ekly,progress repo. rts ...... // Y N lexploratory only] GEOLOGY: ENGINEERING' COMMISSION: R PC/~--_~ BEW~~([ DWJ~ JDH ~ RNC~ ~ CO Comments/Instructions: HOW/lit Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Mar 09 16:48:25 1998 Reel Header Service name ............. LISTPE Date ..................... 98/03/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/03/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Q-03A 500292032201 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 09-MAR-98 MWD RUN 1 AK-MM-80106 K. FERGUSON C. RUSSELL MWD RUN 2 AK-MM-80106 R. KRELL C. RUSSELL MWD RUN 3 AK-MM-80106 R. KRELL C. RUSSELL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-M~-80106 R. KRELL C. RUSSELL MWD RUN 6 AK-MM-80106 M. GABEL C. RUSSELL MWD RUN 6 AK-MM-80106 M. GABEL C. RUSSELL JOB NUMBER: MWD RUN 7 AK-MM-80106 MWD RUN 8 AK-MM-80106 LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD M. GABEL C. RUSSELL S. LAITILA C. RUSSELL 16 lin 13E 446 947 70.20 68.80 39.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 6.000 10952.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1,2,5 AND 6 ARE DIRECTIONAL WITH SLIM HOLE DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), STABILIZED LITHO DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). HOWEVER, NO SLD AND CTN DATA ACQUIRED DUE TO TOOL FAILURES ON RUN 1 AND 5. SLD AND CTN DATA FROM 9089'MD, 8860'TVD TO 9293'MD, 9018'TVD IS MEASURED AFTER DRILLING (MAD). 3. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH NATURAL GAMPU~ PROBE (NGP). 4. MWD RUNS 7 AND 8 ARE DIRECTIONAL WITH SLIM HOLE DGR AND EWR4. 5. GAMMA RAY DATA FROM 9136'MD, 8902'TVD TO 9322'MD, 9029'TVD IS FROM NGP. RESISTIVITY DATA FROM 9143'MD, 8908'TVD TO 9329'MD, 9031'TVD IS MEASURED AFTER DRILLING (MAD). 6. A MAD PASS WAS MADE FROM THE END OF RUN 6, 9832'MD, 9020'TVD TO 9067'MD, 8840'TVD WHILE TRIPPING OUT OF THE HOLE ON RUN 6. 7. DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN G. BERNASKI AND R. KALISH ON 02/20/98. THIS DATA IS PDC. 8. MWD RUNS 1 THROUGH 8 REPRESENT WELL Q-03A WITH API#: 50-029-20322-01. THIS WELL REACHED A TOTAL DEPTH OF 10952'MD, 9018'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SBDC = SMOOTHED BULK DENSITY (CALIPER CORRECTED). SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. SPSF = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY. SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI GR RPD RPM RPS RPX PEF DRHO RHOB FET ROP $ .5000 START DEPTH 8716.5 8716.5 8716.5 8731 5 8738 5 8738 5 8738 5 8738 5 8740 0 8740 0 8740 0 8769 5 8771 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 9743.5 9743.5 9743.5 10908.5 10915.5 10915 5 10915 5 10915 5 9760 0 9760 0 9760 0 10915 5 10952 0 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 MWD 4 MWD 6 MWD 7 MWD 8 $ REMARKS: MERGED MAIN PASS. MERGE TOP 8771.0 8798.0 9174.0 9198.0 9372.0 9832.0 10658.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 8798.0 9174.0 9198.0 9372.0 9832.0 10658.0 10952.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 GR MWD AAPI 4 1 68 NPHI MWD P.U. 4 1 68 RHOB MWD G/CC -4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 FET MWD HOUR 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 ROP MWD FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 8716.5 10952 9834.25 RPX 0.1596 2000 14.2677 RPS 0.4136 2000 22.386 RPM 0.1739 2000 27.3501 RPD 1.6944 2000 31.307 GR 15.6708 517.358 40.5845 NPHI 4.9 62.91 22.2116 Nsam 4472 4355 4355 4355 4355 4355 2055 First Reading 8716 5 8738 5 8738 5 8738 5 8738 5 8731 5 8716 5 Last Reading 10952 10915.5 10915.5 10915.5 10915.5 10908.5 9743.5 RHOB 1. 4146 3. 0038 2. 35749 2041 DRHO -0. 179 0. 8257 0. 129751 2041 PEF 0.8149 14.2896 2.22771 2058 FET 0. 423 94 . 1406 8 . 98678 4293 FCNT 3 . 504 97 . 511 21 . 0591 2055 NCNT 594 . 475 2023.59 1181.02 2055 ROP 1. 6291 986. 133 62. 8359 4362 8740 8740 8731.5 8769.5 8716.5 8716.5 8771.5 9760 9760 9760 10915.5 9743.5 9743.5 10952 First Reading For Entire File .......... 8716.5 Last Reading For Entire File ........... 10952 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUM~Z~RY PBU TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS .5000 START DEPTH 8993.0 8993 0 8993 0 8999 5 8999 5 8999 5 9035 0 9036.0 9036.0 9036.0 9036.0 STOP DEPTH 9756.5 9756 5 9756 5 9764 5 9764 0 9764 0 9799 5 9800 5 9800 5 9800 5 9800 5 RPX RAT MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 9036.0 9800.5 9064.5 9837.5 MAD RUN NO. MAD PASS NO. 6 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 8993.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 PEF MAD BARN 4 1 68 RHOB MAD G/CC 4 1 68 DRHO MAD G/CC 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHM}4 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHM~ 4 1 68 FET MAD HOUR 4 1 68 GR MAD AAPI 4 1 68 RAT MAD FT/H 4 1 68 NCNT MAD CNTS 4 1 68 FCNT MAD CNTS 4 1 68 NPHI MAD P.U. 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 MERGE BASE 9805.0 Name DEPT PEF RHOB DRHO RPX RPS RPM RPD FET GR RAT NCNT Min 8993 1.1811 1.7549 -0.039 1 3526 1 7411 1 8617 2 6064 7 3193 13 3013 33 4257 692.562 Max Mean Nsam 9837.5 9415.25 1690 7.2441 1.98141 1531 2.9079 2.36873 1530 0.7966 0.157519 1530 33.6652 8.24063 1530 2000 12.1782 1530 2000 14.2139 1530 75.4192 15.5816 1530 110.518 43.007 1530 132.68 37.19 1530 352.452 174.94 1546 1849.9 1218.54 1528 First Reading 8993 8999.5 8999.5 8999.5 9036 9036 9036 9036 9036 9035 9064.5 8997 Last Reading 9837.5 9764.5 9764 9764 9800.5 9800.5 9800.5 9800.5 9800.5 9799.5 9837.5 9760.5 FCNT 7 . 098 66. 969 22 . 1712 1528 NPHI 4 . 89 30.57 17 . 7156 1528 8997 8993 9760.5 9756.5 First Reading For Entire File .......... 8993 Last Reading For Entire File ........... 9837.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8731 5 8760.0 RPD 8738 5 8767.0 RPM 8738 5 8767.0 RPS 8738 5 8767.0 RPX 8738 5 8767.0 ROP 8771 5 8798.5 $ LOG HEADER DATA DATE LOGGED: 28-JA/~-98 SOFTWARE SURFACE SOFTWARE VERSION: 5.07 DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 8798.0 TOP LOG INTERVAL (FT) : 8771.0 BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8798.0 .0 .0 TOOL NUMBER P0882SP4 P0882SP4 6.000 6.0 QUIKDRIL N 8.70 45.0 8.5 30000 7.5 .000 .000 .000 .000 79.4 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHM1M 4 1 68 RPM ]~fWD 1 OHM1M 4 1 68 RPD ]~WD 1 OHM]Vi 4 1 68 ROP MWD 1 FT/H 4 1 68 12 16 20 24 Name Min Max Mean Nsam DEPT 8731.5 8798.5 8765 135 GR 51.6237 210.183 80.0719 58 RPX 0.1596 2000 72.2099 58 RPS 0.4136 2000 286.363 58 RPM 0.1739 2000 424.502 58 RPD 2.841 2000 564.548 58 ROP 1.6291 9.4303 5.66608 55 First Reading 8731.5 8731.5 8738.5 8738.5 8738.5 8738.5 8771.5 Last Reading 8798.5 8760 8767 8767 8767 8767 8798.5 First Reading For Entire File .......... 8731.5 Last Reading For Entire File ........... 8798.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 8716.5 NCNT 8716.5 STOP DEPTH 9277.0 9277.0 NPHI 8716.5 PEF 8740.0 DRHO 8740.0 RHOB 8740.0 GR 8761.0 FET 8768.0 RPD 8768.0 RPM 8768.0 RPS 87 68.0 RPX 8768.0 ROP 8801.0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REA/b-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 9277.0 9293 0 9293 0 9293 0 9136 0 9328 5 9328 5 9328 5 9328 5 9328 5 9174 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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 NUtX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 29-JAN-98 5.07 5.03 MEMORY 9174.0 8798.0 9174.0 7.9 28.7 TOOL NUMBER P0882SP4 P0882SP4 P0882SP4 P0882SP4 6.000 6.0 QUIKDRIL N 8.70 45.0 8.5 30000 7.5 .000 .000 .000 .000 79.4 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RPX MWD 2 OHMM 4 1 68 GR MWD 2 AAPI 4 1 68 ROP MWD 2 FT/H 4 1 68 RHOB MWD 2 G/CC 4 1 68 DRHO MWD 2 G/CC 4 1 68 PEF MWD 2 BARN 4 1 68 RPS MWD 2 OH/~4 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHM~ 4 1 68 FET MWD 2 HOUR 4 1 68 NCNT MWD 2 CNTS 4 1 68 FCNT MWD 2 CNTS 4 1 68 NPHI MWD 2 P.U. 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 8716.5 9328.5 9022.5 1225 RPX 1.353 157.301 13.1375 1122 GR 16.2196 517.358 60.5803 751 ROP 4.6417 986.133 71.323 747 RHOB 2.07 3.0038 2.37094 1107 DRHO -0.179 0.7379 0.154335 1107 PEF 1.1811 14.2896 2.4384 1124 RPS 1.5758 2000 20.0656 1122 RPM 1.5458 2000 23.5663 1122 RPD 1.6944 139.968 24.2509 1122 FET 0.423 94.141 24.9037 1119 NCNT 594.475 2023.59 1193.45 1122 FCNT 3.504 97.511 22.5732 1122 NPHI 4.9 62.91 20.7052 1122 First Reading 8716.5 8768 8761 8801 8740 8740 8731.5 8768 8768 8768 8769.5 8716.5 8716.5 8716.5 Last Reading 9328.5 9328.5 9136 9174 9293 9293 9293 9328.5 9328.5 9328.5 9328.5 9277 9277 9277 First Reading For Entire File .......... 8716.5 Last Reading For Entire File ........... 9328.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 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 Genezation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9134.0 9156.5 ROP 9177.0 9197.0 $ LOG HEADER DATA DATE LOGGED: 31-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: 5.07 DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9198.0 TOP LOG INTERVAL (FT) : 9174.0 BOTTOM LOG INTERVAL (FT) : 9198.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 30.3 MAXIMUM ANGLE: 30.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL G~dV~w_A PROBE TOOL NUMBER PCG 47 BOREHOLE ~D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.000 6.0 QUIKDRIL N 8.70 45.0 8.5 30000 7.5 .000 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 49.5 First Name Min Max Mean Nsam Reading DEPT 9134 9197 9165.5 127 9134 GR 24.9208 28.7378 26.7456 46 9134 ROP 2.4745 22.3594 8.32426 41 9177 Last Reading 9197 9156.5 9197 First Reading For Entire File .......... 9134 Last Reading For Entire File ........... 9197 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Nuraber ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Corament Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9156.5 9333.5 ROP 9196.0 9372.5 $ LOG HEADER DATA DATE LOGGED: 01-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: 5.07 DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9372.0 TOP LOG INTERVAL (FT) : 9198.0 BOTTOM LOG INTERVAL (FT) : 9372.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 30.7 MAXIMUM ANGLE: 75.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 PCG 47 6.000 6.0 QUIKDRIL N 8.70 45.0 8.8 30000 8.0 .000 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 49.5 First Name Min Max Mean Nsam Reading DEPT 9156.5 9372.5 9264.5 433 9156.5 GR 17.7908 114.773 30.4893 355 9156.5 ROP 20.4617 302.653 126.776 354 9196 Last Reading 9372.5 9333.5 9372.5 First Reading For Entire File .......... 9156.5 Last Reading For Entire File ........... 9372.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. 6 .5000 START DEPTH 9277.5 9278.0 9278.0 9293.5 9293.5 9293.5 9322.5 9329.0 9329.0 9329.0 9329.0 9329.0 9366.5 SURFACE SOFTWARE VERSION: STOP DEPTH 9743 5 9743 5 9743 5 9760 0 9760 0 9760 0 9790 0 9797 0 9797 0 9797 0 9797 0 9797 0 9833 0 03-FEB-98 5.07 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STA~BILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 5.03 MEMORY 9832.0 9372.0 9832.0 88.9 95.1 TOOL NUMBER P0882SP4 P0882SP4 P0882SP4 P0882SP4 6.000 6.0 QUIKDRIL N 8.70 46.0 8.6 30000 7.5 .060 · 037 .110 .100 87.2 .6 Datum Specification Block sub-type...0 Name DEPT NCNT FCNT GR RPX RPS RPM RPD ROP FET RHOB DRHO PEF NPHI Service Order Units Size Nsam Rep FT 4 1 68 MWD 6 CNTS 4 1 68 MWD 6 CNTS 4 1 68 MWD 6 AAPI 4 1 68 MWD 6 OHMM 4 1 68 MWD 6 OHMM 4 1 68 MWD 6 OHMM 4 1 68 MWD 6 OHM}4 4 1 68 MWD 6 FT/H 4 1 68 MWD 6 HOUR 4 1 68 MWD 6 G/CC 4 1 68 MWD 6 G/CC 4 1 68 MWD 6 BARN 4 1 68 MWD 6 P.U. 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 l0 40 11 44 12 48 13 52 14 Name DEPT NCNT FCNT GR RPX RPS RPM RPD ROP FET RHOB DRHO PEF NPHI Min 9277.5 623.429 6.836 15 6708 2 6793 5 0345 6 3516 8 0952 6 8066 0 5159 1 4146 -0.144 0.8149 13.28 Max Mean Nsam 9833 9555.25 1112 1595.07 1165.91 932 41.99 19.2291 932 138.044 40.8273 936 31.1596 12.063 937 74.209 15.116 937 543.433 16.8807 937 104.569 17.9039 937 371.147 70.2315 934 35.0905 4.34235 937 2.7805 2.34155 934 0.8257 0.100614 934 6.5166 1.97416 934 38.1 24.0232 933 First Reading 9277.5 9278 9278 9322.5 9329 9329 9329 9329 9366.5 9329 9293.5 9293.5 9293.5 9277.5 Last Reading 9833 9743.5 9743.5 9790 9797 9797 9797 9797 9833 9797 9760 9760 9760 9743.5 First Reading For Entire File .......... 9277.5 Last Reading For Entire File ........... 9833 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9765.5 10614.5 FET 9770.5 10915.5 RPM 9770.5 10621.5 RPS 9770.5 10621.5 RPX 9770.5 10621.5 RPD 9771.0 10621.5 ROP 9807.5 10657.5 $ LOG HEADER DATA DATE LOGGED: 05-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: 5.07 DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10658.0 TOP LOG INTERVAL (FT): 9832.0 BOTTOM LOG INTERVAL (FT): 10658.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.6 MAXIMUM ANGLE: 96.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0882SP4 EWR4 ELECTROMAG. RESIS. 4 P0882SP4 CNP COMPENSATED NEUTRON P0882SP4 SLD STABILIZED LITHO DEN P0882SP4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.000 DRILLER'S CASING DEPTH (FT) : 6.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRIL N MUD DENSITY (LB/G): 8.90 ~fUD VISCOSITY (S : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 48.0 8.8 30000 7.5 .060 .040 .120 .090 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 7 AAPI 4 1 68 RPX MWD 7 OHMM 4 1 68 RPS MWD 7 OHMM 4 1 68 RPM MWD 7 OHMS4 4 1 68 RPD MWD 7 OHMM 4 1 68 ROP MWD 7 FT/H 4 1 68 FET MWD 7 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 65.0 Name Min Max Mean DE?T 9765.5 10657.5 10211.5 GR 14.2596 152.055 36.8508 RPX 5.671 61.694 14.289 RPS 6.695 51.6483 19.9487 RPM 8.1916 215.34 23.6978 RPD 10.9146 110.604 26.7852 ROP 7.7992 592.481 55.6925 FET 0.7461 33.3399 3.78276 Nsam 1785 1699 1703 1703 1703 1702 1701 1703 First Reading 9765.5 9765.5 9770.5 9770.5 9770.5 9771 9807.5 9770.5 Last Reading 10657.5 10614.5 10621.5 10621.5 10621.5 10621.5 10657.5 10621.5 First Reading For Entire File .......... 9765.5 Last Reading For Entire File ........... 10657.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 10607 0 10613 0 10613 0 10613 0 10613 0 10613 0 10650 5 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) : STOP DEPTH 10908.5 10915.5 10915.5 10915.5 10915.5 10915.5 10952.0 06-FEB-98 5.07 5.03 MEMORY 10952.0 10658.0 10952.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 85.0 91.6 TOOL NUMBER P0882SP4 P0882SP4 6.000 6.0 QUIKDRIL N 8.90 48.0 8.8 30000 7.5 .060 .040 .110 .090 65.0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 RPX MWD 8 OHMM 4 1 68 8 3 RPS MWD 8 OHMM 4 1 68 12 4 RPM MWD 8 OHMS4 4 1 68 16 5 RPD MWD 8 OHMM 4 1 68 ROP MWD 8 FT/H 4 1 68 FET MWD 8 HOUR 4 1 68 20 24 28 Name Min Max Mean DEPT 10607 10952 10779.5 GR 15.8147 67.462 26.1079 RPX 4.193 43.9098 14.1661 RPS 7.7161 49.547 18.7854 RPM 10.3782 42.1377 21.582 RPD 13.2901 43.2792 25.3542 ROP 8.9973 951.949 70.4828 FET 0.8637 19.714 3.8453 Nsam 691 604 606 605 605 604 604 606 First Reading 10607 10607 10613 10613.5 10613.5 10614 10650.5 10613 Last Reading 10952 10908.5 10915.5 10915.5 10915.5 10915.5 10952 10915.5 First Reading For Entire File .......... 10607 Last Reading For Entire File ........... 10952 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 8993.0 9756.5 NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8993 0 8993 0 8999 5 8999 5 8999 5 9035 0 9036 0 9036 0 9036 0 9036.0 9036.0 9064.5 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: 9756.5 9756.5 9764.5 9764.0 9764.0 9799.5 9800.5 9800.5 9800.5 9800.5 9800.5 9837.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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 (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MA2K CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 03-FEB-98 5.07 5.03 MEMORY 9832.0 9372.0 9832.0 88.9 95.1 TOOL NUMBER P0882SP4 P0882SP4 P0882SP4 P0882SP4 6.000 6.0 QUIKDRIL N 8.70 46.0 8.6 30000 7.5 .060 · 037 .110 .100 87.2 HOLE CORRECTION IN): TOOL STanDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 NPHI MAD 6 P.U. 4 1 68 NCNT MAD 6 CNTS 4 1 68 FCNT MAD 6 CNTS 4 1 68 GR MAD 6 AAPI 4 1 68 RPX MAD 6 OHMS4 4 1 68 RPS MAD 6 OHMM 4 1 68 RPM MAD 6 OHMM 4 1 68 RPD MAD 6 OHMM 4 1 68 RHOB MAD 6 G/CC 4 1 68 DRHO MAD 6 G/CC 4 1 68 PEF MAD 6 BARN 4 1 68 FET MAD 6 HOUR 4 1 68 RAT MAD 6 FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT NPHI NCNT FCNT GR RPX RPS RPM RPD RHOB DRHO PEF FET RAT Min 8993 4.89 692.562 7.098 13 3013 1 3526 1 7411 1 8617 2 6064 1 7549 -0.039 1.1811 7.3193 33.4257 Max Mean 9837.5 9415.25 30.57 17.7156 1849.9 1218.54 66.969 22.1712 132.68 37.19 33.6652 8.24063 2000 12.1782 2000 14.2139 75.4192 15.5816 2.9079 2.36873 0.7966 0.157519 7.2441 1.98141 110.518 43.007 352.452 174.94 Nsam 1690 1528 1528 1528 1530 1530 1530 1530 1530 1530 1530 1531 1530 1546 First Reading 8993 8993 8997 8997 9035 9036 9036 9036 9036 89'99.5 8999.5 8999.5 9036 9064.5 Last Reading 9837.5 9756.5 9760.5 9760.5 9799.5 9800.5 9800.5 9800.5 9800.5 9764 9764 9764.5 9800.5 9837.5 First Reading For Entire File .......... 8993 Last Reading For Entire File ........... 9837.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/03/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/03/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown_ Pull tubing _ 1. Operations performed: CIBP / ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 446' FNL, 947' FEL, Sec. 16, T11N, R13E, UM At top of productive interval 913' FNL, 5101' FEL, Sec. 15, T11N, R13E, UM At effective depth 683' FNL, 28' FEL, Sec. 16, T1 IN, R13E, UM At total depth 4939' FNL, 1004' FEL, Sec. 09, T11N, R13E, UM Stimulate _ Plugging _ Perforate _X Alter casing _ Repair well _ Other_X CIBP 5. Type of Well: 6. Datum ~l'evation (DF or KB feet) Development __X RKB 70 feet Exploratory__ 7. Unit or Property name Stratigraphic__ Service__ (asp's 643511, 5965626) (asp's 644646, 5965180) (asp's 644434, 5965406) (asp's 643437, 5966411) Prudhoe Bay Unit 8. Well number Q-03A 9. Permit number / approval number 197-254 10. APl number 50-029-20322-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10950 feet Plugs (measured) 9018 feet CIBP set @ 9525' (03/25/2002). CIBP set @ 10215' (04/20/1998). Effective depth' measured 9525 feet Junk (measured) true vertical 9037 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor I40' 20" 650 sx PF II (Approx) 170' 170' Surface 2646' 13-3/8" 3448 sx ArcticSet II 2676' 2673' Intermediate 6137' 9-5/8" 990 sx Class 'G', 430 sx 2395'- 8532' 2394'- 8319' ArcticSet I Liner 738' 7" 340 sx Class 'G' 8004'- 8742' 7792'- 8529' Tieback Liner 2518' 9-5/8" x 7-5/8" 295 sx ColdSet III, 350 22'- 2540' 22'- 2538' sx ColdSet II Sidetrack Liner 2353' 4-1/2" 277 sx Class 'G' 8597' - 10950' 8384' - 9016' Perforation depth: measured Open Perfs 9317'-9332', Open Perfs below CIBP 9700'-9840', 9920'-10110', 10170'-10190', Open Perfs below CIBP 10300' - 10420', 10490' - 10590', 10670' - 10720', 10780' - 10850' Tubing (size, grade, and measured depth) true vertical Open Perfs 9025'-9030', Open Perfs below CIBP 9023'-9019', 9024'-9021 ', 9015'-9013' Open Perfs below CIBP 9006' - 9006', 9004'- 8999', 8999'- 9003', 9008'- 9011' 4-1/2", 12.6#, L-8O, Tubing @ 8547'. 4-1/2" Tubing Tail @ 8603R E C E ~ V E D 7"x 4-1/2" Baker S-3 Packer @ 8547'. 4-1/2" HES HXO SLVN Nipple @ 1978'. ,.jl.;.~ !.~'r".~,~ ~,d /.~" ~'_" u '*"~ ~!2 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Packers & SSSV (type & measured depth) Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 16. Status of well classification as' Prior to well operation Well Shut-In Subsequent to operation Well Shut-In 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ Oil _X Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~¢~~.~..~ ~~_~_~~ Title: Techical Assistant DeWayne R. Schnorr Suspended Service Date May 21,2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLiCATE-'""~-~ Q-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/20/2002 PACKERS / BRIDGE PLUGS' DRIFT/TAG 03/23/2002 PACKERS / BRIDGE PLUGS' CAST IRON BRIDGE PLUG; PERFORATING 03/24/2002 PACKERS / BRIDGE PLUGS' CAST IRON BRIDGE PLUG; PERFORATING EVENT SUMMARY 03/2O/02 DRIFT 3.70" SWAGE TO 9308' SLM (STOP DUE TO DEVIATION - HAW). ****LEFT WELL SHUT IN**** 03/23/02 MIRU CTU #3, RIH W/WFD MHA, 3-5/8" WT BAR & 3.5" NZL FOR DRIFT. O3/24/02 DRIFT TO 9550' CTMD. POOH. RIH W/BAKER 4.5" MODEL "K-I" CIBP. SET CIBP AT 9525' CTMD, TAG TO CONFIRM. POOH. RIH W/15' 3-3/8" PERF GUN (PJ3406 HMX CHARGES, 6 SPF, 60 DEG PHASE, RANDOM ORIENT), REALTIME CCL. RIH AND TAG CIBP AT 9522' CTM. ATTEMPT TO LOG UP W/CCL TOOL. COULD NOT GET TOOL TO FUNCTION. POOH. C/O CCL TOOLS AND RBIH. 2ND TOOL FUNCTIONED OK. TIE IN. SHOT 3-3/8" GUN FROM 9317-9332' MD. POOH. ***LEFT WELL FP W/DIESEL AND SI. NOTIFIED PAD OP OK TO POP AFTER SAFE OUT COMPLETE*** FLUIDS PUMPED BBLS , 17 60/40 METHANOL WATER 16 1% KCL WATER 33 TOTAL ..... ADD PERFS 03/24/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 3-3/8" PJ 6SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 9317'- 9332' Page I
